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191-093
Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. l(~ [-'" 0~-~ File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: GrayScale, halftones, pictures, graphs, charts - Pages: Poor Quality Original - Pages: n Other- Pages: DIGITAL DATA [] Diskettes, No. n Other, No/Type OVERSIZED . -[] ' Logs-of vadous kinds . [] Other COMMENTS' Scanned by: Dianna Vincent Nathan Lowell TO RE-SCAN Notes: - Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ 0 r~ 0 0 Z PLUGGI~= & LOCATION REPORT State cf Alaska .~LAS~ 0iL & GAS CTNSERVATION COMMISSION ~e__ .~eview ~--e well .-'= ~ =, and-cc=men= on pluqqing, well head sum=us, and !oca=icn c!ear~nce - provide loc. clear, code. Well head =an a~:_~: lgla, Harkar pos~ or p!a~: rOl,~ Loca:ion Cle~=ca: Conclusions: Code PERMIT DATA 91-093 5117 91-093 407 91-093 DWOP 91-093 SURVEY . AOGCC Individual Well Oe~±ogzcat Materials Inventor_~ T DATa. PLUS RUN '~' 6681-12973 CDR/RECOMPUTED 1 COMP DATE: 05/16/93 JR 07/24-08/09/91. P&A 05/16 220-6675 SPERRY SUN 91-093 CDN ~L~ 6753-12972 COMP 91-093 CDR ~ 6753-12972 COMP 91-093 DGR/CNP/DSFD ~L 204-6753 MD 1-4 91-093 DGR/CNP/DSFD JL 204-4140 TVD 1-4 91-093 DGR/EWR/FXE c/L 204-4140 TVD COMP 91-093 91-093 DGR/EWR/FXE ~ 204-6753 TVD COMP USiT t/h 100-1170 1 Page: Date: 1 01/13/95 DATE_RECVD 11/12/9! 06/07/93 06/07/93 06/07/93 02/11/92 08/21/91 08/21/91 08/21/91 08/21/91 08/21/91 11/04/91 Are dry ditch samples required? Was the well cored? yes ~ Analysis & description receded? Are well tests required? yes {.n~ Received?~s no Well is in compliance '~ In 1 COMMENTS yes ~ And received? ~ no yes no STATE OF ALASKA ALAsF,,A OIL AND GAS CONSERVATION COMMISSION .~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [~ GAS E~ SUSPENDED [~] ABANDONED r~ SERVICE ~ 2 Name of Operator 7 Pe~it Number ARCO Alaska, Inc 91-93 Permit & 92-028 (403 SA 403) 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22194 4 Location of well at sudace 9 Unit or Lease Name 94' FNL, 139' ~L, SEC 20, T12N, R10E, UM"~~~~¢~~' KUPARUK RIVER AtTop Producing Inte~al 1~ ~ I 10 Well Number At Total Dep~ 1 ~' H~~~-- '. 11 Field and Pool 1442' FSL, 287' FEL, ~EC 16, T12N, R10E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease DesignaUon and Serial No. RKB 88', PAD 45' GL ADL 25636 ALK 2569 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Dep~, if offshore 16 No. of Completions 25-Ju1-91 05-Aug-91 05/16/93. (ABAN D) NA feet MSL NA 17 Total Depth (MD+~D) 18 Plug Back Depth (MD+~D) 19 Dire¢onal Su~ey 20 Dep~ where SSSV set ~ 21 Thic~ess of pe~afrost 12972' MD 7126' ~D SURF YES ~ NO ~ NA feet MD~ APPROX 1700' ~ Type Electric or O~er L~s Run 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CSG SIZE ~ GRADE TOP ~ HOLE SIZE ~R~ 16" 62.5~ H-40 SURF 123' 24" 250 SX PF "C" . 9-5/8" 36¢ J-55 SURF 6734' 12.25" 1400 SX PF "E", 660 SX C~SS "G" 24 Pedorations open to Production (MD+~D of Top and Bo~om and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) NA NA 26 ACID, FRACTURE, CEMENT SQUE~E. ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See Operations Summa~ 27 PRODUCTION TEST Date First Pr~u~ion Me~ of OperaUon (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVIS-APl (corr) Press. 24-HOUR ~TE ~ 28 CORE DATA Brief description of lithology, porosi~, fra~res, 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 29. GEOLC~C ~ 30. FORMATION TESTS NA NAME MEAS DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF A'FFACHMENTS P & A SCHEMATIC, REPORT OF OPERATIONS 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. Signed _ Title ~ , DATE INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 FINAL P & A 1R-24 SURFACE Tagged w/ Coil tbg 05/16/93 @ 1168' (Interface depth not known) Permafrost Class C cement 250 sx (42 bbls) pumped- Unknown volume inside casing. Possible 10.6# brine, diesel, and fresh H20 mix 5/8" Casing Detail 16" @ 88' GL, 123' md from 1168' to surf (525+ sx PF C) 91.5 bbls (Unkown vol. cmt below 1168') Suspected hole in casing (depth unknown) 20 sx Class G + 0.2% CFR3 dumped on top of retainer TOC calc @ 6628' Cement Retainer @ 6680' 9-5/8" @ 6734' md, 4132' tvd 8-1/2" hole (10.6 ppg drilling mud) Open hole plugs extending f/ TD to +/-11943'~ 1029' total length cement plugs 350 sx Class G + 2% CFR3 + .2% HR7 cement plugs 70 sx Class G + 0.2% CFR3 squeezed below retainer Top of C1 sand 12330' TD = 12972' md, 7123' tvd 05/16/93 ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 1R-24 NORTH SLOPE BOROUGH KUPARUK RIVER KUPARUK RIVER 50-029-22194 91-93 ACCEPT: 07/24/91 07:07 SPUD: 07/25/91 01:07 RELEASE: 08/08/91 06:08 OPERATION: Drill & P & A DRLG RIG: POOL 7 WO/C RIG' DOWELL(P & A) 07/24/91 ( 1) POOL 7 TD: 122' ( 122) 07/25/91 ( 2) POOL 7 TD: 122'( o) 07/26/91 ( 3) POOL 7 TD: 1400' (1278) 07/27/91 ( 4) POOL 7 TD: 4899' (3499) 07/28/91 ( 5) POOL 7 TD: 6554' (1655) 07/29/91 ( 6) POOL 7 TD: 6753' ( 199) RIG REPAIRS MW: 0.0 VIS: 0 RD & MOVE RIG FROM 1R-26 TO 1R-24. SKID RIG OVER HOLE. UNSTRING DRLG LINE. REPAIR CROWN SHEAVE. ALSO MAKING REPAIRS ON DRAWWORKS. WORK ON CROWN MW: 8.6 VIS: 81 CHANGE OUT CROWN SHEAVES. RESTRING BLOCKS. WORK ON PUMP MANIFOLD. CHANGE OUT BRAKE PADS. SPOOL LINE ON DRAWWORKS.RU 20" RISER AND FLOWLINE. FUNCTION TEST DIVERTER. PU AND STAND BACK 5" DP. DRLG MW: 9.0 ViS: 58 ADJUST FAST LINE SHEAVE ON CROWN. CUT DRLG LINE. PU BHA. ORIENT MWD. DRLD 122'-1139'. ADT 7 HR. MWD FAILED. CBU. POH. CHANGE BIT & MWD. RIH. DRLD 1139'- 1400'. ADT 1.5 HR. LOADING LWD SOURCE PREP RIH MW: 9.4 VIS: 45 DRLD 1400'-4899'. ADT 15.25 HR. CBU & PUMP DRY JOB. POH WET. TIGHT SPOT AT 520'. KELLY UP AND WORK THROUGH. UNLOAD DENSITY TOOL. CHANGE BIT. LOAD LWD TOOL. PREP TO RIH. POH TO WORK ON TOP DRIVE MW: 9.9 VIS: 43 WASH THROUGH TIGHT SPOT AT 1644', 1830',2042',2252' BREAK CIRCULATION. DRILLED AND SURVEYED FROM 4899' TO 6554' ADT=13.5 HOURS TOP DRIVE DOWN. TROUBLE SHOOT AND TRACE THE PROBLEM TO A BURNED OUT MAIN LEAD WIRE IN THE MOTOR. PUMP DRY JOB, PULL 15 STRANDS WET. DRY JOB DIDN'T WORK. MU HEAD PIN AND PUMP ANOTHER DRY JOB. SHORT TRIP MW: 9.9 ViS: 43 POH. TIGHT FROM 718' TO 355' COULD NOT ROTATE SINCE TOP DRIVE WAS DOWN. RU SOS TO RUN SIDEWALL CORES. GR TOOL WOULDN'T WORK. TROUBLE SHOOT AND FOUND PROBLEM WITH CONNECTION. TOOL FUNCTIONING. RIH WITH SIDEWALL CORE GUN % 1. COULD NOT GET PAST 2442' NO STICKY HOLE JUST COULDN'T GET SPEED GOING DOWN. RD SOS AND HAVE STAND BY UNTIL RIH TO CHECK CONDITION. WORK ON TOP DRIVE. MU BIT, LOAD LWD AND MWD. RIH. NO TIGHT SPOT. RELEASE SOS. DRILLED AND SURVEYED FROM 6554' TO 6753' ADT=2.75 HOURS. CIRCULATE AND CONDITION HOLE. PUMP DRY JOB. SHORT TRIP 20 S T RAND S. WELL: API: PERMIT: 1R-24 50-029-22194 PAGE: 2 07/30/91 ( 7) POOL 7 TD: 6753'( 0) 07/31/91 ( 8) POOL 7 TD: 7075' ( 322) 08/01/91 ( 9) POOL 7 TD:10130' (3055) 08/02/91 (10) POOL 7 TD:11948' (1818) MU BRADENHEAD MW:10.0 VIS: 42 CIRCULATE AND CONDITION FOR CASING. PUMP DRY JOB AND POH. PULL KEY SEAT AT 778' AND 50 8' ATTEMPT TO ROTATE WITHOUT SUCSESS. PULL UP AND ABLE TO CONTINUE POH. UNLOAD LWD AND MWD. LD 8" BHA. RU GBR. HELD SAFETY MEETING PRIOR TO RUNNING CASING. RAN 159' JOINTS OF 9-5/8", 36#, J-55, BTC CASING WITH FS AT 6652'. CIRCULATE AND CONDITION CEMENT. RU HOWCO. TEST LINES TO 3000 PSI. DROPPED FIRST BOTTOM PLUG AND PUMPED 100BBLS FW. DROPPED SECOND BOTTOM PLUG. MIXED AND PUMPED 1400 SX OF PF E W/l/4 PPS FLOCELE(491 BBLS SLURRY) AT 12.3 PPG FOLLOWED WITH 660 SX CLASS G W/1/4PPS FLOCELE, 2% CACL2 (135 BBL SLURRY) AT 15.8 PPG. DROPPED TOP PLUG AND DISPLACED WITH 514 BBLS OF MUD. HAD FULL RETURNS UNTIL THE LAST 100 BBLS PUMPED, DID NOT GET CEMENT TO SURFACE. BUMPED PLUG WITH 2000PSI. CIP AT 0200 HOURS ON 7/30/91. RD CEMENTING HEAD. BACK OUT LANDING JOINT. ND DIVERTER SYSTEM. RU AND DO 138 SX(27 BBLS SLURRY) TOP JOB WITH PF C AT 15.5PPG. MU FMC 11-3/4" BTCXll"3M BRADENHEAD. CHECK LWD TOOL MW: 9.0 VIS: 31 MU FMC 11-3/4" BTCXll" 3M BRADENHEAD. NU BOP. MU TEST PLUG. FUNCTION TEST BOP. TEST BOP HYDRIL 500/2500 PSI; BLIND RAMS 500/3000 PSI;MANUAL AND HYDRAULC CHOKE AND KILL 500/3000 PSI. SET WEAR RING. PU DP. PU BHA. CHANGE TURBINE BEARING SECTION. TESTED TURBINE @ 420 GPM. LOAD LWD. ORIENT MWD. RIH TO FIRST STRAND OF DP AND TEST MWD. CUT DRILLING LINE AND LUBRICATE RIG. RIH AND TAGGED CEMENT TO 6621' CIRCULATE OUT CEMENT AND CONTAMINATED MUD. TEST 9-5/8" CASING TO 2000 PSI. DRILLED CEMENT FROM 6621' TO 6644' DRILLED FC AND FS AND 10' OF NEW HOLE TO 6763' CIRCULATE AND CONDITION MUD FOR LEAK OFF TEST. TESTED FORMATION TO 12.4PPG EMW. DRILLED FROM 6763' TO 7075' ADT = 1 HOUR. LWD TOOL NOT WORKING. CIRCULATE AND MIX DRY JOB. POH TO CHECK/CHANGE LWD COLLAR. UNLOAD LWD SOURCE. CHECK LWD TOOL. DRILLING MW: 9.6 VIS: 35 CHANGE OUT MWD ORIENT W/' TURBINE PULL UP AND CHECK BIT-OK RIH CHECK MWD @ lST STND HWDP. - OK DRILL AND MWD SURVEY F/7075' TO 10130' MAKING CORRECTIONS AS NEEDED ADT=16 HRS TRIP FOR BIT AND BHA MW:10.6 VIS: 38 DRILL AND MWD SURVEY TO 10632' ADT=2.5 HRS PUMP SLUG- MAKE 20 STRANDS SHORT TRIP NO TIGHT HOLE, JUST HIGH ANGLE DRAG DRILL AND MWD SURVEY TO l1606'-TOP DRIVE STALLED-PU ON PIPE-STUCK ADT=8 HRS WORK PIPE FREE DRILL AND MWD SURVEY TO 11948' ADT=3.5 HRS BIT STOPPED M3%KING HOLE, CIRC AND MIX SLUG. PUMPED SLUG, POH SLM WELL: 1R-24 API: 50-029-22194 PERMIT: PAGE: 3 08/03/91 (11) POOL 7 TD:t2067' ( 119) 08/04/91 (12) POOL 7 TD:12234' ( 167) 08/05/91 (13) POOL 7 TD:12892' ( 658) 08/06/91 (14) POOL 7 TD:12972' ( 80) 08/07/91 (15) POOL 7 TD: 12972' ( o) 08/08/91 (16) POOL 7 TD: 6628'( o) 08/09/91 (17) POOL 7 TD: 6628'( o) DRILLING MW:10.6 VIS: 45 POH. SLM NO CORRECTIONS. UNLOAD CDR/CDN, BREAK OFF BIT, LAY DOWN TURBINE AND LEAD COLLAR, CHANGE OUT MWD/LWD. PROGRAM MWD/LWD. MAKE UP NEW BHA REAM F/ 11338' TO 11948' TO LOG HOLE DRILL AND SURVEY F/ 11948 TO 12067' ADT=8.25 HRS RIH MW:10.6 ViS: 45 DRILL E/ 12067' TO 12234' ADT 12.5 HRS PUMP SLUG, POH FOR BIT AND BHA CHANGE SET BACK HWDP. UNLOAD SOURCE F/ CDN/CDR/GR, LAY DOWN 1-DC AND N.B. STB. PICK UP WITH NEYFORE TURBINE, CHANGE STB. TEST TURBINE , CHANGE OUT MWD AND LWD ORIENT MWD, PROGRAM CDN/CDR/GR AND LOAD SOURCE, RIH W/ DC AND 1 STN HWDP. SURFACE TEST MWD/LWD --GOOD RIH DRILLING MW:10.6 VIS: 41 RIH TO 9-5/8" SHOE. FILL PIPE CUT DRLG LINE 112', SER RIG, ADJUST BRAKES RIH FILL PIPE @ 8839 AND 12214'. DRILL AND MWD SURVEY F/ 12234' TO 12892' ADT=16.5 HRS PUMP SLUG POH MW:10.6 VIS: 45 DRILL TO 12972'. ADT=2 HR. CIRC & PUMP SLUG. POH. TIGHT HOLE 12278-11900'.RIH W/ OE DP TO TD. CIRC. PUMP 150 SX CL G CMT W/.2% CFR3, .~% HR7, 02% HALAD 344A. "DisPLACED5 PO~h ~5--~D-~--~ERSE OUT CONTAMINATED MUD. CIP 03:40. CIRC. WOC MW:10.6 VIS: 52 POH TO 9-5/8" SHOE. WOC. RIH TAG GOOD CMT @ 12619' PUMP ~00 S~._CLASS G CMT W/ 0.215% HR7, 0.2% CFR3. DISPLACED. POH TO 11865' AND REVERSE OUT. CIP @ 15:45. POH TO 9-5/8" SHOE. WOC. RIH TAGGED GREEN CMT @ 12051'. WOC. CLEAN MUD PITS MW:10.6 VIS: 51 WOC. TAG CMT PLUG AT 11943'. POH. RIH AND SET CR AT 6680' PUMP 70 SX CL G W/ 0.1% CFR3 BELOW CR, DUMP 20 SX ON TOP. CALC TOC 6628'. DISPL MUD W/ 10.6 PPG NACL/NABR WITH 60 BBL DIESEL CAr. POH. ND BOP. NU TBG SPOOL AND LOWER TREE. CLEAN MUD PITS. RELEASE RIG MW: 0.0 ViS: 0 RELEASED RIG AT 0600 ON 8/8/91. MOVE RIG TO 1R-29. WELL: API: PERMIT: 1R-24 50-029-22194 PAGE: 4 05/16/93 (19) TD-12972 PB: 0 WELD DRY HOLE MARKER MW' 0.0 HOT OIL ON LOC. HEATED 250 BBLS DIESEL TO 135 DEG. DS CTU RU ON WELL. HOWCO RU TO CMT. PRESS TESTED ALL LINES TO 4000 PSI. OPENED WELL & WASHED TO PBTD @ 1168' W/CTU USING 110 BBLS OF 135 DEG DIESEL. DISPLACED ARCTIC PACK. HOWCO PUMPED 5 BBLS H20, 525+ SX (91 5 BBLS) OF 15 6 PPG PF "C" · . ff 5 BBL H20. DS CTU DISPLACED CMT @ 1168' W/DIESEL UNTIL CMT WAS 2BBLS OUT OF NOZZLE. POH LAYING CMT F/1168' TO SURF. FREEZE PROTECTED COIL. RD & CLEARED LOCATION. VECO BACKHOE DUG OUT CELLAR 3 + BELOW ORIGINAL TUNDRA -- LEVEL.' GBR & PEAK SUPPORT ON LOC. DS OPERATOR ARRIVED ON LOC @ 0900 HRS TO SIGN HOT WORK PERMIT(SUBMITTED @ CONTROL ROOM 05/15/93 @ 1600 HRS) . AIR DRILLED HOLE THRU CONDUCTOR & 9-5/8" HAD DIESEL IN 9-5/8" PLUMB BOB TAGGED CMT 18" BELOW DIESEL CUT AREA. VAC'D DIESEL OUT OF 9-5/8" FILLED 9-5/8" W/CMT TO 3' ABOVE CUT DEPTH. EXPENDED A FIRE EXTINGUISHER INTO TOP FOR SAFETY PROCEDURE. CUT COND & 9-5/8" 3 + BELOW ORIGINAL TUNDRA LEVEL. THE DRY HOLE MARKER WAS WELDED TO THE TOP CAP & THE HOLE BACK FILLED. SIGNATURE: DATE' 7'/ ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 MARCH 23, 1993 WAYNE MCBRIDE ARCO ALASKA INC. ATO 1448 P O BOX 100360 ANCHORAGE, ALASKA 99510. RE: 91-0069 KUPARUK RIVER UNIT 91-0093 KUPARUK RIVER UNIT 1L-26 1R-24 DEAR MR. MCBRIDE, OUR FILES INDICATE THAT ARCO ALASKA INC. AS THE OPERATOR OF THE SUBJECT WELLS, HAS NOT FULLY COMPLIED WITH ALL THE REQUIREMENTS ASSOCIATED WITH THE OPERATIONAL SHUTDOWN OF THE ABOVE REFERENCED WELLS. ACCORDING TO 20 AAC 25.072(d), "IF WELL OPERATIONS ARE NOT RESUMED WITHIN 12 MONTHS, THE OPERATOR SHALL IMMEDIATELY PROCEED TO ABANDON THE WELL." ITS THE OPERATORS RESPONSIBILITY TO MONITOR THE STATUS OF YOUR WELLS FOR COMPLIANCE WITH THE COMMISSIONS REGULATIONS. WILL YOU PLEASE ADDRESS THE MATTER OF YOUR FUTURE PLANS CONCERNING THESE WELLS. PLEASE LET ME KNOW IF THERE IS ANY PROBLEM WITH SUBMITTING THIS CORRESPONDENCE AS REQUESTED IN A TIMELY MANNER. SINCERELY, STEVE MC MAINS -~- STATISTICAL TECHNICIAN C: ROBERT CRANDALL SR PETR GEOLOGIST ARCO Alaska, inc. Date: February 21, 1992 Transmittal #: 8369 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. one signed copy of this transmittal. Please acknowledge receipt and return 3Q-03 LIS Tape and Listing 1 -27-92 92095 3 R- 12 D LIS Tape and Listing .2 - 4 - 9 2 9 21 15 THE FOLLOWING LIS TAPES ARE STAMPED WITH A CORRECTED COPY STAMP. PLEASE REPLACE THE PREVIOUS COPY THAT YOU HAVE ALREADY ' RECEIVED WITH THIS ONE. THANK YOU. ~'/----/,'¢' I R-1 7 ~/ --/,~ I R-20 ~/.../z3 1R-21 .~,.,,_/o?' I R-22 ~t--./o! 1R-23 q/.-.~'$ 1R-24 ,~/...-~'~.. I R-26 ?/.-/o=-' I R-27 ~/_ ?~z 1 R-29 ?1..--,~t 1R-19 ?/./a? 2M-21 q/-../Y~.2 M - 1 9 f~/---~:~ 1 L-23 ~'/~'~ I L-24 ~,/-?o 1 L-25 ?/--'~ 1 L-26 Receipt LIS Taae and LIS Ta3e and LIS Ta 3e and LIS Ta3e and LIS Taae and LIS Ta3e and LIS Ta3e and LIS Ta 3e and LIS Ta3e and LIS Ta3e and LIS Ta:3e and LIS Ta.~e and LIS Ta 3e and LIS Ta 3e and LIS Ta ~e and LIS Ta 3e and Acknowledged' Listing 9 - 1 9 - 91 9 2026 Listing 9 - 9 - 9 1 9 2026 Listing I 0 - 6 - 91 9 20 26 Listing 9 - 2 4 - 9 1 9 2026 Listing I 0-22-91 92026 Listing 7 - 3 0 - 9 1 9 20 26 Listing 7- 1 8-9 1 92026 Listing 8 - 31 - 9 1 9 2026 Listing 8 - 1 4 - 91 9 20 26 Listing 6 - 1 9 - 9 1 9 20 26 Listing 1 I - 1 1 - 91 9 20 26 Listing 1 1 - 1 7 - 91 920 26 Listing 5 - 9 - 9 1 92026 Listing 5 - 1 9 - 91 920 26 Listing 5 - 2 6 - 91 9 2026 Listing 6 - 3 - 9 1 92026 REC-EWED DISTRIBUTION' Lynn Goettinger FEB 2 8 1992 Alaska 0ii & Gas Cons. Commission Anchorage State of Alaska ARCO Alaska, Inc. Date- February 21, 1992 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. . one signed.copy of this transmittal. '~/'"/~-~ 33R© 1023D~~ LIS Tape and Listing ¢:z-'-~- .' LIS Tape and Listing ~//-//Y' 1 R- 1 7 LIS Tape and Listing ¢ [..-/o~' 1 R - 2 0 LIS Tape and ¢!-//'~ 1 R- 21 LIS Tape and ~!.../o ~ 1 R - 2 2 LIS Tape and ¢/,/.--/~/ 1R 23,.~ . LIS Tape and ~/'-'¢-~ 1 R-24 LIS Tape and 9, ,~. 1 R- 2 6 LIS Tape and q_/,.¢~.,~. 1 R-2 7 LIS Tape and ¢!..-~_~,41 R - 2_9. LIS Tape and i¢-~_~ ~'R-1 9 LIS Tape and ¢/-/~? 2M-21 LIS Tape and ?/- / ~2' 2 M - 1 9 LIS Tape and 'f t---'~ 1 L- 2 3 LIS Tape and ql-~ 1 L 24 LIS Tape and '~t-7°,~ 1 L-2 5 LIS Tape and ¢'/-~ ¢' ~ L- 2 6 .7' LIS Tape and Receipt Acknowledged: DISTRIBUTION: Lynn Goettinger Transmittal #' 8369 Please acknowledge receipt and return 1 -27-92 2-4-92 9-19-91 Listing 9 - 9 - 91 Listing 1 0 - 6 - 91 Listing 9 - 2 4 - 91 Listing 1 0 - 2 2 - 91 Listing 7 - 3 0 - 91 Listing 7- 1 8 - 91 Listing 8 - 31 - 91 Listing 8 - 1 4 - 91 Listing 6 - 1 9 - 91 Listing 1 1 - 1 1 -91 Listing 1 1 - 1 7- 91 Listing 5 - 9 - 91 Listing 5 - 1 9 - 91 Listing -. 5 - 2 6 - 91 Listing 6 -3 - 9 1 Date' State of Alaska 92095 92115 92026 92026 92O26 92026 92026 92026 92026 92026 92026 92026 92026 92026 92026 92026 92026 92026 ...R_E£EIVED FEB 2 5 1992 Alaska 0118, Gas Cons. Commission Ar~chorage Al_A," OILAND GAS CONSERVATION COMMI[ N APPLICAI'ION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Alter casing _ Change approved program X Operation Shutdown _ Re-enter suspended well_ _ Plugging X Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) 2. Name of Operator Suspend _ Repair well 5. Type of Well: Development Exploratory Stratigraphic Service ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 94' FNL, 139' FWL, Sec. 20, T12N, R10E, UM At top of productive interval 1360' FSL, 807' FEL, Sec. 16, T12N, R10E, UM At effective depth At total depth 1442' FSL~ 287' FEL~ Sec. 16~ T12NI R10E~ UM 12. Present well condition summary RKB 88'. Pad 45' GL 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1R-:~4 9. Permit number 91 -93 10. APl number 50-029-22194 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Total Depth: measured 1 2972' feet true vertical 71 2 6' feet Effective depth: measured 1 1 6 8' feet true vertical 1 1 63' feet Plugs (measured) 12972'-11943', total 350 Sx CIG. Cement Retainer @ 6680' with 70 Sx CIG below and 20 Sx on top. Calc TOC at 6628'. 250 Sx CI C with TOC 1168'. Btm of plug not known. Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Leng~ Size 80' 16" 6691' 9-5/8" measured None true vertical Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None Cemented Measured depth 250 Sx Permafrost C 123' 1400 Sx Permafrost E 6734' & 660 Sx Class G True vertical depth 123' 4132' Alaska. Oil & Gas Oons, Oornmissiu~" 13. Attachments Description summary of proposal _ Detailed operation program BOP sketch 14. Estimated date for commencing operation 5/1/92 16. If proposal was verbally approved Mike Minder Name of approver 1/14/92 Date approved 15. Status of well classification as: Oil ~ Gas __ Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~, ~-'~', ~. ~-'~~ Title Area Drilling Engineer / FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity .~ BOP Test_ Location clearance ~ Mechanical Integrity Test__ Subsequent form require Approved by the order of the Commission Form 10-403 Rev 06/15/88 IApproval No. 10- Commissioner Date SUBMIT IN TRIPLICATE Current Status KRU 1 R-24 9 5/8" Casing Detail SURFACE 90 bbl Arctic Pack/Diesel Mixture TOC @ +/-1168' Tagged w/ Wireline 10/15/91 (Interface depth not known) Permafrost Class C cement 250 sx (42 bbls) pumped- Unknown volume inside casing. Possible 10.6# brine, diesel, and fresh H20 mix 8-1/2" hole (10.6 ppg drilling mud) 16" @ 88' GL, 123' md Suspected hole in casing (depth unknown) 20 sx Class G + 0.2% CFR3 dumped on top of retainer TOC calc @ 6628' Cement Retainer @ 6680' 9-5/8" @ 6734' md, 4132' tvd 70 sx Class G + 0.2% CFR3 squeezed below retainer Open hole plugs extending fl TD to +/-11943'~ 1029' total length cement plugs 350 sx Class G + 2% CFR3 + .2% HR7 cement plugs Top of C1 sand 12330' TD = 12972' md, 7123' tvd EDF 2/8/92 Proposed Plug and Abandon Schematic KRU 1 R-24 9 5/8" Casing Detail SURFACE 90 bbl Arctic Pack/Diesel Mixture TOC @ +/-1168' Tagged w/ Wireline 10/15/91 (Interface depth not known) Permafrost Class C cement 250 sx (42 bbls) pumped- Unknown volume inside casing. 16" @ 88' GL, 123' md Cement from bridge plug to surface ridge plug set as Iow as possibe (200' minimum depth) 9.9 ppg or greater brine Suspected hole In casing (depth unknown) 20 sx Class G + 0.2% CFR3 dumped on top of retainer Possible 10.6# brine, diesel, and fresh H20 mix TOC calc @ 6628' Cement Retainer @ 6680' 9-5/8" @ 6734' md, 4132' tvd 8-1/2" hole (10.6 ppg drilling mud) 70 sx Class G + 0.2% CFR3 squeezed below retainer AJaska 0JJ~ ° G~.o" Cons. C0rm-~issior~ Armfiora§e Open hole plugs extending f/ TD to +/-11943'~ 1029' total length cement plugs 350 sx Class G + 2% CFR3 + .2% HR7 cement plugs Top of C1 sand 12330' TD = 12972' md, 7123' tvd EDF 2/8192 ARCO Alaska, Inc." Post Office B,... 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 19, 1992 Mr. David W. Johnston, Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Kuparuk River Unit Well 1R-24 APl 50-029-22194 Dear Mr. Johnston: We are requesting approval to plug and abandon Kuparuk Well 1R-24. Form 10- 403 for Plugging and Abandon and requesting to Change Approved Program is attached for your approval. Well 1R-24 was drilled in late-July/early-August, 1991 and is considered a dry hole. No 7" casing was ever run in this well. Prior to moving the rig off the hole, two cement plugs were set: one in the open hole across the Kuparuk sands, and another plug with a cement retainer across the 9-5/8" casing shoe. The surface casing was displaced with 10.6 ppg brine and a 60 bbl (776 ft) diesel cap left in the well. A Form 10-403 requesting Operation Shutdown was approved August 9, 1991. In September, 1991, an Arctic Pack job was inadvertently pumped into the well which burst the 9-5/8" casing. This job was pumped as if there were a 7"x9-5/8" annulus, and the 10.6 ppg brine and diesel in the well were pushed down hole ahead of the Arctic Pack job. The well was initially pressured up to 2000+ psi and the pressure dropped off rapidly as if an ice plug had been displaced. This sudden drop in pressure is the most likely point at which the casing failed. The job was continued by pumping 380 bbls of water, followed by 42 bbls of Class C Permafrost cement, and 60 bbls of Arctic Pack fluid. RECEIVED ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompaRy FEB 21 t992 Alaska Oil & Gas Cons. 6ommissioO · .!..:., . :). Anchorage Mr. David W. John~ _va, Commissioner February 19, 1992 Page 2 A post-Arctic Pack wireline survey tagged the top of cement at 1168' MD and confirmed that the fluid in the wellbore above this cement was an Arctic Pack/diesel mixture. (See Attachment: Current Status.) A subsequent survey using Schlumberger's Ultrasonic Imaging (USI) tool revealed the presence of worn casing in the 9-5/8" casing above the cement plug. There are several items which are known about this well with a high degree of certainty, the volumes of fluids pumped during the Arctic Pack job, the location of the top of the cement plug (top @ 1168'), and the presence of the Arctic Pack/diesel mixture above the plug. Additionally, we can say with confidence that the plugs in the open hole and across the casing shoe have remained intact. It is much more likely that the 9-5/8" casing would have failed before the plug and cement retainer at the shoe would fail. However, there are several details which are are unknown or cannot be confirmed regarding the status of 1R-24. The actual volume of cement inside the casing below 1168' is not known. There is a possibility that some cement was squeezed through a hole in the casing. Also unknown is the fluid content between the upper cement plug (top @ 1168') and casing shoe cement retainer plug (top @ 6628'). It is possible that this fluid is a mixture of diesel, fresh water, and 10.6 ppg brine. In addition, a casing failure between these two plugs could have occurred. It is suspected that any failures in the casing would be in the areas of greatest wear which occur in the high dogleg sections of the well. For 1R-24, casing wear would be limited to the kickoff point at 300' to the end of the build section at 2800'. The USI survey for the well confirms the presence of casing wear in the buildup section, but the status of the casing below the upper cement plug is not known. By correlating casing wear in the build sections of other Kuparuk wells using the USI tool, it can be inferred that the chances of having holes above or below the build section are greatly diminished. It can then be assumed with a fair degree of confidence that any casing failure on 1R-24 is located above 2800'. If we assume that a single casing failure is located at 2800' and that all 42 bbls of Class C cement is in the upper plug, then the bottom of the cement would be at 1711' and the equivalent fluid weight between the plugs is 9.9 ppg. This fluid weight is equivalent to the mud weight used to drill this interval. If the failure is above 2800', then the fluid density between the cement plugs is greater than 9.9 ppg. A density of something less than 9.9 ppg would provide sufficient hydrostatic pressure to prevent migration of fluids through the interval. Mr. David W. John, ~n, Commissioner February 19, 1992 Page 3 ARCO Alaska, Inc. would like to plug and abandon 1R-24 as shown in the Attachment: Proposed Plug and Abandon Schematic. We feel there is no potential problem in leaving the lower portion of the surface casing in its current condition with the expected fluid density and whatever cement and arctic pack fluid are in place. With your approval, we will complete the P&A with the following procedure: 1. Rig up coiled tubing unit. 2. Run in hole and displace Arctic Pack/diesel mixture with brine EMW of 9.9 ppg or greater; POH. 3. Rig up wireline unit. 4. Set bridge plug as low as possible or at 200' minimum; POH. 5. Rig up coiled tubing unit. 6. Run in hole and spot cement plug to surface; POH. 7. Cut off casing, weld on cap, and erect abandonment marker per AOGCC regulations. We would be happy to discuss this proposal if you have any questions. Please feel free to call Ellen Fitzpatrick at 263-4638 or Wayne McBride at 263-4962. David P~k Jr. Engineer C: E. D. Fitzpatrick ATO-1450 A. W. McBride ATO-1448 R. F. Morgan ATO-1426 D. B. Stoltz ATO-1402 1R-24 Well File ARCO Alaska, Inc. Date: November 8, 1991 Transmittal #: 8281 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATe-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. /.--\\.,-~ 1 R- 2 4 LIS Tape and Listing -'~../ ,,~ 7- 3 O- 9 1 7 4 8 3 9 ,, -.. ¢.~ i._j .:.'.~ 'i DiSTRiBUTiON: Alaska ,Oil & Gas Cons. Cof~'~i-rdssit~ Anchora§e Lynn Goettinger State of Alaska ARCO Alaska, Inc. Date: February 7, 1992 Transmittal #: 8355 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. Please acknowledge receipt /~/ and return o. ne signed copy of this transmittal. ~.~,~, 2M-10 Litho-Density & Casing Neutron 11-29-91 70000-7756 '~ J~ Porosity Data & 12-29-91 700 - 7669 2 M - 1 0 Litho-Density & Casing Neutron 1 1 - 2 9 - 91 7 000- 7756 Raw Data & 12-29-91 7000 - 7669 ,[3Q-04 CCN ~ 1-12-16-92 4517.7-7720 Q-04 CDR ,,, 1-12-16-92 4517.7-7720 i~Q-03 CCN ~ 1-24-27-92 5090-9640 Q-03 CDR ¢ 1-24-27-.92 - 5090-9640 ,THE FOLLOWING LOGS ARE CORRECTED COPIES. IT HAS BEEN REQUESTED ~ ~ THAT YOU THROW OUT THE PREVIOUS (UNCORRECT) COPY OF THIs LOG..~ 7~ ~HANK YOU. ~ ~ 5-9-i3~91 ; 5237.1047~ ~ 1L-26 d~-~~ 6-3-6-91 5225-10065 / 3835-9250 / / 2M-21~/ ~ 1 1-1 1-91 1R-17,~ ~ 9-15-19-91 - ~~/~-- 1R-19J/ ~ 6-19-23-91 · 5390-9841 ~_ . ..- 1R-21~ ~ 10-6-11-91 5070-10180 ] /~ ~[ ~1R-22~ ~ 9--24-29-91 6001-10813 J ~(.~llR-23J/ . ~ 10-22-91 6330-12188 J - 7-18-21-91 5591-10218 ) 8-14-91 6042-11368 ~ 1 L-24 ~ J 5-1 9-22-91 5081-9241 / RECEIVED Alaska Oi~ & Gas Certs. ~mrnission ARCO Alaska, Inc. Date: November 1, 1991 Transmittal #: 8273 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-111 9 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. 23 Receipt Ultra Sonic Imager Corrosion Mode 1 0- 2 1 - 9 1 Ultra Sonic Imager 1 0 - 2 2 - 91 (Cement &Corrosion),,/ Acknowledge: ~~ )~~:~.~. .. Drilling 100-1170 100-6320 Date' : ..... KUPARUK ENGINEERING TRANSMITTAL # 1419 TO: John Boyle STATE FROM: R. M. Brush/P. S. Baxter DATE: August 19, 1991 WELL NAME: KRU 1R-19 and 1R-26 CONFIDENTIAL TRANSMITTED HEREWITH ARE THE FOLLOWING: One copy of Blueline and Sepia 1R-24 1R-24 1R-24 1R-24 2" and 5" Dual Gamma Ray, Compensated Neutron Porosity and/ Dual Simultaneous Formation Density True Vertical Depth Log 2" and 5" Dual Gamma Ray, Compensated Neutron Porosity and Dual Simultaneous Formation Density Measured Depth Log j 2" and 5" Dual Gamma Ray, Electromagnetic Wave Resistivity and Formation Exposure Time (EWR) True Vertical Depth Log ~t 2" and 5" Dual Gamma Ray Electromagnetic Wave Resistivity and Formation Exporsure Time (EWR) Measured Depth LOg v' One copy of Blueline and Sepia 1R-26 1R-26 1R-26 1R-26 2" and 5" Dual Gamma Ray and Compensated Neutron Porosity True Vertical Depth Log ~' 2" and 5" Dual Gamma Ray and Compensated Nuetron Porosity Measured Depth Log ~/ 2" and 5" Dual Gamma Ray, Electromagnetic Wave Resistivity and Formation Exposure Time (EWR) True Vertical Depth LOg V 2" and 5" Dual Gamma Ray Electromagnetic Wave Resistivity and Formation Exporsure Time (EWR) Measured Depth LOg ~/ PLEASE RETURN RECEIPT TO: ARCO Alaska, Inc. ATTN: P. S. Baxter, ATO-1208 P. O. Box 100360 Anchorage, Alaska 9951~ E C E [ V ~ D RECEIPT ACKNOWLEDGED: DAT,.: AUG 2 1 1991 I' /}Ja_~ ,0il ,& Gas Cons. comrnia_sten N~ctto!age ARCO Alaska, Inc. Date: August 16, 1991 Transmittal #: 8197 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 - P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. and return one signed copy of this transmittal. ---'-1L-2 0X CEt~ 4/17-19/91 ~/ ~,~ ~1R-24 CC~ 7/30-8/5-91 - 1R 24 CDN 7/30-8/5-91 Receipt Acknowledged' Please acknowledge receipt 6044-11757 6753-12972 6753-12972 Date' -% ........ DISTRIBUTION: D&M Drilling Franzen Vendor Package(Johnston) NSK State of Alaska(+Sepia) AUG 2 1 1991 '41O~lra 011 &A~naC~hoCOra;~. ABCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 July 5, 1991 Mr. Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Kuparuk River Unit Well 1R-24 API 50-029-22194 Dear Mr. Wondzell: ARCO requests approval to shut down operation of Kuparuk River Unit well 1R-24. The open hole resistivity log shows both 'A' and 'C' sands of the Kuparuk formation to be water saturated. The well is not commercially producible at this bottom hole location. ARCO proposes to plug the open hole and preserve the 9-5/8" surface casing for possible future use in obtaining wireline log information in the West Sak formation. A plugging procedure and well bore schematic are attached. If you have any questions, please contact Ellen Fitzpatrick at 263-4638. Sincerely yours, A. Wa McBride Area Drilling Engineer AUG o 91991 ~ , OIL AND GAS CONSERVATION COMMI/ ')N APPLICATION FOR SUNDRY APPhOVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown ~ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 94' FNL, 139' FWL, Sec. 20, T12N, R10E, UM At top of productive interval 1360' FSL, 807' FEL, Sec. 16, T12N, R10E, UM At effective depth At total depth 1442' FSL, 287' FEL, Sec. 16, T12N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 1 2972' feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 88'. Pad 45' GL 7. Unit or Property name Kul3aruk River Unit feet 8. Well number 1 R-24 9. Permit number 91-93 10. APl number 50-029-221 94 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 7126' feet None as of 8/5/91 Effective depth' measured 12972' feet Junk (measured) true vertical 71 26' feet None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 80' 6691' measured None true vertical Size 16" :4:5:/8" Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None Cemented Measured depth True vertical depth 250 Sx Permafrost C 123' 1400 Sx Permafrost E 6734' & 660 Sx Class G 123' 4132' ]991 13. Attachments Description summary of proposal _ Detailed operation program X.~ BOP sketch 14. Estimated date for commencing operation ~/5/91 16. If proposal was verbally approved Blair Wondzell Name of approver 8/5/91 Date approved 15. 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 ~//~/) ~ ~FoRTitle COMMISSIoNArea Drillin(:j EngineerusE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require 10-~Oq Approved by the order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY RUSSELL A. DOUGLASS Commissioner Approyed C~opy Returnee IApprova .No. , S uD;t; i T~~T~R~I p~L/[ CAT E Kuparuk River Unit 1R-24 Plu in Procedure -- -- -- NOTE: Notify the AOGCC in time so their representative can be present to witness the P&A work. 1. RIH w/ open-ended drill pipe to TD. Circulate and condition drilling mud a minimum of 1 full circulation. 2. Mix and pump the following slurry after circulating: 150 sx Class 'G' + 0.2% CFR3 + 0.23% HR7 + 0.2% Halad 344A 3. Spot a cmt plug from TD to +/-12600'. 4. POH 5 stands (to top of plug) and reverse out 1-1/2 dp volumes. POH to 9- 5/8" shoe. WOC approximately 12 hrs. 5. RIH w/ open-ended drill pipe and tag top of cement plug. Record actual depth of plug. 6. Mix and pump the following slurry after circulating: 150 sx Class 'G'+ 0.2% CFR3 + 0.23% HR7 + 0.2% Halad 344A 7. POH 5 stands (to top of plug) and reverse out 1-1/2 dp volumes. POH to 9- 5/8" shoe. WOC approximately 12 hrs. 8. RIH w/ open-ended drill pipe and tag top of cement plug. Record actual depth of plug. POH. 9. PU 9-5/8" 36# cement retainer and RIH to 6680', (csg shoe at 6734'.) Set retainer. Establish injection rate through retainer. Inject excess drilling mud into formation. Mix and pump 90 sx class 'G' cmt + 0.2% CFR3. Inject 70 sx below retainer. Unsting from retainer and dump remaining 20 sx on top of retainer. 10. POH to above plug and reverse out a minimum of 1-1/2 dp volumes. Shut in well and test casing to 2000 psi. 11. Circulate hole and displace mud with 10.6 ppg corrosion inhibited brine (if corrosion inhibitor available). 12. POH to 200'. Circulate diesel to leave +/- 200' diesel cap. POH. 13. 14. NU tbg spool and lower tree assembly. RD and move out Pool Rig #7. 199]. Kuparuk River Unit 1R-24 Plugging Schematic 200' diesel cap 16" @ 88' GL, 123' md 10.6 ppg corrosion inhibited brine TOC @ +/- 6 Cement Retainer @ +/-6680' 20 sx (22 cu ft) dumped on top of CR Class G + 0.2% CFR3 9_._._:5/8~ @ 6734' md, 4132' tvd ID=8.921", cap=.0773 bpf,.4305 cuft/ft 70 sx (66 cuft + 15% cmt sqz'd below retainer Class G + 0.2% CFR3 8-1/2" hole .0702 bpf (10.6 ppg drilling mud) Open hole plugs extending f/ TD to +/-12230~-'-'''- 742' total length cement plugs 293 cult + 15% excess cement plugs Top of Cl sand 12330' 2-150 sx plugs Class G + ,2% CFR3 + .2% HR7 TD = 12972' md, 7123' tvd EDF 8-5-91 ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 15, 1991 A W McBride Area Drilling Engr ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 1R-24 ARCO Alaska Inc Permit No. 91-93 Surf Loc 94'FNL, 139'FWL, Sec 20, T12N, R10E, UM Btmhle Loc 1471'FSL, 280'FEL, Sec 16, T12N, R10E, UM Dear Mr McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Sufficient notice must be given to allow for a representative of the Commission to witness the BOPE installed on the surface casing and a test of same prior to drilling out the surface casing shoe. Sincerely, AD~aV~kdaW emravnation Commission BY ORDER OF THE COMMISSION jo/encl c: Dept of Fish & Game, Habitat Section, w/o encl Dept of Environmental Conservation w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill [~ Redrill [~ I lb. Type of Well Exploratory D Slratigraphic Test J'~ Development Oil Re-Entry r-] Deepen DI Service D Development Gas D single zone [] Multiple Zone D 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska~ Inc. RKB 88'~ Pad 45' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchoracje, AK 99510-0360 ADL 25636, ALK 2569 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 94' FNL, 139 FWL, Sec. 20, T12N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1350' FSL, 1065' FEL, Sec. 16, T12N, R10E, UM 1R-24 #UG30610 At total depth 9. Approximate spud date Amount 1471' FSL, 280' FEL, Sec. 16, T12N, R10E, UM 7/1 9/91 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1R-25 13,164' MD 3,809 @ TD feet 60' @ Surface feet 2560 7,083' TVD feet 16. To be compleled for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300 feet Maximum hole angle 63° Maximum surface 2457 psig At total depth O'VD) 3450 psig 18. Casing program Settincj Depth size Specifications Top Bottom Quanlity of cement Hole Casin~l Weight Grade Coupling Length IVO TVD IVD 'I'VD (include stage dataI 24" 16" 62.5# H-40 Weld 80' 43' 43' 123' 123' +_200 CF 12.25" 9.625" 36.0# J-55 BTC 6722' 43' 43' 6,765' 4,150' 1330 Sx Permafrost E & HF-ERW 660 Sx Class G 8.5" 7" 26.0# J-55 BTC 13121 43' 43' 13~164' 7~083' 280SxClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemente(:~ ~ ~ ~. ~ ~'l~ea~'~,t, jed depth True Vertical deplh Structural Conduclor Surface Intermediate JU~ ~ ~ ~';~ Production Liner Al~.sk~ Oil & Gas Cons. Pedoration depth: measured 'A~lCh01'agE~ true vertical 20. Attachmenls Filing fee [~ Property plat E] SOP Sketch ~[1 Diverter Sketch [] Drilling program J~ Drilling fluid program [~ Time vs depth plol D Refraction analysis D Seabed report ~] 20 AAC 25.050 requirements 21. I hereby certify lhat the foregoing is true and correct to the best of my knowledge Signed ~//~~ Title Area Drillincj Engineer Date ~/~"~/~f~f-- Commission Use Only / Permit Number JAPI number IApproval/dat,e ISee cover letter for ,~/- .~,~ 50- C~2_.~' '-' ~ ~_.ff' ~P ~ ~/[~ other recluirements Conditions of approval Samples required ~] Yes ~ No Mud log required [~ Yes ~ No Hydrogen sulfide measures D Yes /~ No Directional survey required Yes No Required working pressure for DOPE D 2M ~ 3M D 5M r'] 10M D 15M Other: Approv~ Commissioner the commission Date .~_ _ . DRILLING FLUID PROGRAM (1R-24) Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 8.6-10.0 15-35 15-35 50-100' 5-15 15-40 10-12 9-10 10% _+ Drill out to weight up 8.6-9.3 5-15 5-8 30-40 2-4 4-8 8-10 8.5-9 4-7% Drilling Fluid System: Tandem B~andt Shale Shakers Tandem Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuge, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 10.5 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 <10-12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2457 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3,000 psi. The nearest well to 1 R-24 is 1 R-25. As designed, the minimum distance between the two wells would be 60' @ Surface. The wells would diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or Kuparuk Field well with open annulus used for disposal. *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds. A CO A ASXA Structure ' Pad 1R Well ' 24 Field · Kuparuk River Unit Location · North Slope, Alaska SURFACE LOCATION: 94' FNL, 139' FWL SEC. 20, T12N, RIOE Scale J ' 500.00 E a st > 600 0 600 1200 18E~924-003000 5600 4-200~800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 I I I I I t I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I -1800 TARGET LOCATION:i¢7T,D LOCATION: ] 600 I [ FSL. 280' FELl 1350' FSL, 1065' FEL LSE¢. 16, T12N, RIOEJ SEC. 16, T12N, RIOE TARGET ~VD=6578 TMD=12063 - 600 DEP=9467 NORTH 1444 EAST 9356 N 81 DE(]; 14- MINE 9467' (TO TARGET) Go 60o (J o3 1200- (...- ~J I-- I ~ 5400 Created by : rickb For: E FITZPATRICK IDate plotted : 5-Jul-91 RK8 ELEVATION: 88' Plot Reference is 24 Version J KOP TVD-500 TMD-300 DEP-O ICoordinates are in feet reference slot t24. ~ 2.50 - - - ti-rue Vertical Depths are reference wellhead. \ % / i-]/~)~ E A S T M A N ~ ,;.50 Bu,,o 2.~ oEc /,00, ! !ZgJIICHRISTENSEN 37.5o B/ PERMAFROST TVD=1663 TMD=1760 OEP=449 EOC TVD=2557 TMD=2809 DEP=1242 T/ UGNU SNDS TVD=2813 TMD=3848 DEP=2165 T/ W SAK SNDS TVD=546B TMD=5277 DEP=3435 ~ B/ W SAK SNDS ~/D:3973 TMD=6379 DEP:4414 g AVLRAGE .............. ANGLE "%"'~"~ 9 5/8" CASING PT ~/D=¢150 TMD=6765 OEP=C758 A~V_L~A~I- AIN(~Lb_ '~ ~-1o TVD:42~a T,D=7066 DEP:5025 62 DEG 4-5 MIN d U L Alaska Oil & Gas 6ons. ~-~ TV°=~'--i~°='°3~3 °~:79~~ ~ Anchorage B/ KUP SND$ T~D=6991 TMD=12964 DEP=I0268 .... TD / LOGGING PT TVD=7083 TMD=13164 DEP=10446 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 600 0 600 1200 1800 2:4005000 5600 4200 ~00 54~X36000 6500 7200 7800 ~400 9000 9600 10200 10800 Scele 1 ' .300.00 VerficolSection on 81.23 ~zimufh wifh reference 0.00 N, 0.00 E from slof#24 OSt~ - OOt~ ' 0S£ 1 0~ Ooz i' OOt ' OS' 0O9 I OSS OOS os~ OOg OOS OOt, 0S£ 00£ 0S8 oo~ OSt O0 t I os~ os i. 00~ - OS~ - ' os£ - oo£ - osZ - ooz ' OS l~ - 001 . . . , . . , . , 10. 11. 12. 13. 14. 15. 16. 17. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1R-24 Move in and rig up Pool Rig 7. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (6,765') according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2,000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole logging while drilling to total depth (13,164') according to directional plan. Run and cement 7" casing. Pressure test to 3,500 psi. ND BOPE and install lower production tree assembly. Secure well and release drilling rig. Run cased hole cement evaluation and gyro logs. Move in and rig up Nordic Rig 1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. 7 6 5 4 13 5/8" 5000 [ ..,,I BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECKAND FILLACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3(X)O PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTORAND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE Bo'FrOM PIPE RAMS. TEST Bo'I-I'OM RAMS TO 250 PSI AND 3(X)O PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE ELOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/'8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8"-5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5(X)O PSI ANNULAR JUL ,al~si~a 0i! &. ~s 6o~s. 6o~nmissio~'~ ,~,nchoraDs ,~.JPARUK RIVER UNI', 20" DIVERTER SCHEMATIC 5 6 I 5 4 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION 3 2 UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD At~.st,~:~t 3. FMC DIVERTER ASSEMBLY WITH ~O 2-1/16"- 2~0 PSI BALL VALVES 4. 20"- ~00 PSI DRILLING SPOOL WITH ~O 1¢ CUTLAS. 5. 1fi' HCR BALL VALVES WI~ 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTO~TICALLY UPON CLOSURE OF ANNU~R PREVE~ER. VALVES CAN BE RE~TELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION - 6. 2¢ - ~00 PSI ANNU~R PREVENTER SRE 2/6/90 ARCO ALASKA, INli:. 1 R-24 KiUPARUK NORTH SLOPE JULY 1991 VERTICAL SEF:TION DIF.:ECTION: MAGNETIC COF.'.REF:TION APPLIED: ALASKA MAGNETIC DIP: MAGNETIC FIELD STF.:ENGTH: SPERRY-SUN DF.'. ILL INIB SERV ICES, I NF:. RECORD OF SURVEY MEASURED ANGLE D I RECT I ON VERT I C:AL LAT I TUDE DEPARTURE VERT I CAL DEPTH DEG DEG DEPTH FEET FEET SECT I ON SURVEYS 0.00 N81,2E 80.50 0. 573 CALCULATED USINIB TIE-ON DATA FF.'.OM: EASTMAN CHRISTENSEN 0.C) 0.00 0.00 N 0.00 E 0.(")0 DOG LEG 220.00 0.20 88.0 220.00 C).01 N 0.38 E 0.38 38C).00 4.30 69.C) ' 379'84 1.26 N 6.51 E 6.63 566.00 11.90 71.9 563.85 10.02 N 31. 19 E 32.35 ~=(')/~..00 18.(:)(]) 8(:).8 741.54 -'.~'1.20. N 77.24 E 7'9.58 931.00 24. 10 83.4 91C).38 30. 13 N 141.60 E 144.55 1125.0C) 28.6(:) 81.6 1(')84. 18 41.3'9 N 226.95 E '.730.61 13(])4 .... O0 27 t3 81.7 1242.41 53.58 N ~(.~')'-~.73 E 314.28 1486.00 26.30 83.6 1404.98 64.09 N 390.87 E 396.07 1672.C)0 28.44 79.2 157(]). 15 76.94 N 475.38 E 481.56 1854.o0 31.94 81.3 1727.44 92.5(]) N 565.55 E 573. (:)4 '7037.00 43.90 80.2 1871.54 110.54 N 676.35 E 685.30 2225. C)0 49.35 81.7 2(:)(])(:). 6(:) 132. (])4 N 811.25 E 821.90 '-~ (' ~ · mm m~ · .'4.)~.00 54 76 7'9 8 2111 24 154 89 N 951.2'9 E 963.79 2675.00 61.43 83.5 2253.86 188.2(:) N 1177.90 E 1192.82 2863.00 62.27 84.0 2342.56 2(])6.23 N 1342.67 E 1358.42 ~.,~1 cZ)(:) 64. 17 84 9 2427 25 222.44 N 1509.72 E 1'525.97 3237.00 65. 12 8(:).4 25(:)6.89 243.95 N 1676.38 E 16'93. 3408 00 63 75 81 7 '~'~ . . . ..'~8L.6'9 267.86 N 1828.76 E 1848.21 36(:)8.00 61.93 83.9 2671.99 290. 13 N '.-'.'C)05.29 E 2(:)26. (:)7 3794.(')0 61. 18 84.4 2760.59 306.84 N 2167.97 E 2189.39 '-"~¢' 00 E 2352 58 3980.0C) 61.59 81.5 2849.67 326.90 N ,~ .... 4164.0C) 62.0C) 7'9.6 2936.63 353.48 N 2489.95 E 2514.72 4440.C)0 61.2'9 82.5 3067.72 391.25 N 272'9.85 E 2757.58 4626.00 65.58 79.5 315(').87 417.37 N 2894.~10 E 2'923.88 ~'-'~¢) 5(:) 445 99 N 3063 09 E ~0'-'~ 4815. C)0 64.58 81 . 3 o..'~ ...... o. ~ 26 5000 C)0 60 47 80 9 o~15 84 471 30 N ~'-"-'~ 22 E o...-~'-'~-d. 36 5276.00 59.70 79.6 3453.4'3 511.73 N 3461. (:)cZ) E 34'98.54 5464. (}0 61.23 81.9 3546. 16 538. (:)3 N 3622.42 E 3662.09 5747.00 60.69 83.3 3683.54 56'9.87 N 3867.78 E 3'9(])'9.43 6(])28.00 65.21 83.2 3811.32 598.'96 N 4116.27 E 415'9.45 6215.00 63.39 85.8 3892.41 615.(:)3 N 4283.98 E 4327.64 64(:)(]). 00 62.71 81.3 3'376.26 633.56 N 4447.7'9 E 4492.36 6675.0C) 62.(:)2 81.5 41(:)3.82 669.95 N 4688.68 E 4735.98 0.09 '2. 5 ,-7 · .~. C,,E.-~ 3.53 3.41 2.36 0.82 0.65 2.01 6.55 '2.73 0.52 I. 09 2.22 1.08 1.31 0.47 1 3~ 0.92 0.94 2.73 1.04 2,23 0.50 1 . 34 0.48 1 .E,t 1.58 · ]' '5"? 0.26 I]:ommen t s: CALCULATIONS BASED ON THE RADIUS OF CURVATURE METHOD HORIZONTAL DISPLACEMENT AT 6675.(]) MEASURED DEPTH IS 4736.3 AT N81 DEG 52 MINE PROJECTED DISPLACEMENTS BASED ON 6753.1 MEASURED DEPTH: AT 414(]).4 TRUE VERTICAL DEPTH, 48(])5.2 DISPLACEMENT, AT N81 DEG 52 MINE SURVEYS MEASURED FROM DRILL FLOOR ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE { 1). Fee //Z~r% ?//~//'~/ 1. [2 thru8] 3. 4. 8. [23 thru 28] 'C29-th~6 3i] (6) Other (6) Addl Company Lease g Well Is permit fee attached ............................................... YES NO - RE~-~4RKS ' ' . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. Is well to be located in a defined pool ............................... Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... Is sufficient undedicated acreage available in this pool ............. Is well to be deviated & is wellbore plat included ................... Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease n~nber appropriate .......................................... Does well have a unique name & nLrnber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~o~o psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Additional requirements ............................................. /I///~ / , t ./ 0 -.4 'rZ '--'~ 0 (.nil geo 1 ogy' eng i nee r i ng.:~.~, DWJ ~ MTM//~ LCS-/'(..7'~"' RPC~ BEW.~ P~ dH ~ rev 03/29/91 jo/6.011 INITIAL GEO1 UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Additional remarks' Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX.. No special 'effort has been made to chronologically organize this category of information. , ALASKA COMPUTIMG CEMTER * , * · ****************************** ****************************** CORRECTED COPY MEbL NAMM : IR-24 FIELD NA~E : KUPARUK RIVER &PI NURSER ~ 50-029-~194 REFERENCE NO ~ 92026 RECEIVED FEB 2 5 1992 Alask~ Oil & Ges Cons. ~mml#lon 0 :NOI%VASq2 ** ******************************************************************************* ******************************************************************************* : MqIA &g~q $gt~01~6 : A.L~G 90V[O0 : NOI~a3A Olq~ ; NIDiaO IgtlO/g6 : ~,L~O £I03 : ~a ADIA~9 ****************************************************************************** LL · L~£ LL ~ 88'g O~ :A&ISOOSIA ESL9'.]O H£d::iCl ~;/iq']I~lq ?) ~q 9[~ ,,8/S 6 : D,':lgVD 16-'lflP-O[ :Q3DDO'i 2NOZ so~stA ptnt~ 6ultlI~o ~lsuao plo'[~ IeA~a~Ul ~o~ ao£ ~elIt~O - q%daO te~o~ ~aqmnN ~aP~O epn~Tbuoq uoT~eN aoulno~8 ~o A~uDoo UOl~gOo~ PTeTJ ~qmna lella~ 'LL ' (.)~ 9*O't 'E~L9 ~L6~ 0 oa ~M ~6El i qaJ ~6 ~HU EJ I NIdV E :3D~d ****************************************************************************** ,9~8gi OZ ,,E~L9 I~ISN30/NO~iJ.,f1[,iN DNiqqlMo 3'IIH~ Di,ilDDOq .606gi 0% ,CSL9 aD/X£IAIAS1S:~a DNIqqI~tO :~qlHa DqlDDOq Gaq' SON 0t:~'"666- Q~'aOdO 0§a'666- Q~q'l~q~ 0q~'660- da~'qVD~ ' 6- q ' ' ' ' 0f~,666- Qaq ~OdO 0~g'666- O~'IHdfl 0~'66b- Oaq'q~Do 0fl666- a~'oaafl 0~'666- OMg'~O~ia 0~'666- O~q'gSOa 00o'008~I 0~E'666- daq'ad~£ 0~'666= Oaq',d3d ooo'oo6a/ '~daO OOi'CL6~i 000000 O0 89 9 '[ 0 O0 0 O0 l 0000000000 89 9 I I I 0 O0 000 O0 0000000000 89 ~ i I I 0 O0 000 O0 0000000000 89 ~ I ¥ ; 0 O0 000 O0 0000000000 89 ~ I '~ 0 O0 000 O0 0000000000 B9 9 ~ I 0 O0 000 O0 0000000000 B9 ~ I I I 0 O0 000 O0 0000000000 89 ~ i I I 0 O0 000 O0 0000000000 89 ~ I I I 0 O0 000 O0 0000000000 89 ~ I I I 0 O0 000 O0 0000000000 89 ~ I I I 0 O0 000 O0 0000000000 89 ~ I ; ; 0 O0 000 O0 0000000000 89 ~ T I I 0 O0 000 O0 0000000000 89 ~ I t T 0 O0 000 0 ~MOOMd MdMM 3ZI~ fi~fla ~NflN 3'IIM Id l~TS~ ** N~HD - 3d% 8i~S IdYD qb~i S ~aHO (lgq S ~HO O~'l ~ ED/D O~'l § EOt~ a~q 0 0 99 0 I 99 9t 89 99 9 ........... 5 55 ............... :3DVd buTlSt'l uo~leol~t'taaA oci~ 006'6~ 988'~ 00~'0~ 8~°0 LO0 ° 0 L98~I /..~0 0 [se,,0 oo~ I:~:o.o O0 LO0*O 999'[ 008' ~00'0' 060'~ ~0'0 000.0t £~0 006~0~ £00 o- ~£9°~ O0£'L~ ~00'0 9E8'50 Q~q'dD O~8'PL Ogq'OH~Q 89~'g O~q'~da~ sqg'g Oaq'g90~ O00'o<)qgt o~q'SOdO 006'0I G~q'lHdO g~o'[ O~q'q~oQ 8§~'[ ~a~q'a~d oMq'oH~o Oi~'g O~q'~OHa OL~'g Q~q'gwr3B O00'otiggI 'zd3(i ~E:LO L66I-aVD-[Z bul:'4$T'l uo]::leJi.~l.Ioa ac~e.h Tame Verification [,istinq 5cblumt, erqer ~!asKa Comp%Iti~q Center 07:24 PAGEt 11400.000 ROB2.LWD 44,800 ATR.LWD 14a.413 GR.LWD DF'PT. 11200.000 RLIS2. LWD FE~ LWD 3,337 DCAL.LWD TF~PN ~ I. WD 34. 700 ATR. LwD DFPT, 11100,000 ROS2,LWD PEW. LWD 3. 455 DCAh. LWD TNpN, [.,~,~D 36. 600 ATR, LWD ~C~', Lt~D 197,638 CR. bWD DFPT% I ~ On0. 000 ROS2. LWD PEF.bfD 2.908 DCAL,LWD TNP~.[.,WD 3~ .000 AT~.L, WD R r') pF, I., ::,~ P 234,000 GR, LWD D~iPT. 10900.000 ROS2.LWD PE~ LW'D 3.254 DCA[,. LWD T~PP ' LW'D 36'500 ATR LWD ROPF. LW~ 142.3~9 GR. LWD O~PT. 10800.000 ROS2,LWD PEF,LWD 3,270 DCAb. I, W9 TMP}i,I. WD 3ti.700 ATR.LWD POP~.b~'P 2¢12,907 GR.LWD DFipT. i07o0,000 ROS~.I, WD PEF,LWD 3,306 DCAI,.t, WD T~PM.LWD 32,200 ATR.bWD ROPE.LWD 276.964 GR.LWD D~PT. 10600,000 R(.iS2.LWD PEF.L{D 2.8R0 DCAb. DWD T~PF~.[,~I) 34.600 AT~.LWD ROPF.L~P 2q2.0!6 GR.i,WD 14 22 2.381 RHOB.bWD 1.423 I~PHI.L, WD 2.640 PSR.LWD. 9.909 2.315 R}!O8.b~D 1.342 PPgI.bWO 2.503 PSR,I,~D 5.919 2.383 0.088 OPHI,bWP 2.206 PSR.bwD 7.827 2.46~ RHOB.LWD 0.197 DPMI.bND 1.~9! PSR,LWO 0,123 2.472 RHOB.LWD 0,~12 DPHI.bwD 2, 50 2,810 2.444 RHOB.BWD 0,459 DPMI.bWO 2,656 PSR, PWD 84.486 2. 456 RHOB. hWD 0 2~4 DPHI,LWD 2~3~,3 PSR,DWD 86,~6~ 2.504 RNOB,LWD 0.266 DPHI.LWD 2,264 ~ 8R,LWD 75.298 2.471 RNOB,LWD 0,160 OPHI.bWD 2,152 PSR.I, WD 7~,464 2.448 RltOB.bWD 0.127 D~HI.LMD 2.350 PSR.L~D 82.685 2.408 PHOB.LWD 0,099 DPHI.LWD 2.473 t:'SR.LWD 87.749 2.381 23,600 3.093 2.315 27.600 3.252 2.383 23.500 3.456 2.461 18.700 1.429 2.472 18,100 2.230 2.444 19.800 2.588 2.456 19.000 2.776 2.504 16.100 2.396 2.471 18.t00 2.539 2.448 ~9.500 2.618 2.408 900 21'632 . DRHO,LWD DPOR,LWD DER.LWD DRMO.LWD DPOR.LWD DER.LWD DRMO.LWD DPGR.LWD DER.LWD DRHO.LWD DPOR LWD DRMO LWD DPORiLWD DER LWD DRHO LWD DPOR]LWD DER.bWD DRHO.LWD DPOR,LWD DER,LWD DRMO.LWD DPOR LWD DER~LWD DRMO.LWD DPOR,LWD DER.LWD DRHO LWD DPOR:LWD DER,LWD DRHO.LWD DPOR,LWD DER.LWD 0 001 23:600 2.901 0.014 27,600 2,887 0,004 23,500 2,729 0013 18:700 1,453 0,007 1~,100 .272 0 033 2,612 .003~2,603 ,000 01,008 16'I00 2, 43 -0. 002 1~,: 63 0. 5O5 ~0,002 1.900 2.569 O06'Lt (l~'l~UOd(t 006 £1 900*0 Ot~q OH~Cl ~L~ g ttL,8 O~q ~20 9~L E OOE ~ OMq'8OdQ SO0'O oMq'oHs~ Lg~'g qgq'IHdO Ogq'8OH8 O00'tI OMq'BOdq O00'EI ~IO'O o~q'oHsq 9§§'~ 006 9I Ogq'~OdO 006'9I ~00'0- ogq'OHSO t99![ o~q'a3O E96'[ 008 9[ Ogq'8Od(] 008'9I 000 0 ogq'OH~O £6b*[ ~tqq ' 89d EL[*O fi~q'q~ao ~LO*E ~Lg'~ <liqq'~SO~ 000'~)096 6Z9'68 o~q'~D EOq'5;8 (tgq'Ad08 g9g*O o~q'q'~DO 88~'E ~'l'ASa Lg~'Z o~q'ggO8 OOO'OOL6 '&dg~ 6LL'P6 o~q'sD S90'6§1 £gg'o o~q'q~DCi OL~*E O~q'A~d ~L~'g o~q*&SO~ 000'0086 000'0 (}~q'q~DO :~L~'E ~6£'g Oa'l'g90~ O00'OOIO[ OLg'O ~q'q~D(] 900'£ gg~'g O~']'~SOa 00(')*00~0[ 'idAO £80'L6 O~'t'SD LLg'ggg ~6~'0 O~q'qVDO LO~'£ 9SS'g ~S'l'ggOd O00'O0£Ot 8 laded £0~*£ 00~*~ ~0'0 6£~*£ O0l'*gB ttO'O' 686'~ 00~'0~ ~00'0' 00'0 09I~£ 006 8~ 900°0 ! 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B000,OO0 ROS2.LWD PEF.!..wD 3,178 DCAL.bWD TN~N I, WD 36,400 AT~.bWD ~O[,~LWO 130,744 G~,bwD DFPT. 7900,000 ROS2.LWD PEF.LND 3.211 DCAb. LWD T~P~,I.,,WD 45,200 ATR.LWD ROPF,I,~9 158,160 GR,LWD P~PT. 7800,000 ~EF,L~D 3.324 T~P)~,L. wD 39.000 ROpF,LWD !49.954 OF:pT. 770{), O00 PEF. [,wU 3. 221 T[~PH, LWD 43,300 POPE'., bwD 280,388 ~FPT. 7600,000 PEF. LWD 3,020 T~,~P~. LwD 41,. 700 ReP~, L%;D i8~ 449 ROS2. 9CAL. ATR, G~. LWD LWD 15 W D 2.419 RHOB.bWD 0.166 9PHI.DWO 3.196 pSR,LWD 8~.9i5 2.403 RHOB.bWD 0.224 PPHi. LWD 2.675 PSR.L~D 74.323 2,41,3 RHOB.LWD 0.184 DPHI,LWO 2.730 PSR,bWD 73.587 2.508 RHOB,bWD 0 246 DPHI,LWD 3:730 PSR,DWD 82.316 2,494 RNOB,LWO 0.336 DPHI,LWD 2,498 RHOB.bWD 0,947 OP}tI,bWD 5,074 PSR,LWD 73.407 2,459 RHOS,LWD i,231 DPHI,LWD 3,J63 PSR,LWD 86.551 2.296 R~OB,LWD 0.31t DPH!,LWD 3.536 PSR,LWD 76.960 2.41.9 21.300 3.330 2.403 22.200 2.770 2.413 21.600 2.797 2 508 15:900 4'733 2.494 16.700 3.473 2.498 1.6 500 7:281 2.459 18,900 3.239 2.296 28,700 3.453 DFTpT 7500 000 ROS2.LWD 2,4i3 RMOB,LWD 2.4!3 '~F'L~D 2'934 DCAL.IWD 0.854 DPHI,:[.,~w[) 21 600 TN~F~iLWO ]g:.~O0 ~TR.LWD 3.718 PSR.LWO 32678 ROP~.L~D 228,850 GR. LWD 82,678 [':>~T. 7400,000 ROS2.LwD 2.354 RHOS,LWO 2.354 v~w.l, WP 2.823 DCAL.LWD 1,1.29 DPH!,LWO 25.200 ?'%PH.L~D 43.000 ~TR.LWD 3.403 PSR,LWD 3.385 ROP~.LWD 349.158 GR.LWD 80.876 [3FiPT. 7300,000 R~$2.LWD 2,4:64 RMOB.I:WO 2.464 PEF', L~ 3.296 t~CAL,, LWP 0.667 DP~I,bWO 18 500 T' ~ PW. [,~,,~D 43.500 ~.TR.LWD 3.474 PS~.bWD 3:392 a OPF:. 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