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Home My WebLink About182-071 WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital information available for this individual Well History file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. /~;J tJ7/wen History File # Digital Data Added to LaserFiche File CD's - # Yes No Yes No Yes No DVD's - # Diskettes - # Oversized Material Added to LaserFiche File Maps # Yes No Yes No Yes No Mud Logs # - Other # General Notes or Comments about this file. If any of the information listed above is not available in the LaserFiche file, or if you have any questions or information requests regarding this file, you may contact the Alaska Oil & Gas Conservation Commission to request copies at 279-1433, or email us at: AOGCC - Librarian@admin.state.ak.us ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION . "f) WELL COMPLETION OR RECOMPLETION REPORT AN~E\\lEl j\ \N 1 4 1GG4 1b. Well Class:.., í'ü>,;w:Ù:i$\O!\ Ja\~VèWþ~¥1t' v . 0 Exploratory Ma~ \{i1(j Str~~iØJ,",est 0 Service 12. Permit to Drill Number 182-071 304-042 13. API Number 50- 029-20744-00-00 14. Well Name and Number: PBU 02-24 15. Field 1 Pool(s): Prudhoe Bay Field 1 Prudhoe Bay Pool No. of Completions 1a. Well Status: 0 Oil 0 Gas 0 Plugged 1m Abandoned 0 Suspended 0 WAG 20AAC25.105 20AAC25.110 21. Logs Run: DIL 1 SP 1 BHCS 1 GR, FDC 1 CNL 1 GR 1 CAL, CBL, Memory Caliper 1 GR CASING, LINER AND CEMENTING RECORD SETTING DEPTHMD SETTING DEPTHTVD HOLE lOP BOTTOM lOP BOTTOM SIZE Surface 79' Surface 79' 36" Surface 2593' Surface 2593' 17-1/2" L-80/SOD-95 Surface 9692' Surface 8461' 12-1/4" 9398' 10512' 8203' 9192' 8-1/2" 9770' 10261' 8529' 8966' N/A 26. Date First Production: Not on Production Date of Test Hours Tested PRODUCTION FOR TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED .. Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". 0 GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1799' SNL, 36' EWL, SEC. 36, T11 N, R14E, UM Top of Productive Horizon: 5124' SNL, 1835' WEL, SEC. 35, T11 N, R14E, UM Total Depth: 90' SNL, 2021' WEL, SEC. 02, T10N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 686809 y- 5949381 Zone- ASP4 TPI: x- 685023 y- 5946012 Zone- ASP4 Total Depth: x- 684843 y- 5945762 Zone- ASP4 18. Directional Survey 0 Yes 1m No 22. CASING SIZE 20" 13-3/8" 9-518" WT. PER FT. 91.5# 72# 47# 29# 9.3# GRADE H-40 L-80 L-80 L-80 7" 3-1/2" 23. Perforations open to Production (MD + TVD of To,e and Bottom Interval, Size and Number; if none, state' none"): None MD TVD MD TUBING RECORD SIZE DEPTH SET (MD) 5-1/2", 17#, L-80 9373' 4-1/2", 12.6#, N-80 9447' 25. ACID, FRACTURE, CEMI;NT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9709' Set Whipstock .../" 9713' P&A with 26 Bbls Class 'G', Sqzd to 1400 psi / Zero Other 5. Date Comp., Susp., or Aband. 5/7/2004 6. Date Spudded 05123/1982 7. Date T.D. Reached 06/05/1982 8. KB Elevation (ft): 64' 9. Plug Back Depth (MD+ TVD) 10471 + 9155 10. Total Depth (MD+TVD) 10515 + 9195 11. Depth where SSSV set NIA MD 19. Water depth, if offshore N/A MSL 24. TVD PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): NIA OIL-Bel GAs-McF WATER-BBl OIL-Bel None Form 10-407 Revised 12/2003 GAs-McF WATER-BBl ORIGINAL CONTINUED ON REVERSE SIDE Ft Ft 16. Property Designation: ADL 028308 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) CEMENTING RECORD 415 sx Arcticset II 2700 sx Fondu, 400 sx Permafrost 'C' 500 sx Class 'G', 300 sx PF 'C' 360 sx Class 'G' Scab Liner AMOUNT PUllED PACKER SET (MD) 9361' \~~ ¡,\~"\ CHOKE SIZE I GAS-Oil RATIO Oil GRAVITY-API (CORR) ReDUS 8ft Ø"lt611M ~f ~ 28. GEOLOGIC MARKERS NAME MD TVD Sag River 9703' 8470' Shublik 9742' 8505' Sadlerochit 9826' 8579' GIO Contact 10042' 8770' O/W Contact 10375' 9068' Base Sadlerochit 10416' 9105' ~ 29. FORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None -"") \ ¡. " Rr::.. r:E.. ~\J t::t ~v j\JN 1 41~~4 rn9 fI¡\,,"ka IJIII ,:1. .. C. 'Pi:! < .,n.' ..-- ¡h¡!'\¡'j{"','" ",oNI ... 30. List of Attachments: Summary of Pre-Rig Summary and Daily Drilling Reports 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~.N\J ' tV 1 M-(g Title Technical Assistant Date Oco.. { 0 -Öl.{ PBU 02-24 182-071 304-042 Prepared By Name/Number: Terrie Hubble, 564-4628 W II N b Drilling Engineer: 7ihomas McCarty 564 4378 e um er Permit No.1 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 8: ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection. Gas Injection, Shut-In. or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ~. ~ Well: Field: API: Permit: 02-24A Prudhoe Bay Unit 50-029-20744-01-00 204-030 Accept: Spud: Release: Rig: 05/04/04 05/09/04 05/15/04 Nordic #1 PRE-RIG WORK 04/04/04 TAG TD @ 10273' SLM W/2.800" CENT & SB. LEFT WELL SI. OBJECTIVE: TO CUT 3.5" LINER ABOVE CEMENT TOP. RAN 2 5/8" CHC WITH THREE CENTRALIZERS, ONE WEIGHT BAR, JARS, CCL, AND SAFE SYSTEM. GOOD SHOT INDICATION. SHOT STRING SHOT FROM 9850'-9862', CHC AT 9860' AS PER PROGRAM. PULLED CLEAN AFTER SHOOTING. SEVERING HEAD LOOKS LIKE CLEAN CUT. MISSING TWO CENTRALIZER ARMS FROM 1 FOOT ABOVE THE HEAD, ALL REMAINING ARMS ABOVE AND BELOW HEAD ARE DAMAGED FROM CHEMICAL. MISSING ARMS ARE 1 FOOT LONG, 1/2" WIDE AND .125" THICK. GAVE ONE OF THE REMAINING CENTRALIZER ARMS TO THE WELLS GROUP FOR FUTURE REFERENCE IF FISHING IS REQUIRED. 04/05/04 RAN 5.5", 4.5", 3.5" BB W/GR. TUBING CLEAR TO 9700' SLM. RECOVERED ONE BOW-SPRING. 04/13/04 RIH WITH BAKER 4" G SPEAR. LATCH LINER AT 9419' CTMD, HIT ONE JAR AT 6K OVER, PULLED STRAIGHT PULL TO 31.4K AND POP'ED OUT OF FN. UNABLE TO LATCH BACK UP, POOH. RIH WITH 4.5" WL SUPER GS WI 4.5" BAIT SUB. HIT 5 JAR LICKS PULL UP TO 35 K BUT LINER DID NOT MOVE. 04/14/04 COULD NOT RELEASE FROM LINER, JAR DID NOT WORK. PUMP OFF GS & POOH. RIH WITH BHA # 3 (NEW JAR) EOL = 13.81'. HIT 12 JARS LICKS AT -6K OVER THEN STRAIGHT PULL 31K. LINER DID NOT MOVE. UNABLE TO RETRIEVE BAIT SUB, PUMPED OFF & POOH. RIG DOWN. 04/15/04 RUN 4 112" GR PULLING TOOL TO 9411' SLM TO PULL 41/2" SUPER GS. SHEARED PIN. UNABLE TO PULL. RIH W/4 1/2" GR PULLING TOOL AND PULL 41/2" SUPER GS. DRIFT OUT EOT WI 2.80" CENT & TAG BTM @ 10,290' WLM. WELL SHUT IN UPON DEPARTURE. 04/19/04 CHEMICAL CUT SCAB LINER AT 9841' MD (REF. SCMT LOG DATED 10-NOV-03). RAN 1-STRAND STRINGSHOT PRIOR TO CUT. GOOD INDICATION OF CUT. DID NOT TAG TD. NO PROBLEMS RIH OR POOH. LEFT WELL SHUT IN. 04/20/04 SET RELEASABLE SPEAR IN TOL @ 9408' SLM. UPPER FN=4-1/2" G, INTERNAL FN=3-1/2" G, 31" OAL. WELL LEFT S/I, NOTIFY DSO OF STATUS. 04/21/04 RIH WITH 4" BAKER GS. POOH. SWAP TO 3" BAKER GS. RIH. ENGAGE RELEASEABLE SPEAR / LINER, ATTEMPT TO PULL, MAX OVERPULL 20 KLBS. NO SUCCESS, RELEASE FROM SPEAR 1 LINER AND POOH. RELEASEABLE SPEAR LEFT ON LINER TOP (3-112" GINNER, 4-112" G UPPER.) WELL LEFT SHUT IN. RDMO. 04/22/04 DRIVE CORE DOWN ON RELEASABLE SPEAR WI 3.5 GS. PULL SPEAR WI 4.5 GS FROM 9435 MD, 9416 SLM. WELL LEFT SHUT IN. ~ ~ 02-24A Pre-Rig CTD Sidetrack Page 2 04/23/04 SHOT 12' X 1 STRAND STRING SHOT FROM 9759'-9771'. RAN IN HOLE WITH (25/8") 2.62" CHC, SET DOWN IN LINER TOP AT 9400'. COULD NOT WORK PAST 9400', PULLED OUT OF HOLE TO INSPECT CUTTER. FOUND SHARP MECHANICAL MARKS IN COPPER SEVERING HEAD, PE MADE DECISION TO RD AND POSSIBLY CALL SLlCKLINE TO SWEDGE WELL. PE HAS SEVERING HEAD FOR INSPECTION. DRIFT WI 2.50 TAPERED SWEDGE, 2' X 1 7/8" STEM, 3.80 CENTRALIZER TOP OF LINER. (9409' SLM). 04/24/04 DRIFT SCAB LINER WI 2.755 SWEDGE FOR OBSTRUCTION, LIGHT RESISTANCE @ 9415'. STOP @ 9835' SLMD. DRIFT WI 2.88 TAPERED SWEDGE, DRIFT THROUGH TIGHT SPOT (9415') WI NO PROBLEM, STOPPED @ 9838' SLM. RDMO. RIH WITH 2.625" CHC TO CUT SCAB LINER AT 9770'. RAN THREE CENTRALIZERS ON CHC, TWO 1 11/16" CHEM TUBES, 11" GAS GRAIN, SHOT AT 28 DEG DEV IN KCL WATER. CHEM CUTTER HUNG IN OLD CUT AT 9840', JARRED FREE. DID NOT HAVE ANY PROBLEMS ENTERING LINER TOP. SEVERING HEAD INDICATES GOOD CUT. NOTHING LEFT IN HOLE. 04/25/04 SET RELEASABLE SPEAR IN LINER TOP (9413' SLM). (32" OAL, 31/2" G INTERNAL FN, 41/2" G UPPER FN). 04/26/04 CATCH AND RELEASE 3-1/2 SCAB LINER: MIRU CTU #4. RIH WITH BOT 3" HYDRAULIC GS. TAG LINER TOP AT 9411' CTM. CATCH RELEASEABLE SPEAR AND LINER. ATTEMPT STRAIGHT PULLS TO 25 KLBS OVER STRING WT. NO MOVEMENT. HIT 39 JAR LICKS WITH 8-12 KLBS OVERPULL. NO MOVEMENT. INCREASE JAR LICKS TO 16 KLBS OVER PULL. NO MOVEMENT AFTER 4 JAR LICKS. INCREASE JAR LICK TO 24 KLB OVER PULL, LINER CAME FREE. PULL UP HOLE 100', PULLING WT IS 2-3 KLBS HEAVY - LINER CUT WAS SUCCESSFUL AND CAN BE PULLED BY CTD. RBIH AND SET LINER DN, TOP OF SPEAR I LINER AT 9409' CTM. PUMP DOWN COIL AND RELEASE FROM LINER; PULLING WT CONFIRMS LINER RELEASED. POOH. WELL LEFT SHUT IN. 4-1/2" X 3-1/2" RELEASEABLE SPEAR STILL ENGAGED IN SCAB LINER TOP, DRAWING IS IN WELL FILE. RDMO. 05/02/04 TIO= ?/55010. WELL SI. BLEED IA. (PREP FOR RWO). NO SCAFFOLDING CAN NOT GET TBG PRESSURE. INITIAL IA FL @ 330' (15 BBLS). BLED IA FROM 550 PSI TO 250 PSI IN 45 MIN GOT GAS AND FLUID MIX AT 250 PSI. FINAL WHP'S ?/25010. 05/03/04 T/l/O=520/45010+. TEMP=SI. BLEED lAP. (PREP FOR RIG). IA FL NEAR SURFACE. BLED lAP FROM 450 PSI TO 40 PSI IN 3.5 HRS. MONITORED FOR 15 MIN, lAP INCREASED 30 PSI. FINAL WHP'S=52017010+. **OA HAS BULLET STYLE PLUG (3"X3/4" NPT). WELL HOUSE, SCAFFOLDING, FIL, AND AIL LINE RIGGED DOWN. TIO=6501010 WELL KILL (PREP CTD) PUMP 45 BBLS 60/40 METH-WATER, 45 BBLS CRUDE, 299 BBLS C- WATER TO KNOCK DOWN WELL PRESSURE FOR UPCOMING CTD WORK, CAP W/60 BBLS DIESEL FREEZE PROTECT FINAL WHP'S=60/150/80. ~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-24 02-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/24/2004 Rig Release: 5/15/2004 Rig Number: N1 Spud Date: 5/23/1982 End: 5/4/2004 11:00-11:15 0.25 MOB P PRE Rig released from 02-29C @ 11 :OOHrs on 5/4/2004. Prep to move rig off well. 11:15 -11:30 0.25 MOB P PRE PJSM for moving rig off well. 11 :30 - 11 :45 0.25 MOB P PRE Pull rig off well. Clean up location & conduct post operations pad inspection. 11 :45 - 12:00 0.25 MOB P PRE Held pre-move safety meeting. 12:00 - 12:30 0.50 MOB P PRE Move rig from 02-29C to 02-24. Conduct pre-operations pad inspection. 12:30 - 12:45 0.25 MOB P PRE PJSM. Review procedure, hazards & mitigation for backing rig over well. 12:45 - 13:00 0.25 MOB P PRE Back rig over well & set down. ACCEPT RIG @ 13:00 HRS ON 05/04/2004. 13:00 - 18:30 5.50 RIGU P PRE PJSM with Peak crew on CT reel swap: P/U & lower reel to Peak double drop trailer. Replace reel drive plates. Meanwhile rebuild HCR valve. 18:30 - 22:00 3.50 RIGU P PRE Crew change & PJSM with Peak crew on CT reel swap. P/U replacement reel into reel house & align drive pins & bushing. R/U hardline to inner reel valve. Meanwhile changeout inside kill valve. 22:00 - 00:00 2.00 RIGU P PRE PJSM. N/U BOPE & C/O BOP inserts for 2-3/8" CT. Grease BOP valves. Spot trailers & tanks. 5/5/2004 00:00 - 07:00 7.00 BOPSUF P PRE Perform initial BOPE function/pressure test. AOGCC test witness waived by Jeff Jones. HCR failed PT. Rebuild HCR & retest OK. Meanwhile C/O hydraulic filters on injector & C/O injector gripper blocks. 07:00 - 12:30 5.50 RIGU P PRE C/O injecter head gripper blocks from 2" to 2-3/8". General rig maintenance 12:30 - 13:30 1.00 RIGU P PRE Grease injecter head. General rig maintenance. 13:30 - 15:30 2.00 RIGU P PRE Install 2-3/8" internal slips pull guide on CT. Pick up injecter head. Start to rig up guide arch. 15:30 - 19:30 4.00 RIGU N RREP PRE Found broken 1" bolt on center support beam swivel bushing of guide arch. One of three support beams. Had to remove both outer swivel bushings to access center one. Replace broken 1" bolt. M/U support beams & P/U guide arch. 19:30 - 20:00 0.50 RIGU P PRE M/U guide arch to injector & R/U to stab CT. 20:00 - 20:15 0.25 RIGU P PRE Held PJSM & HA/HM for stabbing CT. 20:15 - 21:15 1.00 RIGU P PRE Slip grapple into CT & pull test. Pull CT over pipe shed with winch & stab into injector. 21:15 - 21:30 0.25 RIGU P PRE R/U hydraulic cutter for cutting CT. 21:30 - 21:45 0.25 RIGU P PRE Held PJSM & HA/HM for cutting CT. Review recent lessons learned from recordable injury during CT cutting operations @ Sajaa. 21 :45 - 00:00 2.25 RIGU P PRE Cut 2949' of 2-3/8" CT. Have 15630' of CT remaining on reel. 5/6/2004 00:00 - 00:45 0.75 PULL P DECOMP Install Baker dimple CTC. Pull test to 35k - OK. Install dart catcher. 00:45 - 01 :00 0.25 PULL P DECOMP Open up well & observe Opsi WHP (well on vac). lAP = 75psi, OAP = 2psi. 01 :00 - 02:00 1.00 PULL P DECOMP Pump 5bbls 1% KCL water. Shut inner reel valve & P/test hardline in reel house to 4000psi - OK. Load wiper dart. Launch & chase with 1 % KCL. Dart hit @ 58.1 bbls. P/test inner reel valve & CTC to 3500psi - OK. 02:00 - 02:15 0.25 PULL P DECOMP M/U liner retrieval BHA # 1 with Baker 3" GS spear, up only jar & MHA (OAL - 17.22'). Stab injector on well. Printed: 5/17/2004 8:26:17 AM ~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-24 02-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/24/2004 Rig Release: 5/15/2004 Rig Number: N1 Spud Date: 5/23/1982 End: 5/612004 02:15 - 02:35 0.33 PULL P DECOMP 02:35 - 04:25 1.83 PULL P DECOMP 04:25 - 05:50 1.42 PULL P DECOMP 05:50 - 07:00 1.17 PULL N WAIT DECOMP 07:00 - 07:45 0.75 PULL P DECOMP 07:45 - 08:15 0.50 PULL P DECOMP 08:15-11:00 2.75 PULL P DECOMP 11:00-11:15 0.25 PULL P DECOMP 11:15 -12:15 1.00 PULL P DECOMP 12:15 - 12:45 0.50 CLEAN P DECOMP 12:45 - 14:15 1.50 CLEAN P DECOMP 14:15 - 16:00 1.75 CLEAN P DECOMP 16:00 - 16:50 0.83 CLEAN P DECOMP 16:50 - 18:40 1.83 CLEAN P DECOMP 18:40 - 19:00 0.33 CLEAN P DECOMP 19:00 - 19:15 0.25 CLEAN P DECOMP 19:15 - 19:45 0.50 CLEAN P DECOMP 19:45 - 20:15 0.50 CLEAN P DECOMP 20:15 - 22:00 1.75 CLEAN P DECOMP 22:00 - 22:15 0.25 CLEAN P DECOMP 22:15 - 22:20 0.08 CLEAN P DECOMP 22:20 - 23:15 0.92 CLEAN P DECOMP RIH with BHA #1 taking FP contaminant fluid to tigger tank. RIH BHA #1 to 8000'. Up wt check = 32k, Down Wt = 19k. Continue RIH BHA#1 to 9000'. Circulate out FP contaminant fluid @ 2.0/1.6bpm & 2560psi. W.O Fluid. Truck delayed due to a spill @ loading plant. Circulate out FP contaminant fluid @ 1.9 1 1.5 bpm & 2400 psi. Take returns to tiger tank. RIH to 9350 ft. Up wt = 39K, RIH circ 1.0 bpm, Tag fish at 9419 ft. Stop pump. Pick up to 46K, then up to 51 K, hold wt. fish not free. Pick up to 60 K, hold wt, fish not free. Pick up to 65K, hold steady wt. Set down wt to 25K and pick up to 60K. Not free. Set down to 25K and pick up to 60K. Up depth = 9408.7 ft. Fish pulled free at 70K up wt. Did not jar. POH with fish. Fill well across the top. 46 K up wt with fish. SAFETY MEETING. Review procedure, hazards and mitigation for laying out 3-1/2" tubing. Layout fishing BHA and 11-2/3 jts, 10' pup and 2, 2 ft pups of 3-112", FL4S tubing MIU left hand thread 3.80" milling BHA to mill out 4-1/2" DB-5 LDC Nipple at 9435'. BHA = 18.9 ft. RIH with milling BHA. All connections up to CTC are left hand thread. Up wt at 9380 ft = 41 K. Tag 4-1/2" DB nipple at 9399 ft. Milling on 3.687" nipple with 3.80" diamond mill at 9399', 2.61 2.2 bpm, 2150 psi, 500# was. Milled out of nipple at 9340.5 ft. milled down to 9405 ft. Back ream. OK. Ream up and down 3 times. RIH dry OK. Mill down in 7" liner to cleanout to top of 3-1/2" liner top. 2.51 2.2 bpm, 2100 psi. Tag top of 3-1/2" liner at 9772' CTD. Pick up 20 ft off of fish and flag coil. Back ream to 9440 ft and ream to top of fish again to cleanout liner. POH while circ. at 2.6 bpm to chase any fill out of the hole. Still have a fluid loss of 0.3 bpm. DOH. PJSM. UD milling BHA #2. Held PJSM & HA/HM for reheading CT & MIU under-reaming BHA#3. Cut CT & install Baker slip CTC. Pull test to 35k - OK. MIU under-reaming BHA #3 with 3-5/8" DB under-reamer, Baker Xtreme motor, up only jar & MHA (OAL - 27.44'). Stab injector on well. RIH with under-reaming BHA #3 without pumping. RIH BHA #3 to 9300'. Up wt check = 39.9k, Down Wt = 19k. Continue RIH BHA#3 to CT flag @ 9775'. Correct CTD to 9762'. PUH to 9500'. Up wt = 42.4k. Bring on pumps to 1.0bpm/550psi. Creep in hole from 9500' to 9510' with 1.55/1.10bpm, 1030psi & 0.8fpm. Observe no motor work. Bring up pumps & establish freespin @ 2.90bpm/2500psi. Under-ream down from 9510' to 9762' with bio-KCL water @ 2.90/2.41bpm, 2500psi & 3.5fpm. Observe no motor work. PUH to 9680'. Printed: 5/17/2004 8:26:17 AM ",-....., /"""'" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-24 02-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/24/2004 Rig Release: 5/15/2004 Rig Number: N1 Spud Date: 5/23/1982 End: 5/6/2004 23:15 - 00:00 0.75 CLEAN P DECOMP Under-ream down/up 3x from 9680' to 9740' @ 2.85/2.53bpm, 2350psi & 7.5fpm. 5nt2004 00:00 - 00:20 0.33 CLEAN P DECOMP Under-ream down/up 1x from 9680' to 9740' @ 2.85/2.53bpm, 2350psi & 7.5fpm. 00:20 - 00:40 0.33 CLEAN P DECOMP Under-ream up from 9740' to 9500' @ 2.85/2.53bpm, 2350psi & 12.5fpm. Bleed off CAP from 680psi to 70psi. 00:40 - 02:35 1.92 CLEAN P DECOMP POOH with under-reaming BHA #3 pumping across the wellhead. 02:35 - 03:00 0.42 CLEAN P DECOMP COHo PJSM. UD under-reaming BHA #3. 03:00 - 03:15 0.25 EV AL P DECOMP PJSM for P/U & RIH GR/CCUCaliper logging tools. 03:15 - 03:30 0.25 EVAL P DECOMP P/U tool into rig floor. Initialize & test logging tools. Program logging tool caliper arms to open up by 06:45AM. 03:30 - 04:05 0.58 EVAL P DECOMP M/U logging BHA #4 with PDS MGR/CCUCaliper logging tool, xes & MHA. M/U injector. 04:05 - 05:50 1.75 EVAL P DECOMP RIH logging BHA #4 to CT flag @ 9783'. Correct CTD to 9763'. Continue RIH to 9770'. 05:50 - 06:55 1.08 EVAL P DECOMP W.O. logging tool caliper arms to open up. 06:55 - 07:30 0.58 EV AL P DECOMP Log up with PDS Memory Caliper/GR from 9770 - 9250 ft at 40 fpm. 07:30 - 09:00 1.50 EVAL P DECOMP POH with Caliper BHA. 09:00 - 09:15 0.25 EVAL P DECOMP SAFETY MEETING. Review procedure, hazards and mitigation for laying out PDS caliper BHA. 09:15 - 10:00 0.75 EVAL P DECOMP UO BHA. Download PDS Caliper Data. Good Data. 10:00 - 10:15 0.25 WHIP P WEXIT Install 2 SWS RA Tags in Baker Gen 2 Retrievable 3.625" Whipstock [10.0' top whipstock to RA tag]. 10:15 - 10:30 0.25 WHIP P WEXIT SAFETY MEETING. Review procedure, hazards and mitigation for M/U of Baker whipstock and Sperry MWD tools. 10:30 - 12:00 1.50 WHIP P WEXIT M/U Baker whipstock, setting tool, Sperry MWD, Orienter and MHA. OAL=71.23'. 12:00 - 13:30 1.50 WHIP P WEXIT RIH with BKR Whipstock BHA. SHT Sperry tools and orienter. Trouble getting a steady pulse signal from Sperry tools. Try different pump rates and switch pumps. Got good signal, Could not orient. 0 of 6 clicks. 13:30 - 14:30 1.00 WHIP N DFAL WEXIT POH for different orienter. 14:30 - 15:00 0.50 WHIP N DFAL WEXIT C/O orienter, test orienter at surface. OK, 2 of 2 clicks. 15:00 - 16:00 1.00 WHIP N DFAL WEXIT RIH with BKR Whipstock BHA to 4000 ft. SHT Sperry tools OK. 16:00 - 17:20 1.33 WHIP P WEXIT RIH at 70 fpm to 9710 ft. 17:20 - 18:00 0.67 WHIP P WEXIT Orient TF to 29L. 18:00 - 19:00 1.00 WHIP P WEXIT Log down from 9710 ft top of whipstock depth. Tie-in with BHCS/GR of 6/05/1982 with GR. Correct -24 ft CTD. 19:00 - 21 :00 2.00 WHIP N DFAL WEXIT Pick up to 9700'. RIH and position top of Whipstock at 9710 ft. TF = 29L. Circ. at 3.35 bpm, 4900 psi for 2 min. Drop pump to 0 bpm. Wait 2 min. Bring back pumps to 0.75/0.35bpm & 500psi - still getting returns which indicates that pins have not sheared and/or setting mandrel has not retracted back. Repeat process 4x without luck. TF index from 29L to 33R. 21:00 - 21:20 0.33 WHIP N DFAL WEXIT Reorient TF to 29L. Need about 1830psi pressure drop to shear pins. Mix/pump down 2ppb biozan pill to obtain enough pressure drop across shear pins. 21 :20 - 22:25 1.08 WHIP N DFAL WEXIT Pump biozan pill thru the BHA @ 3.40/3.05bpm & 4800psi. Surge pressure 3x from 2800psi to 4800psi. Drop pump & wait Printed: 5/17/2004 8:26:17 AM ~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-24 02-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/24/2004 Rig Release: 5/15/2004 Rig Number: N1 Spud Date: 5/23/1982 End: 51712004 1.08 WHIP N DFAL WEXIT 21 :20 - 22:25 22:25 - 00:00 N DFAL WEXIT 1.58 WHIP 5/8/2004 DFAL WEXIT 00:00 - 01 :45 1.75 WHIP N 01 :45 - 02:00 0.25 WHIP N DFAL WEXIT 02:00 - 02:45 0.75 WHIP N DFAL WEXIT 02:45 - 04:15 1.50 WHIP N DFAL WEXIT 04:15 - 05:45 1.50 WHIP N DFAL WEXIT 05:45 - 06:00 0.25 WHIP N DFAL WEXIT 06:00 - 06:25 0.42 WHIP P WEXIT 06:25 - 07:30 1.08 WHIP P WEXIT 07:30 - 08:00 0.50 WHIP P WEXIT 08:00 - 08:15 0.25 ZONISO P WEXIT 08:15 - 08:40 0.42 ZONISO P WEXIT 08:40 - 10:10 1.50 ZONISO P WEXIT 10:10 - 10:20 0.17 ZONISO P WEXIT 10:20 - 10:55 0.58 ZONISO P WEXIT 10:55 - 11 :45 0.83 ZONISO P WEXIT L I 5 mins. Pump 5bbls @ 2bpm via the back side to fill hole & see if setting mandrel can be retracted. Bring on pumps to 0.75/0.35bpm & 400psi - still getting returns. Discuss with ANC & decide to set W/S by Eline. Call for SWS Eline unit. Paint EOP flag @ 9600' & POOH whipstock BHA#5 pumping across the wellhead. DOH. PJSM. UD W/S setting BHA. Observe that FAIV was not sheared, but shear pins were partially loaded due to not enough pressure drop across the two 1/4" orifices - suspect the additional MWD equalizer jet (5/32") could have reduced the pressure drop to 1540psi < the required 1830psi. Was able to shear pins @ BTT shop with 1600psi. Held PJSM with Baker & SWS logging crews on whipstock setting job. R/U SWS E-line unit. Calibrate E-line p~s tool to HS & arm. Align/orient wt bars to 15degs LOLS & M/U to whipstock. CCL to TOWS = 23.75'. RIH with P~S tool, weight bars, setting tool, & Baker Gen II 4-1/2" x 7" whipstock. Gently tag top of cut 3-1/2" 1m @ 9775' ELM. P/U wt @ 938Q' = 3.7k. Log up hole to 9300' ELM. Tie-into SWS BCS/Ç3Rlog of 6/8/82. Subtract 10' from ELMD. RBIH to 9750' ELM. Log back up to CCL depth of 9686.2' (TOWS @ 9710' ELM). Set W/S,~ith good wt loss indication & tray orientation of 9 ---- degs LOHS. Log off, tag W/S, log off again & confirmed W/S setting depth. POOH Eline & W/S setting tools. UO SWS ÊLinetools and rig down SWS. SAFETY MEETING. Review procedure, hazards and mitigation for M/U of Cementing BHA. M/U Cementing BHA. 'Big hole nozzle, 1 jt 2-3/8" PH6, Hyd Disc, XO and CTC. OAL = 36 . RIH with Cementing BHA. R/U SWS cementing unit. Tag Whipstock pinch point at 9730 ft. Correct CTD to 9714 ft. ~ Pick up 10 ft and flag CT SAFETY MEETING. Review procedure, hazards and mitigation for pumping Cement Job. Batch mix 13.8 PPG cement with 8% Bentonite. Circ. 0.6 bpm, 0.4 m r turns. Cement at weight at 1045 hrs. St 5.6 Is, 13.8 ppg G Cement with 8% Bentonite. 2.3 --- bp 700 psi, Stg 10 bbls water, 2.2 bpm, 1200 psi. Stop pump, close CT valve, Vac cement line clean. Displace with 30 bbl Biozan water, 2.6/2.2 bpm, 700 psi. 43K up wt with cement in coil. Close choke at 30 bbls displacement. 2 bpm, 700 psi, Nozzle at 9710 ft. 32 bbl displacement, Cement at nozzle, 2 bpm, 790 psi, 37 bbl displ, 2.0 bpm, 830 psi, Cement at top perf at 38 bbls. 41 bbl displ, 1.8 bpm, 950 psi, Printed: 5/17/2004 8:26:17 AM /'"""". ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-24 02-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/24/2004 Rig Release: 5/15/2004 Rig Number: N1 Spud Date: 5/23/1982 End: 5/8/2004 10:55 - 11 :45 0.83 ZONISO P WEXIT 44 bbl displ, 1.1 bpm, 850 psi, switch to KCL water. 48 bbl displ, 1.0 bpm, 1270 psi, POHat30fpm, layinat1:1. 35K up wt. 54 bbls, 1.0 bpm, 1300 psi, 9520 ft. 58.1 bbls, 1.0 bpm, last of cement out nozzle, TOC at 9400 ft. Drop pump to 0.3 bpm and Pull to safety at 9000 ft. 11:45-12:30 0.75 ZONISO P WEXIT Circ. at 9000 ft at 0.2 bpm. 35K up wt. Squeeze cement to 1400 psi. 12:30 - 12:45 0.25 ZONISO P WEXIT RIH. Found cement top at 9430 ft. Circ 2.7 bpm, 1700 psi, RIH at 30 fpm, Cleanout cement to Flag at 9704'. Top of whipstock at 9710 ft. 12:45 - 15:00 2.25 ZONISO P WEXIT POH at 80%, Flag CT at 9500 ft EOP. POH at 80%. 3 bpm, 2000 psi, full returns. 15:00 - 15:45 0.75 ZONISO P WEXIT UO Cementing BHA. P/U side jetting nozzle and jet stack to cleanout any cement or fill. 15:45 - 16:00 0.25 ZONISO P WEXIT M/U 3.80" diamond HCC window milling BHA. OAL = 83.98 ft. 16:00-18:15 2.25 STWHIP P WEXIT RIH with window milling BHA. Tag top of cement and correct -20 ft to 9704 ft. 18:15.18:30 0.25 STWHIP P WEXIT Press test against firm cement. 2000 psi - bled down to 1910psi after 10mins, with no changes in lAP & GAP. P/U wt @ 9700' = 40.2k. 18:30.19:00 0.50 STWHIP P WEXIT Ease in hole & stall @ 9702' - suspect we're @ WS/Lnr pinch pt. P/U with 5k a/pull. Ease in & stall again. P/U with 10k a/pull. Flag pipe & correct depth to 9714.6' (pinch pt ELM D). Establish freespin @ 2.65bpm/1350psi. 19:00 - 20:15 1.25 STWHIP P WEXIT Mill from 9714.6' to 9717' with 2.65/2.65bpm, 1350/1680psi, 1-3k WeB & 1.9fph ave ROP. P/U clean @ 40.2k & ease back into milling. 20:15 - 21:35 1.33 STWHIP P WEXIT Mill from 9717' to 9718.5' with 2.65/2.65bpm, 1350/1700psi, 3k WeB & 1.5fph ave ROP. P/U clean @ 40k & ease back into milling. 21:35-23:15 1.67 STWHIP P WEXIT Mill from 9718.5' to 9720.5' with 2.65/2.65bpm, 1560/1750psi, 3-4k WeB & 1.5fph ave ROP. Stall 2x. P/U clean @ 40k & ease back into milling. 23:15 - 00:00 0.75 STWHIP P WEXIT Control mill to 9721' with 2.65/2.65bpm, 1570/1650psi, <1k WeB & 1fph ave ROP. Seems we're out. Pump down 12bbls of 2ppb bio hi-vis sweep. 5/9/2004 00:00 - 01 :20 1.33 STWHIP P WEXIT Mill formation to 9731' with 2.65/2.65bpm, 1570/2050psi, 2k WeB & 8fph ave ROP. Pump down 8bbls of 2ppb bio hi-vis sweep & follow with Flopro mud. 01 :20 - 02:00 0.67 STWHIP P WEXIT Swap well bore to 8.6 ppg flopro mud. Meanwhile backream/dress window/rat hole 3x & drift 2x. Window looks clean. Tentative window depths are: TOWS = 9710', TOW = 9714.6', RA PIP Tag = 9720'. BOW = 9720.5', BOWS = 9727.5'. 02:00 - 03:25 1.42 STWHIP P WEXIT Paint EOP flag @ 9604' & POOH window milling BHA#7. 03:25 - 04:30 1.08 STWHIP P WEXIT PJSM. UD BHA#7 & inspect mills. DWM gauge 3.80" go / 3.79" no-go & DSR gauge 3.80K. Wear on window mill face indicates center crossed the liner wall. 04:30 - 04:45 0.25 DRILL P PROD1 Held pre-spud safety meeting. Reviewed well plan, potential hazards & drilling BHA M/U procedures. 04:45 - 06:30 1.75 DRILL P PROD1 Rehead & M/U DS CTC. Pull & pressure test. M/U build section Printed: 5/17/2004 8:26:17 AM . , ~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-24 02-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/24/2004 Rig Release: 5/15/2004 Rig Number: N1 Spud Date: 5/23/1982 End: 5/912004 04:45 - 06:30 06:30 - 08:30 08:30 - 08:45 08:45 - 09:10 U~:lU -11:bO 11 :50 - 14:00 14:00 - 14:30 14:30 - 16:00 16:00 - 16:15 16:15 - 16:45 16:45 - 18:30 18:30 - 19:30 19:30 - 19:35 19:35 - 19:45 22:00 - 22:35 1.75 DRILL P PROD1 2.00 DRILL P PROD1 0.25 DRILL 0.42 DRILL P P PROD1 PROD1 2.6/ lJHILL p PHOlJ1 2.17 DRILL 0.50 DRILL N N DPRB PROD1 DPRB PROD1 1.50 DRILL N DPRB PROD1 0.25 DRILL 0.50 DRILL N N DPRB PROD1 DPRB PROD1 1.75 DRILL P DPRB WEXIT DPRB WEXIT DPRB WEXIT 0.08 STWHIP N 2.17 STWHIP N DPRB WEXIT DPRB WEXIT 0.58 STWHIP N DPRB WEXIT BHA #8 with used HYC DS100 3-3/4" x 4-1/4" bicenter bit, 1.37deg bend motor, MWD & newly-improved orienter [has new actuating piston & 2 new external springs for better TF locking]. Check orienter at surface. Got 4 of 34 clicks. RIH with MWD Build 1 Turn BHA #8 with 1.37 deg motor. SHT MWD and Orienter. OK. RIH. Orient TF to 30L. RIH, sat down in window 2 times with 30L TF. RIH clean thru window on third try. Tag TO and correct depth to 9731 ft. Attempt to Drill Build section in Sag river. many stalls on bottom, maybe 1 ft of progress. Checked GR tie-in. On dep with BHCS/GR at 9670'. Very light weight on bottom and otor stalls. Stalls with no weight on bit indicate we drilled into 7" centralizer and are catching the blade with the 4.25" Bi-cen router cutters. No progress. POH to check BHA. Gauge on bit was beaten up, pilot cutt s were fine, indicatiang no juck on bottom, but metal on si of 4-1/4"hole at 9731 It. , Best guess is we drilled into a 7" entralizer. Replaced motor with 1.37 d motor, Checked MWD Probe orientation - OK. M/U 3.76" Diamond 0 1 parabolic mill and diamond string reamer to clean uQ indow area and drill ahead to tie-in with RA tag. RIH with B #9. SHT MWD and Orienter. RIH. Stop at f at 9500' EOP. -12 ft CTD correction. Orien F to 30L. R m down thru window, 2.7/2.7 bpm, 3200 psi, 46L, tailed at 9721' at bottom of window. Ream down very slow at 9721' at 35L, Some motor work, no stalls. Ream down to 9732 ft, Stalled on bottom, Ream down again, no stall. Drilling Build section with 3.76" 0331 mill to get GR tie-in with RA tag in whipstock. 2.7/2.7 bpm, 3200-3900 psi, 18L, 5-10K WOB, 12 FPH. Drilled to 9752 ft. Backream/ream 3x from 9720' (BOW) to 9731' (end of rat hole) with HS TF, 2.8bpm/3500psi & 5fph aye Rap. Stalling @ 9720' while backreaming. Orient TF to 150R (180degs out from window). Backream/ream 2x from 9720' to 9731' with 150R TF, 2.8bpm/3550psi & 5fph ave ROP. Still stalling @ 9720' while backreaming. Orient TF to 50L. Ease back to 9719' & park. Dress spot with 50L TF, 2.7bpm/3350psi. Slowly backream to TOW. RBIH clean with pumps on. PUH clean thru window with pumps on. RBIH below window. Orient TF to 15R. Backream clean to TOW. RBIH below window. Log down GR & tie-in RA Pip tag into the Geology PDC log- Printed: 5/17/2004 8:26:17 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 "'-lGA- z..¡ q ( Wr) t.{- orrS 2j'¡o!cJ- 1. Type of Request: 181 Abandon 0 Suspend 0 Operation Shutdown 0 Perforate 0 Waiver 0 Other 0 Alter Casing 0 Repair Well 181 Plug Perforations 0 Stimulate 0 Time Extension 0 Change Approved Program 0 Pull Tubing 0 Perforate New Pool 0 Re-Enter Suspended Well 0 Annular Disposal 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. IBI Development D Exploratory 182-071 /- 3. Address: D Stratigraphic Test D Service 6. API Number: ¿ P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20744-00-00 7. KB Elevation (ft): 64' 9. Well Name and Number: PBU 02-24 /" 8. Property Designation: 10. Field / Pool(s): ADL 028308 Prudhoe Bay Field 1 Prudhoe Bay Pool 1,11..". '.",.,,'i ' 1 , , ! ,..'), . R~E$EN;r,VVI;L~GqNOI[I()N.SuKAMAR,( ". " " ' , , I ,!:I ,I I I " 'II I' ' ,I', ,I I" I 1'1':11" Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10515 9195 10471 9155 None 10288 CasinQ LenQth ," Size" .. MD" TVD' .'., Burst '.' ' Collarise :'. , StrlJdlJr;:¡1 r.nnrllJr.tnr 79' 20" 79' 79' ~lJrf;:¡r.p. 2593' 13-3/8" 2593' 2593' 5380 2670 I ntp.rm p.rI j::ltP. 9692' 9-5/8" 9692' 8461' 6870 4750 Prnrlu~tinn L inp.r 1114' 7" 9398' - 10512' 8203' - 9192' 8160 7020 Perforation Depth MD (ft): I Peñoration Depth TVD (It): I Tubing Size: / Tubing Grade: I Tubing MD (ft): 10269' - 10341' / 8973' - 9038' 5-1/2" x 4-1/2" x 3-1/2" L-80 & N-80 9447' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker 'SAB' packer; Packers and SSSV MD (ft): 9361' 5-1/2" Camco 'Bal-O' SSSV Nipple 1994' 12. Attachments: 13. Well Class after proposed work: ~ IBI Description Summary of Proposal D BOP Sketch D Exploratory 181 Development D Service D Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: ./ Commencing Operations: February 17, 2004 DOil DGas 0 Plugged 181 Abandoned 16. Verbal Approval: Date: 0 WAG DGINJ DWINJ 0 WDSPL Commission Reoresentative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Thomas McCarty, 564-4378 Printed Name Thomas McCarty Title CT Drilling Engineer SiQnatur; /¿:'--:F # - - Dated / 'f /0 'I Prepared By Name/Number: / Phone 564-4378 Terrie Hubble, 564-4628 , ' ¡I"" " """ ConunissionUseOraly , ." '. ". ' ','. ",' ... "'. ' " "', .' , .' I Sundry Number: -5D-'I-/!)¥/- Conditions of approval: Notify Commission so that a representative may witness 0 Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance RECEIVE.D Other: FEB 0 9 2004 Alaska Oil .& Gas Cons. Commï;\~Üon ~prov~Õy. 3/j/Jt{ BY ORDER OF Anc::::o0 ,/d ft 0 COMMISSIONER THE COMMISSION Form 10-40~d 12/~' '-- SÚbmit/n Dup(icate ~CANNEI» fEB 1 8 2004 nqlGINAL trØIAS BfL 'FEI 1,J .' bp To: Winton Aubert Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Thomas McCarty Drilling Engineer Date: Feb 5, 2004 Re: Well 02-24 prep for a CTD sidetrack Well 02-24 is scheduled for a through tubing sidetrack with the SLB/Nordic 1 Coiled Tubing Drilling rig. The sidetrack, 02-24A, will exit.eat at the existing 7" liner from a thru tubing whipstock and target Zone 2 reserves. ./ The existing perfs will be isolated with a cast iron bridge plug set in the 3-1/2" tubing tail. 1he following describes work planned for the P&A and sidetrack and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. Pre CTD Summary 1) Slickline -Drift/Caliper tubing. Dummy gas lift valves. Pressure test IA to 2500 psi. - already done 2) Eline -S.et CIB,P at ap.prox: 9875' (855,8'TVDss}, cut 3-112" tubing at approx. 9860'. / T ~vt S l 0 ,''- yo ~ C\f P ÿ\C>" Ct- ( . CTD Sidetrack Summary 1) MIRU CTD rig. .' 2) Pull 3-1/2" tubing tail, Run Thru tubing whipstock set in 7" liner at approx. 9840' (8527'TVDss) / 3) Mill 3.8" window at 9840' md. 4) Drill 3.75" openhole sidetrack to 11227' planned TD with MWD/gamma ray. 5) Run 3-3/16" x 2~7/" ",'ner completion. Top of liner will be at 9390' md (8132'TVDss) in 4 Y2" tubing tail. Cement liner wi 2 bls of 15.8 ppg cement, plan to bring cement to liner top. 6) Run MCNL, Pe ê. 7) RDMO. The pre CTD work is scheduled to begin Feb 17th, 2004. / Thomas McCarty CTD Drilling Engineer 564-4378, 748-2598 CC: Well File Terrie Hubble TREE,= ? 02-24A / Proposed CTO Sidetrack I SAFETY NOTES: - WELLHEAD = FMe ACTUA TOR = AXELSON KB. REV = 64' BF. REV = KOP= 3100' Max Angle = 42 @ 6500' Datum MO = 10147' Datum 1V0 = 8800' SS 8 1994' -15-1/2" CAM BAL-O SSSV NIP, 10 = 4.562" I GAS LIFT MANDRELS OEV iY PE V LV LATCH PORT OA 1£ 2 CAMCO RK 39 CAMCO RK 42 CAMCO RK 39 CAMCO RK 35 CAMCO RK 34 CAMeO RK 32 CAMCO RK 32 CAMeO RK 29 CAMeO RK 29 CAMCO RK 113-3/8" CSG, 72#, L-80, 10 = 12.347" I ST MD 1V0 1 2706 2706 2 4754 4568 3 6438 5844 4 7696 6791 5 8375 7333 6 8453 7397 7 8780 7670 8 8857 7735 9 9200 8030 10 9278 8098 -15-1/2" BAKER PBR ASSY I -19-5/8" X 5-1/2" BA KER SA B PKR I -15-1/2" X 4-1/2" XO I /' I 4-1/2" TBG-NPC.12.6#, N-80. .0152 bpf, 10 = 3.958" 4-1/2" CAM OB-5 LOG NIP, 10 = 3.687" (BB-iIND CT LNR) -14-1/2" BKR SHROUT SUB I -14-1/2" TUBING TAIL (BB-iIND CT LNR) I I-1RMD- TT LOGGED 06/14/82 I 19-5/8" CSG, 47#. L-80/S00-95. 10 = 8.681" I PERFORATION SUMMARY REF LOG: BHCS ON 06/05/82 ANGLE AT TOP PERF: 26 @ 10211' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DAlE SEE PAGE 2 FOR PERF BREAKDOWN Chem cut 3-1/2" LNR 13-1/2" LNR-CT. 9.3#, L-80, .0087 bpf, 10 = 2.992" I 17" LNR. 29#, L-80, .0371 bpf, 10 = 6.184" I [!ë] DATE REV BY COMMENTS DAlE REV BY COMMENTS 06/14/82 ORIGINAL COM PLETION 12/27/00 SIS-SL T CONVERTED TO CANVAS 02/16/01 SIS-MD FINAL OS/24/01 RNITP CORRECTIONS 08/17/03 CMOfTLP PERF ANGLE CORRECflON PRUDHOE BA Y UNIT W8..L: 02-24 ÆRMIT No: 1820710 API No: 50-029-20744-00 SEC 36, T11N, R14E. 2019.9' Fa. & 88.14' FNL BP Exploration (Alaska) TREE = ---_? WELLHEAD = FMC ACTUA TOR = AXELSON KB. ELEV = 64' BF. ELEV = KOP= 3100' Max Angle = 42 @ 6500' Datum MD = 10147' DatumTVD= 8800'SS 113-3/8" CSG, 72#, L-80, 10 = 12.347" 1 Minimum ID = 2.992" @ 9407' NO GO SUB 15-1/2" lBG, 17#, L-80, .0232 bpf, 10 = 4.892" H 9373' ITOP OF 4-1/2" TBG-NPC l-i 9373' ITOP OF 7" LNR I 13-1/2" LNR LANDED IN OB-5 NIP I 9435' 4-1/2" TBG-NPC,12.6#, N-80, .0152 bpf, 10 = 3.958" 19-5/8" CSG, 47#, L-80/S00-95, 10 = 8.681" 1 J 3-1/2" LNR, 9.3#, L-80, .0087 bpf, ID = 2.992" I 10261' ÆRFORA TION SUMMARY REF LOG: BHCS ON 06/05/82 ANGLE AT TOP ÆRF: 26@ 10211' Note: Refer to Production 00 for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE SEE PAGE 2 FOR ÆRF BREAKDOWN 17" LNR, 29#, L-80. .0371 bpf, ID = 6.184" 1 [!£J 02-24 / 8) 1994' ST MD TVD 1 2706 2706 2 4754 4568 3 6438 5844 4 7696 6791 S 8375 7333 6 8453 7397 7 8780 7670 8 8857 773S 9 9200 8030 10 9278 8098 I SAÆTY NOTES: -is-1/2" CAM BAL-O SSSV NP,ID = 4.562" 1 GAS LIFT MANDRELS DEV TYÆ VLV LATCH PORT DATE 2 CAMCO DMY RK 0 01121/04 39 CAMeO DMY RK 0 42 CAMeO DMY RK 0 39 CAMCO DMY RK 0 01/21/04 35 CAMCO DMY RK 0 34 CAMCO DMY RK 0 32 CAMCO DMY RK 0 32 CAMCO DMY RK 0 29 CAMeO DMY RK 0 29 CAMCO DMY RK 0 01/21/04 -15-1/2" BAKER PBR ASSY 1 -i9-S/8" X 5-112" BAKER SAB A<R I -i5-1/2" X 4-112" XO I 9407' -i NO GO SUB, ID = 2.992" I 4-1/2" CAM OO-S LOG NIP, 10 = 3.687" (BB-IIND CT LNR) -14-1/2" BKR SHROUT SUB I -i4-1/2" TUBING TAL (BEHIND CT LNR) I l-i ELMO- TT LOGGED 06/14/82 I 10510' -i PERF GUN (LOST 06/22/97) I -iFISH (XO & CENTRALIZER ON 11/07/03) I DATE REV BY COMMENTS DATE REV BY COMMENTS 06/14/82 ORIGINAL COM PLErION 01/21/04 KSBI1lH GL V C/O 02/16/01 SIS-MD FINAL 05124/01 RNITP CORRECTIONS 08/17/03 CMOI1lP PERF ANGLE CORRECTION 02/14/00 JA DI1lP NO GO SUB/REMOV E PBR 12/20/03 MH/TLH FISH (XO & CENRALIZER) PRUDHOE BA Y UNrr WELL: 02-24 PERMrr No: 1820710 API No: SO-029-20744-00 SEC36, T11N, R14E, 2019.9' Fa. & 88.14' FNL BP exploration (Alaska) PERFORA TION SUMMARY REF LOG: BHCS ON 06/05/82 ANGLE AT TOP PERF: 26 @ 10211' Note: Refer to Production DB for historical perf data SIZE SPF INTER\! AL Opn/Sqz DATE 3-1/8" 4 10211 - 10231 S 10/24/86 3-1/8" 4 10231 - 10251 S 10/24/86 3-1/8" 4 10256 - 10261 S 1 0/24/86 3-1/8" 4 10261 - 10266 S 10/24/86 3-1/8" 4 10269 - 10287 S 10/24/86 3-3/8" 4 10269 - 10289 0 09/18/89 3-3/8" 4 10270 - 10290 S 05/07/89 3-3/8" 4 10291 - 10295 0 09/18/89 3-3/8" 4 10292 - 10296 S 05/07/89 3-3/8" 6 10323 - 10331 0 06/22/97 3-3/8" 4 10325 - 10333 S 10/15/88 3-3/8" 4 10326 - 10334 0 OS/20/89 3-3/8" 4 10326 - 10334 S 05/07/89 3-3/8" 6 10334 - 10341 0 06/22/97 02-24 PERFS ./ 8 DATE REVBY COMMENTS DATE REVBY COMMENTS 06/14/82 ORIGINAL COM PLETION 01/21/04 KSBI1lH GL V C/O 02/16/01 SIS-MD FINAL OS/24/01 RNITP CORRECTIONS 08/17/03 CMOI1lP PERF ANGLE CORRECTION 02/14/00 JADI1lP NO GO SUB/REMOV E PBR 12/20/03 MHlTLH FISH (XO & CENRALIZER) PRUDHOE BAY UNIT WELL: 02-24 PERMIT No: 1820710 API No: 50-029-20744-00 SEe 36, T11 N, R14E, 2019.9' FB.. & 88.14' FNL BP exploration (Alaska) Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Well 1-01/J-19 \ X~ -n ~ --P- U-02A C- ~ -;:J --:2.C:; D.S.09-20 '-:;'~ -{)L.( , \. W-17 ~ ~<,.{ --(~q c:; G-15A q'(,< ;-- ~..L..1 01-33 c., - X,L;::J.. D.S. 2-24 " ;¡ -C'J"J \ Q-07 A q ~ -f"r -~ MPS-26 ;:')Ö ~ '. f)V5' \ MPK-21A n'n~ ... \ loA MPS-16 ,R~r)~ -rd r;r:-.;, Job # 10662975 10708038 10674403 10621748 10564495 10568434 10560320 10572013 10563066 10621740 10563067 Log Description Date LDL LDL PSP LDL TEMPERATURE PROFILE RST-SIGMA RST -SIGMA SCMT SCMT SCMT USIT SCMT 12/04/03 12/09/07 11/26/03 11/28/03 07/11/03 04/15/03 11/10/03 04/21/03 05/30/03 11/01/03 05/31/03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc, Petrotechnical Data Center LR2-1 900 E, Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~~\ ------- (~ .~ l'- ' \J;'.. v'\. ...\...~'- ,1 '-~ ~ f'.....^, ,. ,... t f (,., '~_..-. r)EC Cj) 0 2003 ::':ìIi\":',;,.':i'~~;;-;)'!i. 'il ~ \¡.. 1'". . 0..1" .. t,:,..., ~~) \" -.,~, Blueline NO. 3068 Company: 12/11/03 State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Wee pie 333 West 7th Ave, Suite 100 An~horage, AK 99501 Field: Prudhoe Bay Color Prints 1 1 1 1 1 1 CD ( 1 1 / IJri ~'q J2') ~, ~?") 2 2 2 2 2 ..' ( '- Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 Rf"'. ""~r"' ~\ !I'EO- A TTN: Beth ." r~'Y "~--. 1 v, : - J .\I_\"";"""""~'" . Received by: .r 1? ?() ~ .- - 'IN Ala5kc:1 Oil ¿~ GES CDOS. Commjs~n f\rlt:;hcr;ðge ~i~ STATE OF ALASKA S(u SKAOILAND GAS CONSERVATION COMMIS ~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate.__ Plugging _ Pedo rate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: ARCO Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage~ AK 99510-0360 4. Location of well at surface: 1799' FNL, 36' FWL, Sec 36, T11N, R14E, MM. At top of productive interval: 156' FSL, 1833' FEL, Sec 35, T11N, R14E, MM. At effective depth: At total depth: 90' FNL, 2020' FEL, Sec 2, T11N, R14E, UM. 5. Type of Well: Development _X Exploratory _ Stratagrapic _ Service _ 6. Datum of elavation (DF or KB feet): 64' RKB 7. unit or Property: Prudhoe Bay Unit 8. Well number: 2-24 9. Permit number/approval number: 82-71 10. APl number: 50-029-20744 1. Field/Pool: Prudhoe Bay Oil Pool 2. Present well condition summary Total Depth: measured true vertical Effective Depth: measured true vedical Casing Length Conductor 79' Surface 2529' 10515feet 9194 feet 10420 feet 9109 feet Size 20" 13-3/8" Production 9628' 9-5/8" Liner 1114' 7" Liner 854' 3-1/2" Plugs (measured) Junk(measured) PBTD Tagged @ 10420' MD (6/2/97). Cemented Measured depth True vertical depth 415 Sx AS II 79' 79' 2700 Sx Fondu & 2593' 2593' 400 Sx PFC 500 Sx Class G & 9692' 8461' & 300 Sx PFC 360 Sx Class G 9398 - 10512' 8202 - 9191' 10 Bbls LARC 9407- 10261' 8210- 8965' =erforation Depth measured 10269- 10290'; 10292- 10296'; 10326- 10334'; 10337- 10344' true vertical 8972 - 8991 '; 8993 - 8997'; 9024 - 9031 '; 9034 - 9041' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, NPCT @ 9373' MD; 4-1/2", 12.6#, N-80, NPCT @ 9447' MD. Packers and SSSV (type and measured depth) Baker SAB Packer @ 9361' MD; Camco Bal-O SSSV @ 1994' MD. 13. Stimulation or cement squeeze summary u'L £9 1997 Intervals treated (measured) Intervals treated (measured) see attached ORIGINAL 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Prior to well operation 889 5297 29 Subsequent to operation 955 5580 15. Attachments 116. Copies of Logs and Surveys run _ Daily Report of Well Operations _ X Oil _X Gas _ 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 06/15/88 297 Casing Pressure Tubing Pressure 190 201 Status of well classification as: Suspended _ Service _ Date ~'- 2 z~_ ? 7 SUBMIT IN DUPLICATE 2-24 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 612/97: RIH & tagged PBTD at 10420' MD. 6122/97: MIRU & PT equipment. RIH w/perforating gun to shoot 15' of perforations as follows: Reperforated: 10326 - 10334' MD (Z2) Ref. Log: BHCS 6/5/82. Added Perforations: 10337 - 10344' MD (Z2) Ref. Log: BHCS 6/5/82. Used a 2-1/2" carrier & shot the perfs at 6 spf at 60 degree phasing at underbalanced pressures. POOH w/perf gun. Rigged down. Returned the well to production & obtained a valid welltest. STATE OF ALASKA '~ ALASKA~ ,L AND GAS CONSERVATION C ~viMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing .... Alter casing ~ Repair well ~ Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1799' FNL, 36' FWL, Sec 36, T11N, R14E, UM. At top of productive interval 156' FSL, 1833' FEL, Sec 35, T11N, R14E, UM. At effective depth . At total depth 90' FNL, 2020' FEL, Sec 2, T10N, R14E, UM. 5. Type of Well Development X.~ Exploratory Stratigraphic Service ORt6 NAL 6. Datum of elevation(DF or KB) 64' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 2-24 9. Permit number/approval number 82-71 10. APl number 50 - 029-20744 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10515 feet 9194 feet Plugs(measured) Tagged PBTD @ 10364' MD (5/9/96). Effective depth: measured 10364 feet true vertical 9058 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 79' 20" 415 Sx AS II .. 79' 79' Surface 2529' 13-3/8" 2700 Sx Fondu & 400 Sx PFC 2593' 2593' Production 9628' 9-5/8" 500 Sx Class G & 300 PFC 9692' 8461' Liner 1114' 7" 360 Sx Class G 9398 - 10512' 8202 - 9191' Liner 854' 3-1/2" 10 bbls LARC .9407 - 10261' 8210 - 8965' Perforation depth: measured 10269 - 10290'; 10292 - 10296'; 10326 - 10334' true vertical 8972 - 8991'; 8993 - 8997'; 9024 - 9031' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, NPCT @ 9373' MD; 4-1/2", 12.6#, N-80, NPCT @ 9447' MD. Packers and SSSV (type and measured dePth)Baker SAB Packer @ 9361' MD; Camco Ba~~ N~bMD. 13. Stimulation or cement squeeze summary Intervalstreated(measured) see Attached MAY 2 8 1995 Treatment description including volumes used and final pressure ,~1#1~ 0tl & (~1~ CI:II~. C01111t~ 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 1545 26929 0 -- 1092 1183 379 16. St~us of wellclassification as: Oil X Gas Suspended Service Tubing Pressure 907 191 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed "~'/,L~,~ ~1- ~ Title Engineering Supervisor Form 10-404 Rev 06/15/88 Date 5"--2 ~- ~ SUBMIT IN DUPLICATE 2-24 DESCRIPTION OF WORK COMPLETED SCAB LINER INSTALLATION FOR GAS SHUTOFF 1/23/96: RIH & tagged PBTD at 10324' MD. 4/29/96: MIRU CTU & PT equipment. 4/30/96: RIH w/CT to bottom loading the well w/Seawater, then pumped Gelled Sand Slurry containing 1500 lbs of 20/40 mesh sand, to spot an isolation sand plug across the open perforation intervals located at: 10269 - 10290' MD (Z2) 10292 - 10296' MD (Z2) 10326 - 10334' MD (Z2) Ref. Log: BHCS 6/5/82. Tagged final sand top at 10267' MD & POOH w/CT. MU & RIH w/3-1/2" Scab Liner assembly (860'). Landed liner in the 4-1/2" DB nipple at 9435' MD, to put liner shoe at 10261' MD. Pumped 12 bbls of Latex Acid Resistive Cement to set the liner & to isolate leaking squeezed perforation intervals located at: 10211 - 10251' MD (Z2: Sqzd) 10256 - 10266' MD (Z2: Sqzd) Ref. Log: BHCS 6/5/82. Placed 2 bbls of cement behind pipe & attained 1000 psi maximum squeeze pressure held for 1 hour. Estimated top of cement behind liner to be at 9880' MD. 5/1/96: POOH w/cementing tools. WOC. MU & RIH w/milling BHA. from 10183' to wiper plug at 10191' MD. Milled & circulated cement from liner 5/2~96: Milled on wiper plug. to 10240' MD. POOH w/BHA. MU & RIH w/milling BHA & milled through wiper plug & cement 5/3/96: Milled cement to cement/sand interface, then cleaned out the sand plug w/biozan to 10345' MD to uncover the lower open perforation intervals (listed above). POOH w/milling BHA. Rigged down. 5/7/96: RIH & tagged PBTD at 10262' MD. RECEIVED 5/8/96: RIH w/CT & jetted a fill cleanout w/biozan down to 10400' MD. 5/9/96: RIH & tagged PBTD at 10364' MD. MAY 2 8 leJ Jtl Returned the well to production & obtained a valid welltest. Oil rate decreased by 453 BOPD, but the decrease in the gas rate provided an incremental rate benefit of 1619 BOPD, resulting in a net oil benefit of 1166 BOPD. GeoQuest ~<~ 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9958 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 1/2/96 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 02-24 ~~ LPRODUCTION PRORLE 9511 27 I 1 . D.S: 6-16~'~ TDT-BOR~ 951208 I 1 D.S. 6-19 ~- ( ( ~ L~K DETE~ON 951205 I 1 ~.s. ~-~ ~' ~7 .RO~UC~O...OR~ ~s~ ~0~ ~ ~ D.S. 6-22A ~ ~ ' S ~ PRODU~ON PRORLE 9511 28 I 1 D.S. 15-2 E~- ~' TDT-BOR~ 951 207 I 1 , SIGNED: JAN 0 5 ~996 Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. STATE OF ALASKA ALASKA(' ..AND GAS CONSERVATION C(~ ,llSSION REPORT UF SUNDRY WELL OPErIATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1799' FNL, 36' FWL, Sec. 36, T11N, R14E, UM At top of productive interval 156' FSL, 1833' FEL, Sec. 35, T11N, R14E, UM At effective depth At total depth 90' FNL, 2020' FEL, Sec. 2, T10N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 64' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 2-24 9. Permit number/approval number 82-71 10. APl number 50 - 029-20744 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10515 feet 9194 feet Plugs(measured) PBTD tagged @ 10372' MD (8/29/95) Effective depth: measured 10372 feet true vertical 9065 feet Junk(measured) Casing Length Size Cemented Conductor 79' 20" 415 sx AS II Sudace 2529' 13-3/8" 2700 sx Fondu & 400 sx PF'C" Production 9628' 9-5/8" soo sx CrG' & 300 sx PF'C' Liner 1114' 7" 360 sx CI'G' ~a~red, depth True vertical depth 2593' /9692 ~,,~, 8461' .10152' ~ 8867' Perforation depth: measured 10269-10290'; 10292-10296'; 10326-10334' true vertical 8972-8991'; 8993-8997'; 9024-9031' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, NPCT @ 9373' MD; 4-1/2", 12.6#, N-80, NPC tail @ 9447' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 9361' MD; Camco BaI-O SSSV @ 1994' MD 13. Stimulation or cement squeeze summary 14. Intervals treated(measured) See attached Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data .~,,,...,,~ . OiI-Bbl Gas-Md Water-Bbl Casing Pr_,e~.~ %- ,~t.~'151'ng Pressure Prior to well operation 1544 21282 87 -'-:~' ~ ' 850 Subsequent to operation 1369 1807 341 --- 210 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~""~'~'"~ ~' Form 10-404 Rev 06/15/88 OJW cc: KZ, JWP Title Engineering Supervisor SUBMIT IN DUPLICATE 2-24 DESCRIPTION OF WORK COMPLETED MARASEAL GEL SQUEEZE FOR GAS SHUTOFF 8/5/95: RIH & tagged PBTD at 10401' MD. 8110195: RIH w/CT to bottom & pumped Gelled Sand Slurry containing a total of 3500 lbs of sand, to place an isolation sand plug across the open perforation intervals located at: 10269 - 10290' MD (Z2) Ref. Log: BHCS 6/5/82. 10292- 10296' MD (Z2) 10326 - 10334' MD (Z2) POOH w/CT. Rigged down. 8/1 I 195: RIH & tagged sand plug top at 10255' MD, then dump bailed 4 gallons of mud on top of the sand plug. 8/18/95: A Maraseal Gel Squeeze of leaking squeezed pedorations was performed for Gas Shutoff as follows: MIRU CTU & PT equipment. RIH w/CT loading the wellbore w/Seawater. Tagged mud/sand plug top, then switched to pumping Maraseal Gel to resqueeze the leaking cement squeezed perforation interval located above the sand plug at: 10211 - 10251' MD (Z2: Sqzd) Ref. Log: BHCS 6/5/82. 10256 - 10266' MD (Z2: Sqzd) Pumped 192 bbls of Maraseal Gel @ 1.2 bpm & placed all 192 bbls of Gel behind pipe at 1900 psi maximum squeeze pressure. POOH w/CT displacing w/Seawater & Crude. Rigged down. 8/23~95 & 8/28/95: RIH w/CT & jetted Maraseal Gel & mud / sand plug from the wellbore to uncover the open perforation intervals (above). Rigged down. 8/29/95: RIH & tagged PBTD at 10372' MD. Returned the well to production w/gas lift & obtained a valid welltest. Note: Oil rate decreased by 175 BOPD, but the decrease in the gas rate provided an incremental rate benefit of 1401 BOPD, resulting in a net oil benefit of 1226 BOPD. GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie APR 2.. 7 1995 Alaska Oil & Gas Cons. commission Anchorage NO. 9431 Company: 4/26/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 -~ Field: Prudhoe Bay Floppy Well .Job # Log Description Date BL · RF Sepia DIR MWD Disk D.S 2-24 ~. -~'~ CNT-D 040695 I 1 7 '7/ D.S. 3-13 PERF RECORD 040895 I 1 D.S. 4-13 ~ ~'- =~ I INJECTION PROFILE 040795] I 1 D.S. 9-10 -~,- ~ PERFRECORD 040595 I 1 D.S. 9-12 '7'~ -'] PERFRECORD 040795 I 1 D.S. 9-23 i¢~ ~ ',~ GAS LIFT SURVEY 040695 I 1 D.S. 15-17 ~Zl/'gC~ CNT-G , 040595, 1 1 D.S. 18-24 ~c~./.p_~ TBG. CLrrrERRECORD 040695 1 1 .... , SIGNED: __ _ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrle NO. 9409 Company: 4/13/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay FloPpy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 1-22A 95110 MWDGR 010995 1 ..... D.S. 15-08A 95148 MWDGR 102693 1 , ........ D.S. 2-24 PROD PROFILE 040395 I 1 ...... D.S. 3-19 INFLATABLE BRIDGE PLUG 040395 I 1 ....... D.S. 5-12 PROD PROFILE 040395 I 1 D.S. 9-25 PERF RECORD 032795 I 1 D.S. 9-25 PERF RECORD 032895 I 1 D.S. 9-40 PERFRECORD 0331 95 I 1 ., D.S. 11-6 PATCH SETTING RECORD 032595 I 1 ...... D.S. 14-3 PATCH SETTING RECORD 040495 I 1 .... D.S. 15-17 Gcr 040595 ~ I 1 D.S. 16-23 c'OLLAR & JEWELRY LOG 0331 95 I 1 D.S. 16-23 PERF RECORD 0 4 0 3 9 5 I 1 ..... D.S. 18-02A GCT 0401 95 I I I APR 1'3 J99,5 SIGNED: / DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. Drill Site: 2 Well: 24 K-VALVE DESIGN Fri Sep 02 07:23:24 1994 DOME SET PRESSURE: 535 FTP @ CLOSE (PSIG): 700 K-VALVE CLASS (A, B, C ): A PSIG @ ~ PSIG · COMMENTS: Due to changing well conditions, time to c/o the k-valve. CC: ENGINEERING FILE / COORDINA~~$,24 (WITH ATTACHMENTS) J.C. SMART / M.G. SHOE~ J~ 1PRB 2~ (WITHOUT ATTACHMENTS~^_ FS 1 DS Supervisors PRB DS 2 Eng, ATO 15 (w DESIGNED BY: MMM Drill Site: 2 Well: 24 CK LGR FTP OIL %WTR 56 56 60 59' 59 59 6O 60 6O 6O 60 6O WELL. TEST DATA GOR GLR LIQ PWF 0 984 1666 4.1 12245 11730 1739 1579 0.86 0 986 1726 3.3 12262 11857 1785 0 791 1731 3.4 12525 12099 1792 0 811 1828 3.4 12034 11621 1893 0 807 1806 4.1 12319 11802 1885 0 708 1777 3.4 12550 12121 1840 0 688 1780 2.9 12331 11962 1835 0 681 1793 2.9 12286 11920 1848 1376 0.00 0 676 1820 3.3 11681 11291 1883 0 0.00 0 630 1883 0.0 10995 10995 1883 0 0.00 0 622 1767 0.0 11406 11406 1767 0 0.00 0 600 1889 2.0 10252 10044 1928 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 Fri Sep 02 07:23:37 1994 PI SEPARATOR DATE SEL TEMP PRES 79 170 08/30/94 Y 79 174 08/29/94 83 183 08/04/94 83 189 07/25/94 82 178 07/22/94 85 186 07/06/94 83 179 06/30/94 83 181 06/30/94 83 177 06/22/94 83 202 05/28/94 84 193 05/17/94 83 2o4 05/08/94 ESC=EXIT; FI=HELP; F3=DESIGN; F4=DISTRIBUTION LIST; F5=SENSITiVITY TABLE; F6=CHECKLIST; F10=ACCEPT; SF8=RESTORE WELL TEST; CF9=CYCLE DATA; SSSV DEPTH (MEAS): 1994 FTP @ CLOSE (PSIG): 700 PRESS ADJUSTMENT: 288 TEMP CORRELATION: PIPROF NOTE: LINEAR CORR USES SEP TEMP, PI PROF USES BH TEMP AND WELL PI WPS C= ..68300e-3 N= 1.000000 NEW C= ..68417e-3 ENTERED N= 1.000000 Drill Site: 2 Well: 24 Sat Jan 29 09:25:10 1994 K-VAL%-E DES I GN DO~.iE SET PRESSU-~E: FTP @ CLOSE (PSIS): K-VALVE CLASS (A~B,C): 215 PSiG @ 80 DEG F 259 PSiG . i Redesigned well to allow K-valve to be tested in well. This may required the well to be choked back to keep well from dumpin9. To dump (test), the test separator may need to be depressured and/or drain system opened. CC: ENGINEERING FiLE / COORDINATOR PRB 24 (WITH ATTACF~iENTS ) J.C. SF~RT / M.G. SHOF24AEE PRB 20 (WITHOUT ATTACHMENTS ) .. E.E. VAUGHN / E.A. CAM~'BELL PRB 15 ( CO~ER ONLY) D.L. ADDIE ATO 1552 (WITMOUT ATTACHMENTS ) STATE OF ALASKA (COVER ONLY) DESIGNED BY: RTB Drill Site: 2 Well: 24 K-VALVE DESIGN Thu Jul 02 10:08:54 1992 DOME SET PRESSURE: 115 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 150 PSIG K-VALVE CLASS (A,B,C): C COMMENTS: Redesign K-valve. Pulled on 7/1/92 and GOR has decreased since last design. CC: C.P. FARMER ! W.D. COOPER J.C. SMART / M.G. SHOEMAKE C.B. HURST ! E.A. CAMPBELL ENGINEERING WELL FILE PRB 24 B.T. SEITZ PRB 2O PRB 15 BY: Burno ATO 1556 RECEIVED JUL 1 1992 Alaska Oil & (~a~ aons. (;ommi;sion Anchorage Drill Site: 2 Well: 24 Thu Jul 02 10:09:43 1992 K-VALVE DESIGN SSSV DEPTH (MEAS): 1994 FTP @ CLOSE (PSIG): ~ PRESS ADJUSTMENT: 5~3 TEMP CORRELATION: PIPROF NOTE: LINEAR CORR USES SEP TEMP, PI PROF USES BH TEMP AND WELL PI CONDITIONS OF WELL TEST: CK LGR FTP OIL %WTR GOR GLR 88 1771 195 693 3.2 493 2951 CONDITIONS AT CLOSURE: 88 1771 150 711 3.2 493 2887 WELL TEST @CLOSE TEMPERATURE @ SSSV: 107 107 PRESSURE @ SSSV: 244 ~ SEP COML LIQ PWF PI TEMP PRES DATE SEL 716 1092 0.28 60 0 07/02/92 Y 734 938 0.28 60 0 DOME SET PRESSURE PRIOR DESIGNS: DATE: 01/20/92 SET PRESSURE: 105 ~07/19/91 140 01/21/91 110 FTP @ CLOSURE: 150 TEMP: PIPROF 155 LINEAR 140 PIPROF ESC=EXIT; Fi=HELP; F2=WELL TESTS; F4=DISTRIBUTION; F5=SENSITIVITY TABLE; F6=CHECKLIST; F10=ACCEPT; SF8=RESTORE WELL TEST; CF9=CYCLE DATA; WPS C= ..85315e-4 N= 1.000000 NEW C= ..95969e-4 ENTERED N= '1.000000 Drill Site: 2 Well: 24 SENSITIVITY TABLE Thu Jul 02 10:10:07 1992 P.I. 0.30 0.20 0.10 0.30 %WTR 3.0 2.0 2.0 3.0 GOR 500' 800 800 800 LGR 1800 0 2000 2000 FTP 1 195 244 338 241 241 FTP 2 100 136 189 1'35 136 FTP 3 .. 205 254 351 250 250 ENTER VALUES FOR PRODUCTIVITY INDEX, WATER CUT, GAS-OIL RATIO, LIFT GAS RATE, AND FLOWING TUBING PRESSURE 1, 2, or 3. PRESSURES AT THE SSSV WILL BE CALCULATED FOR EACH GROUP OF ITEMS ENTERED. ESC=EXIT; FI=HELP; F2=WELL TESTS; F3=DESIGN; F4=DISTRIBUTION LIST; F6=CHECKLIST; F10=ACCEPT; Drill Sits: 2 Well: 24 K-VALVE DESIGN Thu Jan 16 O8:56:03 1992 DOME SET PRESSURE: 105 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 150 PSIG K-VALVE CLASS (A,B,C): C COMMENTS: Redesign K-valve following wellwork. FTP floats CLP. CLP drops to 160 psi. Bench test K-valve. CC: C.P. FARMER / W.D. COOPER PRB 24 J.C. SMART / M.G. SHOEMAKE PRB 20 J. M. Ralph / T. J. Brass field PRB 15 ENGINEERING WELL FILE T.D. WEISS ATO 1556 ~BTATE OF. ALAS~ (COVER:) DESIGNED BY: Kara Printing contents of current screen - wait for message to clear RECEIVED FEB 1992 Ala~k~ Oil & Gas Cons. Commission Ar~c~horage DATE: 5-24-9~ . REFERENCE' ARCO CA~ED HOLE FINALS 2-t6 4-28-9t PROD. F'ROF. RUN t, 5 2-24 4-28-7t "':"PROD. PROF.";'"'~ ............. RUN t , 5 6-i3 5-5-9t ' PROD, PROF. RUN t, 5 9-4 5-5-9t .... :":'i~"LEAK DETECT," ~ .... RUN t, 2 9-8 4-S0-9~ ~ GR RUN t, 5 9~t 6 .... 5-6-9t "~"~INJ;."PROF'J ............................................................ RUN -~-~ -5 9-~7 4-25-9t .';:~; INJ. PROF. RUN ~.; 5 9 ~ 4-25-9t - INJ F'ROF RUN t 5 t2-t6 5-2-~t ~ F'ROD. PROF'.-GA~ LIFT RUN t, 2 ~ J-? 5-4-9t ..........LEAK DETEC. T, ................ RUN '~, 2 ~3-28 4-~7-9~. ~.[.GA$ ENTRY RUN ~, 2 PLEASE SIGN AND RETURN"'FHE:.iATTACHED COPY AS RECEIPT OF DATA. · · ! ! · · ! CAMCO C~MCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO --' RECE I VED ~BY .......................... :'~ ........ ~'i:~"~ ................. ~.~: SONYA WALLACE "': ....... :'.i.::.'..i~"i:. '! _' :: !: ":: ? : !:: :.:; ':::?!~z: :.r .."".:~F,F;RO, VEi) ATO-t 529 ?" ~"':":":" TRANX:~ 9t DISTRIBUTION - · - ~..~;~....~ ~,~.~ .... ~ ........... . ..-~ CENTRAL FILES ~ F'HII_L. IF'S ~'~-CHEVRON" ' ....: ....................... F'B 'WELL D & M .:' R & D ~ EXTENTION EXPLORATION ..... - ...... ...'"' BF'X ......... ...-' EXXON ~.~ STATE OF ALASKA MARATHON ....................... :.' ............. '-. TEXACO FILES ....................... Drill Site: 2 Well: 24 K-V~J4VE DESIGN Sun May 05 07:56:36 1991 il DOME. SET PRE. SS,J.~: 140 PSIG @ 60 DEG F CO.~/4ENTS: Redesign to increase FTP @ Closure following pulling the valve for a PPROF. Increased the FTP @ Closure to be safer. Possibly a B valve if dumped to a PP_~ 24 PPg 2O PRB 15 depressured separator. CC: C.P. K.M. KENNEDY ! W.S. WILDER C.B. HURST / E.A. CAMPBELL ENGINEERING .WELL FILE T.D..WEISS A_~O_ 1556 STATE OF ALASKA (COVER) DESIGNED BY: ~L~TT MAGU!RE Printing contents of current screen - wait for message to clear Drill Site: 2 Well: 24 K-VALUE DESigN Mort Jam 21 i4~$1:01 1991 ..-.houid dump at i80 p.-_i whii-_ on raw llf% and 120 p~i wh~_n hoe lx f ~.,~4, CC-'. C, P, Fk~MER / P~B 24 K, M, _W~NmaDY / W, S, WILDER PRB 20 C, B, H?_r~BT / D, B, ~gNT~DME~:f P~B 15 ENGIN~ERiN,~. 'w-~LL FiLE T,D, W-~iSS ATO 1556 ,_'£a'-'m ,.,~ ALASKA DESi,~_NED BY: K, L, Martin Printing cont~_nt~ of curr~n+.. ~cr~_en - wait for men.ag-,_ tm_ clear Drill Si+.~: 2 W~_ii: 24 Sun Jan 20 18:52:00 1991 K-VAL .~ DESiC~N 888%.' n-- . ,. ~F-~--~ (~AS), 1994 FTP ~ C-'LC~SE (PSIS); i80 PRESS Ai~iUST~NT; 46 ~ CORRELATION; PiPRO~ NOTE; LiN-~R CORRECTION USES SEPARATOR ~~~, Pi PROFILE USES ~LL ~ ~_-"ONDiTiONS OF WELL EST ~ SEP COML C-'K L~?9_. ~ OiL %~ C~R ~LR LiQ P~ Pi 79 0 227 i48~ 2.0 396~ 3881 1513 534 0,48 75 0 il/~i/90 Y CONdiTiONS AT 79 0 180 i~1~ ~, 0 396~ 3881 i~44 469 0,48 75 1-31 2.39 PRIOR. DESi~_-NS; DATE; 01/01/81 SET PRESSURE; 0 F'~ ~_ C_.'LOS~E; 12.5 TE~; NA 01/01/81 0 0 NA .~,_: u-~81 0 0 NA ESC-'-B-XiT; El-HELP; Drill .... , _ '..~LL ',_'~ST DATA C:K LOR FTP OiL %W'~'UR _~3R OLR LiQ 79 79 79 89 89 89 89 89 89 89 89 227 1482 2,0 3962 388i 1513 534 238 18,94 3,6 4347 4189 1872 0 0,00 240 1848 3,8 4286 4121 1922 0 0,00 180 560 5,0 80,9 759 589 1409 222 1854 2,6 4324 4208 1905 567 ,9,00 191 343 7,0 799 745 368 1547 0,00 215 1863 4,0 4367 4i89 1942 0 ,9,,9,9 220 1717 4,7 4481 4267 1803 0 0,00 225 1606 4 a ~.z 4553 1687 u 0·00 192 280 6,0 2898 ""'~z,z ...... 298 n 187 696 5,0 799 760 732 1412 0,00 195 1114 7,2 3073 2850 1201 0 0,00 195 1080 7,i 3243 3011 1163 0 0,00 202 1069 7,2 3377 3134 1152 0 0,00 Sun Jan 2,3 i4:15:14 1991 Pi SEPARATOR D~TE SEL TEMP PBES 7~ 188 ''' ''qa " . _ 111211 _ - 17o 11113190 71 172 11/13/90 4,9 0 11/02/90 72 172 11/01/90 0 0 10/08/90 62 163 10/03/90 60 172 lO/O2/9o 70 185 09/05/90 70 !83 o8!28/9o o o ~ i.~ ..... .. ~7 182 u~,~ 66 189 ,98/07/9,9 ESC-EXiT? Fl-HELP; F3-DESiGN; F4-DiS'T'RIB; Fi0-ACCEPT? SFS-BEST~DB~.; CF9-CYCLE; SSSV DEP--'~H (M~AS): 1994 ~ -8. PRESS AD,.~3STME. NT' 46 ~MP CO~ELATiON~ PIPRO~ FTP m CLOSE (PSiO)~ ' a NOTE-'. LI 'NEAR COBRELATION USES SEParATOR 'r-~.~ERA',_-~',_~E~ Pi P_~DFILE USES ..WELL Print. in~ cont.~nt..~, of curr~n%. ~cr~n - wait. for m~a~ to cigar Drill Si%.~ ~ W~ii: 24 8un Jan ~0 14:i6=04 1991 K-V~%~ DESIGN 888V DEP~ (~AS) ~ 1994 F~ $ CLOSE (PSiO)~ 180 PBESS ~/~N~: 46 ~ COB~ELATiON~ PiPBDF NC~ LiN~. ~OB~kATION USES 8EP~AT~R ~E~A~u~E; Pi PBDFiLE USES W~LL CONDITIONS OF WELL TEST: C.'K LOR FTP OiL %%~'~'FR ~DR GLR LiQ 79 a 227 -~.,. 2.,0 396~ 3881 1~1q CONDiTiONS AT 79 0 180 1512 2,0 3962 3881 i SEP CO.~L P~ Pi ~_~_~ PBES DATE 534 0,48 75 0 ii/~-1/90 469 0,48 75 0 TEMPEFC~.T~_rRE ~ SSSV: 131 PRESS~_~E ~ SA.~v: z .o DOE SET PBESSURE: 145 131 239 PRIOR DESigNS: DA'x'~; 0 i / 0 i / 8 i SET PB~.SSUBE; 0 F'ii'~ 6 C'.LOS%Fg_~.: 0 TE~: NA 01/01/81 0 0 NA ' "~I 8i 0 0 NA ESC-~iT; _~i-HELP; _'f2-'..'L 'r~STS; F4-DiS'I'--RiB~ Ei0-ACCEPT~ SFS-B~.ST©RE~ C.~9'CYCLE Printing '.~~~~~ scr_~_.n - wai lear MODL .~.GP . D~ ~ PH2 3810 296 ' ' '0 158 1420 ~,i/10/91 Y ~SD PORT 60 ~E CAS~ V~ ~AS Prudhoe Bay Operations Engineering K-Valve Design Checklist Well: 2"~ Date: '/~.°(~' Reason for k-valve redesign (recent wellwork performed?)' No wellwork on active or pending worklist? Subject well is producing into the high or Iow pressure commonline? ~(-~ Past 7 day average commonline pressure '"///~ ~ and Iow pressure "' J~ 0 Subject well's past 7 day average surface flowing tubing pressure? '"' /~ ~ Past 7 day Iow FTP? ~' J~ ~ Reason' ~o~ CJ/_ Does the FTP versus CML pressure indicate a choke restriction or undersized choke? Current choke setting is at CFR or high limit (wide open)? ~{(/~ /-~,~ Subject well is gas lifted? flca~/-.,'~'~;/Gas lift is operating smoothly? ~o/-'o^ Any recent gas lift valve changes have been entered into the WPS 'Wellbore Hydraulics Data' Summarize sensitivity analysis below: If well is gaslifted, will the k-valve shut above 100 psi surface FTP at 0 GLG rate? Detail the recommended test procedure. 1/1/91 PRUDHOE BAY FIELD K-VALVE DOME SETTING PRESSURE DATA SHEET Drillsite-Well: DS 2-24 Date: Comments: The previous design did not dump during state testing The well conditions had changed Category B valve 1/20/91 Previous K-valve Settings: Production Data: ROR = 660 CFR = Swing Well (very high or Iow GOR) ..... ; ........ Design Parameters: Design parameters are based on (Mark one of these) XXX XXX* Oil Rate Watercut Formation GOR Gas Lift Gas Rate Total GLR Flowing Tbg. Pressure Flow. Wellhead Temp. Set Pressure, psig 110 26O 79O BOPD @ 88 deg. choke BOPD @ deg. choke No Choke Priority Well ..................... Actual Well Test ..... Date of Test ..... Nov 21 90 Flowing Press. Survey ...... Date of Survey ...... Theoretical Rates used with Hydraulics Program Date 4/5/90 12.3/89 8/26/89 no If hydraulics program..was used of the parameters, mark which program... 1482 BOPD 2 percent 3962 - . scf/stbo Raw Included mscfpd 3881 scf/stbl 227 psig I 1 0 * deg. F Temp. @ SSSV ............. Pressure @ SSSV ....... Pressure Adjustmen to get some xxx PH2 PH3 PRUDHYD Other 131 deg. F* 286 psig* 45 psig Calculated Dome Set Pressure = 144.0 psig @ 60 deg. F IActual Dome Set Press. 145 FTP at K-valve Closure = 180 psig @ 60 deg. F psig @ surface cc: Alternate / Farmer Wilder / Kennedy (2 copies) State of Alaska cc: D.S. Engnr. T. Weiss D.S. Supvsr. Campbell / Hurst Prepared by K. L. Martin ARCO Alaska, In~" Prudhoe Blk..ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager October 11, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 2-24, Approval No. 8-646 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Sincerely, D. F. Scheve DFS/SLW/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 2-24) W1-3 RECEIVED OCT 2 o 1..989 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE Of ALASKA ALASl~' OIL AND GAS CONSERVATION REPOR' OF SUNDRY WELL OF,-:RATIONS 1. Operations performed: Operation shutdown Stimulate Pull tubing Alter casing Plugging Perforate X Repair well Off, er X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1799' FNL, 36' FWL, Sec. 36, T11N, R14E, UM At top of productive interval 156' FSL, 1833' FEL, Sec. 35, T11N, R14E, UM At effective depth At total depth 90' FNL, 2020' FEL, Sec. 2, T10N, R14E, UM 5. Type of Well Development Exploratory Strat~graphic Service 6. Datum of elevation(DF or KB) 64' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number DS 2 - 24 9. Permit number/approval number 82 - 71 /8 - 646 10. APl number 50 - 029 - 20744 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10515 feet Plugs(measured) 9194 feet Effective depth: measured true vertical Casing Length Conductor 79' Sudace 2529' Production 9628' Liner Perforation depth: 1114' 10471 feet 9154 feet Junk(measured) Size Cemented Measured depth True vertical depth 20" 415 Sx AS II 79' 79' 13-3/8" 2700 sx Fondu & 2593' 2593' 400 sx PF 'C' 9-5/8" 500 sx Cl 'G' & 9692' 8461' 300 sx PF 'C' 7" 360 sx CI 'G' 10152' 8867' measured 10270 - 10290'; 10292 - 10296'; 10326 - 10334' true vertical 8973 - 8991'; 8993 - 8997'; 9024 - 9031' Tubing (size, grade, and measured depth) 5-1/2",17#, L-80, NPCT @ 9373' MD; 4-1/2",12.6#, N-80, NPC Tail @ 9447' MD Packers and SSSV (type and measured depth) Baker SAB Packer @ 9361' MD; Camco BaI-O SSSV @ 1994' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) SEE ATTACHED Treatment description including volumes used and final pressure KELEi V OCT 2 01_989 Alaska 0ii & Gas Cons. C0mmissi0[~ 14. Prior to well operation Subsequent to operation Reoresentative Daily Avera0e Production or Iniecti0n Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 2591 15564 0 447 2024 179 Anchorage Tubing Pressure 1809 213 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~;~//i;~'~~,,'~~ Title Operations Engineering Manager Form 10-404 Rev 06/15/88 S.L. WARD Date /~'/W ~ SUBMIT IN DUPLICATE DS 2-24 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR GAS SHUT-OFF 10/2/88: MIRU CTU & Stimulation Equipment. PT Equipment to 4000 psi. RIH w/CT and washed perforations at: 10211 - 10251' MD Ref. Log: BHCS 6/5/82. 10256- 10266' MD 10269- 10287' MD 10326- 10334' MD Pumped the following treatment: 29 bbls OSR Diverter (800 lbs solid/70g liquid), followed by, 95 bbls 12% HC1, followed by, 189 bbls 12-3% HCI-HF, followed by 190 bbls 2% NH4C1-Water, followed by, 45 bbls Diesel w/EGMBE, followed by, 24 bbls 12% HC1 w/25% Xylene. Displaced w/30 bbls Diesel. POH. Rigged down. Flowed well. 10/15/88: The Squeeze was performed as follows: MIRU CT & Cementing Equipment. PT equipment to 4000 psi. RIH w/CT and fluid packed wellbore w/seawater. Pumped 30 bbls cement, squeezing perforations: 10211 - 10251' MD Ref. Log: BHCS 6/5/82. 10256- 10266' MD 10269- 10287' MD 10326- 10334' MD Contaminated cement with 105 bbls contaminant. 10/16/88: Cleaned out contaminated cement from WB. 10/30/88: Reperforated: 10270- 10287' MD 10326- 10334' MD Ref. Log: BHCS 6/5/82. Added perforations: 10287 - 10290' MD 10292 - 10296' MD Ref. Log: .BHCS 6/5/82. Returned well to production and obtained valid production test. 12/8/88: Ran Spinner/Pressure/Temperature/Density Logs. Logs indicated that a resqueeze was required. DS 2-24 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR GAS SHUT-OFF 5/4/89: MIRU CTU & Stimulation Equipment. PT Equipment to 4000 psi. RIH w/CT and washed perforations at: 10270 - 10287' MD Ref. Log: BHCS 6/5/82. 10287- 10290' MD 10292- 10296' MD 10326- 10334' MD Pumped the following treatment: 35 bbls 12% HC1 w/ 10% Xylene, followed by, 32.bbls 6-1.5% HC1-HF, followed by 24 bbls 12% HCI. Displaced w/28 bbls Diesel. POH. Rigged down. Flowed well. 5/7/89: The Resqueeze was performed as follows: MIRU CT & Cementing Equipment. PT equipment to 4000 psi. RIH w/CT and fluid packed wellbore w/seawater. Pumped 34 bbls cement, squeezing perforations: 10270 - 10287' MD Ref. Log: BHCS 6/5/82. 10287 - 10290' MD 10292- 10296' MD 10326- 10334' MD Contaminated cement with 90 bbls Bentonite contaminant. Cleaned out contaminated cement from wellbore. POH. Rigged down.. 5/20/89: Reperforated: 10326- 10334' MD Ref. Log: BHCS 6/5/82. 9/18/89: Reperforated: 10270- 10290' MD 10292- 10296' MD Ref. Log: BHCS 6/5/82. Raw gaslifted well to flow. Returned well to production and obtained valid production test. ARCO ALASKA, INC. F'~O. BOX t0~S60 ANCHORAGE, ALASKA 995t0 DATE · 9--27--89 REFERENCE' ARCO CASED HOLE FINAL~ 2-'24 9-- ~ 8-89 COLL. AR/PERF 3-2 9- ~ 5-89 COLLAR/PERT 4-- ~ 9-7 m89 NO I SE 5-i i '?-8-89 S'F'INNEI:~ SURVEY 6-'2t 9-'t 4-'89 CNL-GAMMA 7-27 7-28-89 F'ERF RECORD i i""t 8 '7-24-'89 PERF RECOI~D t t""t 2 7-'2S-89 F'ERF RECORD t t-t 7 9/t t "t 2/89 COL. I...AR/F'ERF' t 2-t 3 9'-t 7-89 COLI_AR/PERF t 4-3t 9-t t-89 COL. LAF(/PE:F(F:' / RUN i, 5" RUN t, 5" RUN t, t" RUN t, 5" RUN t , 5" RUN i , 5" RUN t , 5." RUN i , 5" RUN i, 5" RUN t , 5" R'LJN t , 5" F'LEAS'E 6?IGN AND RETURN 'THE, AT'II'ACHED COPY A.~ RF'CEIF'T OF DATA, A F:' P F.: 0 V E D .!~. ...... 'I"RAN &':~ 8 9 4't',:] ('.)' DISTRIBUTION '"' CENTRAl_ FILES 'If ,i1. ,,- CHIEYRON · Il. ' I " 'l ' · .. E'XTEN$ION EXFI_URAI lC.IN EXXON MARATHON '~ MOBIL · ,-"" F:' !"t I L. L .[ F ,., PB WEEL. L.. F'ILEiS' R & D · .~BF'X '"'... ,~'lr'ATE OF ALASKA ...~" T Fi: X A C C! PRUDHOE BAY FIELD K-VALVE DOME SETTING PRESSURE DATA SHEET Drillsite-Well: 02-24 Date: 8/26/89 Comments: GOR HAS~E UP CONSIDERABLY SINCE LAST I:)ESIC=N. K-Valve should close easily if well is dumped into LP commonline Previous K-valve Settings: Set Pressurer psig Date 570 1 2/1/88 700 12/31/86 Production Data: ROR- 1111 CFR- 6000 Swing Well (very high or Iow GOR) ........... Design Parameters: Design parameters are based on (Mark one of these) xxx Oil Rate Watercut Formation GOR Gas Uft Gas Rate Total GLR Flowing Tbg. Pressure Flow. Wellhead Temp. 5845 0 6732 0 6732 951 121 BOPD @ BOPD @ YES deg. Choke Priority Well .................. Actual Well Test ..... Date of Test ...................... Flowing Press. Survey ...... Date of' Survey ...... Theoretical Rates used with Hydraulics Program If hydraulics program was used to get some of the parameters, mark which program... xxx percent scf/stbo mscfpd scf/stbl psig deg. F Temp. @ SSSV ............. Pressure @ SSSV ....... Pressure Adjustment PH2 PH3 PRUDHYD Other 141 deg. F 1 276 psig 1 00 psig Calculated Dome Set Pressure - 788.0 psig @ 60 deg.F I Actual Dome Set Press. .IFTP at K-valve Closure 790 850 Dsig @.60 deg. F ! Dsig @_ surface I cc: Sennett/Farmer Wikter/Kennedy (2 copies) State of:Alaska cc: D.S. Engnr. D. Lagerlef ATO 1556 D.S. Supvsr. Montgomery / Hurst Prepared by: R. KRAUSE ARCO ALASKA, F'~CI. BOX t()6,36 ANCHORA6E, ALA,~¢K A 995t DAI'E' 5-26-89 REF'ERIENCE' ARCO CASED HOI_E FINALS t --;':5~ 5-'6-89 PROD, F'F;,'OF ]Z[.E/LEAK DEI'EC'I ].ON RI_iN 2-.t t 5-4-89 'f'EHF'/FLUID DEN~'ITY I-~UN 2-24 .5-"~ O- 89,:. COLI_.~R/F EF, F F;,'IJ N. · 3-9 5-~ 8-89 CNL-GAMMA RUN 3-9 5-i8-89 DIFF I'EHP RUN 3-i ~ 5-,~..-.89 IN,JEC'I'~ON I::'RUFII_E RUN S'"i ::~ .5'"'3"-89 INJECTION F:'ROF:'ILE/TE. MF' RLJN ..~'-~-.0-89 CNI_-GAMHA 4 - 2 "" '~ !:;,' U N 4"".5' '5 .... '19-'89 CNL.""GAMMA RUN 4- '? 5- i 9-89 CNL-t~AMMA RUN 4 - t .5 .5 - .5 '"' 89 I N J E C l' .110 N F:' R 0 F' I L F f.,: L.I N ~'. ' "l *'t ..... i" 4-'2e 4- t -89 COI..I_AR/I" I.".I-,F RUN 4-'26 5-' t 8-89 CNL.-GAMMA RUN 5-5 $-29-89 COI_I_AR/F'FI:~!z RUN ..... JI...l_Af./F ERF' RUN 5 i7 S '29-89 Cr , ~''"'"'" ... · · °'l -i '°~ I ' 7-'3() 5 t '?-89 DUAL B~Jk$'l" TDT-P I,,LIq 7 - 3 (') 5 -' t '? '-Iii 9 C N L R LIN .,. · i *'! I ' 9--28 3 3e-.89 COI_I_AR TO ,S'E'IF F'ATCH I-,dN t i i 0 5- t (.)-..Iii'? I_ E A K L F. l E'.- C 1 I ON R LIN t t-..26 5-5-89 INJECT]iON I:'ROFILE/TEMP RUN "I- i8-1 5-8-89 FLUID LEN,~ITY/TEHP I:~UN ......... ., . I~ " "l *" ! ' ' t 8-'~ .:"-8-89 F'I_UID DE. NS I'I'Y/TEMP RUN i iii - 23 S - 26 "" 89 C 0 l. L A R / F' E R F R U N · PLEASE SIGN AND F,:ETURN 'lr'HE ATTACHED COF'Y AS I:;:ECEIF"F OF:' DA'fA. C A H C 0 CAMCO ATLAS A'f LA:.'9 CAMCO CAMCO A fLA;~' ¢~ fL. AS A 'I L A C A H L; CI HL.S A I'L.~,S' HLS SCH S C Fl HLS CAMCO CAMCO C A M C 0 C A H C 0 I-II...S R EE C; E ]: V E D B Y HAVE A NICE DAY! .S'ALL..Y HOFF ......... E C K E R' A'rO-t 529 ka Oil & Gas Cons. 6ommissio~ Anchorage DISTRIBUTION ~ CENTRAL FIL. E~' ~ ~ F'HII_I..I'-f-"$ ,,-'"' CI-IEVRON PB WELl_ F']~L.E.$ D & M I;,' & D · ,,'"'. E"' X T E:N,S' 1. ON EXF:'LORAI" I ON .,.'"' BF:'X '"' EXXON -,,-'"' $'I'A"I'E'." OF" ALA$1(A ... ~..... MARA I'HON ,,."~' 1 E. XA, ~ MOBIl.. ARCO Alaska, Inc./~ Prudhoe Ba~. gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager June 2, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 2-24 Permit No. 82-71 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/TPA/jp Attachment cc: T.B. Gray, BP J. Gruber, ATO-1478 PI(DS 2-24)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C ALASK~¥~ APPLICA STATE OF ALASKA 'L AND GAS CONSERVATION C~ VIISSION , ION FOR SUNDRY APPROVALS 1. ,Type of Request: Abandon ~ Suspend Alter casing Repair well Change approved program 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 Operation shutdown Plugging Pull tubing Variance 5. Type of Well Development :X Exploratory Stratigraphic Service 4. Location of well at surface 1799' FNL, 36' FWL, Sec. 36, T11, R14E, UM At top of productive interval 156' FSL, 1833' FEL, Sec. 35, Tll, R14E, UM At effective depth At total depth 90' FNL, 2020' FEL, Sec. 2, T10N, R14E, UM Re-enter suspended well Time extension Stimulate X Perforate Other 6. Datum of elevation(DF or KB) 64 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 2-24 9. Permit number 82-71 10. APl number 50 - 029-20744 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10515 feet Plugs(measured) 9195 feet Effective depth: measured 10471 feet true vertical ~9154 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 79' 20" 415 sx AS II 79' 79' Sudace 2529' 13-3/8" 27000 sx Fondu & 400 sx PF 'C' 2593' 2593' Production 9628' 9-5/8" 500 sx CI 'G' & 300 sx PF 'C' 9692' 8461' Liner 1114' 7" 360 sx CI 'G' 10512' 9192' RECEIVED Perforation depth: measured 10326-10334' ~UN 0 ~ ~989 true vertical 9024-9031' Jt, laska 0il & Gas Cons. Corrl~issJorl Tubing (size, grade, and measured depth) 5-1/2', 17#, L-80, NPC @ 9373' MD~, ~C~l~gel2.6#, N-80, NPC tail @ 9447' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 9361' MD; Camco Bal-0 SSSV @ 1994' MD 13. Attachments Description summary of proposal x~ 14. Estimated date for commencing operation June 1989 16. If proposal was verbally approved Name of al)prover Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .~'~'/,'~t~/~~~ Title Operations Engineering Manager FOR COMMI.~ION URI= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commissioner ~ Form 10-403 Rev 06/15/88 Detailed operations program BOP sketch x,,, 15. Status of well classification as: Oil ~ Gas__ Suspended , I Approval No. ~ ...-,5,z'~,~.-- ~.pproved CoPY Returned - Commissioner Date SUBMIT IN TRIPLICATE 051 T. P. Allen, 263-4837 Drill Site 2-24 ARCO Alaska, Inc. intends to perform a mud acid treatment on DS 2-24. The treatment will be performed as follows: 1. Obtain a wellhead fluid sample and perform emulsion and sludging tests. Add non-emulsion and anti-sludging additives to pass ARCO's emulsion/sludging tests. 2. MIRU wireline unit. Tag bottom and ensure there are no tubing restrictions and fill is not covering the perforations. 3. Load the 5-1/2 x 9-5/8" annulus with dead crude/diesel and ensure that the annulus is fluid packed. 4. Load 1000 gals of 6% HCl acid and 1000 gals of 6%-1.5% HCI-HF acid with additives. Titrate acid and test'for iron content. 5. Load 1000 gals of 2% NH4CI water, 1000 gals of xylene, 230 bbls of seawater and 250 bbls of dead crude. 6. MI and RU pump trucks, transports and CTU. 7. Load the well with 230 bbis of seawater. Do not exceed 1800 psi and monitor rate and pressure and record it on the ERAD chart. 8. RIH with the CT and set the nozzle at 10325' MD. 9. Pump the following fluids down the coiled tubing at a maximum 4000 psi: A. 1000 gals Xylene 19. 5 0 0 gals 6% HCL w/additives Immediately start pumping down the CT/tubing annulus with dead crude at 3000 psig as the maximum surface pressure. C. 5 0 0 gals 6% HCL w/additives B. 1 0 0 0 gals 6% HCL - 1.5% HF w/additives C. 1000 gals 2% NH4CI water D. 1500 gals Methanol/Water 10. Continue pumping down the CT/tubing with dead crude. After the methanol/water stage, pump a total of 25 bbls to overflush the acid deeper in the perforations. 1 1. POH with CT. 1 2. RD CT and flow well after remedial operations. Obtain a valid well test. RECEIVED IUN o 0 t989 /Uaska Oil & Gas Cons. Commission '" ! ~chorage 6 5 4 3 2 COILED TUB]~Nt3 UNIT BOP E0U l PIE NT 1. ~:)00 PSI ?" WELLHEAD CONNECTOR FLANG£ 2. 5000 PSI 4 '1/16" PiPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS, 4. 5000 PS,I4 1/6" SHEAR RAMS 5. ~ PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 2 ~JUN 0 5 :i989 ska 011 & Gas Cons, Commlaslon Anchorage I,IIRELINE BOP EOUIPHENT 1. 5000 PS,I 7" WELLHEAD CONN£C1OR FLANGE 2. 5000 PSI WlRELINE RAUS (VARIABLE 2,. 5000 PSI 4 1/6" LUBRICATOR .4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager April 13, 1989 C. V. "Chat" Chatterton Alaska 0il & Gas'Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 2-24 Permit No. 82-71 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, DFS/SLW/jD Attachment cc: BP Exploration, Inc. 3. GruSer, AT0-1478 Pi(DS 2-24)W1-3 WELLS3 / 127 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-O £ STATE OF ALASKA AL)L, ,A OIL AND GAS CONSERVATION COMM~'~' ,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation ~hutOown ._. Re-enter suspended well ~ Alter casing m Repair well __ Plugging ~ Time extension m .Stimulate ~ Change approved program __ Pull tubing ~ Variance ~ Perforate '/,, Other ~ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) 3. Address P. O, Box 100360~ Anchorase~ AK 99510 Location of well at surface Development Exploratory Stratigraphic Service kt799 FNL, 36' FWL, Sec. 36 TllN, R14E UN; top of productive interval ' ' 156' FSL, 1833' FEL, Sec. 35, TllN, R14E, UM At effective depth At total depth 90' FNL, 2020' FEL, Sec. 2, T10N, R14E, UM 12. Present well condition summary Total depth: measured true vertical 10515 feet 9195 feet Plugs (measured) 64' RKB 7. Unit or Property name Prudhoe Bay Unit 8. Well number DS 2-24 feet 9. Permit number 82-71 10. APl number 50-- 029-20744 11. Field/Pool Prudhoe Bay Oil Pool Effective depth: measured true vertical Casing ~ngth Conductor 79' Surface 2529' Production 9628' Liner 1114' Pedorationdepth: measured 10270-10290'; 10292-10296'; truevertical 10471 feet 9154 feet Size 20" 13-3/8" 9-5/8" 7" 10326-10334' 8974-8992'; 8994-8998'; 9024-9031' Junk (measured) Cemented Measuredde~h 415 sx AS II 2700 sx Fondu & 400 sx PF 'C' 500 sx Cl 'G' & 300 sx PF 'C' 360 sx C1 'G' ~ueverticaldepth 79' 79' 2593' 2593' 9692' 8461' 10512' 9192' Tubing (size, grade, and measured depth) ~ ': ~.. i~' n cfi0rage' '', 5½", 17~, L-80, NPC @ 9373' MD; 4½", 12.6~/, N-80, NPC tail @ 9447' MD . Packers and SSSV (type and measured depth) Baker SAB Packer @ 9361' MD; Camco Bal-0 SSSV @ 1994' MD 13. Attachments Description summary of proposal '¢J Detailed operations program __ BOP sketch 'i41 Estimated date for c~)mmencing operation ~ 15. Status of well classification as: April 1989 16. If proposal was verbally approved Oil ..~ Name of approver Date approved Service "17. I hereby c..ertify that the foregoing is true and correct to the best of my knowledge. Signed Titleoperations Engineering Manager FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- ~.~ ORIGINAL SIGNED BY Approved by order of the Commissioner LONNIE C. SMITH Gas __ Suspended Approved CoPY Returned Commissioner lapprOval NO, Date SUBMIT IN TRIPLICATE WELLS3/127 S. L. Ward, 265-1305 Form 10-403 Rev 06/15/88 DS 2-24 CTU CEMENT SQUEEZE AFE # AP1107 PRELIMINARY PROCEDURE 1. Make a slickline tag run to verify the PBTD. Perform a fill cleanout. 2. Surge the well with slickline surge tool set in the tubing tail. 3. RIH with coiled tubing and acid wash the perforations with mud acid. 4. RIH with coiled tubing and fluid pack the wellbore with filtered seawater. 5. Pump 30bbls of cement followed by 2 bbls of water and 60 bbls of contaminant. Hold 1500 psi surface squeeze pressure for 60 minutes. Squeeze off the following perforations: Zone Perforations 2 10270-10290 2 10292-10296 2 10326-10334 ( Ref.: BHCS 6/5/82) 6. Jet or reverse out the contaminant. 7. Perforate as follows: 2 2 2 Perforations 10270-10290 10292-10296 10326-10334 8. Test the well and return to production. SPF FSD FSD FSD ( Ref.: BHCS 6/5/82) Well Information Current status: Producing Expected static bottomhole pressure: 3720 psi @ 8800' SS Expected fluid in wellbore at reperforation: seawater ,5 4 2 COILED TUB/~N0 UNIT BOP E0U ! PllENT 1. ~:)00 PSI 7" WELLHEAD CONNECTOR FLANGE: 2. 5000 PSI 4 1/16" PIPE RAIDS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAIDS 6. 5000 PSI 4 1/16" STUFFING BOX HI, RELINE BOP EOUIPME. NT 1. 5000 PSI ?" WELLHEAD CONN£C'I'OR FLANGE 2. 5000 PSI WIRELINE RAUS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF ARCO ALA£KA, INC. P.O~ BOX JOe3&O ANCHORAGE, ALASKA DATE: 'J-6-87 REFERENCE: ARCO CASED HOLE FINALS 2-6 J2-JJ-88 PRODUCTION PROFILE 2-7 J 2-9-88 PRODUCTION PROFILE 2-J3 J2-J8-88 PRODUCTION PROFILE 2-20 J 2-7-88 PRODUCTION PROFILE 2-2~ J2-J2-88 PRODUCTION PROFILE 2-24 J 2-8-88 'PRODUCTION PROFILE 4-J9 ~2-J0-88 INJECTION PROFILE 7-J(} ~ 2-J 8-88 PRODUCTION PROFILE J2-JJ J2-J7-88 PRODUCTION PROFILE J 2-J 9 J 2-J 9-88 INJECTION PROFILE J4-28 J2-8-88 LEAK DE,TECTION SURVEY HAVE A NICE DAY! ..... S AL L Y HO F F E C K Alaska Oil & Gas Cons. Commission ' ',-., ~chorage ATO- ~ 529 ' TRANS ~890~ APPROVED _~___ DISTRIBUTION RUN RUN RUN ~, 5' RUN J, 5" RUN J, 5" 'RUN RUN ~, 2"&5' RUN RUN J, 5" RUN RUN CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CENTRAL FILE£ CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIP£ F'B WELL FILES R & D SAF'C STATE OF ALASKA TEXACO PRUDHOE BAY FIELD K-VALVE DOME SETTING PRESSURE DATA SHEET Drillsite-Well: 02-24 Date: 12/16/88 Comments: INITIAL DESIGN. Post GSO squeeze and reperf. K-Valve should close easily if well is dumped into LP commonline Previous K-valve Settings: Set Pressure~ psig Date 700 12/31/86 Production Data: ROR = 1626 BOPD CFR = 1651 BOPD Swing Well (very high or Iow GOR) ........... No Design. Parameters: Design parameters are based on (Mark one of these) XXX Oil Rate Watercut Formation GOR Gas Lift Gas Rate Total GLR Flowing Tbg. Pressure Flow. Wellhead Temp. 1852 7 4763 0 4446 814 94 @ 5 0 deg. choke @ 51 deg. choke Choke Priority Well .................. Actual Well Test ..... Date of Test ...................... Flowing Press. Survey ...... Date of Survey ...... Theoretical Rates used with Hydraulics Program If hydraulics program was used to get some of the parameters, xxx PH2 mark which program... BOPD percent scf/stbo mscfpd scf/stbl psig deg. F PH3 PRUDHYD Other Temp. @ SSSV ............. 118 deg. F Pressure @ SSSV ....... 922 psig Pressure Adjustment 1 00 psig Calculated Dome Set Pressure = 571..~ 0 . psig @ 60 deg. F IActual Dome Set Press. FTP at K-valve Closure 570 714 psig @,60 deg. F psig @. surface cc: Sennett / Zibell Wilder / Kennedy (2 copies) State of Alaska cc: D.S. Engnr. D. La.qerlef ATO 1556 D.S. Supvsr. Montgomery / Hurst Prepared by: A. Brooks PRB #15 ARCO ALA~.., INC. F'. 0. BOX i '>}':DS6~.D · ,..~.~ ,~,,,.,-~GE, ALA~KA ~'~, DATE' i2-9-88 F'LEASE ARCO CASED HOLE FINALS -S0-88 CNL RUN 4: 5" ~' ..CIO !-'!]1 /AR'/""" ' .... ' ,.~ u -_,--._ ~. ............ r ERF RU.:.'w '~ , -3A-88. CNL R",ut-4 .... i , : -,T,.n-88.., COLLAR/F'ERF F;,'Uk~.. '~.:.,';'" -4--88 COLLAR/F'ERF RUN t, 5" -o-o,:: COLLAR/PEF:F F:.UN i , 5" -,:--',-~8 CN~ -GAMMA F;.:UNi , 5-'" _.-")4 _,::,o F".,'"~ ! ~F.'/.r:,r.:'r-'.,i-- :.':".'.:UNt., ~" .,.' --2-°°,..,,., C~]~'~ ,_ ,... .-~/'~ E'/F'EF;;F, RUN. . 1 , =*'-," -i-R8 C.NI_-I]AHHA.::.,* PiT'"~'., RIIN.. . t, -,~'~'" "Z i - .....8 COI_LAR/PIERr-' RUN5' I &"~ · ..,¢ J -' ,~ -.2-:.--:P, CNI. _ RUN i, ..,.'"~'" N AND RE"f'UI;'.N THE ATTACHi"-D COF'Y A3' RECEIPT OF-- DATA. R-F:r:'- E' L-.._.~J.V .D BY ...... HAVE A NICE DAY! .--~ ~ ....... I"i F'F'ECKER ATO .... i 529 .. TRANS ~887(-') t ~ AF'F'ROVED DISTRIBUTION '5' I~. CENTn'AL. FILES · ,-'"' CHtEVRON D & H · ~¢ EX'f'EN;'.~' I CJN F:XF'LOI:;.:A'f' I ON ~ E:XXON HARA'T'I-iON ~ HOBIL $': .I:':' I'-t I L.L. I F'5' F'B .WELL FILE2 R & D :~- $ A F' C ~ ~"f,'ATE OF' ALA;'£KA · ~"*T E X A C 0 ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager August 22, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 2-24 Permit No. 82-71 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/DMF/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 P1 (DS 2-24)W1-3 WELL S 3 / 16 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing ~ Amend order [] Perforate ~ Other 2. Name of Operator ARCO Alaska ~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1799' FNL, 36' FWL, Sec. 36, TllN, R14E, UM At top of productive interval 156' FSL, 1833' FEL, Sec. 35, TllN, R14E, [TM At effective depth At total depth 90' FNL, 2020' FEL, Sec. 2, Ti0N, Ri4E, UM 11. Present well condition summary Total depth: measured true vertical 10515 feet 9195 feet Plugs (measured) Effective depth: measured 10471 feet true vertical 9154 feet Casing Length Size Conductor 79' 20" Surface 2529' 13-3/8" Production 9628' 9-5/8" Liner 1114' 7" Junk (measured) Cemented 415 sx AS II 2700 sx Fondu & 400 sx PF 'C' 800 sx C1 'G' 360 sx C1 'G' 5. Datum elevation (DF or KB) 64' m<3 6. Unit or Property name Prudhoe Ba7 Unit 7. Well number DS 2-24 feet 8. Permitnumber 82-7] 9. APInumber 50-- 029-20744 lO. Pool Prudhoe Bay Oil Pool Measured depth WueVerticaldepth 79' 79' 2593' 2593' 9692' 8461' 10512' 9192' Perforation depth: measured 10211-10251'; 10256-10266'; 10269-10287'; true vertical 10326-10334' 8921-8957'; 8962-8971'; 8974-8990'; 9024-9031' Tubing (size, grade and measured depth) 52" 17# L-80 NPC @ 9373' MD 2 , , , Packers and SSSV (type and measured depth) Baker SAB Packer @ 9361' MD; Camco Bal-0 SSSV @ 1994' 12.Attachments Description summary of proposal [] Detailed operations program [] 13. Estimated date for commencing operation August 1988 14. If proposal was verbally approved Name of approver Date approved 15. I hereby~ertify th/~ ~~true and correct to the best of my knowledge Signed ,~_~-~~ Title Operations Engineering Manager Date Conditions of approval Approved by Commission Use' Only Notify commission so representative may witness I Approval ~ Plug integrity [] BOP Test [] Location clearance &pproved Copy Returned -ORIGINAL SIGNED BY tONNIE C. SMITH '-- by order of Commissioner the commission Date Form 10-403 Rev 12-1-85 WELLS3/16 D. M. Fife, 263-4278 Submit in triplicate DS 2-24 CTU Cement Squeeze AFE# 797961 Preliminary Procedure 1. Make a slickline tag mn to verify the PBTD. Perform a fill cleanout. 2. RIH with CT. Perform an acid stimulation of the perforations with full strength mud acid. Flow well to produce out all the acid. 3. Surge the well with the slickline surge tool set in the tubing tail. 4. RIH with coiled tubing and fluid pack the wellbore with f'fltered seawater. 5. Pump 30 bbls of cement followed by 2 bbls of water and 60 bbls of contaminant. Hold 1500 psi surface squeeze pressure for 60 minutes. Squeeze off the following perforations: Zone Perforations 2 10211-10251 2 10256-10266 2 10269-10287 2 10326-10334 (Ref.: BHCS 6-5-82) 6. Jet or reverse out the contaminated cement. 7. Perforate as follows: Zone Perforations SPF 2 10269-10289 FSD 2 10326-10334 FSD (Ref.: BHCS 6-5-82) 8. Test the well. If the well will not flow, add the following contingency perforations: ..Zone Perforations SPF (Ref.: BHCS 6-5-82) 2 10256-10266 LSD Other Well Information: Current status: On production. Expected static bottomhole pressure: 3720 psi. @ 8800' SS Expected fluid in wellbore at reperforation: seawater. 6 .4 2 COILED TUBI. Nt3 UNIT BOP EgU l P.E NT 1. 5000 PSI ?" W[LLHr. AD CONNECTOR FLANGE 2. 5000 PSi 4 1/16" PiPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SH£AR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUrrlao Box H]REL]NE BOP EQU]PHENT 1. 5000 PSI ?" W[LLH[.,I~ CONNECTOR IrLANGI 2. 5000 PSI WIR[LIN[ 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUB[ PACK-OFF hi. h,.~l< h, ! 14[', . ~flTE: 4-2~-RR RFt::'E:RENCE: ~R'C,O na..~ED HOLE F.TN~I... ~-I? 4-t 7-8R 4- t 7-RR F:'Rr. lh, F:'F;.'F:I..E'/F'I...IITD DE:N,~TTY/TFiMF' PETII~.. PRF'I F./FI.II.TD DF.N,~'TTY/TE. MP . TFMF'F!~RAI'IIRr-. ,~F'TNNF!'E' RIIN t, R'IJN t , .5 · I'RAN..S' APPROVED D .T .~TR.T..RI IT T ARCO Alaska, Inc· F'.O· Box 100360 Anchormge, ALmska 99510 I.~TE Dece~,;ber t i, t986 REFERENCE' ARCO Cased HoLe Final ~ 2-1c.~_ tt-~',-,.,_°,4 CNL/GR Mu L+ i =.?pace. '~ 2-24 ~t-?-86 E:NL,:GR Mul~i=Z. pace Z~-.8 t t-t E)-.-86 Gamma Ray "~3-t 7 J ~3'~-86 F'FC Log R.'btn i ~ q''_, F.'. u n t, Dr e.s~ Dr I)re~ Dress DISTRIBUTION of data. Cen±raL FiLes ~ PhiLLips Chevron_ c'=', ~. We' L~ Fi Le~ D&H R&D Ex~nsion,. _ ExpLorations. ~ Sohio Exxon $ $~ate of ALaska Marathon ~ Texaco Mobil ARCO ~La.s'ka, Inc~ Ant:Jior'~g e, A [ a !; I,' ~':'~ I)AI'E: I)ec:ember 8 , i986 .... · Al-,, .., 0 M a .ct n e i' i c T a p e.'s' w / I. i .s' i' i n g REFERENCE "'r' · i - 6" i i .... i,.,~'" · o.., ,.)/' H a g t a p e E. C C .,- ,-...> 64 P D I< - i - Z "' ,:,,.) H a g a p e ,~. ,:.4 ' t t "' ('r~ T I:.{.,C 5-5 · i l -i S-86 Magi'ape E:CC~:2562 PDK-i 0(.) D'r'e.:z' c. r, r, ~.-~,:r.., 8 C H C 7--i 4' i i -. t 4-86 Mag ~alr, e ,...,.,,.,,.~...,, ~ N I)~ ...... e · :~ - '~ · .1~, ~ m~' 7'-2''>' ~ t -i 4---B6 Hag '{'ape J::.[,C~,.~..- c'<', r'.,.-~ ~' "z ") C H C N D r e ~' z' '7....2Z~- 9....8-P~...,~., Hagtape ~..u,,.,-,.,~...,~,~.. i 8 .... t,1' t i .... 4..-.86 Hag 'tape ECC:~:25S7 01..I I)r'ez'z' i8-.i9, i() .... i8'"-86 Hag!'ape E:CC l' I::,' A N $ '"'-.- oC> c,: ,~,° ~0 5 o i" d a i' a, D I S 'T R I B U T I 0 N ARCO Alaska, Inc. ! Prudhoe Bay'~r..,~gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager November 17, 1986 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Re' DS 2-24 Permit No. 82-71 Enclosed is the "Subsequent" Sundry Notice detailing work completed on the above-mentioned well. Very truly yours, DFS/MRM/sd Enclosures cc: Standard Alaska Production Company File: PI(DS 2-24)Wl-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COM ,¢ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] Add Perforations 2. Na.m~e,e,,,of .O, per{~tor 5. Datum el~z~e~ti~r~l~DF or KB) AKt. U AlaSKa, Inc. Feet 3. A~ress 6. Unit or Pl~ue(~o~ar~y Un i t vos~: Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 1799' FNL, 36' FWL, Sec. 36, T11N, R14E, UN At top of productive interval 156' FSL, 1833' FEL, Sec. 35, T11N, R14E, UM At effective depth At total depth 90' FNL, 2020' FEL, Sec. 2, T10N, R14E, UN 11. Present well condition summary Total depth: measured 10515 feet true vertical 9194.6 feet Plugs (measured) 7. Well number DS 2-24 8. Approva16ngU6~%%r 9. APl num~rg_20744 50-- 10. Pool Prudhoe Bay 0il Pool Effective depth: measured 10412 feet true vertical 9102 feet Junk (measured) Casing Length Structural Conductor 79 ' Surface 2593' Intermediate Production 9692' Liner 1114' Size 20" 13-3/8" 9-5/8" 7" Perforation depth: measured (BHC$ 6/5/82) true vertical (SS) Tubing (size, grade and measured depth) 5½", 17#, L-80 Plastic Coated Packers and SSSV (type and measured depth) Cemented Measured depth True Vertical depth 415 sx 79' 79' 3100 sx 2593' 2592.9' 8OO SX 360 SX 10212'-10252' 10257'-10267' 8857' -8893' 8897' -8906' Camco BAL-0 SSSV @ 2103'MD; Baker SAB Packer @ 9374' 12. Stimulation or cement squeeze summary 9692' 8460.6' 9398'-10512' 8203'-9192' 10270'-10288' 10326'-10334' (Add Perfs) 8909'- 8925' 8959'-8966' (Add Perfs) Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oii-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 2902 2009 0 9-5/8"-~80; 13-3/8"-+ 743 2632 2023 0 9-5/8"-180' 13-3/8"-+ 737 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed RevP~. 1; - Form 10-404 - MRM (265-6872) Title 0peration~s Engineerin9 Manager Date Submit in Duplicate SUMMARY OF OPERATIONS On November 7, 1986, perforations were added to the current 2-24 completion interval. Dresser Atlas performed the job using a 3-3/8" tool wi th Jumbo Jet Kone shots. The perforated interval was from 10326'-10334'MD (Ref: BHCS 6/5/82). The shot density and orientation used were 4 spf and 120°, respectively. ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telepho.ne 907 276 1215 Date: July 24, 1985 Reference: ARCO CH Finals . .... 9-16 Spinner 7-10-85 9-17 Spinner 7-10-85 13-22 Spinner §-26-85 13-23A Spinner 7-11-85 13-23A spinner 6-26-85 Run 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" DA Otis Otis Otis Otis Otis Please sign as receipt of data. Received by, Pam Lambert ATO 1429C JOL29~-~-~ ~ ,:,ia,:,~,~ ~ & 6;as Corls. ColTimiss|orl ~nchorage Trans 223 ~ron D&M Expl. Services Ext. Exploration ~,xon Marathon PB Well Files R&D SOhio 3~a~ ~. Alaska Texaco ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: June 5, 1985 Reference: ARCO Magnetic Tapes 2-24. CNL 5-12-85 4-31 OH 5-16-81 #ECC 2170 # 70431 Please sign as reciept of data. Received by Pam Lambert ATO 1429C Trans 137 *****EXTENSION EXPLORATION ONLY WILL RECEIVE OH MAG TAPE.***** Chevron D & M Phillips Expl. Services PB Well Files Ext. Exploration R & D Exxon Sohio MaraChon .$~:~el of Alaska Mobil Texaco ARCO Alaska, Inc. Post Otf~ce Box 100360 Anchorage. Aias~a 99510 Telephone 907 276 1215 Date: June 5,1985 Reference: ARCO CH Finals 1-17 Neutron GR 5-17-85 Neutron GR 5-12-85 3-12/ Spinner 5-9-85 4-12'-'~ Neutron GR 5-13-85 15-1/ Neutron GR 5-16-85 / 15-3 Spinner 5-11-85 Run 4 5" DA 1 5" DA 1 5" GO 1 5" DA 1 5" DA 1 5" Otis Please sign as receipt of data. Received by Pam Lambert. ATO 1429C Trans 141 D& M Expl. Services Ext. Exploration Exxon Marathon M~biI Phillips PB Well Files R & D Sohio '~'S~a~e of Alaska Texaco ARCO Alaska, Inc('~ Prudhoe Ba'¥ Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer September 19, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: DS 2-24 Permit No. 82-71 Dear Mr. Chatterton: Enclosed is an "Intention" Sundry Notice detailing work proposed on Drill Site 2-24. Very truly yours, D. F. Scheve Regional Engineer DFS/JCD/la Attachments cc: Sohio Petroleum Co. Well File 100.0 ARCO Alaska, Inc. Is a Subsidiary of AflantlcRIchfleldCompsny STATE OF ALASKA ALASKI[i' .~IL AND GAS CONSERVATION (](' vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL EK OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-71 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20744 4. Location of Well 1799' FNL, 36' FWL, Sec. 36, TllN, R14E, UM (Surface) 156' FSL, 1833' FEL, Sec. 35, TllN, R14E, UM (Top Prod) 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 2-24 90' FNL, 2020' FEL, Sec. 2, T10N, R14E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 64' RKB I ADL 28308 11. Field and Pool Prudhoe Bay Field PrudhOe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other E~x Pulling Tubing [] 12. (Note; Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc..intends to replace the surface controlled subsurface safety valve in D.S. 2-24 with an Otis Type K, ambient type tubing safety valve. This valve is a normally,closed type with a preset dome charge. The valve uses a plunger and seat for its seal and closes when flowing tubing pressure drops below the preset dome pressure charge. Pressure must be applied to the tubing from the surface to reopen the valve. This change is necessitated by the loss of both surface control lines to the valve which.was previously in place. Well 2-24 is completed with 5%" tubing and presently produces with a capacity of 2900 BOPD at a tubing pressure of 800 psi. Its producing GOR is 600 scf/STB. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed V~'~'~_ _,~ 3 ~ The space below for Commission use Conditions of APproval, if any: ORIG,NAL SlINEil Title Approved by BT LONNIE C. $111'1'11 · Regional Enqineer Date ~/~$ Approved C.~p)~JlI~ ~ Returned - - - ~- BV Order of ~ _~Z.__~_3 COMMISSIONER the Commission Date _~ ..... Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Post Otlice Box 360 Anchorage. Ala~" 99510 Telephone 907 . .,637 June 23, 1983 Reference: Arco Cased Hole Finals D.S. 1-25-°' 3-14-83 D.S. 2-19{/' 3-26-83 D.S. 2-21'-' 3-27-83 D.S. 2-23~,. 3-25-83 D.S. 2-24;,./ 3-23-83 D.S. 2-25' 3-23-83 ~.S. 2-26L. 3-24-83 D.S. 6-9' 3-3-83 D.S. 6-22~" 4-29-83 D.S. 13-2A~-J'3-1-83 D.S. 13-12,-~ 3-3!-83 D.S. 13-22- 3-20-83 D.S. 13-98:' ....... 3-17-83 D.S. 14-26 / 2-27-83 ACBL/VDL/GR/Signature PLS/$pinner PLS/PBU-Spinner PLS/PBU-Spinner PLS/Spinner PLS/Flowmeter .PLS/PBU-Spinner DDTNLL/GR - - . CCL & Perf Record ACBL/VDL/GR/Signature PLS/$pinner PLS/Temp/Spinner/Flovaneter/HP/GR GR. DDTNLL/GR Run 1 5" DA Run 1 5" DA Run 1 5" DA Run 1 5" DA Run 1 5" DA Run 1 5" DA Run 1 5" DA Run 2 5" DA Run 1-3 5" GO Run 1 5" DA Run 1 5" DA ' Run 1 5" DA Run 1 5" DA Run 1 5" DA e sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429D 'Trans. # 385 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON .. MOBIL GETTY D&M STATE OF ALASKA DALLAS CAROJ--~NE SMITH , ? , ', .! ARCO Alaska, Inc. (" Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer . May 25, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive AnchOrage, Alaska 99501 Dear Mr. Chatterton: Re: D.S. 2-20 Permit No. 82-29 ~~~ Permit No. 82-71 D.S. 2-25 D.S. 14-6 D.S. 14-9B D.S. 14-11 D.S. 14-22 D.S. 14-26 D.S. 14-28 D.S. 14-29 Permit No. 82-96 Permit No. 78-65 Permit No. 82-34 Permit No.. 80-131 Permit No. 82-75 Permit No. 81-110 Permit No. 82-12 Permit No. 81-168 Enclosed are Completion Reports for work done on the above- mentiOned wells. Very truly yours, D. F. Scheve DFS/JCD/cl Enclosures cc: Sohio Petroleum Co. RECEIVED JUN t ,983 Alaska 0il & Gas Cons, C0mmissio~. Anchorage ARCO Alaska. Inc. lJ · Subsldlary ,~! Atl~tlcR!chfletdCompany WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVlCE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-71 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20744 4. Location of well at surface 9. Unit or Lease Name 1799' FNL, 36' FWL, Sec. 36, TllN, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 156' FSL, 1833' FEL, Sec. 35, TllN, R14E, UM 2-24 At Total Depth 11. Field and Pool 90' FNL, 2020' FEL, Sec. 2, T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 64' RKB ADL 28308 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 05/23/82 06/05/82 06/14/82I N/A feet MSL 1 17. TotalDepth(MD+TVD) 18. Plug Back Oepth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set 121. Thickness of Permafrost 10515'MD,9194'TVD 10471'MD,9154'TVD YES ~x NO [] nipple @199fe4etMD/ 1900' (approx) 22. Type E. lect.ric or Qther Logs .Run . . DIL/SP/BHCS/GR, FDC/CNL/GR/Cal, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20:: 9i. 5¥~ H-40 Surf. 1'3-'3/~' 72.0~ L-SO ~ur~. 2593' 17%" 2700sx Fondu & 400 sx ]'ermafrost C ~-5/8" 47.O~ L-80~ Surf. ~gz' 12k" 5OOSx ulass G ~ 300 s:[ Ferma~rost C 300-95 /" z~.o~ L-Bu 9398; 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) 10212'-10252'MD 4spf 5-~" 9447' 10257 ' -10267 'MD 10270 ' -10288 ' MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8921' '8989'TVD ~ " 'N/A Ref: BHCS 6-5-82 , , 27. PRODUCTION TEST Date First Production 1-29-83I Method of Operation (FIowingr gas lift, etc.) Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 3-28-83 12.3 TEST PERIOD ~ 1949 655.0 65 59 553 Flow Tubing . Casing Pressure CALCULATED OIL-BBL GAs-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 790 ~ N/A 24,HoUR RATE I~. 3658 2023 140 25.7 28. cORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 ,~," Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Top Sadlerochit G/O Contact O/W Contact Base Sadlerochit MEAS. DEPTH 9826' 10042' 10375' 10416' TRUE VERT. DEPTH 8578' 8769' 9068' 9105' Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/^ 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 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 ~°r only the interval repor:~ed 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- ~,ji~'t'~on, GaS'r'~jection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". · .~. ~, Form 10-407 ARCO Alaska, Inc. [, J Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 2, 1983 Mr. C. V. "Chat" Chatterton State of Alaska DivisiOn of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 2-20 DS 2-24 DS 2-25 DS 14-22 DS 14-28 Permit No. 82-29 Permit No. 82-71 Permit No. 82-96 Permit No. 82-75 Permit No. 82-12 Enclosed are the Completion Reports for work done on the above-mentioned wells. Very truly yours, D. F. Scheve Regional Engineer DFS/JCD/lmi Enclosures cc: Sohio Petroleum Co. WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Welt Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc .... 82-71 3. Address 8. APl Number P.O. Box 100360~ Anchorage~ Alaska 99510 - . 50- 029-207M+ : .... 4. Location of well at surface 9. Unit or Lease Name 1799' FNL, 36' FWL, Sec. 36, TllN, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 156' FSL, 1833' FEL, Sec. 35, TllN, R14E, UM 2-24 At Total Depth 11. Field and Pool 90' FNL~ 2020' FEL~ Sec. 2~ T10N~ R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 64' RKBI ADL 28308 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore I 16. No. of Completions 05/23/82 06/05/82 06/14/82 N/A feet MSL 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 10515'MD,9194'TVD 10471'MD,9154'TVD YES [~ NO [] nipple @199~et MD 1900' (approx) 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL/GR/Cal, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 9i.b~ ~-40 ~ur~. 79' 36" 415sx AS 11 13-3/8' 72.04A L-80 Surf. 2593' 17½" 2700sx Fondu & 400 sx Permafrost C 9-5/8" 47.'04A L-80& Surf. 9692' 12~" 500sx Class G & 300 s~ Permafrost C S00-95 7" 29.0# L-80 9398' 10512' 8½" 360sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 10212 ' -1025 2'MD 4spf 5-½" 9447 ' 9347 ' 10257 ' -10267 'MD . 10270'-10288'MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH .INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8921' -8989'TVD N/A Ref: BHCS 6-5-82 27. PRODUCTION TEST Date First Production .. '1 MethOd Of Operation (Flowing, gas lift, etc.) 1-29-83 I Flowing Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OI L RATIO 3-28-83' 12.3 ' TEST PER'IOD I~ ' 1949 655.0 65~ 59 553-- Fiow Tubing Casing Pressure CALCULAT.ED ..~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press." .790 N/A' 24-HOUR RATEI~ 3658 '"' ' 2023 '~' 140 25.7 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None .. . RECEIVED · Alaska 0~l Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE i NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ,, , Top Sadlerochit 9826' 8578' N/A G/O Contact -.10042 ' 8769' · O/W Contact 10375' 9068' Base Sadlerochit 10416' 9105 ' 31 LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed_'~..'?~2~_.._ ~,~.~ t_~%~ Title Regional Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is cOmpleted for separate production from more than one interval (multiple completion), so state .i;n item 16, and in item 24 show the producing intervals for oply 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 ARCO Alaska, Inc. Post Office B~~''~ ;60 Anchorage, Alaska 99510 Telephone 907 277 5637 February 11, 1983 Reference: Arco Pressure Data D.S. 2-19 1-28-83 D.S. 2-20 1 .-28-83 'D.S. 2-21 1-29-83 D.S. 2-23 1-30-83 D.S. 2-24 1-30-83 D.S.-2-25 1-31-83 Static Survey Static Survey Static Survey Static Survey Static Survey Static Survey GO GO GO GO GO GO P~lease sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 Trans. # 126 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D &M STATE OF ALA~~ DAL LAS CAROLINE SMI t~'~,,~, "'.-' L,"., ARCO Alaska, Inc. Prudhoe Ba~ gineering Post Office E,',.,x 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer February 10, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska .99501 Dear Mr, Chatterton: Re: D.S. 2-19 D.S. 2-20 D.S. 2-21 D.S. 2-23 D.S. 2-24 D.S. 2-25 D.S. 2-26 Permit No. 81-186 Permit No. 82-29 Permit No. 82-45 Permit No. 82-120 Permit No. 82-71 Permit No. 82-96 Permit No. 82-107 Attached are "Subsequent" Sundry Notices detailing work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/TKKW/kn Attachments cc: Sohio Petroleum RECEIVED FEB1 4,1 &3 Nas~'0il & Gas Co~s, C0mmissio,~ A~chorag~ ALASKA iL AND GAS CONSERVATION C ,,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE L LX[~ OTHER [] 2. N~d60~~a' Inc. 7. Pe~t_~ 3. A~.r~s. BOX 360 Anchorage Alaska 99510 8'APl~-~be~0744 ' ' 50- 9. Unit or Lease Name Prudhoe Bay Unit 4'L~a]t~6J'°f:~l~, 36' :FWL, Se(:::. 36, T11N, :R14E, UM 156' FSL, 1833' FEL, Sec. 35, TllN, R14E, UM 90' FNL, 2020' FEL, Sec. 2, T10N, R14E, UM 10. Well Number DS 2-24 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Desi_qnation and Serial No. 64' RKB ADL 283~8 12. Check Appropriate 8ox To Indicate Nature of Notice, Report, or Other Data 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~[ Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 fOr each completion.) [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work for Abandonment see 20 AAC 25.105-170).. . Bega~ perforation operations 1/28/83. Pressure tested tree, casing and wireline perforating equipment. Perforated 10212'-10252' (40') MD, 10257'-10267' (10') MD, 10270'-10288' (18') MD (Ref: BHCS 6/5/82) with 4 shots per foot 120° phasing. Well cleaned to tank and then flowed to flow station. Ran static pressure survey after 26 hour shut-in. Ran, set, and tested SSSV and installed and tested tree cap 1/31/83. RECEIVED FEB t. 4 1983 Alaska 0it & Gas Cons. Commission Anchorage 14. I hereby cej~ify that the foregoing is true and correct to the best of my knowledge. ~. ~,. ~/~~~ Regional Engineer Signed ............. Title The space below for Commission use Conditions of Approval, if any: Date By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" i n Duplicate ARCO Alaska, Inc. Bay < neering Prudhoe Post Office Bo~( ,~60 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer January 11, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Re' D.S. 2-19 Permit No. 81-186 D.S. 2-20 Permit No. 82-29 D.S. 2-21 Permit No. 82-45 D.S. 2-23 Permit No. 82-120 D~S'~ 2-24~ Permit No. 82-71 D.S~ 2-25 Permit No. 82-96 D.S. 2-26 Permit No. 82-107 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/TKKW/1 mi Attachments cc' Sohio Petroleum RECEIVED JAN 1 21983 Alaska Oil & Gas Cons. COITIITIJ,SBjOri Anchorage. ARCO Alaska, Inc, Is a Subsidiary of AtlantlcRIchlleldCompany '~AC STATE OF ALASKA (~' ALASK IL AND GAS CONSERVATION C ivlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~( OTHER [] 2. Na o_f_Op~r_ator. 7. Permit No. ~CU Alaska, Inc. 82-71 3. Address 8. APl Number P.O. Box 360, Anchorage, Alaska 99510 50- 029-20744 4. Location of Well 1799' FNL, 36' FWL, Sec. 36, T11N, R14E, UM 156' FSL, 1833' FEL, Sec. 35, T11N, R14E, UM 90' FNL, 2020' FEL, Sec. 2, T10N, R14E, UN 5. Elevation in feet (indicate KB, DF, etc.) 64' RKB 6. Lease Designation and Serial No. ADL 28308 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 2-24 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. (Submit in Triplicate) Perforate FXIX Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate selected intervals within the Sadlerochit Sand for production from the Prudhoe Bay Unit. Upon perforating, the well will be flowed to the flow station for clean-up and production. Should additional drawdown be necessary to unload the wells, it may be flowed to a tank for initial clean-up. The perforated intervals will be given in the subsequent report. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the ~conclusion of the perforating and clean-up operation. Proposed Perforation Intervals- Ref' BHCS 6/5/82 10212-10252' 40' MD 10257-10267' 10' MD 10270-10288' 18' MD R£C£1vE9 Alaska Oil & Gas Cons. Anchorage 14. I hereby certify that the,~oregoing is trUe and correct to the best of my knowledge. Signed .......... Title Regional Engineer The space below for Commission use Date Conditions of Approval, if any: Approved by COMMISSIONER Approved Copy Returned _~_1 , .... By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports"in Duplicate ARCO Alaska, Inc. Post Office B~x 360 Anchorage,( ,ka 99510 Telephone 90~ 277 5637 September 21, 1982 Reference: Arco Open Hole Final D.S. 2-24 6-5-82 CPL/Cyberlook Run i 5" ase sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 Trans. # 483 DISTRIBUTION NORTH GEOLOGY R&D DRILLING pHILLIPS SOHIO MARATHON CHEVRON t,J.~.sk~ O~J & EXXON MOBIL GET~ D&M GEOLOGY STA~ OF A~S~ Anchorage, Alaska 99510 " ' 277 Telephone 5637 · August 10, 1982 Reference: Arco Magneti'c Tapes w/Listings *D. S. ~2,24 D.S. 13-33 6-5-82 ACC-65160 8-1-82 ACC-65404 * This tape is a replacement tape, please discard the one previously sent. . Please sign and return the attached copy as receipt of data. Kelly McFarland Trans. # 368 DISTRIBUTION NORTItGEOLOGY R&D DRILLING PMILLIPS MARATHON CHEVRON EXXON MOBIL GETTY D&M. GEOLOGY ARCO Alaska, Inc. is a subsidiary of AllantlcRictHieldCompany ARCO Alaska, Inc. Post Office Box 360 Anchorage, Al ~ 99510 Telephone 907 ~_. ! 5637 August 10, 1982 Reference: Arco Open Hole Finals D.S. 13-22 D.S. 13-24 D.S. 13-25 6-7-82 Geodip w/listing Run 1 2" 5-17-82 Geodip w/listing Run 1 2" 7-2-82 Geodip w/listing Run 1 2" DL~' 12-24':~ 6-5-82 BHCS Run 1 2" D.S. 2-24 6-5-82 BHCS Run 1 5'" D.S. 2-24 6-5-82 Density/Neutron (Raw) Run 1 5" D.S. 2-24 6-5-82 Density/Neutron (Poro) Run 1 5" D.S. 2-24 6-'5-82 DIL/GR Run 1 2" D.S. 2-24 6-5-82 DIL/GR Run 1 5" Sc Sc Sc Sc Sc Sc Sc SC ~~Please sign and return the attached copy as receipt of data. Kelly McFarland Trans. # 364 D]~STEIBUTION NORTqt GEOLOGY R&D- DRILLING PHILEIPS . MARATHON CHEVRON ARCO Alaska, Inc. is · subsidiary of AtlanticRichlleidCompany EXXON. MOBIL GETTY D&~ GEOLOGY Alaska Oil & Gas Cor~s. Coirtt~lssic,;-i Anchorafi~ ARCO Alaska, In~,~ , · Post Offic( ,x 360 Anchoragev Alaska 99510 Telephone,90T 277'5637' July 27, i. !982 Reference; ARCO DIRECTIONAL DATA North Prudhoe Bay St. #2 5/31'/82 Gyroscopic Job No. Boss-16040 D.S.2-24 6/14/8Z Gyrosopic Job No. Boss-16057 Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 306 DISTRIBUTION DRILLING · , ~]~S:~?~ .~::~0~.. _ ARCO Alaska !nc. is a Sub',.c'ary of Attan!icRichfieidCom~any ARCO Alaska, Inc. Post Office ~,~ ~'~60 , Anchorage, _a 99510 Telephone 907 277 5637 July 14, 1982 Reference: ARCO CASED HOLE FINAL LOGS D.S.13-22 DOS.13-26 D. S. 2-24 D. S. 13-26 D. S. 2-24 D.S.12-5 D.S.12-10 D.S.12-11 6/15/82 CNL Run 1 5" 6/13/82 ACBL/VDL Run 1 5" 6/8/82 ACBL/VDL Run 1 5" 6/16/82 CNL Run 1 5" 6/14/82 CNL Run 1 5" 6/20/82 & 6/30/82 CPL(TDT-M) 5" with computer list 6/18/82 & 6/30/82 CPL(TDT-M) 5" with computer list 6/17/82 & 6/3,0/82 CPL(TDT-M) 5" with computer list Please sign and return the attached copy as receipt of data. Mary F. Ketlis North Engineering Transmittal # 270 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M GEOLOGY ~S TATE'~''OF~ 'ALAS IfA ARCO Alaska, Inc. (' Post OfficeB~.. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 27, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Well Completion Reports Dear Mr. Chatterton- Enclosed are completion reports and following wells- gyroscopic surveys for the DS 13-22 DS 15-6 North Prudhoe Bay St. #2 Since the information on North nature, we would appreciate it area. If you have any questions, Sincerely, P. A. Van Dusen District Drilling Engineer PAV/JG:llm Enclosures GRU1/L57 Prudhoe Bay St. #2 is of a confidential if you could store it in a secure please call JoAnn Gruber. RECEIVED JUL 2 8 ]982 Alaska Oil & Gas Cons. Commission AnChorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany ' · STATE OFALASKA 0 R I § I N A L ALASKA( ..LAND GAS CONSERVATION C[ 'MISSION WELL COMPLETION OR RECOMPLETIO# I,tEPORT AND LOG 1. Status of Well Classification of Service Well OILY~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-71 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20744 4. Location of well at surface 9. Unit or Lease Name 1799' FNL, 36' FWL, Sec. 36, TllN, R14E, UN ~LC~ATIONS! Prudhoe Bay Unit At Top Producing Interval VERIFIED . 10. Well Number 156' FSL, 1833' FEL, Sec. 35, TllN, R14E, UM---~'~r~-~ . Surf.'_ ~-- 2-24 -~---~ I 11 FieldandPool At Total Depth B, H- ._ · 90' FNL, 2020' FEL, Sec. 2, T10N, R14E, UM-.2 ~Z/[ ..... - Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Prudhoe Bay Oi 1 Pool 64' RKBI ADL 28308 12. D. ate Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 05/23/82 06/05/82 06/14/82 N/A feet MS LI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 10515'MD,9194'TVD 10471 'MD, 9154'TVD YES ~-1 NO [] nipple ~1994feet MDI 1900' (approx) 22. Type Electric or Other Logs Run D IL/SP/BHCS/GR, FDC/CNL/GR/Cal, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 20" ~1..5~ H-~,O 5urt 79' 36" 415sx AS II 13-3/8" 72.0# L-80 Surf 2593' 17-1/2" 2700sx Fondu & 400 sx Pemlafrost C 9-5/8" 47.0# L-80& Surf I 9692' 12-1/4" 500sx Class G & 300 sx Pl;rmafrost C 500-95 7" 29.0# L-80 9398' 10512' 8-1/2" 360sx Class C 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None 5-1/2" 9447" 9347' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIALUSED N/A · 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) . Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER~BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing PressUre CALCULATED.1~ OIL~BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor"r) Press. · 24~HOUR RATE 28. CORE DATA Bri°f descripti°n °f lith°l°gY' P°r°sity' fractur°s' apparent dips and presence °f °il' gas °r water' Submit e°re chi~ ~ C E I VE D None , , JUL 2. 819a2 Alaska ~chorage . Form 10-407 Submit in duplicate Rev. 7-1-80 GRU1/WC12 CONTINUED ON REVERSE SIDE , I NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GQR, and time of each phase. Top Sad] erochi t 9826' 8578 ' N/^ G/0 Contact 10042' 8769' 0/W Contact 10375 ' 9068' Base Sadl erochit 10416' 9105' 31. LIST OF ATTACHMENTS Drilling History, Gyroscopic Survey (2 copies) _ 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed 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 !: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is.completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 DS 2-24 Drilling Hi story NU 20" Hydril & diverter. Spudded well @ 0000 hrs, 05/23/82. Drld 17-1/2" hole to 2615'. Ran 63 jts 13-3/8" 72#/ft, L-80 BTC csg w/shoe @ 2593'. Cmtd 13-3/8" csg w/2700 sx Fondu & 400 sx Permafrost C. ND 20" Hydril & diverter. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 2000 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 9725'. Ran 238 jts 9-5/8" 47#/ft, L-80 & S00-95, BTC csg w/shoe @ 9692'. Cmtd 9-5/8" csg w/500 sx Class G. Instld 9-5/8" packoff & tstd to 5000 psi - ok. Drld FC & cmt. Tstd csg to 2000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 10515' TD (06/05/82). Ran DIL/SP/BHCS/GR f/10494'-9625', FDC/CNL/GR/Cal f/10498'-9668'. Cont log with CNL/GR to 13-3/8" shoe. Arctic packed 9-5/8" x 13-3/8" annulus w/300 bbls H20, 300 sx Permafrost C cmt & 131 bbls Arctic Pack. Ran 27 jts 7" 29#/ft, L-80, BTC csg f/9398'-10512'. Cmtd 7" lnr w/360 sx Class G cmt. Drld cmt to 10471' PBTD. Tstd lnr lap to 2000 psi - ok. Displaced well to NaC1. Ran CBL f/10442'-9300'. Ran 5-1/2" completion assy w/tail @ 9447' & pkr @ 9347'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Nipple for SSSV @ 1994'. Instld tree cap & tstd to 5000 psi - ok. Secured well & released rig @ 1700 hrs, 06/09/82. NOTE: There is a dummy valve in the well. Gyroscopic survey ran 06/14/82. JG:llm 06/29/82 GRU1/DH11 O' June 16, 1982 Mr. Bob Hines ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Our Boss Gyroscopic Survey Job No. Boss-16057 Well: 2-24 (SEC36 TllN R14E) Prudhoe Bay Field Survey Date: June 14, 1982 Operator: Everett Sellers Mr..Hines: Please find enclosed the "Original" and one (1) copy of our Boss Gyros~ic Multishot Directional ~ c~ the above well. Thank you for giving us this opportunity to be of service. Sincerely, Ken Broussard District Manager KB/pr Enclosures · =,FERRY-._,L N WELL. ~ URVEY IN- COMPANY . F'AGF - 1 ~IOB NUMBER BOSS-16057 KELLY BUSHING ELEV. := 64.00 FT. uF ERA] UR-~,ELLER~ f~[ ' .............................................. ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ [ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ [ [ ~ ~ ~ ~ ~ ~ ~ [~ ~ ~ ~] ~ ~[ ~ ~ ~ ~ ~ ~ ~ ~ [~ ~] ~[~ ............................................... ~ ~ ~ ~ ~ ~ [~ ~[ ~. ................................................................. 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OZ c:565.57 o ~o51.56~: W 411.:,.o7 - S .=,7, O"W 0 1'~' 3570 7.::) S ~'¢'P;~' '-'"' . ~ . .-'-., .... ,.o~* W 41'.."(~.31 i . . i~:~'. '....x :: ".."; .~, .... ,:. :::= '".:-.i .:=:..!.......'~:::,p!i:'..'..:"..:'~=:::; '-':: '.:. ::::::::: .::-..~-.~.. =::::: ':..:::::~ .... :::::~=::: :::.¢.~~.: .....:::.::,,;::::,:.......,.... .......... ........ :..:::::::............ ..... ::=,===,, .............. ; 0 oPERRY-~,UN WELLSURVEYING COMPANY F'AGE~ 5 ALASKA BAY dOB NUI KELLY BUSHING ELEV. OPERATOR-SELLERS 64. O0 F T. MEAoURED L EF TI--I TRUE VERT I CAL DEPTH SUB-SEA VERTICAL DEPTH .r_ _ .'~ ~ ~ii!~ ~ ' REOTANBULAR:,:;~;OO~RBI:!NATE~ .~: MD-TVD NORTH/u, uUTH~.., :EA~T/WEoT DIFFERENCE VERTI.CAL CORRECT I ON 3000 4000, .~,9.~,~ ~o.81 39950.23 29934.81 ~o~6. ._ 7..8~, E' ~ '1.199 · '" '::,.'_4 9z_- : 499. Z,...., ~ .799 ,W' 77 1.14 48.58 8000 'P000 10000 77¢]2.56 ' 8667.80 ~70. ~,~ 1 143.44 1*":t ~/:,o. 20 232.16 172;,46 124.76 SPERRY-S~ lNG 'COMPANY . 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KELLY BUSHING ELEV. = 64~ 00 FT. · '/'~: :~ '' :: OPERATOR-SELLERS, MEA.=.L RED DEPTH TRUE~''' SUB'SEA VERTICAL ~ VERTICAL DEPTH ~': DEPTH RECTA MO-TVD DIFFERENCE VERTICAL. ,, CORRECTION 2164 2164. O0 . : ~264 2264. O0 2 ~ oo- co .,. 4. 2200.00 ' , 4.15 ,S' E':::: ' :: 0'07 E, .: O' 07 0.01 O. O0 2664 ' 2664.. 00 '-' ' (' .~6C} J. 00 2764 2764. O0 2700, 00. · ,-,_,6 4 00 2:~:~0. 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O0 FT. MEAoLRED DEPTH TRUE ': B-SEA VERTICAL ' VERT!CAL DEPTH DEPTH ' REC~ANGUL MD-TVD ~WEST DIFFERENCE VERTICAL CORRECTION .'?008 .','1 .-'-4 7864.00 ',' 7ouo, c-u 7.~64. oo 7:"?00. oo ~o4s, ' ' ;5 :1! 44. 67 ,81 W: ,- 1160.82 17. t3 16.15 Q _0 ' 3276~.74 , 331~, ., , 8.74 w' 1232. eo 4;:93 W" 1~46.45 14.23 14.06 13.65 10371 10481 9064 O0 '~' '' . 9164.00 9100.00 .92 1307.03 lo17. '-'= SPERRY-SUN:' WELL SURVEYING COMPANY PAG~ 11 , r [ FRU[HuE BAY ALASKA dOB NUMBER BOSS-16¢. :~7 KELLY BU.:,HINu ELEV. = ,- , · c. - .,,.-_. F ERATOR-:,ELLER.:, 64. (])0 FT, MEASURED DEPTH TRUE VERTICAL DEPTH SUB-SEA VERTICAL DEPTH RECTANGULA i 'ii ':MARKER 9770 8577,72 0464.._'. a o4o¢3.19 o'-, 13.72 3304. :. IF( ZONE B 3311'1 ' ,4w ~ ,:'sHuBLIi< ZONE C ._ .-_,.__, c,,. '.c: :.;;'"::: ""~' OF sAriLEROCH ! T :.~:5, ~.1 ,~, ;?; :18~.~.~4.-- W :: TOP 10258 10375 10400 8962.27 9067.5::: 9090.12 :3401.76 3522.39:S 3531.03 S ,. 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':':::::~i' :' '~ ~::.*.' :'::' '": ....... :::::" ':'"':":'"'" :':: ':"¢-':" ::~:~: '!::'<: .?'.i~!~ : '":: ?:?:: :" .................. :~::::": ...... !::s:~:::':s': ............. ::: ~::': ....... · .................................................................. ..... :::1:~:~.~: ::::::::::::::::::::::::::::::: ................. I:~:::::::::::~ ' ~'.:: ..::::::::::::: :: ::~:: ~ ...... t ......... '.' ': ...... :::t' ':::::::::' : .-:::*::: ........ ' .......... t::i .......... :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::iiiiiii iiliii ::il i : :::i:iii · .:: ~:', ' ':. :::::-' :: :: ':::::: .: ":: '. ,.' : ' ~ '"" '-' :::-'".:. · .::.".:'-'".' '-: :::::'"'.: ::"::::: ~:~::~`~::~`:~:~`~::::!::~:~::::::~;:~:~::~`~v:~:+~:~`~:::~::~x~:::~x~:~:~::::::::::::::::~:::!:::i:`::::::::::::::::::::::i::::::::::: :::: :2 ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::: ::::~::::~,:,,,:,~~:~~:~:,,,i~,:~ ·.~:~:~:~---::::~i::~: ~:·m .~ ,~... ============================= ............ ~ .................. ~:,:::,:::,,,,:,:,,:,:~,,::,,,:~,:~::::, .............................................................. .... .............. DATE OF SURVEY dLINE 14, 198'? :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::: :: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: E :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: : : . . ... . i- .> ~~.; 0 ARa). Alaska" Inc. Our aJss Gyrosa;,pic Survey ,Job, No':, Boss-16057 ,"welT:" ,2-24" (SEC36 TIlN R14E) 4 ' Prt:d1De Bay Field : ';':~~~"NCrth~ SÍope#Alaska . , , ,.:~',; .:, ,~-:~ rate: June 14---, 1982- , . -~::';:;~~iA~~~:"~,,~~tt Sell~ . ':;~'~'!Ò~:f5il~~r-::¡~r'~' . . ~ ,. , '. . . .. ~. " .' ',.' ;. .<, . , '> ." ~- ,:<- ..... ',' " ~, - '" ",:':,..,: :.' :.' ., .. .:' '," .. . ' .. ',' .. ,', " , , 11nJ~ HORT.,. -,' .' , .. . ..' ',. " .: ',','," "'..' . " ' , ", Surface üx:aticn, 1:799mI. 36FWL) :. ,~ ~'" ',,', , , -.. '", .. ., ..' .. " , '","'." " 0 HcrAIZ(jNTRL -~.._~.__._,.._...........-.,..~-....",._""".,'T '.,".... '" ,".""', .""'~"'W'-"-""--""',---"'- "',,-""""""" ....,.."""..,"""'-' ", mo,_, .. ,;',' , < ':;:.:',- i l' I '" -" ".. ','- ..,'.. ",' .< " ' .. ' :~ :., ':,-, ,," .. "';"':, '~ . ...' " , .. , ',,>," , "'" ". '.' ,',: .,{~i:;:~~~~, , '....., ~ (. ,¿ '.. to "~ 'I, , - ,::Ü~~':::~r .. "-"""";,'""'..~.:',z;;..'T.) , .' "";r:a';.y"""';"'¡"" ""'-""':',':::~':'~'{"""" ..' -' ~ i' ' - , " ' : f';: '. , PR(jJECTI(jN .. '-! "'-~"'~"""""""""."""""',"""""'=""~~~- . ,J l # /'" ", ,:,',,:" -'" Y"'<;4,:',::,,~;::~:~i.:~~,.,~.>. ~' -', ;",,:, 0..0 ,'~ -, ,',,;' ~,' ';¡-;.' -','¡ -. ' .,,:'- i--~:, ~;:'¡:;;:,~.:,':~";~<~;~~,~-,j;,it;.:,:,',~J'," -",,-,:,,'~~'-'" '"," :,'," , " , "" ' """" ,.., '.",~",-"',,;' ,.."~"",:,,L, '-, .AR:X) Alas1<a" Ir:lc. ,.'--t.':':;:>:~~"'.\'-c" ,""-- ",.,', 'c', , ., .'",: ,:';' ?i~ :)o.j2:J~VJ~¡~r~~~~il~i~:~~;~~~>~ ::<; ~~c SUrve"f ,> 'c -,<0' ' ;, ,..-,,-,~...~",:,,"" ,,-- '-~-~~., '>":'-L~_-,- -. '. '-, ,--""j-"' Well" 2-24 (Stir36 T11N Rl4E) .. --",' -,,-~~., .' ;".:'::,:~::~'~_::;:~;~;:è,,~tt-;:~',,;::¡-i,~;;¿{-~~?'~~~~,';~~;;--~:~~)~.i"~i>,,~;Y~,'-,,j..~n-~, . e1d', ,- , - ~, ,'.. , "",""','" '"""""',' '~""-f,~._'"'~"'~,',ú",,,,,,,.:l?~"\,r,~,I~::, ~"""'~,'-"-.-."",š-:""'C",,,~,:~,, ,"",'""'" ::,:""',~-,"""",~"~"""'",',','",r.u..u.AJC;, , Bay Pi , "~;'.-;":-~,,:::~ ";:~:,.::~~:,;(lÄ7~!<~~:." ~~~~7~;~':i'/'¡¡~~~t~~:f4<;.Q-.,~l~~ii'¥:4::':>~':'..r....~,", 51, AI ~ ,', " ,', .. -: ';' " ,',',,-.. :".~"'<:' ',,".""-""'-:-:~,." ,;;~.~'7-",",~~~~.~""....,..~,~...ft~"':'~~';i',,ç:,,~ "~~ '-I-~,:O¡)e:, as"'C1 , " - .:/. ".-:.,',:: '~~~~;'::.~J:':¡',~~~~,.~7~:-¡:'}'~~~,,::-:'I'~"~.',<!:~"'~:~':;"':',~~;;~';',.. n..,.'te- 4f\,-- 14 1982 ' " -,', -'. ,;;-"~;~;,~,w;¡:l.':;"~;f'-,'3i,~~~:1\.~...,;':;tl~1/,.¡':~~~~~";';s,,¡'1,,,:"".':;""~"::::,,,,,- "...,z' ~ 6" '" UUI::;- # , " ,,: .,-":';,,, ,:;J,~~.{~;:::¿j't,:~,,~,~'t.~':'~~~::ik".:.:,..~>,~f;~:i,',~~:;:-~:';~;;:¿,;;,"~~",~;t:::[,:~' ,;, "C'._~ Sell, , , " . ~"-,, """""",;'«"L""""'~"~"'>~~"~;,~...'t4'~i;-,:'.':<'J,.....~,.""""Ù",;~~"""'""'C"~"""""'.~'pPEœ., ator:, '¡':'Vc.L.C'-'- ers, , .~:".:~~~::, ...;; . ~,~~.,>:,,'<. ;'~. J):. i,~;"~~~~~,~:,,,':X,~~,:,::\;~\~:<.:..:i,.~~;~7-.¡;',:~i-;~~;{$.:~i;;<:,:,.' i ,",;, ,:':,';. , '" " "" ..',..' .':--,",':h""" '.' .I:"~:"':~;'-'..,... ',':. '1~;....' ..~~-;-"'-"~":-'" '~. '~~~i~~:..r~~'~~'i~;-..'¥..;>'<;'scate"" ,111"; - '2000'" , h: , ~:~~~~~~.. " .'. " "'>""'... ,0','" . .,'# " , " "",:~"" :,',~ ,..', ... / 0 " '- ,c, - ,,' ,'-,:- ..' , ""', ..' " ,':" ". ' Q.; 00", . .. . ".,... ~. ." , . , ," " , . " \., ;~~tf~~k~I~~:;::~ " ' ,,', , ' - "'~ . " ". "., ", , ';. , .. '.' , '" ,.:.:,)":,,,..: ,"" '.' ,'-'4120.31'; ,,-, S2~~2!" c' 1 QSl.!:i ',." , " '...' '.:,,'" ,,-'" "~"""",,',.'" .,,~>~:,';:: ' ',',- ' :' .' , , " ~,,"..,:, , , .' ,:'~ ',; ',.' . ' , .. , ~ . 20 a. DO 40 -.. .. " ;,.. ':.,!,,',: :.':""-:,~<."':' ," ".':,;':':, ' .',.:"""" ,-" .."...,:<:;'".":"..'"c:."".'>:.",' 'õ ~,,~ ."'" .. '. ' , "":- , '. ~'.- -' , - ' .. ~ ,,1, " ":'" , , , """""'".' '", ., " ',:':H;t';.)f;-fi,;"~' ,,-: :"'~~- . ,..,:-. ',.. ,.; ..' "'.", . ;' "., "., --- 0' , , .. , , ",' '..' ,. " .. " " "', " .. ,;" >: . " , , '...,:":.:":: " , , , :' VERTICAL PA"~JECT I aN , , ,,' ,~ '" ," , ~ ',: ,', ,....':, ."..:,.' " ,~ ."'"""""""_.,...".".,.""",.",~,....." ,""...."~",."""","~""""",,"~'~",,,,"'" .,."-,,..,..', n' ,.' -~...".., ...""..--,-,..-- , " ", ~-'.' ---,...."-~-.-..."--.,_..._---,,,--..,,.., , h"",,"""""",,"" Eastman/ Whipstock 1,) REP of $UB - S URF,~ CE DIRECTiON~4 L SURVEY ARCO ALASKA, INC. COMPANY DS 2, Well Number: 24 WELL NAME P~ldhoe Bay, North S!ome, Alaska LOCATION JOB NUMBER DATE Directional Single S~L-8 i982 22-HA~-82 A~sk~ 0it & Gas Oons. Commission SURVEY BY Controlled Drilling Consultants OFFICE Chapman/Creager ) F'f;.'l!l'~l--If}F7 tt'c~Y ? ~Ofi'l'l'-I f-';I t'71f:'f:', ¢tl F: 71' tr~ | i~OI..J~IN -4si li~17fk'Ef~l'ltr)N¢~l. COHF'ANY: CONTF;tOI...I...F~Ii~ 17~f:.:Tt...l.. TNG C(1N,C..~I..II...T~NT..C..~ R I! F~:~,.~IF; Y F'F~O U T D E:i.D ~{ Y .f'.; D C UE;Fi~I' ]; CAI.. ,.qf~'g..l'.ION C:¢tl...t?.I..II..ATI~!;D IN PLANE £)F F'[ROF'OSAI.. [~TFir.F.;CTIf)NI $ 29 I)EG, 4 HIN, bi fi:l:i;l'i:(-11::¢lT~ OF ..q.'I.IF.'.UF..;Y f~ ~ D I I.I ..?., O f:' f.'. I.I Fi' ~.) ~.~ T [! Fi'. [!7 ~'l E.-". T H O DF.-'. ?, t,t1.*:*1. I t,!F! | ?.4 F'F:'IIIiHOF" RAY, HAR]'H ,c.;I.OPF:', Al. AOKA .., r~AI'E' '- 2.1 ---, tf liq.--- ~ ,9. N I::; A .q t.IR E' D D R ]' F 1' r~F F:'I'H Ai',!G I. tF F E F 1' D Dr~. T F 1? ('..' C, IRS D T F? E' ,F,.', 1' I 0 N I. 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'7 0, (;, 7~./., 0, !. % t), ]7<::' 7957. 37 45 8453, 34 30 8855, 32 15 92179, 29 45 9384. 28 45 5'.'9 28 5?8 ,',-°..9 3 O 312. 6991,40 2825, 18 6927,40 496, 7391 · 98 311. 7,53 7327,98 4 02 77':) '7,67 '~ TM - ...... ..,_.38.63 7663.67 374, 8048,22 3531,23 7984,22 155. 8183.46 54606.96 8119,46 2514.06 S 1292.12 W 2826.67 2771,01 S 1431.63 W 311.8.98 2966.25 S 1535,44 W 3340,10 3135,52 S 1627~35 W 3532,67 3201,44 S 1664.64 G! 3608.35 S 5?7 12 W S '~7 lq) W S 27 22 W S ")'7 ,:.6 W ,, S 27 28 0 , 7A 0.67 0, Sd, O, 6P 0. '7'2 I... L N ii..1 l J ~j~ 4 l~ j S S BAY, i',~ORI'H St..OF'F.. ~ AI..A~.'KA 'J'l' JtJ!i 11-1A T [!' ,. 14125115 21 - ...11 .Ij'~l- t~ ?, 'fRIJE; i"II!!]ASIIR'EI,~ DP1TFT DRIFT ~O!JRSE VE. RTICAL. VERT.T. CAt. SUJ.::SE.A R E C.. T A N ~ t.I L A R C I... 0 S I..I R E; DOf;L. tFr: rHri;F"l'H ANGLE; I)I'f~tE;C.:I'];Ot4 I..ENGI'H I'fl~!;F'TH SECTION TVD C 0 0 &' D I N A 1' E S DISTANCE I'~.T. REC..I'ION SE'UE'Rlr"~ F' E E 1' D H P Pi F' E Fi] 1' F' Iii ~.--. 1' F' E IE 1' F' E IE T F' E E 1' F' E' E T [t H [i G / 10 ~"; I: 9657, 29 0 975?5. 29 0 S 34 0 W 04,.,0. 26 0 g 38 0 W 0515. ..... /: 0 ,.$;38 0 273. 8422.52 3730,59 8358,52 3313.21 S 1734,48 W 3739.76 S 27 38 W 68. 8481.99 3771.43 841.7.99 3340.54 S 1752.92 W 3777,52 S 5?7 41 W 725. 9125.00 4103,65 9061.00 3611,29 S 1949.63 W 4103,96 S ?8 22 W 65, 9183,42 4131,79 9119,42 3633,74 S 1967,17 W 4132,05 S 28 .,.~ W O. 71 0.00 O. 49 O. 0¢", FINAl.. CI..OSURE-- I)IRE'CTI'f'~NJ [mi SI'ANC. F.r: S 28 DF..6S 25 t4INS 46 SECS W 4132.05 F'E:iET ;:'~I~;:CO Al. AE;KA, I i'l E~ 2, Idl:!:l. I. f'J..0; .'=:.4 D..C2,.,.q.' I::'F~:I..IDH£)E; BAY, f-~ORTFI ~!~I. JRLJE:Y FTI..E: NI..IMBffF;.' ( CDC ) D E F' 1' H BOl"l'Ot4 I--IOI_E: A,.R.',qE:HBL. Y LJ~tl...I.JE:,.q I..IS.;;E:I) flOR DEF'TH ARE: t"iD l:.l f= ,.> C R .'[ F' T ! O 2'615. O0 4539. O0 6Y;P;O. O0 8500.00 97.':-.? ~;. O0 99 .'10. O0 0.% 15.00 ,JEI'I' I HG ,JE'T T I fl[.-; A,.q._qE'i4Bl.. Y I::'ACKE: D HOI..E f:'ACKE:D FIOI. E". A,q;E;EHBLY F'A f.'. K f.!: D H 13 I.. E: F~ S ~!; F: M B L Y F' ~ f..'. K fi: D HOI_ E: A ~,c,.; F: H R I. Y DAY ? 3 4 7 10 11 13 14 15 1/, 17 D .F F' T H 2615; · O0 _6550.00 f.I 500. C, 0 9725, O0 ~9.J 0,00 51 05] 5. O0 DRTI..I. INf; DAY :: V~I..I..IF;S IISf.[D FflF;: DE]F'I'H t.~fltEi; MD .[! E]F' 1' H , '0,00 P61.5,00 2 (.; 1 ':' ,.,, O0 3'?f!C), O0 4539.00 59'50, O0 I;;' 6 ....... ,0. O0 7/.,50, O0 8500, O0 95'.'70. O0 9725,00 9725,00 9910, O0 10471, O0 1O471, O0 1051 S. O0 10515, O0 1051. 5 ,.. oO WEII.:.;HI' ON BIT WEIGHT IS GIVEN f:'F:R 1000 F'OL!NDS Vfil..I..IE:S I.JSE:D FOR DE:F'TH AF,:F: I4D Gl'IT 60, O0 60,00 (.>0, O0 f!;5, O0 /,0, O0 45, O0 ,% 0,00 DEF'TH 261 ..'5.00 45S9o O0 ~. ...... 0 O0 8~500. C,O 9725. O0 9910,00 0 5.1. ',5,0 0 ~J~I..I.JF!IE~ I.JSE;D F'OF~ DEF'TH i~iRE; HD 80. O0 1 40. O0 140. O0 120.00 !l.'qo. oo ?. 9o~ oo :: 90, O0 ': Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. ' ~rator, Wel 1 N~une and Number -. Reports and Materials to be received by: Required Date Received Remarks Comp lotion Report Yes 7 -- ~ ~ .-- ~ ~,~t',~'' '~ Well History . Yes ,, , , Core ~scription~/F-~ ~ : / , , , Registered ~ey Plat ~% S InClination Su~ey . ~'p ,Drill St~ Test RemUs :: ~e Pr~u~ion Test Re~s ::"'--'n~ > '"'"' ~sR~, Yes AR~O Alaska, Inc. Post Office Bo~ J Anchorage. Alaska 99510 Telephone 907 277 5637 July 12, 1982 ¥ Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are monthly reports for June on these drill sites: ~~ 14-22 2-25 15-6 6-17 18-1 13-22 18-2 13-25 1E-13 13-26 1H-8 14-15 Also enclosed is a well completion report for Kuparuk 1E-12, and subsequent sundry reports for: 3-14 14-6 4-9 15-3 4-15 Eileen No. 1 11-4 NGI-7 (Since the information on the Eileen well is of a confidential nature, we would appreciate it ~if you could store it in .a secure area. ) Surveys for 2-22 and 13-21 are being reran; completion reports for these wells will be submitted when approved surveys are received. Sincerely, P. A. VanDusen Regional Drilli'ng Engineer PAV/JG:llm '. Enclosures GRU1/L48 ARCO Alaska, Inc. is ,3 subsidiary of Atlantic'RichfieidCompany' STATE OF ALASKA ALASKA (~"_ AND GAS CONSERVATION CO( fISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling wellxI~ Workover operation [] 2. Name of operator 7. Permit No. ARCO A]aska, Inc. 82-71 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20744 9. Unit or Lease Name FNL, 36' FWL, Sec. 36, T11N, R14E, UM Prudhoe Bay Unit 4. Location of Well 1799' at surface 5· Elevation in feet (indicate KB, DF, etc.) 64' RKB 6. Lease Designation and Serial No. ADL 28308 10. Well No. 2-24 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0ii POD'] June 82 For the Month of ,19__ 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded we]] ~ 0000 hfs, 05/23/82. Dr]d 17-1/2" hole to 2615'. Ran, cmtd & tstd 13-3/8 csg. Dr]d 12-1/4" hole to 9725'. Ran, cmtd & tested 9-5/8" csg. Drld 8-1/2" hole to to 10515'. Ran logs. Ran & cmtd 7" liner. Disp we]] to NaC]. Ran CBL. Ran 5-1/2" completion ass¥, Secured we]] & re]eased rig @ 1700 hfs, 06/09/82. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressur9 tests 20", 91.5#, H-40, conductor set ~ 79'. Cmtd w/415 sx Arcti'c Set II 13-3/8",72#/ft,L-80,BTC csg w/shoe @ 2593'.Cmtd w/2700 sx Fondu & 400 sx Permafrost C. 9-5/8", 47#/ft, L-80/S00-95, BTC csg w/shoe ~ 9692'. Cmtd w/500 sx Class G. 7", 29#/ft, L-80, BTC csg f/9398'-10512'. Cmtd w/360 sx Class G. SEE DRILLING HISTORY 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SP/BHCS/GR f/10494'-9625' FDC/CNL/GR/Cal f/10498'-9668' continued w/CNL/GR to 13-3/8" shoe. CBL f/10442'-9300'. 16. DST data, perforating data, shows of H2S, miscellaneous data N/A RECEIVED JUL t 2 1982 Alaska 0il & Gas Cons. Commissi~ Anchoraoe 17. I hereby certify that the foregoing is true and correct to the best of my knowledge· ' -. . _ , TITLE ........... NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 GRU1/MR7 DS 2-24 Drilling History NU 20" Hydril & diverter. Spudded well @ 0000 hrs, 05/23/82. Drld 17-1/2" hole to 2615'. Ran 63 jts 13-3/8" 72#/ft, L-80 BTC csg w/shoe @ 2593'. Cmtd 13-3/8" csg w/2700 sx Fondu & 400 sx Permafrost C. ND 20" Hydril & diverter. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 2000 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 9725'. Ran 238 jts 9-5/8" 47#/ft, L-80 & S00-95, BTC csg w/shoe @ 9692'. Cmtd 9-5/8" csg w/500 sx Class G. Instld 9-5/8" packoff & tstd to 5000 psi - ok. Drld FC & cmt. Tstd csg to 2000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 10515' TD (06/05/82). Ran DIL/SP/BHCS/GR f/10494'-9625', FDC/CNL/GR/Cal f/10498'-9668'. Cont log with CNL/GR to 13-3/8" shoe. Arctic packed 9-5/8" x 13-3/8" annulus w/300 bbls H20, 300 sx Permafrost C cmt & 131 bbls Arctic Pack. Ran 27 jts 7" 29#/ft, L-80, BTC csg f/9398'-10512'. Cmtd 7" lnr w/360 sx Class G cmt. Drld cmt to 10471' PBTD. Tstd lnr lap to 2000 psi - ok. Displaced well to NaC1. Ran CBL f/10442'-9300'. Ran 5-1/2" completion assy w/tail @ 9447' & pkr @ 9347'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Nipple for SSSV @ 1994'. Instld tree cap & tstd to 5000 psi , ok. Secured well & released rig @ 1700 hrs, 06/09/82. NOTE: There is a dummy valve in the well. JG:llm 06/29/82 GRU1/DH11 RECEIVED J U L 1 21982 Alaska Oil & Gas Cons. Commission Anchorage ' STATE OF ALASKA ALASKA(_ AND GAS CONSERVATION C~-- VIISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling wel~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-71 3. Address 8. APl ~)~J3_e~0744 P. 0. Box 360, Anchorage, AK 99510 50- 9. Unit or Lease Name Prudhoe Bay Unit 4. Location of Well atsurface 1799' FNL, 36' FWL, Sec. 36, TllN, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 64' RKB ADL 28308 10. Well No. 2-24 11. Field and Pool Prudhoe Bay Fi el d Prudhoe Bay 0il Pool' For t. he Month of. May ,1982 12. Depth 'at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 0000 hfs, 05/23/82. Drld 17-1/2" h01e to 2615'. csg. Drld 12-1/4" hole to 9270' as of 05/31/82. Ran, cmtd & tstd 13-3/8' See Drilling History 13. Casing or liner run and quantities of cement, results of pressur9 tests 20", 91.5#, H-40, conductor set @ 79'. Cmtd w/415 sx Arctic Set II 13-3/8",72#/ft,L-80,BTC csg w/shoe @ 2593'.Cmtd w/2700 sx Fondu & 400 sx Permafrost C. See Drilling History 14. Coring resume and brief description None 15. Logs run and depth where run None to date 1 6. DST data, perforating data, shows of H2S, miscellaneous data N/A RECEIVED Alaska Oil & Gas Cons. Comm~sion ~chorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~ ~ TITLE Area Drilling Engineer NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 GRU1/MR7 DS 2-24 Drilling Hi story NU 20" Hydril & diverter. Spudded well @ 0000 hrs, 05/23/82. Drld 17-1/2" hole to 2615'. Ran 63 jts 13-3/8" 72#/ft, L-80 BTC csg w/shoe @ 2593'. Cmtd 13-3/8" csg w/2700 sx Fondu & 400 sx Permafrost C. ND 20" Hydril & diverter. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 2000 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 9270' as of 05/31/82. JG'llm 06/04/82 GRU1/DH11 RECEIVED JUN- 9/982 AJ~aska Oil & Gas Cons. Commission Anchorage ARCO A,,o~.,~, ,nc. Post Office Box 360 AI~r'- ~ 99510 Anchorage, Telephone 907 ~f7 5637 July 1, 1982 Reference: ARCO MAGNETIC TAPES & LISTS D.S.13-.22z' 6/7/82 D.S.I'3-1~'/ 6/19/82 D.S 13-26z 6/9/82 D.S.5-4~/.· 5/22/82 D.S.2-15j 5/21/82 D.S.2-1 .'1~'~' 5/20/82 6/13/82 5/10/82 D.S.13-24j' 5/27/82 D. S. 14-17-~ 5/13/82 D.S 13-22--_ 6/15/82 D.S 13-26~ 6/16/82 Tape # 65174 Tape # 65233 Tape # 65176 Tape # ECC 1314 Tape # ECC 1315 Tape # ECC 1310 Tape # ECC 1~43 Tape # ECC 1303 Tape # ECC 1321 Tape # ECC 1299 Tape # ECC 1349 Tape # ECC 1348 ~~Please sign and return the attached copy as receipt of data. Mary F.'Kellis North Engineering Transmittal # 250 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO .MARATHON CHEVRON EXXON MOBIL GETTY D&M GEOLOGY Anchorage, Alaska 99510 Telephone 9~=' '77 5637 June 30, 1982 Reference: ARCO· DIRECTIONAL DATA D.a.13-22 5/25/82' Single-Shot D.S.18-1 6/7/82 Single-Shot D.S.15-6 5/16/82 Single-Shot D. ~i~!~i~ 5/22/82 Single-Shot ase sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 249 DISTRIBUTION 'NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO' MARATHON CHEVRON EXXON MOBIL GETTY D&M GEOLOGY STATE~'' ' ARCO Alaska. Inc. is a subsidiary of AtlanticRichfieldCompany A.N;~,~ Alaska, Inc. Post Office Box 360 Anchorage,/~~ 'ska 99510 Telephone 9. 277 5637 June 15, 1982 Reference: ARCO MAGNETIC TAPES & LISTS ~,~~ 6/5/82 Tape # 65160 D.S.15-6 6/6/82 Tape # 65164 · D.S.15~5 5/19/82 Tape # ~5167 ign and return the attached copy as receipt of data. Mary Fo Kellis North Engineering Transmittal # 234 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO' MARATHON CHEVRON EXXON MOBIL GETTY D&M GEOLOGY Alaska Oil & Gas Cons. Commission AnChorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office B~ 60 Anchorage, AlasKa 99510 Telephone 907 277 5637 June 8, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton' Enclosed are monthly reports for May on these drill sites' 1-'9 13-26 2-21 14-17 2-22 14-22 ~~'~ .... 15-5 13-21 15-6 13-.22 1H-6 13-24 1E-12 Also enclosed is a well complet,ion report for Kuparuk 1E-11. Sincerely, P, A, Van Dusen Regional Drilling Engineer PAV/JG'llm Enclosures GRU1/LI$ Alaska Oil &AaCSOrageGas Cons. Com~issioo ARCO A'laska Inc. is a subsidiary of AllanticRichfieldCompany MEMORANDUM St ,,e of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION TO: ~~~ DATE: Chat on Chair~z~f~ '-'- FILE NO: TELEPHONE NO: THRU: Lonnie C, Smith -~ C ommi s s lone r SUBJECT: FROM: Doug Amos ~ Petroleum Inspector May 28, 108A/Q 1982 Witness BOPE Test on ARCO's DS 2-24 Well Sec. 36, TllN, RI4E, U.M. Permit No~ 82-71 on Rowan's Rig 35 ~ond.a.y.,......May. 2_4, 19B_2- I traveled this date from Anchorage to Prudhoe Bay to witness the BOPE test on ARCO's DS 2-24 well. The BOPE test commenced at 10:30 p.m. and was concluded at 1:30 a,m. May ~25, 1982. There were no failures and I filled out an A.O.G.C.C. BOPE test report which is attached. In summary I witnessed the successful BOPE test on ARCO's DS 2-24 well on RoWan's Rig 35, I filled out an A,O BOPE test report which is attached. 02-00 IA(Rev.10/79) · 0~.~ #4 STATE OF ALASKA ALASKA OIL & -CAS CONSERVATION CQv~iISSION B .0. P.E. Inspection Report Date _Inspector Operator Wel 1 Location: Sec Frilling Contractor Representative, Permit # // ~~asing Set ReDre~ntat ive Location, C~neral~ .. Wel 1 Sign_ Ceneral Housekeeping___ Reserve pit Rig BOPE Stack Annular Prev~nte~/ '/--~ - ~ipe R~- t~. O~,~/_ ,z Blina Rams.. 'W/ ~ -- Choke Line Valves/~/~ H.C.R. Valve v/ ~ Kill Line Valves ~/~+ - 2heck Va lye__ ~ ~-- Test Pres sure . .~: o , ,, // /! /t /, ACCUMULATOR SYSTEM Full Charge Pressure ..~/~ psig Pressure After Closure /373 psig Pump incr. clos. pres. 200 psig min ~_sec. Full Ch~ ~Pressure Attained: ? min_o_fp_sec. '2,O~o, ~I,.~¢i,~1D~9 /__ 210,o.27,00 psiq. ~O ~/~%_ ~2 Controls: Master ~ Kelly and Floor Safety Valves Upper Kelly /~est Pressure Lower Kelly_ ? ~/~Test Pres sure Ball Type ..... J Test Pressure Ins ide BOP / Test Pres sure Choke Manifold / Test Pressure No. Valves .... . . /~ No. flanges. ~ ~ ~dj ustab le Chokes.. Hydrauically operated choke Pest Results: Failures 'A~O~n ~ ' Test Time' ~ ?epair or Replacement of failed equipment to be made within [nspector/Ccmmission office notified. ~emarks: ..... hrs. Od day s and III //1/ //!/ 111 )i stribut ion ,rig. - ~O&CCC ~\ ~c - Operator ~ ~c - Supervisor Inspector .. ~_~!d¢~ ~tr. ~lark A. ~ajor Area Dr i 11 lng Engineer ARCO Alaska, Inc. P. Oo Box 360 Anchorage, Alaska 99510 Prudhoe Bay Unit DS 2-24 ARCO Alaska, Inc. PeX~ni t No. 92-? I Sur. Lo.e. 1799'S, 36'B of 1~ cF See 36, TIlN, RI4B, ' Bt~ole Loc. 198~S, 1996~E of ~ c~ Sec 2,TION, RI4~, ~. Dear ~. ~aJor: Enclosed is the approved application for permit to drill the above referenced well. Well samples and a mud log are not requi~edo A continuous directional survey is required as per 20 AAC ~5.050(b)(5)o If available, a tape containing the digitized log Information shall be subraitted on all logs for eopylng except experimental logs, velocity surveys and dip~eter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to .AS 16.05,876 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, ~apter 3, Article ? and the re~lationa promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal ~/a. ter Pollution Control Act, as a~ended; Prior to ec~encing operations you may be contacted by a representative of the Department of £nviron~ental C~nservatton. To aid us .in scheduling field work, ~e would appreciate your notifying this office within 48 hours after the well is spudded. ~ ~ould also like to be notified so that a representative of the Co~nission may be present to witness . Prudhoe Bay Unit DS 2-24 testing of blowout preventer equipment before surface casin~ shoe is drilled. In the event of suspension or abandor~aent, please I~ive this office adequate advance notification so that we may have a wi tness present. Very truly yours, C. V. Chatterton Chairman of ..~y ORDER OF Alaska Oil and Gas Cease=ration ~ission Ene 1 o su re Department of Fish & Game, Habitat Section w/o ariel. Departmnt of J~nviromaental Conservation w/o enol. C~C: be ARCO Alaska, Inc~ Post Office~_ ~x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 7, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' DS 2-24, Permit to Drill Dear Si r' Enclosed is our application for Permit to Drill DS 2-24 and the required $100.00 filing fee. Attachments to the application include a plat detailing th~section and plan views of the proposed wellbore; a proximity plat showing the subject wellbore's position to the nearest well drilled; and a sketch and description of the surface diverter, BOP equipment, testing procedure, and an as-built conductor pl at. As we anticipate spudding this well approximately May 12, 1982, your prompt review of this application would be appreciated. Sincerely yours, M. A. Major Area Drilling Engineer MAM:JG-ltc Enclosures ARCO Alaska, inc. is a subsidiary of Atlan~icRichfie~dCompany RF.C£1v£o o 9e2 Abska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA {,L AND GAS CONSERVATION C~i,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL []~( lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, ][nc. 3. Address P.O. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 9. Unit or lease name 1799'S & $6'E of NW cr Sec. 36, TllN, R14E, UM Prudhoe Bay Unit At top of proposed producing interval 10. Well number 145'N & 1819'E of SW cr. Sec. 35, T11N, R14E, UM Drill Site 2-24 At total depth 11. Field and pool 198'S & 1996'E of NW cr. Sec. 2, TION, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF etc.) ] 6. Lease designation and serial no. Prudhoe 0i 1 Pool 64'RKB, 34' PadI ADL 28308 12. Bon~[ infqrmat[o9 (see 20 AAC 25.025) Fed 3~a~ewlae Ins Co. #8088-26-27 Type Surety and/or number Amount ,I~:DUU, UUU · 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed NW of Deadhorse, 5 miles 198' feet well@ surface 120 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 10,536'MD, 9198'TVD feet 2560 5/12/82 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 3695 psig@ Surface K~CK OFF POINT 2700 feet. MAXIMUM HOLE ANGLI~6-I/TI (see 20 AAC 25.035 (c) (2) ~4480 ...psig@_919~ ft. 'mD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) H-40 Welded 80' 30' 130, _110'! 110' 200sx. 32" 20" 94# Permafrost~,~ 17-1/2 13-3/E 72# L-80 Butt 2570' 30' ~30' 2600'~1 2600' 2300sx Fondu & 400sx 12-1/4 9-5/E 47# L-80 Butt 9600' 28' 28' 9628'1 8467' 500sx Cl.ass G (1st st S0095 ~ ~ 300sx PF (2nd stage) 8-1/2 7" 29# L-80 Butt 1208' 9328'~, 8225' 10536't~ 9198' 350sx Class "G" 22. Describe proposed program: . ARCO Alaska, Inc. proposes to directionally drill this well to 10,536' MD (9198'TVD)'to produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8" 5000 psi RSRRA BOP stack will be installed and tested to 5000 psi. The BOP equipment will be pressure tested each week and operat.ionally tested each trip. The well will be completed with 5-1/2", 17#, L-80 plastic-coated tubing with provisions for a subsurface safety valve. A nonfreezing fluid will be left in all uncemented annuli within the permafrost zone. The packer will be set above the Sadlerochit and Sag River formations. A separate SUndry Notice will be submitted before the well is perforated. RE£EIVED MAY 0 7 1982 ...... 23. I hereby certify that the foregoing is true and correct to the best of my knowledge ~~ Alaska 0il & Gas C0ns. C0mm_is~i0n · SIGNED TITLE Ar~_a Ilrill in9 Fngi~rBg~rE ~'"// The space below for Commission use CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required APl number E-]YES ~NO I-lYES ,[~.NO ~YES []NO 50- 0 V~' 7~ ~ ~'~ ... Permit number Approval date APPROVED BY ,COMMISSIONER DATE by order of the Commission / Form 10~01 ~ Submit in triplicate Rev. 7-1-80 ..... , , . "~-~"! ~_~_~.,'. ww-~---~-+-~-~+---~ ]-: ~-~--~---q--Z---~--i--~ ~- 1--- .......... SURFACE HOLE DTVERTER SYSTEM SCHEMATIC ARCO ALASKA ]'NC'. IO" HYD. OPR. BALL VALVE WELL BORE (SEE DETAIL) IO" HYD. OPR. BALL VALVE ALL 90° TURNS ARE "TEE" CUSHION . ~LL BORE i, RESERVE PIT AREA NOTE' FLC~ INE F DR ILL ING RISER 20" 2000 PSI WP ANNULAR PREVENTOR Valves on diverter lines open automati- cally when the annular preventer' is closed. CONDUCTOR PIPE IO" HYDRAULIC OPERATED BALL VALVES "DETA IL" 2026010203 PREVENTER BLIND RAMS PIPE RAMS SPOOL PIPE RAMS 13-5/8" BOP STACK DIAGRAM Accumulator Capacity Test ~. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultane- ously and record the time and pressure remaining after all units are closed with charging pump. 4. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. 13-5/8" BOP Stack Test 1. Fill BOP stack and manifold with a non-freezing liquid. 2. Check that all hold down screws are fully retracted. Mark running joint with predeter- mined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 3. Close annular preventer and chokes and bypass valves on manifold. 4. In each of the following tests, first hold a 250 psi low pressure test for a minimum of ,3 minutes, then test at the high pressure. 5. Increase presure to 3000 psi and hold for a minimum of 3 minutes. Bleed pressure to zero. 6. Open annular preventer and close top set of pipe rams..~ Increase pressure to 5000 psi and hold for at least 3 minutes. Bleed pres- sure to zero. 7. Close valves directly upstream of chokes and open chokes. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero. 8. Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to 5000 psi below the bottom set of pipe rams and hold for at least 3 minutes. 9. Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. 10. Bleed pressure to zero. Open bottom set of pipe rams. 11. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. 12. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full of non-freezing liquid and all valves are set in drilling position. 13. Test standpipe valves to 5000 psi. .14. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. 15. Check operation of Degasser. 16. Record test information on blowout preventer test form. Sign and send to Drilling Super- visor. 17. Perform complete BOPE test once a week and functionally operate BOPE daily. Rev. 3/12/81 Oil &Anchorag~Gas Cons. C°mrn/ss/on I HEREBY CERTIFY THAT i AM PROPERLY REGISTERED AND LICENSED' TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS AN AS. BUILT SURVEY MADE BY ME, AND. THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT, AS OF: [~-/Z~/~I ~( ~4)~Gr- t45° £41' ~ S. "~,o" Y: ~'~4~ t4G,.4.~ LA'r. · '1'~e ' S' ~T. I.~-.= t4.&e &~' zo..4'"JI" / II II III I I III I I I II I I.. ARCO Oil and Gas Company · "NORTH ALASKA DISTRICT-PRUDHOE BAY II IIIII IIIIII I II I III i i DRAWING No.: '1 i CHECK LIST EOR NEW WELL PERMITS Company Lease & Well No. f, ~ ~ IT~ APPROVE DATE (1) .Fe (2) Loc .~2 thru 8) (4) 24) (6) Add: 1. Is the permit fee attached ................................. 2. Is well to be located in a defined pool ...... iiio 4. Is well located proper distance from other wells . ~.. 5. Is sufficient undedicated acreage available in this pool ......... 6. Is well to be deviated and is well bore plat included ............ 7. Is operator the only affected party .................. , ........... 8. Can permit be approved before ten-day wait ....................... ° o 3. 4. 5. 16, 17. 18. 19. 20. 21. 22. 23. 24. 25. YES NO . · , R~W~kRKS Does operator have a bond in force ................................. Is a conservation order needed ...................................... ~--~. Is administrative approval needed ................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ....... ..~ Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons ................. Will sUrface casing protect fresh water zones ................... Will all casing g±ve adequate safety in collapse, tension and burst. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ ~-- Is adequate well bore separation proposed .................. , ........ Is a diverter system required ..... ' .......... Are necessary diagrams of diverter ~ ~ ~q~i~n~ a~;a~ Does BOPE have sufficient pressure rating - Test to ~O psig . Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Additional requirements Additional Remarks: eeeeeeeeeoeeeeeeeeeeeeeeeeeeeeeeeeeeoeeeeeeei ~~ . Geology: Engineering' rev: 01/13/82 ..... INITIAL GEo. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ,, Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process b~ 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. .............................. RECEIVED * * * ALASKA COMPUTING CENTER * * * JUL ~4 1998 ............................. .~l~ka Oil & O~t~ Con~. Commission ........ SCH~.r~BERGER ........ ~OhOmflO COMPANY NAME : ARCO ALASKA INC. WELL NAME : DS 2-24 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-20744-00 REFERENCE NO : 98327 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/07/13 ORIGIN : FLIC REEL NAME : 98327 CONTINUATION # : PREVIOUS REEL : CO~NT : ARCO ALASKA INC, D.S. 2-24, PRUDHOE BAY, 50-029-20744-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/07/13 ORIGIN : FLIC TAPE NAME : 98327 CONTINUATION # : 1 PREVIOUS TAPE : COMI~ENT : ARCO ALASKA INC, D.S. 2-24, PRUDHOE BAY, 50-029-20744-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: DS 2-24 API NUMBER: 500292074400 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 13-JUL-98 JOB NUMBER: 98327 LOGGING ENGINEER: H. KIRKBY OPERATOR WITNESS: WORTHINGTON SURFACE LOCATION SECTION: 36 TOWNSHIP: 1 iN RANGE: 14E FNL: 1799 FSL: FEL: FWL : 36 ELEVATION(FT FROM MSL O) KELLY BUSHING: 64. O0 DERRICK FLOOR: 26. O0 GROUND LEVEL: 63.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) .............................................. 1ST STRING 3. 500 7. 000 10512.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: 1 PASS NUFIBER : 1 DATE LOGGED: 05-JUN-82 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH .............. 88888.0 10313.0 10295.5 10291.0 10288.0 10277.5 10264.0 10253.0 10251.0 10237.5 10228.5 10227.0 10224.0 10215.5 10207.5 10205.0 10196.0 10194.0 10176 5 10171 5 10148 0 10133 5 10132 0 10122 5 10119.5 10111.5 10090.5 10084.0 10082.5 10070.5 10061.0 10056.0 10052.5 100.0 $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH ....... 88893.0 10269.0 10256.0 10242.0 10230.0 10228.0 10219.0 10209.5 10198.5 10181.5 10151.5 10136.5 10124.5 10095.0 10086.5 10061.5 105.5 TDTP 88888.0 10313.0 10296.5 10295.0 10291.0 10280.0 10255.5 10230.0 10210.0 10198.5 10173.5 10136.5 10124.5 10113.5 10086.5 10074.0 10063.5 10055.5 103.0 REMARKS: CONTAINED HEREIN IS LDWG FORMATTED 3 PASS CASED HOLE TDTP DATA ACQUIRED ON ARCO ALASKA'S D.S. 2-24 WELL. TDTP PASS #1 WAS DEPTH CORRECTED TO THE GR.BCS CURVE PROVIDED BY THE CLIENT. PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 PAGE: **** FILE HEADER **** FILE NAFIE : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 10286.0 10034.0 TDTP 10313.0 10048.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. REMARKS: THIS FILE CONTAINS CASED HOLE TDTP PASS #1. TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA NO PASS TABLE TYPE : CONS TUNI VAL U DEFI CN FN WN APIN FL SECT TOWN RANG ARCO ALASKA INC. PRUDHOE BAY DS 2-24 50-029-20744-00 1799' FNL & 0036' FWL 36 lin 14E Company Name Field Name Well Name API Serial Number Field Location Section Township Range LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 PAGE: 4 TUNI VALU DEFI .................................................................................................... COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Nation WITN A WORTHINGTON Witness Name SON 1208458 Service Order Number PDAT RKB Permanent datum EPD FT O. Elevation of Permanent Datum LMF MSL Log Measured From APD FT 64. Above Permanent Datum EKB FT 64. Elevation of Kelly Bushing EDF FT 26. Elevation of Derrick Floor EGL FT 63. Elevation of Ground Level TDD FT 10334. Total Depth - Driller TDL FT 10314. Total Depth - Logger BLI FT 10313. Bottom Log Interval TLI FT 10034. Top Log Interval DFT PRODUCED FLUIDS Drilling Fluid Type DFD G/C3 9. Drilling Fluid Density TLAB 0930 27-APR-98 Time Logger at Bottom BHT DEGF 209. Bottom Hole Temperature TABLE TYPE .. CURV DEFI ........................................................... DEPT Depth SIGM Sigma (Neutron Capture Cross Section) TPHI TDT Porosity SBHF Borehole Sigma - far detector SBHN Borehole Sigma - Near detector SIGC Sigma Correction SIBH Corrected Borehole Sigma TRAT Ration Total Near to Far counts SDSI Standard deviation of Sigma BACK Background Count Rates - Near Detector FBAC Background Count Rate - Far Detector TCAN Total counts analyzed - near detector (TDTP) TCAF Total counts analyzed - far detector (TDTP) TCND Total capture counts - Near detector TCFD Total capture Counts - far dectector TSCN Total Selected Counts - Near Detector TSCF Total Selected Counts - Far Detector INND Inelastic count rate - near detector INFD Inelastic count rate - far detector GRCH Gamma Ray in Casing TENS Surface Tension CCL CCLAmplitude GR API-Corrected Gamma Ray LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ....................................................................................... DEPT FT 1208458 O0 000 O0 0 1 i 1 4 68 0000000000 SIGM TDTP CU 1208458 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI TDTP PU-S 1208458 O0 000 O0 0 1 1 1 4 68 0000000000 SBHF TDTP CU 1208458 O0 000 O0 0 1 1 1 4 68 0000000000 SBHN TDTP CU 1208458 O0 000 O0 0 1 1 1 4 68 0000000000 SIGC TDTP CU 1208458 O0 000 O0 0 1 1 1 4 68 0000000000 SIBH TDTP CU 1208458 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT TDTP 1208458 O0 000 O0 0 1 1 1 4 68 0000000000 SDSI TDTP CU 1208458 O0 000 O0 0 1 1 1 4 68 0000000000 BACK TDTP CPS 1208458 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC TDTP CPS 1208458 O0 000 O0 0 1 1 1 4 68 0000000000 TCANTDTP CPS 1208458 O0 000 O0 0 1 1 1 4 68 0000000000 TCAF TDTP CPS 1208458 O0 000 O0 0 1 1 I 4 68 0000000000 TCND TDTP CPS 1208458 O0 000 O0 0 1 1 1 4 68 0000000000 TCFD TDTP CPS 1208458 O0 000 O0 0 1 1 1 4 68 0000000000 TSCN TDTP CPS 1208458 O0 000 O0 0 1 1 1 4 68 0000000000 TSCF TDTP CPS 1208458 O0 000 O0 0 1 1 1 4 68 0000000000 INND TDTP CPS 1208458 O0 000 O0 0 1 1 1 4 68 0000000000 INFD TDTP CPS 1208458 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH TDTP GAPI 1208458 O0 000 O0 0 1 1 1 4 68 0000000000 TENS TDTP LB 1208458 O0 000 O0 0 1 1 1 4 68 0000000000 CCL TDTP V 1208458 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 1208458 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 PAGE: ** DATA ** DEPT. 10400.000 SIGM. TDTP -999.250 TPHI.TDTP -999.250 SBHF. TDTP SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP SDSI.TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP TSCF. TDTP -999.250 INND.TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP TENS. TDTP -999.250 CCL.TDTP -999.250 GR.BCS 41.375 DEPT. 10039.500 SIGM. TDTP -999.250 TPHI.TDTP -999.250 SBHF. TDTP SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP TENS. TDTP -999.250 CCL. TDTP -999.250 GR.BCS -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 12.500 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION : O01CO1 DATE : 98/07/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUM~J~Y LDWG TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 PAGE: GRCH 10278.0 10066.0 TDTP 10306.0 10076.0 $ CURVE SHIFT DATA - PASS TO PASS (F~ASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 102 66.5 10260.5 10250.0 10242.0 10238.0 10229.0 10217.0 10207.5 10205.5 10198.0 10192.0 10181.5 10174.5 10163.5 10158.0 10144.0 10133.5 10128.5 10126.0 10112.0 10104.5 10089.5 10084.0 10082.0 10068.0 100.0 $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. 88894.5 88890.5 10269.0 10263.0 10256.5 10244.0 10210.0 10197.5 10180.0 10163.5 10138.5 10134.5 10086.5 10073.0 105.0 10244.0 10230.5 10219.0 10210.0 10200.5 10184.5 10166.0 10147.0 10136.5 10128.5 10114.0 10107.0 10092.5 10086.5 102.5 REMARKS: THIS FILE CONTAINS CASED HOLE TDTP PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #2 AND GRCH PASS #1, ALSO CORRELATIONS BETWEEN SIGM PASS #2 AND SIGM PASS #1 CARRYING ALL TDTP CURVES WITH THE SIGM SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 PAGE: 8 TABLE TYPE : CONS TUNI VALU DEFI .................................................................................................... CN ARCO ALASKA INC. Company Name FN PRUDHOE BAY Field Name WN DS 2-24 Well Name APIN 50-029-20744-00 API Serial Number FL 1799' FNL & 0036' FWL Field Location SECT 36 Section TOWN liN Township RANG 14E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Nation WITN A WORTHINGTON Witness Name SON 1208458 Service Order Number PDAT PJfB Permanent datum EPD FT O. Elevation of Permanent Datum LMF MSL Log Measured From APD FT 64. Above Permanent Datum EKB FT 64. Elevation of Kelly Bushing EDF FT 26. Elevation of Derrick Floor EGL FT 63. Elevation of Ground Level TDD FT 10334. Total Depth - Driller TDL FT 10314. Total Depth - Logger BLI FT 10313. Bottom Log Interval TLI FT 10034. Top Log Interval DFT PRODUCED FLUIDS Drilling Fluid Type DFD G/C3 9. Drilling Fluid Density TLAB 0930 27-APR-98 Time Logger at Bottom BHT DEGF 209. Bottom Hole Temperature TABLE TYPE : CURV DEFI ........................................................... DEPT SIGM TPHI SBHF SBHN SIGC SIBH TRAT SDSI BACK FBAC TCAN TCAF TCND TCFD TSCN Depth Sigma (Neutron Capture Cross Section) TDT Porosity Borehole Sigma - far detector Borehole Sigma - Near detector Sigma Correction Corrected Borehole Sigma Ration Total Near to Far counts Standard deviation of Sigma Background Count Rates - Near Detector Background Count Rate - Far Detector Total counts analyzed - near detector (TDTP) Total counts analyzed - far detector (TDTP) Total capture counts - Near detector Total capture Counts - far dectector Total Selected Counts - Near Detector LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 PAGE: DEFI ........................................................... TSCF Total Selected Counts - Far Detector INND Inelastic count rate - near detector INFD Inelastic count rate - far detector GRCH Gamma Ray in Casing TENS Surface Tension CCL CCLAmplitude ........................................................... ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ....................................................................................... DEPT FT 1208458 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM TDTP CU 1208458 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 1208458 O0 000 O0 0 2 1 1 4 68 0000000000 SBHF TDTP CU 1208458 O0 000 O0 0 2 1 1 4 68 0000000000 SBHN TDTP CU 1208458 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 1208458 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 1208458 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 1208458 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 1208458 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 1208458 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 1208458 O0 000 O0 0 2 1 1 4 68 0000000000 TCAN TDTP CPS 1208458 O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 1208458 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 PAGE: 10 NAM~ SERV UNIT SERVICE API API API API FILE NUFIB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CI.~SS MOD NUlVlB SgMP ELI~I CODE (HEX) TCND TDTP CPS 1208458 O0 000 O0 0 2 1 1 4 68 TCFD TDTP CPS 1208458 O0 000 O0 0 2 1 1 4 68 TSCNTDTP CPS 1208458 O0 000 O0 0 2 1 1 4 68 TSCFTDTP CPS 1208458 O0 000 O0 0 2 1 1 4 68 INND TDTP CPS 1208458 O0 000 O0 0 2 1 1 4 68 INFD TDTP CPS 1208458 O0 000 O0 0 2 1 1 4 68 GRCH TDTP GAPI 1208458 O0 000 O0 0 2 1 1 4 68 TENS TDTP LB 1208458 O0 000 O0 0 2 1 1 4 68 CCL TDTP V 1208458 O0 000 O0 0 2 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 10308.500 SIGM. TDTP 16.838 TPHI.TDTP 22.997 SBHF. TDTP SBHN. TDTP 42 . 333 SIGC. TDTP 2. 858 SIBH. TDTP 46. 530 TRAT. TDTP SDSI. TDTP O. 549 BACK. TDTP 126. 411 FBAC. TDTP 34.132 TCAN. TDTP TCAF. TDTP 13602. 432 TCND. TDTP 26473. 109 TCFD. TDTP 8782. 402 TSCN. TDTP TSCF. TDTP 2875.939 INND. TDTP 2022.598 INFD. TDTP 473.658 GRCH. TDTP TENS. TDTP 1187. 000 CCL. TDTP O. 001 DEPT. 10071.000 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP TENS. TDTP -999. 250 CCL. TDTP -999. 250 35.421 1.667 31703.535 6703.024 -999.250 -999.250 -999.250 -999.250 -999.250 51.088 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 PAGE: 11 **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE ' FLIC VERSION ' O01CO1 DATE : 98/07/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCR~ENT: 0.5000 FILE SUFWL~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10246.0 10070.0 TDTP 10275.0 10078.0 $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 10263.5 10253.5 10242.5 10237.0 10217.5 10212.5 10211.0 10208.0 10205.5 10195.0 10192.5 10189.5 10183.0 10178.5 10172.0 10154.5 10148.5 10145.0 10136.0 10134.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88893.0 88890.5 10242.0 10217.0 10215.0 10209.5 10197.0 10182.0 10155.5 10150.5 10138.0 10266.0 10256.0 10244.5 10219.0 10210.0 10197.5 10192.0 10184.5 10173.5 10156.5 10147.5 10136.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 PAGE: 12 10132.5 10136.0 10123.0 10125.0 10105.0 10107.0 10091.5 10095.5 10087.5 10089.5 10083.0 10086.5 10074.5 10077.5 100.0 103.0 102.0 $ REMARKS: THIS FILE CONTAINS CASED HOLE TDTP PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #3 AND GRCH PASS #1, ALSO CORRELATIONS BETWEEN SIGM PASS #3 AND SIGM PASS #1 CARRYING ALL TDTP CURVES WITH THE SIGM SHIFTS. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA INC. Company Name FN PRUDHOE BAY Field Name WN DS 2-24 Well Name APIN 50-029-20744-00 API Serial Number FL 1799' FNL & 0036' FWL Field Location SECT 36 Section TOWN 1 IN Township RANG 14E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Na ti on WITN A WORTHINGTON Witness Name SON 1208458 Service Order Number PDAT RKB Permanent datum EPD FT O. Elevation of Permanent Datum LMF MSL Log Measured From APD FT 64. Above Permanent Datum EKB FT 64. Elevation of Kelly Bushing EDF FT 26. Elevation of Derrick Floor EGL FT 63. Elevation of Ground Level TDD FT 10334. Total Depth - Driller TDL FT 10314. Total Depth - Logger BLI FT 10313. Bottom Log Interval TLI FT 10034. Top Log Interval DFT PRODUCED FLUIDS Drilling Fluid Type DFD G/C3 9. Drilling Fluid Density TLAB 0930 27-APR-98 Time Logger at Bottom BHT DEGF 209. Bottom Hole Temperature LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 PAGE: 13 TABLE TYPE : CURV DEFI DEPT Depth SIGM Sigma (Neutron Capture Cross Section) TPHI TDT Porosity SBHF Borehole Sigma - far detector SBHN Borehole Sigma - Near detector SIGC Sigma Correction SIBH Corrected Borehole Sigma TRAT Ration Total Near to Far counts SDSI Standard deviation of Sigma BACK Background Count Rates - Near Detector FBAC Background Count Rate - Far Detector TCAN Total counts analyzed - near detector (TDTP) TCAF Total counts analyzed - far detector (TDTP) TCND Total capture counts - Near detector TCFD Total capture Counts - far dectector TSCN Total Selected Counts - Near Detector TSCF Total Selected Counts - Far DetectQr INND Inelastic count rate - near detector INFD Inelastic count rate - far detector GRCH Gamma Ray in Casing TENS Surface Tension CCL CCL Amplitude ........................................................... ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 PAGE: 14 ** SET TYPE - CHAN ** ....................................................................................... NA~E SERV UNIT SERVICE API API API API FILE NUF~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP EL~4 CODE (HEX) DEPT FT 1208458 O0 000 O0 0 3 1 1 4 68 0000000000 SIGMTDTP CU 1208458 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 1208458 O0 000 O0 0 3 1 1 4 68 0000000000 SBHF TDTP CU 1208458 O0 000 O0 0 3 1 1 4 68 0000000000 SBHNTDTP CU 1208458 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 1208458 O0 000 O0 0 3 1 1 4 68 0000000000 SIBH TDTP CU 1208458 O0 000 O0 0 3 1 1 4 68 0000000000 TRATTDTP 1208458 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 1208458 O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 1208458 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 1208458 O0 000 O0 0 3 1 1 4 68 0000000000 TCANTDTP CPS 1208458 O0 000 O0 0 3 1 1 4 68 0000000000 TCAF TDTP CPS 1208458 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 1208458 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 1208458 O0 000 O0 0 3 1 1 4 68 0000000000 TSCN TDTP CPS 1208458 O0 000 O0 0 3 1 1 4 68 0000000000 TSCF TDTP CPS 1208458 O0 000 O0 0 3 1 1 4 68 0000000000 INND TDTP CPS 1208458 O0 000 O0 0 3 1 1 4 68 0000000000 INFD TDTP CPS 1208458 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH TDTP GAPI 1208458 O0 000 O0 0 3 I 1 4 68 0000000000 TENS TDTP LB 1208458 O0 000 O0 0 3 1 1 4 68 0000000000 CCL TDTP V 1208458 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 10277.500 SIGM. TDTP 16.257 TPHI. TDTP 33. 044 SBHF. TDTP SBHN. TDTP 40. 052 SIGC. TDTP O . 1 O0 SIBH. TDTP 41 . 612 TRAT. TDTP SDSI . TDTP O . 489 BACK. TDTP 176.428 FBAC. TDTP 59.924 TCAN. TDTP TCAF. TDTP 14616. 367 TCND. TDTP 26080.598 TCFD. TDTP 7916. 427 TSCN. TDTP TSCF. TDTP 3076. 997 INND. TDTP 1360. 635 INFD. TDTP 370. 910 GRCH. TDTP TENS. TDTP 1485. 000 CCL. TDTP -0. 002 51.081 2.012 39101.320 8231.502 -999.250 DEPT. 10073.000 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP -999.250 SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP 81.575 TENS. TDTP - 999.250 CCL. TDTP - 999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 PAGE: 15 **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION : O01CO1 DATE : 98/07/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT O. 5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS .......................... 1, 2, 3, TDTP $ Riff_ARKS: THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF CASE HOLE TDTP PASSES 1,2, AND 3. DATA WAS CLIPPED OF INVALID READING BEFOR FIRST READING AND AFTER LAST READING PRIOR TO AVERAGING. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN FN WN APIN FL SECT TOWN RANG ARCO ALASKA INC. PRUDHOE BAY DS 2-24 50-029-20744-00 1799' FNL & 0036' FWL 36 liN 14E Company Name Field Name Well Name API Serial Number Field Location Section Township Range LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 PAGE: 16 TUNI VALU DEFI COUN NORTH SLOPE County STAT ALASKA State or Province NA TI USA Nat i on WITN A WORTHINGTON Witness Name SON 1208458 Service Order Number PDA T RKB Permanent datum EPD FT O. Elevation of Permanent Datum LMF MSL Log Measured From APD FT 64. Above Permanent Datum EKB FT 64. Elevation of Kelly Bushing EDF FT 26. Elevation of Derrick Floor EGL FT 63. Elevation of Ground Level TDD FT 10334. Total Depth - Driller TDL FT 10314. Total Depth - Logger BLI FT 10313. Bottom Log Interval TLI FT 10034. Top Log Interval DFT PRODUCED FLUIDS Drilling Fluid Type DFD G/C3 9. Drilling Fluid Density TLAB 0930 27-APR-98 Time Logger at Bottom BHT DEGF 209. Bottom Hole Temperature TABLE TYPE : CURV DEFI ........................................................... DEPT Depth SIGM Sigma (Neutron Capture Cross Section) TPHI TDT Porosity SBHF Borehole Sigma - far detector SBHN Borehole Sigma - Near detector SIGC Sigma Correction SIBH Corrected Borehole Sigma TRAT Ration Total Near to Far counts SDSI Standard deviation of Sigma BACK Background Count Rates - Near Detector FBAC Background Count Rate - Far Detector TCAN Total counts analyzed - near detector (TDTP) TCAF Total counts analyzed - far detector (TDTP) TCND Total capture counts - Near detector TCFD Total capture Counts - far dectector TSCN Total Selected Counts - Near Detector TSCF Total Selected Counts - Far Detector INND Inelastic count rate - near detector INFD Inelastic count rate - far detector GRCH Gamma Ray in Casing LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 PAGE: 17 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 80 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1208458 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM PNAV CU 1208458 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI PNAV PU-S 1208458 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF PNAV CU 1208458 O0 000 O0 0 4 1 1 4 68 0000000000 SBHNPNAV CU 1208458 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC PNAV CU 1208458 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH PNAV CU 1208458 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT PNAV 1208458 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI PNAV CU 1208458 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 1208458 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 1208458 O0 000 O0 0 4 1 1 4 68 0000000000 TCANPNAV CPS 1208458 O0 000 O0 0 4 1 1 4 68 0000000000 TCAF PNAV CPS 1208458 O0 000 O0 0 4 1 1 4 68 0000000000 TCNDPNAV CPS 1208458 O0 000 O0 0 4 1 1 4 68 0000000000 TCFD PNAV CPS 1208458 O0 000 O0 0 4 1 1 4 68 0000000000 TSCN PNAV CPS 1208458 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF PNAV CPS 1208458 O0 000 O0 0 4 1 1 4 68 0000000000 INND PNAV CPS 1208458 O0 000 O0 0 4 1 1 4 68 0000000000 INFD PNAV CPS 1208458 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 1208458 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 PAGE: 18 DEPT. 10313.000 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP 111.708 FBAC. TDTP 35.494 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD. PNAV -999.250 TSCNoPNAV -999.250 TSCF. PNAV -999.250 INND.PNAV -999.250 INFD.PNAV -999.250 GRCH. TDTP -999.250 DEPT. 10039.500 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD. PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND.PNAV -999.250 INFD.PNAV -999.250 GRCH. TDTP 12.500 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/13 MAX REC SIZE : 1024 FILE TYPE ,: LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SUFmUhgY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... TDTP 10307.0 10100.0 $ LOG HEADER DATA DATE LOGGED: 27-APR-98 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 PAGE: 19 SOFTWARE VERSION: TIFIE LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 8C1-205 930 27-APR-98 10334.0 10314.0 10034.0 10313.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~L~ RAY TDTP THERMAL DECAY $ TOOL NUMBER ........... CGRS-A TNC- P BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 3.500 10512.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS 9.00 209.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 REMARKS: TIED IN WITH ATLAS CEMENT BOND LOG OF 6-8-82 THREE PASSES RUN WITH TDT-P NOTE: THERE IS A CASING - TUBING CHANGE 9407'-10261' : 3.5: 9.3# L-80 9368'-10330' : 7" 29# L-80 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 PAGE: 2O SO THE FOLLOWING PARAMETERS WERE SET: FROM 10100' TO 10261' : CSIZ=7",CSID=6.184",CWEI=29#,BS=7 FROM 10261' TO TD: CSIZ=7",CSID=6.184",CWEI = 38.3#,BS=3.5 PUMPING SUMM~ARY: A TOTAL OF 325 BBL OF CRUDE AND i0 BBL OF DIESEL WERE PUMPED. THIS FILE CONTAINS THE RAW DATA OF CASED HOLE TDTP PASS #1 $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA INC. Company Name FN PRUDHOE BAY Field Name WN DS 2-24 Well Name APIN 50-029-20744-00 API Serial Number FL 1799' FNL & 0036' FWL Field Location SECT 36 Sec ti on TOWN 1 IN Township RANG 14E Range COUN NORTH SLOPE County STAT ALASKA State or Province NA TI USA Nat i on WITN A WORTHINGTON Witness Name SON 1208458 Service Order Number PDAT RKB Permanent datum EPD FT O. Elevation of Permanent Datum LMF MSL Log Measured From APD FT 64. Above Permanent Datum EKB FT 64. Elevation of Kelly Bushing EDF FT 26. Elevation of Derrick Floor EGL FT 63. Elevation of Ground Level TDD FT 10334. Total Depth - Driller TDL FT 10314. Total Depth - Logger BLI FT 10313. Bottom Log Interval TLI FT 10034. Top Log Interval DFT PRODUCED FLUIDS Drilling Fluid Type DFD G/C3 9. Drilling Fluid Density TLAB 0930 27-APR-98 Time Logger at Bottom BHT DEGF 209. Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT Depth SIGM Sigma (Neutron Capture Cross Section) TPHI TDT Porosity SBHF Borehole Sigma - far detector SBHN Borehole Sigma - Near detector LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 PAGE: 21 DEFI SIGC Sigma Correction SIBH Corrected Borehole Sigma TRAT Ration Total Near to Far counts SDSI Standard deviation of Sigma BACK Background Count Rates o Near Detector FBAC Background Count Rate - Far Detector TCAN Total counts analyzed - near detector (TDTP) TCAF Total counts analyzed - far detector (TDTP) TCND Total capture counts - Near detector TCFD Total capture Counts - far dectector TSCN Total Selected Counts - Near Detector TSCF Total Selected Counts - Far Detector INND Inelastic count rate - near detector INFD Inelastic count rate - far detector TENS Surface Tension GR API-Corrected Gamma Ray CCL CCL Amplitude ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 O.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1208458 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM PS1 CU 1208458 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 PAGE: 22 NAFIE SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELI~ CODE (HEX) TPHI PS1 PU 1208458 O0 000 O0 0 5 SBHF PS1 CU 1208458 O0 000 O0 0 5 SBHNPS1 CU 1208458 O0 000 O0 0 5 SIGC PS1 CU 1208458 O0 000 O0 0 5 SIBH PS1 CU 1208458 O0 000 O0 0 5 TRAT PS1 1208458 O0 000 O0 0 5 SDSI PS1 CU 1208458 O0 000 O0 0 5 BACK PS1 CPS 1208458 O0 000 O0 0 5 FBAC PS1 CPS 1208458 O0 000 O0 0 5 TCANPS1 CPS 1208458 O0 000 O0 0 5 TCAF PS1 CPS 1208458 O0 000 O0 0 5 TCND PS1 CPS 1208458 O0 000 O0 0 5 TCFD PS1 CPS 1208458 O0 000 O0 0 5 TSCN PS1 CPS 1208458 O0 000 O0 0 5 TSCF PS1 CPS 1208458 O0 000 O0 0 5 INND PS1 CPS 1208458 O0 000 O0 0 5 INFD PS1 CPS 1208458 O0 000 O0 0 5 TENS PS1 LB 1208458 O0 000 O0 0 5 GR PS1 GAPI 1208458 O0 000 O0 0 5 CCL PS1 V 1208458 O0 000 O0 0 5 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 ** DATA ** DEPT. 10322.500 SIGM. PS1 -999.250 TPHI. PS1 -999.250 SBHF. PS1 SBHN. PS1 -999.250 SIGC. PS1 -999.250 SIBH. PS1 -999.250 TRAT. PS1 SDSI.PS1 -999.250 BACK. PSi -999.250 FBAC. PSi -999.250 TCAN. PS1 TCAF. PS1 -999.250 TCND.PS1 -999.250 TCFD.PS1 -999.250 TSCN. PS1 TSCF. PS1 -999.250 INND.PS1 -999.250 INFD. PSi -999.250 TENS. PSi GR.PS1 83.906 CCL.PS1 -0.010 DEPT. 10032.500 SIGM. PS1 12.254 TPHI.PS1 15.391 SBHF. PS1 SBHN. PS1 52.835 SIGC. PS1 0.611 SIBH. PS1 102.822 TRAT. PS1 SDSI.PS1 0.196 BACK. PSi 84.024 FBAC. PS1 14.007 TCAN. PS1 TCAF. PS1 20196.051 TCND. PS1 24257.715 TCFD. PS1 9244.260 TSCN. PS1 TSCF. PS1 4245.475 INND.PS1 1832.134 INFD.PS1 350.158 TENS. PSi GR.PS1 12.644 CCL.PS1 -999.250 -999.250 -999.250 -999.250 -999.250 1010.000 38.680 1.533 38485.516 8090.161 1478.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 PAGE: 23 **** FILE TRAILER **** FILE NAFIE : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01COi DATE : 98/07/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... 10307.0 10100.0 TDTP $ LOG HEADER DATA DATE LOGGED: 27-APR-98 SOFTWARE VERSION: 8C1-205 TIME LOGGER ON BOTTOM: 930 27-APR-98 TD DRILLER (FT) : 10334.0 TD LOGGER (FT) : 10314.0 TOP LOG INTERVAL (FT): 10034.0 BOTTOM LOG INTERVAL (FT) : 10313.0 LOGGING SPEED (FPHR): 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAMMA RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUMBER ........... CGRS-A TNC~P 3.500 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 PAGE: 24 DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 10512.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS 9.00 209.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 REMARKS: TIED IN WITH ATLAS CEMENT BOND LOG OF 6-8-82 THREE PASSES RUN WITH TDT-P NOTE: THERE IS A CASING - TUBING CHANGE 9407'-10261' : 3.5: 9.3# L-80 9368'-10330' : 7" 29# L-80 SO THE FOLLOWING PARAMETERS WERE SET: FROM 10100' TO 10261' : CSIZ=7",CSID=6.184",CWEI=29#,BS=7 FROM 10261' TO TD: CSIZ=7",CSID=6.184",CWEI = 38.3#,BS=3.5 PUMPING S~Y: A TOTAL OF 325 BBL OF CRUDE AND 10 BBL OF DIESEL WERE PUMPED. THIS FILE CONTAINS THE RAW DATA OF CASED HOLE TDTP PASS #2 $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN FN WN ARCO ALASKA INC. PRUDHOE BAY DS 2-24 Company Name Field Name Well Name LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 PAGE: 25 TUNI VALU DEFI APIN 50-029-20744-00 API Serial Number FL 1799' FNL & 0036' FWL Field Location SECT 36 Sec ti on TOWN I iN Township RANG 14E Range COUN NORTH SLOPE County STAT ALASKA State or Province NA TI USA Nat i on WITN A WORTHINGTON Witness Name SON 1208458 Service Order Number PDAT RKB Permanent datum EPD FT O. Elevation of Permanent Datum LMF MSL Log Measured From APD FT 64. Above Permanent Datum EKB FT 64. Elevation of Kelly Bushing EDF FT 26. Elevation of Derrick Floor EGL FT 63. Elevation of Ground Level TDD FT 10334. Total Depth - Driller TDL FT 10314. Total Depth - Logger BLI FT 10313. Bottom Log Interval TLI FT 10034. Top Log Interval DFT PRODUCED FLUIDS Drilling Fluid T3~oe DFD G/C3 9. Drilling Fluid Density TLAB 0930 27-APR-98 Time Logger at Bottom BHT DEGF 209. Bottom Hole Temperature TABLE TYPE : CURV DEFI ........................................................... DEPT SIGM TPHI SBHF SBHN SIGC SIBH TRA T SDSI BACK FBAC TCAN TCAF TCND TCFD TSCN TSCF INND INFD TENS GR Depth Sigma (Neutron Capture Cross Section) TDT Porosity Borehole Sigma - far detector Borehole Sigma - Near detector Sigma Correction Corrected Borehole Sigma Ration Total Near to Far counts Standard deviation of Sigma Background Count Rates - Near Detector Background Count Rate - Far Detector Total counts analyzed - near detector (TDTP) Total counts analyzed - far detector (TDTP) Total capture counts - Near detector Total capture Counts - far dectector Total Selected Counts - Near Detector Total Selected Counts - Far Detector Inelastic count rate - near detector Inelastic count rate - far detector Surface Tension API-Corrected Gamma Ray LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 PAGE: 26 DEFI ........................................................... CCL CCL Ampl i rude ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1208458 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PS2 CU 1208458 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PS2 PU 1208458 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF PS2 CU 1208458 O0 000 O0 0 6 1 1 4 68 0000000000 SBHNPS2 CU 1208458 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC PS2 CU 1208458 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH PS2 CU 1208458 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PS2 1208458 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI PS2 CU 1208458 O0 000 O0 0 6 1 1 4 68 0000000000 BACK PS2 CPS 1208458 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC PS2 CPS 1208458 O0 000 O0 0 6 1 1 4 68 0000000000 TCANPS2 CPS 1208458 O0 000 O0 0 6 1 1 4 68 0000000000 TCAF PS2 CPS 1208458 O0 000 O0 0 6 1 1 4 68 0000000000 TCNDPS2 CPS 1208458 O0 000 O0 0 6 1 1 4 68 0000000000 TCFD PS2 CPS 1208458 O0 000 O0 0 6 1 1 4 68 0000000000 TSCN PS2 CPS 1208458 O0 000 O0 0 6 1 1 4 68 0000000000 TSCF PS2 CPS 1208458 O0 000 O0 0 6 1 1 4 68 0000000000 INNDPS2 CPS 1208458 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 PAGE: 27 NAM~ SERV UNIT SERVICE API API API API FILE NUIVIB NUF~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP ELI~I CODE (HEX) INFD PS2 CPS 1208458 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1208458 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1208458 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 1208458 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 10314.500 SIGM. PS2 -999.250 TPHI.PS2 -999.250 SBHF. PS2 SBHN. PS2 -999.250 SIGC.PS2 -999.250 SIBH. PS2 -999.250 TRAT. PS2 SDSI.PS2 -999.250 BACK. PS2 -999.250 FBAC. PS2 -999.250 TCAN. PS2 TCAF. PS2 -999.250 TCND.PS2 -999.250 TCFD.PS2 -999.250 TSCN. PS2 TSCF. PS2 -999.250 INND.PS2 -999.250 INFD.PS2 -999.250 TENS. PS2 GR.PS2 55.938 CCL.PS2 0.010 DEPT. 10062.500 SIGM. PS2 10.909 TPHI.PS2 16.384 SBHF. PS2 SBHN. PS2 54.721 SIGC. PS2 0.572 SIBH. PS2 109.996 TRAT. PS2 SDSI.PS2 0.154 BACK. PS2 121.404 FBAC. PS2 25.039 TCAN. PS2 TCAF. PS2 21079.309 TCND.PS2 24821.703 TCFD.PS2 9159.914 TSCN. PS2 TSCF. PS2 4413.902 INND.PS2 1818.110 INFD. PS2 357.712 TENS. PS2 GR.PS2 54.779 CCL.PS2 -999.250 -999.250 -999.250 -999.250 -999.250 872.000 40.397 1.625 41885.227 8770.557 1437.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : 001 CO1 DATE : 98/07/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 PAGE: 28 FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCPd~4F2FT: 0.5000 FILE SUM~NL~Y VENDOR TOOL CODE START DEPTH ........................... 10307.0 TDTP LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 10100.0 27-APR-98 8C1-205 930 27-APR-98 10334.0 10314.0 10034.0 10313.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY TDTP THERMAL DECAY $ TOOL NUMBER ........... CGRS-A TNC-P BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 3.500 10512.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS 9.00 209.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 PAGE: 29 BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 RElqAPJfS: TIED IN WITH ATLAS CE~fF2TT BOND LOG OF 6-8-82 THREE PASSES RUN WITH TDT-P NOTE: THERE IS A CASING - TUBING CHANGE 9407'-10261' : 3.5: 9.3# L-80 9368'-10330' : 7" 29# L-80 SO THE FOLLOWING PARAMETERS WERE SET: FROM 10100' TO 10261' : CSIZ=7",CSID=6.184",CWEI=29#,BS=7 FROM 10261' TO TD: CSIZ=7",CSID=6.184",CWEI = 38.3#,BS=3.5 PUMPING SU~FiARY: A TOTAL OF 325 BBL OF CRUDE AND 10 BBL OF DIESEL WERE PUMPED. THIS FILE CONTAINS THE RAW DATA OF CASED HOLE TDTP PASS #3 $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA INC. Company Name FN PRUDHOE BAY Field Name WN DS 2-24 Well Name APIN 50-029-20744-00 API Serial Number FL 1799' FNL & 0036' FWL Field Location SECT 36 Sec ti on TOWN 11 N Town ship RANG 14E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Na ti on WITN A WORTHINGTON Witness Name SON 1208458 Service Order Number PDA T RKB Permanent datum EPD FT O. Elevation of Permanent Datum LMF MSL Log Measured From APD FT 64. Above Permanent Datum EKB FT 64. Elevation of Kelly Bushing EDF FT 26. Elevation of Derrick Floor EGL FT 63. Elevation of Ground Level TDD FT 10334. Total Depth - Driller TDL FT 10314. Total Depth - Logger BLI FT 10313. Bottom Log Interval TLI FT 10034. Top Log Interval DFT PRODUCED FLUIDS Drilling Fluid Tylue DFD G/C3 9. Drilling Fluid Density LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 PAGE: 30 TUNI VALU DEFI TLAB 0930 27-APR-98 Time Logger at Bottom BHT DEGF 209. Bottom Hole Temperature .................................................................................................... TABLE TYPE : CURV DEFI ........................................................... DEPT Depth SIGM Sigma (Neutron Capture Cross Section) TPHI TDT Porosity SBHF Borehole Sigma - far detector SBHN Borehole Sigma - Near detector SIGC Sigma Correction SIBH Corrected Borehole Sigma TRAT Ration Total Near to Far counts SDSI Standard deviation of Sigma BACK Background Count Rates - Near Detector FBAC Background Count Rate - Far Detector TCAN Total counts analyzed - near detector (TDTP) TCAF Total counts analyzed - far detector (TDTP) TCND Total capture counts - Near detector TCFD Total capture Counts - far dectector TSCN Total Selected Counts - Near Detector TSCF Total Selected Counts - Far Detector INND Inelastic count rate - near detector INFD Inelastic count rate - far detector TENS Surface Tension GR API-Corrected Gamma Ray CCL CCLAmplitude ........................................................... ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE V~UE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 PAGE: 31 TYPE REPR CODE VALUE 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1208458 O0 000 O0 0 7 1 1 4 SIGM PS3 CU 1208458 O0 000 O0 0 7 1 1 4 TPHI PS3 PU 1208458 O0 000 O0 0 7 1 1 4 SBHF PS3 CU 1208458 O0 000 O0 0 7 1 1 4 SBHNPS3 CU 1208458 O0 000 O0 0 7 1 1 4 SIGC PS3 CU 1208458 O0 000 O0 0 7 1 1 4 SIBH PS3 CU 1208458 O0 000 O0 0 7 1 1 4 TRAT PS3 1208458 O0 000 O0 0 7 1 1 4 SDSI PS3 CU 1208458 O0 000 O0 0 7 1 1 4 BACK PS3 CPS 1208458 O0 000 O0 0 7 1 1 4 FBAC PS3 CPS 1208458 O0 000 O0 0 7 1 1 4 TCANPS3 CPS 1208458 O0 000 O0 0 7 1 1 4 TCAF PS3 CPS 1208458 O0 000 O0 0 7 1 1 4 TCNDPS3 CPS 1208458 O0 000 O0 0 7 1 1 4 TCFD PS3 CPS 1208458 O0 000 O0 0 7 1 I 4 TSCN PS3 CPS 1208458 O0 000 O0 0 7 1 I 4 TSCF PS3 CPS 1208458 O0 000 O0 0 7 1 1 4 INND PS3 CPS 1208458 O0 000 O0 0 7 1 1 4 INFD PS3 CPS 1208458 O0 000 O0 0 7 1 1 4 TENS PS3 LB 1208458 O0 000 O0 0 7 1 i 4 GR PS3 GAPI 1208458 O0 000 O0 0 7 1 1 4 CCL PS3 V 1208458 O0 000 O0 0 7 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. 10281.500 SIGM. PS3 -999.250 TPHI.PS3 SBHN. PS3 -999.250 SIGC. PS3 -999.250 SIBH. PS3 SDSI.PS3 -999.250 BACK. PS3 -999.250 FBAC. PS3 TCAF. PS3 -999.250 TCND.PS3 -999.250 TCFD. PS3 TSCF. PS3 -999.250 IArArD.PS3 -999.250 INFD. PS3 GR.PS3 184.265 CCL.PS3 -0.010 -999.250 SBHF. PS3 -999.250 TRAT. PS3 -999.250 TCAN. PS3 -999.250 TSCN. PS3 -999.250 TENS.PS3 -999.250 -999.250 -999.250 -999.250 1114.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-JUL-1998 13:29 PAGE: 32 **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/07/13 ORIGIN : FLIC TAPE NAME : 98327 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, D.S. 2-24, PRUDHOE BAY, 50-029-20744-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/07/13 ORIGIN : FLIC REEL NAME : 98327 CONTINUATION # : PREVIOUS REEL : COF~ENT : ARCO ALASKA INC, D.S. 2-24, PRUDHOE BAY, 50-029-20744-00 RECEIVED MA Y 0 1995 Alaska Oil & G as Cons. Co . AnchoragE) mnllSSlo.l,. 8:z -7! ~ ~ ~ ~(\ R'EC'EIVHD MAY 04 1995 Alaska Oil & Gas Cons. Commission Anchorage *t*****~*.*.*****'************ * * * ALASYA cn~PUTING C~NTER * * * ***************************.** *---___-_-8-_-~__-----~-~---~* *---.--... S(:hLU¡VIBFRGER --...--....-* *---_.--_-_~B-___~_---~---~--* ****************************** c U ì'~ P f~ ¡\j Y N f\ ¡']; [ !j E L. L, f,: Þ. fA E vIELe r-1AMt: RCHCI!GH BTP-,TF ðJ;JI 1',:urlbEH F F~ F f~ HEr,] C E N C: ~ ÞRCU ALASKA, INC. .. n c; '-24 oø ,_-.L. - ,- ; P f< U D HUt, B ¡~ Y ~ NOPTH SLOPE : ÞL,ò,t)I<.,4 : 50~O29~20744-00 ; 95154 [:IS Tape Yer]f..tcatJo~ List.~.nq $chlun-~berqer AlaSka Computino Center 1-~AY-1995 14:05 S~RV]CE NA~c,E .' D~TF : 95105/ 1 U~ICi~! : VLJC RFEI~ ?~A~-~3 : 95154 C~'JNUA'FIU~q ~ : PREVIOUS ~EEb : C0~4~[.:t-1'I : A~C{.) ALASKA INC., PRUD~OE BAY, O8 2-24, AP1 ~50-029-20744-00 6FRVJ'CE NA,~4E : EDT'I~ D~TF ~ ~5/05/ 1 O~ IC ].I'~ : FLiC TApv ~,~A~-~'E : 95154 CO~iTINiJATIU~.~ ~ ~ ~ PREV] O!JS TAPE : CF~:t'4'I' : hRCt~ .. ALASKA lt,iC., PRI..IDHOE BAY, DS ..... 2-~4, APl ~50-0~2q-20744~ . -00 TAPV Hk;ADEb: CASED HObE WIRELII~jE LO(aS WPh[. NA~.~!E: LOGClt~G C~-~DANY: TAPE CREATION DATE: LOG~I~4G SI~RFACE LOCATIO~ TO~;NSHIP: FSL: Fwb: f~Lt:;;VATION(FT FR[),~, MSI~ O) C RO!.~D LEVEL~ WEb[, CASI~:G RECOR~ ?fit, STRI~,G RP, D STRI~!G D,S, 2'24 5002920?4400 SCHI-,UMBE~GER ~,LL SERVICE5 95154: BAILEY ~,~EYDOLDS 36 11~ ~799 63 O0 OPEN HOLE CASING DRILLERS CASING BIT SIZF (i~) SIZE (I~) DEPTH (FT) WEIGHT (LB/FT) 9.625 g2"O. 6q 47 O0 7.0(.!0 105~2.0 29i00 5,500 9~73,0 17 O0 4.500 9447.0 12 60 ,SHIFT DATA -. AbL PASSE,_' 7'~ T(''~ ........... $'I:A~'~DARt)(V;EASU~'~jD D~:PTb') PAGE: LIS TaDe Scb lumber 103 lu3 1 1 ('3 ! 03 103 10 ~ 10~ 102 1C, 2 162 !02 102 101 101 1 01 101 !01 ! 61 1 !01 1 O0 verif lcatlor'. ;,istlno Qer AlasKa Computino Cer~ter E!..,IfqE CURVE FOk 5HI~'TS Lr)~G CURVE bATE I, OGGED: LF)GCI~G COt..~PA~':Y: SCPLU~4BE~GE~ 60,5 43,0 10343,0 30.0 1.0330.0 2~.5 24,5 1O324.0 2O ,5 J. 6 5 1o316.5 · OR.5 0 fi, 5 96,5 95.0 10295, O 92,5 8R.5 ~4,5 84.,n 1.6284.o 76,5 10278.O 66.5 !.0~66.5 60,5 56,5 55,5 1.0256.0 4~,5 4~.5 36.5 32,5 2R,5 24.5 12.5 09,0 1.0~09.5 0n, 5 96.5 72:5 6R,5 60,5 56,5 45,5 10146,0 44.5 40,5 85,5 10087,0 84.5 1-~Y-1995 14:05 .......... EOUIVAb~iaT tiNS~IFTED DEPT~t-- ....... GRCH CNTD 1.0360,5 1O328,5 !.0325,0 10321.0 10316,5 10312,5 10309 0 10301i0 10297 5 1. 0294 0 10290i~ 102~5 10281.0 10276.5 1o260 5 10256:0 10248 0 10243 5 10235 5 10231. 0 10227 0 1O222 5 lu210 5 10206,0 10!98,0 ~0193.5 10185.5 1018~,0 10170 0 101,6615 10156 ~ 10143,0 10139,5 10083.5 PAGE: LIS Tape ver~f~.catlor: bistinn Scblumber~.~er A]..asKa Computino Center 1-~AY-1995 14:05 1(~0,5 1006P,5 10O64 5 10056,5 10052,5 1004R.5 1O024,0 t0025.0 ~g2,0 9983,0 9972,5 9~6R.5 9052,5 9e54,0 9932,5 9900.5 9896,5 QRT~,5 9~75,O 9R67,5 9869.5 9~32.5 9829.0 9~28.5 O~24,5 9R20.5 982~,5 9797 0 9798,0 1.00;m 101.0 $ tO All $ $ 10079,0 ~.0067,0 10062.5 10058,5 10055,0 1O051.0 10047,5 9971.5 9967,0 9931.,0 9926,5 ~898 5 ~895;0 987~.,0 9866,5 9830.5 9827,0 9823,0 9819,5 99,0 depth correction showR above reflects cased hole GR oper~ hole GR, and cased hole NPHI~ to open hole GR.. other' C~'rD curves were carried with NPHI shifts, **** FILE HEADER **** FILE ~A~E : ~;OIT ,OOi SFRV]CE : FLIC V~RSID~ ~ O0~CO1 DATE ~ Q5/05/ ! MaX kF;C S1'ZE : 1024 FILE q'YP~ : [,O LhST FIf,E : PAGE: FIL~ HEADER FILE k~O?'.!fi~:R: 1 EDITED CUPVMS DePth shifted and clipped PASS DFPmH IMCRE~ENT: 0.5000 FTLF for each pass in separate files, [,iS '?ape Verl. ftcattor~ bistinq Schlt~mberg~r AlasKa Com~:,'utlng Center 1-~A¥-!995 14:05 CO0~: START ne.;P',,:H STO. P DEPT}: l 0374.0 9785.0 "' -- PASS . EA!~ TO PgS~(MEASURgD DEPTN) CIIRVE FOR SHIFTS .......... M{}UIVASE~T UN5NIFTED DEPTH---------- iIl~I~iiii~III This file conatlns pass ~'1 of the CNTD. ~o pa.ss to pass shifts ~,~ere applied to this daEa. PAGE: ** D~TA FORNAT SPECTFICATIi3N RECOP. D ** SET TYPE - 64ga ** T~PE REPR CODE VALUE i 6b 0 2 66 0 3 73 48 4, 66 1 5 66 6 73 7 65 8 68 0,5 9 65 1~ 66 21 17 68 1] 66 0 14 65 15 66 16 66 0 66 0 LIS Ta~e Verlflcattor~ Llstin~ Schlumberger h]..as~.a Co~.,putin~ Center I-N~Y-1995 14:05 *~ SET TYPE - C!4A~ *~ ~M~: . E . I IP AP! gPI FILE NU NUmB SIZE REP~ PROCE$ DKPT FT .0 O0 000 O0 0 1 4 68 OD0 ._ 0 0 O0 000 00 0 I t !. 4 68 0000000000 NPHT Ci~TD PU-S 5~6303 ~A? C~TD 5u6303 O0 000 00 0 I 1 1 4 68 CDAT C~TD 506303 o0 000 00 0 1 I ~ 4 68 NCNT C~TO CPS ~06303 00 000 00 0 1 1 1 4 68 FC~ C~TD CPS 506303 00 000 00 (~ I 1 l 4 68 CFTC C:~TD CP6 hc~303 o0 000 00 0 I 1 1 4 68 CNTC CNTD CPS ~96303 00 000 O0 0 1 I 1 4 68 G~C~ CNTO GAPI 5~)~30~ 00 OO0 00 0 1 1 ~ 4 68 TFNS CNTD bB 506303 00 000 00 0 1 1 1 4 68 CCL C~TD V 506303 00 000 00 O I 1 1 4 68 GR BCS GAPI 5U6303 00 000 00 0 I 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 D~PT. lO469.t~00 ~PH!. Ci'~TD -999.250 NCN T. C'!'.iWD -9q9.25(, FCNT.CNTD -999.250 GRCH. C~'~TO -999.25(~ TE,~[S. CNTD -999.~50 DEpt. qo6N.OnO NPHI.CNTD NCNT.C~TD -999.25U FCNT.C~TD (;~C~.C~TO -9q~.250 TENS.CNTD NRAT.C~TD CFTC.CNTD CCL.C~TD -999.250 NRAT.CNTD -999.250 CFTC.CaTD -999.250 CCL.C~TD -999.250 CRAT.CNTD -999 'O . . .~ CNTC,CNTD -999.250 GR.BCS -999 · o 25. Cn~T.C~O -999~250 CNTC'CN?D -999.250 GR.BCS -999.250 -999'250 122,500 -999.' 250 -999,250 '67~125 FTLF N~!E : EOIT .001 SFRVi;rE : ~L~C VFH$!OH DAT~ MAX ~EC SIZE : !0~4 FIL~ TYPE : LAST FILE **** FILE HEADER SFPVICE : FLIC V~RSZn~i : nOlCO1 DAT~ : 95/05/ 1 NAX RFC SIZE : 1~24 FILF 'tYPE : SchluiT, ber~]~r AlasKa ComF, tlt~.nq (._nter I.-~AY-1995 14105 '1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 ! ! 1 cllpmed curves 500O for each pass separate files. F,'::G TOO[, CUD[,] START DEPTI'! STOP DEPTH ~CH ................. !035~i; .... '~793.0 '' i,~q'D 1. 0~7 4,0 9793.0 SHIFT DATA - PASS T~3 PASS(~.IEASURED DEPT~) ~SELINE CURVE P"rJR SHIFTS l,OwG CUR~'~: CODS: qRCH 36~.5 356.0 351.5 342 5 337:5 336.0 32~.0 324.5 32~.0 ~21.0 312 5 304:0 29g.0 ~9~.5 ~90.0 279.0 ~7~.0 ~70.5 76~.0 960.0 ~50.0 ~43.5 236.5 73~.5 ?26.0 224.5 211,0 20~.5 ---- ...... E~tlIVALEMT (;RCH CNTD BUlB . . B ,5 10369,0 10356.0 10351.0 10343.0 10336.0 10324.5 10292,0 1.028().5 10268.5 10237.5 10234.0 !0226.o 1o209.5 ]033R.0 10333,0 10327.0 10324.0 10321.0 10312.5 ~0304,0 !0294,0 10289,0 10279.0 ~0273.0 1(!270.5 1 0260 0 0244 5 10231,0 10226,0 10213.0 ~,0196.0 UNSHIFTE[ DEPT~' [.,IS Tape Verification List.lnq Schlumberger Alaska ComputinO Center 1-~AY-1995 t4:05 0181.o 10~84.5 0179,O 10179.0 6175.0 10177.5 0157.5 10157.5 014~.5 10~47.0 0144.,0 1014~,0 0127.0 ~0~28.5 008R 5 10089.5 (,06~i5 10063.5 0047 0 1004~,5 00~5.5 10026.5 10026.5 9~82.0 99B~.0 9983.0 9~48.0 9949,5 9912.5 9914.0 9914 S 9~9!,0 9993,0 ~879,5 9881,0 9~7~,5 9875,0 9967,5 9~69,5 9869,5 9857,0 9859,5 9R45,5 9948,0 Q~3~,5 9~35,5 9~23.0 9824,5 g~20 5 9821.5 9814:0 9815,5 9~11.0 9811,5 O806.5 9fl07,5 9799,0 9800.0 9797,0 9798.0 9794,0 9795,5 PEr'ARKS: This file contains CNTG Pass shown above relict GRCH PaSs WPH~ pass ~2 to ~PHI pass Sbis Ff)R~,~AT DATA ~2. The depth ~2 to GRCH PaSS shifts #1 and PAGE: ** DAT~, FORe'AT SPw~C!F[CAT!ON [.{~,C,~RL ** SET TYPE - 64E~ ** T .PR COPE VAL.jE I 66 0 2 66 0 3 73 44 4 66 I LiS Tape Verification Listlnn $cbl~lnberger AlasKa Con~putfn~ Cemter ~-~;AY-1995 14:05 PA~E: ';T b 66 b 73 7 65 ~ 68 9 65 II 66 12 6d i3 66 0 14 65 FT 15 66 6~ 16 66 1 0 66 ~ 0.5 FT 23 h ~ i;iF S~:RV UNI ID ORDE D~PT fit NPH] C:qTD PU-S 5063 NPAT CNTD 5u63 C~AT Ci'~ T 0 5063 NC~T C~TD CPS 5063 FCkT C ~"~ T D CPS 5063 CWTC CNTD CP6 5063 CNTC ChTD CPS 5063 GDCH C~,~T~) GAPI 5063 TENS C?.~ TD bB 5063 CHAN ** ............... '"" '" ....... '"'"'"'"' .... bOG I PF,, CLASS MOD NUmB SAMP ELEa CODE (HEX) 03 O0 000 O0 0 2 1 i 4 68 0000000000 03 O0 000 O0 0 2 1 1 4 68 0000000000 03 O0 0o0 O0 0 2 ! I 4 68 0000000000 03 O0 OOO O0 0 2 ! ! 4 68 0000000000 03 00 O00 00 0 2 1 I 4 68 0000000000 03 O0 OOO O0 o 2 ! 1 4 68 0000000000 03 00 000 O0 0 2 1 I 4 68 0000000000 03 oo 000 O0 0 2 I I 4 68 0000000000 O3 o0 0o0 O0 o 2 I I 4 68 0000000000 03 O0 O(:O O0 0 2 1 1 4 68 0000000000 DEPT. 10374.500 NCNT.CNTD 2565.130 GaCN.Ci~TO -999.250 DEPT. 97~4.000 NCNT.C~iTD 4248.6~3 NPHI.C~TD 25.790 NR'AT.CNTD 4.500 FCNT.CNTD 576.577 CFTC.CMTD 525'570 TENS.CNTD i205,000 CCL.CMTD 0.000 ~,~PHI.CaTD 17,8~1 NRAT.CNTD 3.518 FCNT.CNTD i330'6~1 CFTC.CNTD 1268~, 191 T~;N S. C~'JTD 1150.000 CCL, CM'I'D 0,000 CRAT CNTD CNTC:CNTD CRAT.CNTD CNTC.CNTD 4.520 25It..774 4423,469 2,292 LIS Tape verl. f!catjon [.,ist~.nq Schlumberger GlasKa Computlnq Cch%er 1-~A¥-!995 1~:05 PAGE: ** *.*. ? ]' [,F~ P, E A DW.R ~ .FRV ]. C;.. ,,.F'bTC DATE : 95/05/ 1 '!,i~X J-.,:wC STZr~: : ~024 E~ [T~'.i) CLI~V~S Pe~th sf~Ift',e~ and cll~ea curves for each pass in separate files. l,t~wG T~f]t, CODE St. ART Dt:;PT~ STOP DEPTH CRC~ 10353.0 9747.0 Ci~;TD 10374.0 9747.0 CIIRVE SHIFT DATA - PASS TO PASS(~-:!EASU~Eg DEPTH) BASELINE CURVE FOR SUIFTS PASS NUM6~R: I .... - ..... EQUIVALENT U~SNIFTED DMPTN--- ....... BASEI,INE DEPmH G~CH C~TD ~8~d~.O 88886, 8 10364,5 10364.0 ~0347,5 10346,0 10343,5 16343,0 1.032~,5 10324,0 ~032~,5 i032~,0 10304,5 ~0303.5 ~029~,0 10294,0 10~95,% 10~g5,0 10)91,0 1.0~89,0 102~!,5 10280,5 LIS g'aDe ver~ficatior~ L]stin~ Schlumberger AlasKa Co!~.F. utin~ Center 14:05 PAGE: 10 # ln779.5 10272.5 10272,5 10770.5 ~0~70.5 10208.5 lo~69.5 10255.5 1, 0256, n 10234.5 ~0235,5 10230.0 10231,0 ~ 0211.5 102~3,0 101.9~o 5 1(') 196.5 10170.5 1018~ .5 10~6S,5 !0170.0 1 01 50.5 1 01 3~.5 10136.5 !0~%5.5 loll6.0 100~6.0 10087.0 10055.0 10056.0 10022.0 10022,5 90~{2,5 9983,0 9073.0 9073.5 9065.0 9966,5 9963.0 9964.0 9954,5 9952,5 9g5~,5 9q~8,5 9949,0 994~,5 9941,5 9943,5 9943,0 9938.0 993o,0 9913.0 9914.5 9890,0 9900,5 9897,0 9889,0 9~74.n 9875.0 9~Pg,n 9869,5 9R69,5 o~34.0 9835.5 9~30.0 9~3!.0 9823.5 9824,5 9820.5 9794.5 9795.0 9790,0 9790,5 ~00,0 !00,5 100.5 $ ]'his file contains CNTG pass ~3. The depth shifts showr~ above relect cRc8 pass ~3 to GRCH pass #l and NPHI Da~s ~3 tO t~PHI pass S DATA LIS Tame verit~ication I,istina Schl:]mberaer Al. asks Co~,putln.O. Center' 1-MAY-1995 i4:05 PAGE~ 11 DA'PA ** SET TYP~: - CHAN * .............. N~. ,.,~ ~. .V SEPVICF API. ID ~RD~R ~ b[iG !)..PT FT 5(>6303 0U NPHT C~'rD PI!-S 506303 O0 NRAT CdTF., CPAT C~uTD NCNT C:,~'r D CPS [;'C N T Ci,! TD CPS CFTC C ;'~ 'PD CPS CNTC CqTD CPS GPCN C:~ TD GAPI CCL C4T~) V Ap AP TYPE CLASS 000 00 0 000 00 506303 00 000 00 0 506303 O0 000 00 0 5U~303 00 000 O0 0 506303 00 000 O0 0 5(;6303 O0 OOO O0 0 506303 O0 000 O0 0 5063n3 00 000 00 0 5063~3 00 UO0 O0 O 5u6303 00 000 00 0 m m m ~m mm m mm m m mm m~ -~ m mm m mm m mm mm mm mm FILE NUMB NUMB SI g EDR PROCES 3 I I 4 68 0000000000 3 ! 1 4 68 0000000000 3 I 1 4 68 0000000000 3 1 ! 4 68 0000000000 3 1 I 4 68 0000000000 3 .1 I 4 68 0000000000 3 1 i 4 68 0000000000 3 1 i 4 68 0000000000 3 1 1 4 68 0000000000 ~ 1 I 4 68 0000000000 ~ 1 I 4 68 0000000000 DEpT· 10373.50u ~,,~.,m,.,~-=..~ C~TD, . 28.715 'NRAT.CNTD~. 4 588. ~P~T.C"~Tb.... , 26:~9.511.. FCKT'CN'fD.. 5v5. .'090. , CFTC,C~i?D~,. 515~344 CH C"TD -999.25~ TENS CNTD 1230 000 CCb.C:~'iD O 000 CRAT CNTD C)/~C.*CNTD CRAT.CNTD CNTC. ~ ~TD 4.887 2558,590 768 458 975 Schlumberqer Alaska Con~puglnq Center ~-~qAY-1995 !4;05 PAGE: FTL~ ~.~4~£; : EDIT .003 SFRVIC~{ : FLIC V~RSIf~ '~ : oOICO! FILF TYPE : LAST FiI~E FTL~' i~t~'4E : EDIT ,004 SERVICE : FLIC VERsIO~ : OU;CO1 DATF : 95105/ 1 ~hX skEC SIZE : 1(;24 FILF TYPE : LAST FII,E FILF ~;U~BER: 4 AVERAGED CUPVF, S Compensated ~;eutron: Arithmetic average of edited passes for all curves.. Pulsed ~{eutro.: ~naveraged edj. ted Pass i Gamma ~ay and Packrou~d counts; arithmetic average o~ e~ited static pasellge passes for all other curves. DWF'T~ I~C~E~EHT 0.5000 P~SSCS ~i,JCLUD~D l~q AVERAGE LDWG TOOL (]ODE PAS5 ~.IU~BER& ........................ PPi~,'~APKS: The arithmetic averaqe of passes~ 1.2 & 3 ~as computed after all depth Shifts and C]~PDiDg was a~plied. I, I5 FrlR~AT DAmA I.IS Tare veriflcatJom Listlno Schlumberger AlasKa C'omr. utJnq Cente!' 1-~:'.AY- 1995 14;05 ~¥~E ~EPP CODE VALUE 1 60 0 2 66 0 3 73 44 4 66 1 5 ? 65 ~ 68 0,5 11 60 23 12 I3 60 0 i4 65 FT 16 60 0 66 ** SET TyPE - C~qAM ** i'~a~E $ R AlP, AP ID ~RDER ~ LOG ~!'YPE CLASS mmmmmmmmmm.mmmmmmmmmmmmmmmmmmmm~mmmmmmmmmmm DEpT FT 506303 00 000 O0 0 NPH? CMAV PU-S 506~03 O0 000 O0 0 ~AT CNAV 506303 O0 000 O0 0 CPAT C~V 5~6303 O0 000 00 0 NCiqT C~AV CPS 506303 00 000 O0 0 FCNT Ci~IV CPS 506303 00 000 00 CFTC C~A¥ CPS 506303 O0 000 00 0 CNTC Ci~l¥ CPS 506303 OD u00 00 0 GPC~ C~'I'D GAPI 506303 O0 000 00 0 T~NS C~TD LB ~06303 O0 00o O0 o ...... ...................... . ..... .. FILE NUMB NUMB SI PROCESS NUMB SAMP EbEM CODE (HEX) ..m.m.mmmm.mmmmmmmmmmmm~mm~mmmmm~4~mmm.!) mmmm~mm~mm~m 4 I t 4 68 0000000000 4 I I 4 68 0000000000 4 I I 4 68 0000000000 4 1 i 4 68 0000000000 4 1 i 4 68 0000000000 4 1 i 4 68 0000000000 4 1 i 4 68 0000000000 4 1 i 4 68 O000000000 4 1 i 4 68 0000000000 4 13 ** bATA ** DFP*. 10374.(:00 NPHI.C?aAv -999,250 NRAT,CNAV -999,250 NC:)~T. CNg V -909°250 FCNT.CN'Av -999.250 CFTC,CNAV -999,250 GPC~, O,s~Ti) -999.25u TET'~$. C~TD 1230,000 CCL,CNTD 0,O00 D~ipW 97~8 00o f,iP~I f:..~ -999,250 NRAT,CNAV -999 250 NCi'qT C;,~V -909.250 FCNT CNAV 999 250 .~TC, (;~C~.C;"~'I'D n80a3 TENS CN~.L 1!20,000 CCL.CN~D 0,000 CRAT.CNAV CNTC.CNAV CRAT.CNAV CNTC.CNAV '999 250 '999:250 '999,250 ~999,2.50 LIS Tape veri~.Icmtion bistlnt.~ Schlumberqer AlaSKa COmPUti. D~ Cepter 1-MAY-1995 14:05 PAGE~ 14 DATA **** FILM HEADER **** $~RVICE : FLIC VERS]O~ : 001C01 IDATR : 95/05/ 1 ~AX R~C 5TZK : 1024 FILF TYPE : 1,0 FIL, F ~4EADER FIL~ ~,U~R 5 RA~ CURVES Curves and loa header data for each pass in separate files; raw baCk~.rou.Dd passln last file P~S$ N!J~BER: 1 DEPTH INCREMENT: 0,5000 # FILF V~;,~!DOR TrloL C(IDE START DEPTH . Ci, TD 10374.0 bOG HEADER DATA DATE bOGgED: SOFTWARE VERSIF~i,~: TD DRILLER (FT): TD bOGGER(FT)I TOP b~G IN~EnV~b (FT): BoT'ro~ bOG IN'rERvA[, (FT): LOGGTN~ SPEED (ffPNR): DEPTH CONTROL USED (YES/hO): T[')O[~ STRING (TOP '.[0 BOTTO~i) VFNDO~ TOOL CODE TOOL TYPE STOP DEPTH 9 8 ,0 9785.0 06-APR-95 43,005 1658 10408,0 10401.0 9800 0 !800.0 NO O6-APR-g5 LIS Ta~e Verification [,istinq $chlumberqer AlasKa Computtnn Center 1-~AY-1995 14:05 PAGE: 15 POPEHOLE AND CASIaG DATA DRI[,bERS CASING DEPTH (FTJ: LnGGERS CA61~'JG DEPTH eFT) I FLUID DEr,iS1TY (LB/G): SI1RFACE TEt4D~PATUPE (DEGF'): BOTTO~ HOLE TFi,~P~;~AT!,I~ (DEGF): FLUID SAbII~!TY (PPh): FLUID L~VbTL (~T): FLUrD RAT~ AT ~ELt, HEAD ~A'I~ER CUTS (PET): CPSC'A-a67 CPLE~A-867 CTSM-A-10 CGRS'A-862 9692,0 CRUDE THERMAL SANDSTONE 2.65 51,UEL!ag CUltiST RATE ~]ORSAI, ZZATION I~~ PlL ZONE TOP ¢~OPMAbIZISG ~ASE aOR~ALiZI~G ~laDOW (ET): BhU~I, TNE CO{;r~'r PATE SCALES SET BY FIELD ENGINEER FAR Ct)liNT PATE LF.,W SCALE CCPS): 0 FAP COIJb~T RATE HIG}~ SCA~ (CP~): 4000 ,~EAR CnUNT R~TF LOw SCALE (CPS); O ?EAR COU~,,T RATE HlGit SCALE (CPS.): !8000 PI~NPED 275 gBL,S CWUDE AT 4.5 BP~;I P~.IOR TO BOGGING, P[;i~lmED ]85 ¢SLS TOTAL DIESEL. PU~PED nT 3/4 BPS WHILE LOG bOG '.-~;A6 NII~ TO FIND GOC, APPROXI~ATE GOCml0190', $ LIS Ff'.'R~AT DATA [,IS Tape Verification I,istir, O $chlumheroer AlasKa Computlno CeNter 1-~AY-1995 14:05 ** PATA ....... FnP;~-~AT SPECIVTCATItltt~. R~'COPD~.? , ** ** CUDE VALUE 6 3 73 5 66 7 65 9 65 11 66 12 66 13 66 14 65 15 66 16 66 0 66 0 44 0,5 ** SET TYPE - CHA NAMV S~RV (i~) iT SERVICE A ~m ~m ~m mmm ~m ~mm ~, mm ~m 4m~ ~m, mm ~m mm~ I, mm m~ ~ Jm ~mm ~ ~ ~ ~ ~ ~ ~ ~ DF[UT FT 506303 OO NmHI PS1 PI! 506303 00 RTN~ PS1 5(;6303 00 Ta~Rh PSi 506303 O0 RCaT PSi CPS 506303 00 RCFT PSi CPS 506303 CNTC PS! CPS 506303 oO CFTC PS! CPS 566303 O0 GM PS1 GAPI 506303 00 TFNS PSi DB 506303 CCLD PS1 V 506303 00 N , P I. OG mmmmmmmmmmmmmmmmmmmm~mmmm~mlmmmmmm~im AP1 APl AP1 FILE NUMB NUNB SIZE R~PR PRUCESB TYPE CLASS MOD ~L1MB SA~P ELEM ~0 E (flEX) ooo OO 0 5 1 1 4 68 000o0o0000 OoO oo 0 5 I I 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 00 0 5 i 1 4 68 0000000000 00o O0 0 5 i I 4 68 0000000000 UO0 O0 0 5 1, ! 4 68 0000000000 000 O0 0 5 1 i 4 68 0000000000 O00 00 0 5 1 1 4 68 O000000000 O00 00 O 5 1 I 4 68 0000000000 go0 O0 0 5 1 :t 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 PAGE: !6 DFPq~. 10387.500 MPH!.PS1 RCNT,PS1 2538.461 RCFT.PSI GP.PS1 38.719 TENS.PSi DFPT. 9787.000 NPHI.P$1 RCNT.PS1 4277.720 RCFT.PS1 GI~. PS1 ~.063 TENS.PSi 27.752 RTNR.P$1 .4. 714 I'NR..PS1 538.462 CNTC.PSI 2529~462 CFTC'PSi 945.n00 CCLD.PS! 0.026 !6.662 RTMR,PSI 3 .220 TMRA.PSt 139g'3~8 CNTC.P$1 43441218 CFTC.PSI 1120.000 CCLO.PSI 0°000 .768 51. ,566 '03 [,IS Tape verification !.,j. st~Do Schlumberger AlasKa Computin9 Center t-~AY-1995 14:05 PAGE: 17 **** FILE TRAI!,EP ~*** FIbF NAaE : EOIT .005 SERVICE : FLIC ¥~RSIPN : OOl. C01 D~TF : 95105/ 1 SAX ~C $[Z~ : IU24 FTLF TYPE : l,f) bAST FILE : **** FTLE FILE HA~E : SERVICE : FLIC VERSIO~ : 001C01 D~TF : ~5/o5/ MAX RFC SiZE : 1024 Curves and lnQ header data ~or each pass in ~eparate ~iles; raw bac~rou.~ Pas~ In I~t file DFPTVt I~CRE?~ENT: 0.5000 VEt, DO~ TOOL Ct)DE START DEPTH C~TD 1. 0374.0 LOG ~EADE~ DATA DAT~., bOGGED: SOVT~ARE VERSIOnal: TltqE LOGGER Oi~ TI; LOGGE~(FT): TOP LOG TNTEPVAb (ET): POTTOM LOG INTERVAL [,GCGING SPEED (FPHR) Df;~PT~ CO~x~TRUL l~.5EI) (YES/NO~; TODI, ST~I~G (TOP '.Pf.t VF;NDO~ TOOt, COD~; Tn[}L TyD~ STOP DEPTH 9793°0 9793.0 06-APR-95 43,005 1658 06-APR-95 10408.0 10401,0 9800,0 i0360.0 1800,o TOOL NUMBER LIS Tape Ver!ficatIon l, lst. lng 14:05 18 DR1LI~RS CASING DF]PTH (F':.['): LOGCE~S CA,ST~-~G OEPT~--~ (FT): PCREHOLE C(~NDI tla~.~S FI, UTI) TYPF: SURFACE 'I'~',iPE~AI~kJ~ (DEGF): FLL)IL) SAhTaITY (PPM): FLUTD LEVEL (FT): FLI.~TD RA~r~] aT W~]L[,HEAP ~:ATER C~;TS (PCT): G~S/Ft!L CHO~E (DEC) ~ TOOL TYPE (EP~T~RMAh UR THERMAL): ~:ATRI X: ~'.h'[~ I X 9692.0 CRUDE THERMAL :SANDSTONE 2.65 bI,IIaI.,INE CO!.Ii-]T RATE: NOR~'~ALZZATION iN nil ZONE FA~ COUNW RATE LOW SCAL~ [CPS): 0 FA~ COUNT PATE tilG[.i SCAI~M (CPS): 4000 N~.~AR COLJNT RATE LOw SCALE (CPS): 0~ NEAR COUNT RA'/'E HIGH SCALE (CPS): 18000 TOOb STANDOFF (IN) ~ PF"t,~ARKS: TIE[) IN TO SWS BHC DATED 6/5/82, P[IMP~2D ~75 BS[,S C~DE AT 4,5 BP~ PRTQR TQ P[;MPED ]85 ~SLS TOTAL DIESEL, PU?4PED AT 3/4 BP~ WHILE LOG LOG ~{AS RI.II~ TO F'IND GOC, APPROXI)4ATE GOC=I01go', bis FDR~.~AT DATA LIS Tane verification t,ist:[nq Scblumberq~r AlasKa Computlnq Cemter !-MAY-t995 14:05 PAGE~ DATA ~'t~Rt,,~AT SPF;CIFICAT!f-')~f RECORD ** SET TYPE - 646~ TYPE REP~ C~DE 2 66 0 3 73 4~ 4 66 ~ 66 ~ 73 7 9 68 0,5 9 65 FT 11 66 23 12 68 1.3 66 0 14 65 ~T 15 66 68 16 66 0 66 ** SET ~D DEPT FT ~t~ PS2 RC~V PS? CPS RCFT P82 CPS CNTC PS2 CPS CFTC PS~ CPS G~ PS2 GAFI CCLD P$2 TYP~i ORDE 5. 33 .0 5O6303 5063o3 O0 5U63~3 O0 506303 O0 506303 O0 5063O3 O0 506303 O0 5u6303 O0 506303 O0 CHAN ** API APl AP]. PI F g NUMS NdNB SIZE REPR R S$ LOG "fY".PE" CLASS.. MOD NUMB SAMP ELEM CODE (HEX) .....Of)() '00 ............... 0 6 1'''''''''''''''''''''''''''''''''''4 68 0. 000 0 . I :1 4 68 0000000000 000 O0 O 6 000 00 o 6 I i 4 68 0000000000 000 O0 0 6 1 I 4 68 0000000000 000 OO 0 6 i 1 4 68 0000000000 000 O0 0 6 I 1 4 68 0000000000 000 O0 0 6 i I 4 68 0000000000 000 O0 0 6 ! 1 4 68 0000000000 000 O0 0 6 1 i 4 68 0000000000 000 00 0 6 1 ~L 4 68 0000000000 oo o 4 oooooooooo 19 , * [)ATA ** DEPT. 10389.500 GD.PS~ ~6o34~ TENS,gS2 DEPT. q792,500 f~PHI.PS2 RC~T.P$2 43R3.562 PCFToPS2 GP.PS? 49.900 TE~S.PS2 24 t40 RTNR o~ 5~4 ~!7 CNTC~'°2 4,258 _NRA.PS2 . ._ P$2 2478,813 CFTC,PS2 985,000 CCLO.PS2 0'030 18,I45 RTNR,PS2 3 360 TNRA.PS~ 1204.489 CNTC,PS2 4274]448 CFTC,PS2 115o.000 CCLD.PS2 0,000 4 3O6 $ss:o: 6 3 '03 LIS Tac, e vmrlficat.~on Listlnq Scblumberqmr A].asKa Computinq Center 14:05 2O **** FTLF, T~A i [~,E~ **** FILF MA~E : EDIT ,006 SFRV!C6 : FLOC VENSI~N : O01CO1 DAq'F : 95105/ i ~X ~(: SIZE : 1 FIL~ TYPE LAS? FILE : **** FIL~; I~EADER **** F~LF !~A~4E : FOTT .007 SERVICe: : FLTC VERSI['!r~ : 00! CO1 D~TF : 95/05/ 1 ~'~AX BEC SIZE : t024 FI'bF TYP~2 : TjU LAST VILE : F]L~ HEADER FTLF ~IIJMBER 7 RAw C~IRVES Curves and !oD header data ~or each pass in separate files; raw bacKoround pass in laSt 'file PaSS NU~BER: 3 DEPTit 1 I~iCREP',EMT: 0.500(,) FILF VEt'..IF~OR TF)()I'~ CODE STAR~ DEPTH HFADER DATA DATE LOGGEO: SOFT~APE VERSION: TD DPlbLER (FTI: mD LOGGEP(FT): TOP I,OG INTEPVAb (mT): gOT'J'O,~ LOG ,IN'L'ERVAb (FT): ~Odt;It~d SPEED (F'P~R): TOOL STRTNG (TOP TO BOTTO~) VF;NDUR q'i. lgl~ cruDE TgOb TYPE STOP DEPTH 9747.0 06-APR-95 4].005 1658 10408.0 10401.0 9800.0 t. 0360.0 1800.0 06-APR-95 TOOL NUMBER LIS Tape Verification Listinc Schlumberqer AlasKa Computinq Center I-~AY-1995 14:05 ,PAGE; 2! LIS U~R...R!OGE NC-D-101 C~!T~ N~UTRON SONDE CPSC-A-867 C~.!T~ NEUT~O~ CPLE-A-867 CNTD a~UTRON CTSM-A-10 GR GAi4~A R~Y CGR$-A-862 $ ~_~NO[,E Ah!D CA$'I.?~G DATA t)PE~,I HUI,E BI~£ SIZE (IN): DRILLERS CASI~'.~'~; I)FPTH L, FIGGER,5 CA,STOiC DEPTH FLUID TYP~;: FI,,UID DENSITY (I,B/G): S~IRFACE "['FfiiPEPATURE (DEGF): bf!TTO~ HOLE 'I'Ef,~PE~ATiJRE (T)EGF): FI,0ID SALINITY (PPM): FI,LID bEVEI, (FT): FLdID RATE AT b~L[,HEAD (13PN): GAStUTL RaTIt.3~ C}~(.)KE (DEC) ~ 9692.0 CI~.UDE i~! E!l"i7 R [) N TO[lb TOOL TYPE (EPITbtERMAL UR THERf'4Ab): ~3 L U E T THER~{hL SANDSTONE ~.65 LINE COI~NT RATE N.P_,R~.AbIZA-~ION DP NURaALTZING WINDOW (FI): ASE NORMALIZING WINDOW (FI): iN OIL ZONE t3l, bM!,IaF CO!ihT RATE: SCALES SET BY FIELD ENGINEE~ FAR COUNT PATE LO~' SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEaR COIJ~!T RATE HIGt{ SCALE (CPS): 18000 STANDOFF (.[iq): TIED Ii',{ TO SWS R'.dC DATED 6/5/~. PIIr.4PED 275 BBLS C~UDE ;iT 4' '5 ~-~4 PRIOR TO LOGGING. Pl~¢qPEn 385 R~3[,S '.?OT~L DIESEl,, PUMPED AT 3/4 BPM WHILE LOG bOG wAS RUN TO WIND GflC. aPPPUXIMATE GOC=i0190'. S FORe, AT DATA [,IS Ta~e Verlficatlon LZstinq $chlUr,,berqmr Alaska Computino Center - 9 ..... 4 05 PAGE: DATA FORe'AT SP~C.TFICATI(3N P~CUPD $$ ** SET TYP~ - CMAN ** ....... SERVICE ADI AP DEPT FT 506303 O0 O00 O0 0 NPHT PS3 PU 506303 O0 OOO O0 0 RTNP PS3 506303 O0 009 O0 0 T~-~ R~ PS3 506303 O0 000 O0 0 RCNT PS3 CPS 506303 O0 qOO O0 0 RCF~ PS3 CPS 506303 O0 090 O0 0 CM~C PS3 CmS 5063~3 OO 000 O0 O C~C PS3 CPS 506303 O0 000 OO O G~ P83 GAPI 506303 O0 0o0 O0 0 E CbA$S MUD NUMB SA.~P EbEM CODE (HEX) 7 1 I 4 68 0000000000 7 i I 4 68 0000000000 7 ! 1 4 68 0000000000 7 1 I 4 68 0000000000 7 ! I 4 68 0000000000 7 I ! 4 68 0000000000 7 i t 4 68 0000000000 7 I i 4 68 0000000000 7 I 1 4 68 0000000000 7 4 68 oooooooooo 20 O. Z 1 i 4 .6.8 .0.0.000000.00 DEPT. 10388.5n0 ~PHI.P$3 RCNT.PS3 24a9.941 RCFT.PS3 GP.PS3 25.297 TENS.PS3 DFPT. ~'748 500 NPHi. PS3 RCNT.P53 ~.472:050 PCFT.PS3 G~.PS3 ~b.625 TENS,PS3 27.!75 RT~R'PS3 4.643 TNRA.PS3 527 680 ~,'~TC PS3 2441.255 C..TC.P$3 995.000 CCLO.P$3 0.021 20.1i~ RT~R.PS3 3'658 TN'RA.PS3 1282.700 CMTC,PS3 4580.975 CFTC.PS3 I~50.000 CCLD.PS3 0.000 4. 695 501'323 3. 768 1198'286 [:I$ Tane Verification [_,istinq Schl,]mberqer AlasKa Computi. nq Center 1-~AY-!995 14:(35 LIBRARY TAPE CURVE SPECIFICATIONS Company ARCO Alaska, Inc. Well D.S. 2-24 ~ Field Prudhoe Bay County, State North Slope, Alaska ~!'~C ~ 0 19~6 Mas~ Oii & G~s Co~, Oomm:$mon Date 11/7/86 Curve Name (Abbrev.) Standard Curve Name Logs Used Scale Files' 1-3 CCL Casing Collar Locator t " 60 - 0 CN Compensated Neutron SSN Short Space " 50 - 550 LSN Long Space i " 0 - 200 GR Gamma Ray t " 0 - 100, 100- 200 File 4 .l CNAV Ay.er age CN i 60 - 0 C C, :j;q T ?/STAT N E UT ~O !,,i &V -; 2 G - '~;?;~, 331 e :3 1'z.4 '~'/. = 17. f, ], "J"UT~CN ,,) "', t21. 13©. N-UT;3N &VE;;GE N ELI T q O':'j t 2 : t " N 7- U T ~ GN .& V- q ~ G E :!7. ?S. I L ~ 1 t 1, ! ~,~ E iJ T S O !x 53.C 5! .7 ~',, E d T ~ C h LI BR.~dtY TAPE CURVE SPECIFICATIONS ECC {; 2170 ARCO ALASKA, INC. Well D.S. 2-24 F~e]d P~,~D,.O_ BAY County, State NORTH SLOPE, AI.%SKA Date MAY 23, 1985 (Abbrev.) Standard Curve Xame Logs Used Scale ' CN1 i xmr'' r ' , CO.a ~XSAT~D NEUTRON i LSY1 ~ ~0,,o SPACED DETECTOR i S~.,1 , SHORT SPACED DETECTOR 'PASS 1 CN: MSN 60- 0 0 - 200 " 50- 550 (.'.RI , GA.X~-~5~ KAY " " 0-100, 100-200 ; !. ' CCL1 ~ CASING COLLAR LOCATOR " " 0 - 10 ! CN2 I CO.MPE::'SATED NEUTRON PASS 2 " 60 0 ..... =~.~o _: =.CmD DETECTOR 0 - 200 SSN2 ~ SHORT SPACED DETECTOR " " 50 - 550 ' GR2 G3~ ~Y " " 0-100, 100-200 _ CCL2' " " 0 - 10 CN3 · '~ . LSN3 · SSN2 CASING COLLAR LOCATOR COY'~ENSATED NEUTRON PASS 3 LONG SPACED DETECTOR " SHORT SPACED DETECTOR " G A.%MA tG~,Y " CASING COLLAR LOCATOR " CO.~PE,,SATED NEUTRON AVER~kGE GR3 CCL3 C%AV 60 - 0 0- 200 · 5O - 550 0-100, 100-200 O- 10 60 - 0 ROGRAM:LZST=.R R2,0 ECC NUM~' 2170 0~' RC~-J~ INC. R-U g H O E BAY ~:,,,CURVE S : DAT~:~ 5/23/$5 TIM'-_: 8: ~.:31 ,~CO ALASKA TNC. 2-2~ DRUDHOE BAY NORTH SLOPE, AL.ASKA LSd;1 SSFJ1 DATE: 5/23/85 TIME: 8:5:31 ARCO ALASKA INC. 2-24 PRUDHO= BAY NORTH SLOPE, ALASKA -DEPTH CN1 CN2 CN3 CNA-V LSN1 SSN1 GR1 ~FT. % % % % APZ ~98!4~ 2:6,636 32,5~ 32.5~( 30.602- ~9.260 202.479 47.347 DATE: 5/23/85 TIME: 8:5:31 ARCO ALASKA INC. 2-24 PRUDHO: ~AY NORTH SLOPE, ALASKA DATE: 5/23/$5 TIME: 8:5:31 ARCO ALASKA !NC. 2-24 PRUDHOE ~AY NORTH SLOPE, ALASKA DATE: 5/23/85 TIME: 8:5:31 ARCO ALASKA INC. 2-24 PRUDHOE BAY NORTH SLOPE, ALASKA SSN! GR1 DATE: 5/23/85 TIME: 8:5:31 ARCO ALASKA INC. 2-24 FRUDHOE BAY NORTH SLOPE, ~LASKA OATE: 5/23/83 TIME: 8:5:31 ARCO ALASKA INC. 2-24 DRUDHOE ~AY NORTH SLOPE, ALASKA DATE: 5/23/85 TIME: 8:5:31 ARCO ALASKA INC. 2-2~ PRUDMOE BAY NORTH SLOP=, ALASKA DATE: 5/23/85 TIM:: 8:3:31 ARCO ALASEA INC. 2-24 PRUDHOE BAY NORTH SLOPE, PAGE --~_ PTH CNi CN2 ' CN3 ? F ° % Ti % .o CNAV -- LSNi SSNi % ,~ ~' s~:~:',,. ,..:c~.~ .... ~;. ;;,. ..... .~.,~...~.,. · ....... .~:~ ........... .,.~ ..... ~,.'~ ~,......,.~ ......., ~,,.,. · ..... .,.~... ~. ~ ....,.. ~ ~'~ ~3~:~ B:~.:~ ~ ~:~:~::~::::::::~:~:~ B:~:~::~8i?~::~::~:~:~:::~::~::8~8~ ~ ..:~.::~:~ ....... ..,:.~.~;~&.. J-~z, ....... ~.,~c..?~'.~. ' ,;~:.,.. ',~::. ,~.. ~::~ .~....,~,, :~? .,~'~ ..... ..~:~:: ~:,.' .,.~.. ~..:,.~:~. .,. ,,..: ..~~~~r~ ~::~:~3::~c~(~::~:~:}::~::~}::s::::~::::~::~:::~::?~::8:}::~:}:::~}:~::~}~:~:::~::$:::~:::::~:}:}::}~::$:~}:::~8::~:¢:~}~::~:}~.:~:~:~:~::~..~:~$~;~::~{:?.~:~:::~:~::~}.{}..:~::~:}:::~::c~:~i$~:~:~:}~}~:~`~::~::~:~:~}~:~:`~.~:}:~:~:~8~:~}~a`..~::~:~:}~.:~:~:;:}~:~:~8~::.~::~::~:::}~:}:~:~:}:~:~}~.:~}~:~::~.:~:}~:::}7:}~}{{:~8:~:}::~:a~{~:~}~:}:{:~:~:~}~::~:~::~}:.~::::}~:~:::}::::}::::~:~:~:7::}}:::~}::}::~:}~:}::~:~:}}~:~::}~::?.:~:::~::~::~:8::~}:~:}::::~::}}::~::::}~:::~}~:}::::~:~:}::~:~}}~:::~::~:~:::}:~::::}~::j:::~:::}~:~::~:::::~8}:~:}:~::~::~.::5::`}~:}~::::~::::~:~:::~::~:`~:}:::~:?~:~:}}~:~ ~::~::~::::}::~:~::~::}:~:}:~:~:x~:::::~::}::~7:~:~:~:~:::~::}:::~::::~:~:~:~::~:(.~:}~:}::::~ DATE: 5/25/85 aRCO ALASKA iNC, PRUDHOE BAY TIME: 8: 5:31 2-24 NORTH SLOPE, ~LASKA OAT;: 5/23/85 TIM=: 8: 5:31 ~RCO ALASKA INC. 2-24 PRUDHOE BAY NORTH SLOPE, AL&SKA P6GE 11 'O-E~ TH CN1 ..... ~ ,~. ~ ~ C N A V - FT. LSN1 API DATE: 5/23/85 TIME: 8:5-31 ~CO ALASKA !NC. 2-24 P~UDHOE BAY NORTH SLOPE, ALASKA 12 DATS: 5125185 TIME: $: 5:31 ARCO AL~,SKA T. NC. ?-2/-+ PRUDHOE BAY NORTH SLOPE, ALASKA PAGE 13 ~EPTH CNI CN'2 CN$ ~ FT. % .. % . % DATE: 5/23/S5 aRCO ALASKa iNC. PRUDHOE BaY TIME: 8: 5:31 2-24 NORTH SLOPE, aLASKA I,., I,I I --" FT, CN2 CN3 CN'~V '- L~t 5SNi GRI DATE: 5/23/$5 aRCO ~L~SK~ iNC. PRUDHO~ SAY TIME: 8' 5:31 2-2~, NORTH SLOP:, ~L~SKA P~GE 15 ~TH CNi __ LVP 010.H01 VERIFICATION LISTING ** REEL HEADER ** SERVICE NAME ZSERVIC DATE I82/08/ 4 ORIGIN ~ REEL NAME IREEL ID CONTINUATION # ~01 PREVIOUS REEL 1 COMMENTS ~REEL COMMENTS ,~ TAPE HEADER SERVICE NAME tSERVIC DATE I$2/05/ 4 ORIGIN =1070 TAPE NAME 165160 CONTINUATION # I01 PREVIOUS TAPE COMMENTS ITAPE COMMENTS ~ FILE HEADER *~ FILE NAME ISERVIC,O01 SERVICE NAME I VERSION # = DATE l MAXIMU~ LENGTH I ~024 FILE TYPE I PREVIOUS FILE = INFORMATION RECORDS MNEM CONTENTS CN I ATLANTIC RICHFIELD COMPANY WN I DS 2-24 TN I PRUDHOE BAY RANGI R 14 E TOWNI T 11 N SECTI 36 COUNt NORTH SLOPE STATI ALASKA CTRYI U,S,A, MNEM CONTENTS PRESl DILOO1E LVP 010,H01 VERIFICATION LISTING - ~ PAGE ** R£CORD'TypE 047: :*:~::..::.'. : - ,, R~CO~O .ryP~ 0.4? ::*:~::'-: ::-.:': :-'-::-::;': ::r '::':::: :.._- :. - ,~* COMMENTS ** ~::' ~ SCH~UMBERG'ER:" ...... : :._.: _:...:.~ ::..:.::_.. ::: _.:,::: _:::__:: .._ ,.. :_ . . COMPANY = ATLANTIC RZCHFIEbDC WE~L = D,$, 2-24 . ' _ -: · :::-..:j:< :: FIE~D = PRUDHDE BAY COUNTY = NORTH ~OPE BOROUGH STATE = A~ASKA =========================================================. . . . . .~=~==='~=,=_~~~"':::'.. . :::.::. :- ::: .:: JOB NUMBER AT ACCI 10707,65160 RUN #1, DATE LOGGEDI 5 JUN 82 BOTTOM DEPTH = {05~4 FT, CASING = 9,625 BIT SIZE = 8,5 IN, TYPE FLUID m bXGNOSUbFONATE DENSITY = 20,2 LB/G VISCOSITY m 41,0 S bVP 010oH01 VERIFICATION LISTING PH = tl S FLUID LOSS = 5.] C3 RM = 1,480 ~ 68,0 DF RMF = 1.140 ~ 68.0 DF RMC = 1.860 ~ 68.0 DF RM AT eHT = o,569 ~ 18~. DF ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE 4 9 0 ID DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT AP! ORDER # DEPT SFLU IbM DEL XLD DIL SP DEL GR DIL NPH! FDN RHOB FDN GR FDN CAb! FDN DRHO FDN NRAT FDN NCNb FDN FCNL FDN DT BHC GR BHC DATA ** DEPT 10523,5000 FT OHMM OHMM OHMM MV GAPZ PU G/C3 GAPI G/C3 US/F GAPI SFLU bVP OIO.HO1 VER2F2CATION LISTING 32,5938 OR 8P ~)99 2500 CALl OR '. . NCNb 999.2500 FCNb D£PT 10500.0000 8rbU Sp -30.6094 GE OR 115.0625 CAb[ NCNb 2394.0000 FCNb DEPT 10400. 0000 SFLU SP '79.8125 GR GR 55.6563 CAb[ NCNb 3410.0000 {cCNL D£PT 10300.0000 SFLU Sp -45.0313 GR GR 90.1250 CALl NCNb 30?2,0000 FCNb DEPT 10200.0000 8FbU 8P -90.1250 GR GR 53.5000 CALl NCNb 3162.0000 FCNb DBPT 10100.0000 8rbU p -101,1250 GR R 29,9062 CALI NCNb 3612.0000 FCNb DEPT 10000.0000 SFbU SP -99.4375 GR GR 30.8125 CAb! NCNL 2936.0000 rCNb D£PT 9900 0000 8rbU 8P -95:3125 GR GR 42.3438 CAbI NCNb 2872.0000 rCNb DEPT 9~00.0000 SFLU SP 65.6875 GR GR 8~,5000 CAb! NCNb 494 .o0oo rCNb DEPT 9'/00.0000 SFLU SP '19,2813 ~RA GR 117.3750 NCNb 1695.0000 rCNb D£PT 9624,5000 SFbU Sp -98,8750 GR GR '999,2500 CAb! NCNb '999.2500 rCNb '138, 999. . -13~ 918 8 1534 1348. 1049 57 1325 2470, 2, 106, 4 . '999, '999. LVP 010,HO1 VERIFICATION LISTING FILE NAPE :SERVIC,O01 VERSION # : DATE : MAXIMUM LENGTH : 1024 FILE TYPE NEXT FILE NAME ~ TAPE TRAILER ~m SERVICE NAME :SERVIC DATE :82108/ 4 ORIGIN :1070 ~APE NAME :65160 CONTINUATION # :01 NEXT TAPE NAME : COMMENTS :TAPE COMMENTS ~ REEL TRAILER SERVICE NAME :SERVIC DATE :82/08/ 4 ORIGIN : REEb NAME :REEL ID CONTINUATION # :01 NEXT ~EEL NAME COMMENTS :REEL COMMENTS ~ ~ .~ =....-==~[ =.= <...-..~=~- · - LIBKAM~' ~AYE CURVE SPECIFICATIONS Co~panv ~eil ARCO ALASKA, INC. D. S. 2-24 ~ieid PRUDHOE BAY County, State N. SLOPE, ALASKA Date 6-13-82 Curve ~ame (Abbrev.) standard Curve ~ame Logs Used GR1 Ga_mrna Ray Pass 1 CN-Multispaced 0-100, 1~_.2 ~0~.~ GP,2 " " " 2 " " ,,, , ..... II I Ill Ill Il Il , i I CCL1 Casing. Collar Locator P~ss 1 ..... . . " ,, ,,,O - 1 ,,, CCL2 " " " ~.,, , , ,,, , ,, , ~ , ... ..... ., ,, ,,., SS~i Short Space.~eutron Pass ~ ,, ,,, , 8S~2 " " ,,,,, , LSN1 Long Space ~eutron Pa,s 1 " 0 - 1250 LSN2 " " " , eR1 Compensated ~eutron Pass 1 " 60 - 0 ,,,,,, ,,, ,, , ,, ,, , ,,,, ,,, CN2 " " " 2 " " ............ ] ...... ................. . . . . . . NUMBER 13q~.O0 ARC?_. A__L. A_S_K_A__!__N_ C ,_ .................................................................................................................................................................................................................................................. ~ D.S. 2-2~ APl GR1 CCL1 $$N1 LSN1 CN1 GR2 CCL2 SgN2 LSN2 CN2 FROR 9160.00 TO 10460.00 62, SAMPLES PER RECORD PAGE ~RCO ALASKA INC, ),S. '2-24. API 9160. 9180. 93.3 121.8 315.1 910.9 295.0 241.1 43.7 47.6 9200. 107.8 112.2 220.6 ~23.7 256.4 255.6 9220. 114.0 156.0 246,8 937,1 258,7 255,6 48 5 4q 7 ~ . 6 ~1.1 ~ .5 261.8 270.9 52.3 q.~. 2 51 8 . ~7.3 ~.~ 26 .9 2 ~0.7 3c~.6 6~0. 52.9 51.5 261.5 253,5 290,8 282,4 47.1 ~.1 .................. kRCO ALASKA INC. ).S. 2-24 API FT. API API PASS I PASS 2 PASS 1 PASS 9680. 63.9 68.9 179.1 189,5 237.3 22~.4 39.5 9700. 99.9 91,5 221.2 251,7 269,4 555,5 39.9 31.1 9720. 51.2 51.9 363.9 M77.9 ~66.3 48416 26 3 2A, 8 O. 154.1 39.0 ~90.7 A~4,4 665,4 881,4 18,0 lA.1 9760. 74.5 7q.5 417.6 395,6 522,7 465.5 26~0 21,0 2O.3 21,6 2~.7 2M.9 ~RCO ALASKA INC. ).S. 2-24 API t0. 2 .2 21.9 376.7 ~70,6 %64.0 g39.6 31.2 30.1 10200. 29.8 27.8 410.2 412.1 471.6 489.2 27.4 29.2 10220. 25.2 24.6 393.2 587.1 487.6 ~65,5 27.7 2R,~ .3 2~. 5