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193-196
XHVZE Pages NOT Scanned in this Well History File 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. ~'~ ~ '" I~ ~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: scanned bY: Beverly~Vincent TO RE-SCAN Nathan Lowell Date: 'I~ ...~' Isl~.~ Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: /si oN oR BEFORE PLUGG!N= & LOCATION REPORT PERMIT DATA AOGCC indlv±dual Well Geological Materials Inventory 93 196 e-z-LWD 93 196 CDR- ~,..D CDR-VER/LWD DATA_PLUS 93-196 6112 ~151-10888, OH-CDR/CDN ~i0-i0890 ~'"~ lOiO0-10820 Page- Date- RUN 1 10/13/'95 DATE_RECVD o5/o9/94 o5/o9/94 o5/o9/9~ Are dry dinch samples required? yes ~And received.?-~--Fa~s---ne~ ...... ~ .-,,:~vsis & description receiv~a----_y_e~__~no Was the well cored? i'~.~ ~ .... _ Are well tests required? ~es ~Receive~ Well is in compliance ini t 5 ai COMMENTS ARCO Alaska, Inc. Date: May 06, 1994 Transmittal #: 9078 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. Please acknowledge receipt and return one signed copy of this transmittal. ,/3H-25 < H-25 - %3H-25 ,/3H-31 ~'~(~ ~,, 3H-3! ',.3H-31 (H-23 H-23 H-23 "--_ \ 3M-23 c~..-j~3¢ ~ 3M-23 ------~3M-23 ~-_ /3M-26 -~'/ .~ \ 3M-26 H-26 ~/'3M-24 ~,-'tq5~,,.3M-24 ~/ 3M-24 /3M-25 ~-~,--[q (~ 3M-25 %3M-25 ¢CDR '/CDN ¢CDR Very-Enhanced l~esistivity ¢CDR ¢'CDN ~' CDR Very-Enhanced Resistivity './'CDR DR Very-Enhanced Resistivity ¢13DR ,/CDN ,,,CDR Very-Enhanced Resistivity ,,'CDR ¢'CDN ,.'CDR Very-Enhanced Resistivity v'~NT-G v"CDR ,/'CDN '"'CDR Very-Enhanced Resistivity .¢0 DN ,/'CDR Very-Enhanced Resistivity 2E-17 ,./CNT-G . Acknowledged: _/~ 02-22-25-94 02-22-25-94 02-22-25-94 02-9-12-94 02-9-12-94 02-9-12-94 02-16-18-94 02-16-18-94 02-16-18-94 12-21-28-93 12-21-28-93 12-21-28-93 01-13-16-94 01-13-16-94 01-13-16-94 04-28-94 01-20-25-94 01-20-25-94 01-20-25-94 01-2-5-94 01-2-5-94 01-2-5-94 4-22-94 Date: DISTRIBUTION- 4650-12414 4650-12414 11800-12300 4950-10734 4950-10734 10100-10700 4080-9358 4080-9364 8795-9296 5350-12740 5320-12740 11750-12740 4282-9625 4750-9620 4282-9625 6090-6450 5200-12490 5170-12480 11600-12480 5050-10890 50151-10888 1010O-10820 8700-10000 -.% ARCO Alaska, Inc. Date: May 06, 1994 Transmittal #: 9079 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. and return one s_ig.ned copy of thins transmittal. 3H-31 /LIS Tape and Listing: 04--25-94 · '" LWD CDR/CDN 1 Bit Run 3H-25 LIS Tape and Listing: - 04-27-94 '/"L. WD CDR/CDN 1 Bit Run 3H-23 LIS Tape and Listing: 04-25-94 ¢' LWD CDR/CDN 1 Bit Run 3M-23 LIS Tape and Listing: 04-22-94 '/"CDR/CDN-4 Bit Run with QRO Processing 3M-26 ,LIS Tape and Listing: 04-27-94 ¢CDR/CDN-4 Bit Run with QRO Processing 2E-17 LIS Tape and Listing: 05-03-94 "'"2 Pass CNTG Cased Hole Edit 3M-25 ./,LIS Tape and Listing: _...., "Run with QRO Processina Receipt Acknowledged: _:,~, Please acknowledge receipt 94066 94083 94075 94018 94O23 94102 05-02-94 94027 uaie: DISTRIBUTION' Bob Ocanas State of Alaska STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM,,_,SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL ~] GAS [~ SUSPENDED [~ ABANDONED r~ SERVICE [] 2 Name of Operator ARCO Alaska, Inc 3 Address P.O. Box 100360, Anchora~le, AK 99510-0360 4 Location of well at surface 962' FNL, 1602' FEL, SEC 25, T 13N, R SE, UM At Top Producing Interval At Total Depth 2000' FNL, 2038' FWL, SEC 23, T13N, R8E, UM 5 Elevation in feet (indicate KB, DF, etc.) RKB 68', PAD 27' GL 12 Date Spudded 30-Dec-93 17 Total Depth (MD+TVD) 10888' MD, 6351' TVD 7 Permit Number Permit Nc.g3-196 & SA NO 93-004 8 APl Number 50-029-22433 9 Unit or Lease Name KUPARUK RIVER 10 Well Number 3M-25 1 Field and Pool KUPARUK RIVER 6 Lease Designation and Serial No. ADL25522 ALK2558 [13DateT. D. Reached.. ~-114 DateC~,Susp. orAband. I 15 Water Depth, ifoffshorej 16 Nc. of Completions 05-Jan.-¢3' ~':'I¢ 01/06/~',',~p& A)CIP 1151 HRS I NA feet MSLI NA 18 Plug Back Depth (MD+TVD) 19 Directional~Survey ~ 20 Depth where SSSV set 21 Thickness of permafrost 5181'MD, 3396'TVD, KOP@5250' YES IXIMWD NO IXI NA feetMD 1700'APPROX 22 Type Electric or Other Logs Run CDR/CDN/GR 23 CASING SIZE w-r 16" 62.5# CASING, LINER AND CEMENTING RECORD HOLE SIZE CEIVENT RECOF~ I SETTING DEPTH MD GRADE TOP BTM H-40 SURF 121' L-80/J-55 SURF 5150' 24" 25O SX ASI CMT 9.625" 47#/36# 12.25" 1000 SX ASIII, 550 SX G 24 Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) NONE 25 TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) NONE 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10405'-10880' 2OO SX CLASS G CMT PLUG(Tagged) 5181 '-5434' 140 SX CLASS G CMT PLUG Cragged', 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I FlowDate of Test Hours Testedii'TEST IPRODUCTION FOR OIL-BBL IGAS-MCF PERIOD ~ WATER_BBL i CHOKE SiZE i GAS.OiL RATIOI Tubing Casing Pressure ICALCULATED OIL-BBL GAS-MCF WATER-BBL lOlL GRAVITY-APl (corr) Press. 124-HOUR RAT[: I~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NA RECEIVED ~:E~B-"i 1994 A.~.ska Oii & Gas Cons. Commission Anchorage Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE S~DE 29. 30. G~OLO~IC MA~ FOFff-JATION TESTS , NAME Include interval tested, pressure data, all fluids recovered and gravity, 'i MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. I NA NA I 13. /IS-I- OF ^-FI-^CHM[NTS 32. REPORI OF OFISR^IIONS, F' & ^ SCH[M~I1C, 2 COPI[S OF DIRECI1ON~J_ SURVEY I hereby certify fha! the ~oregoing is true and correct to lhe best of my knowlege. , / . 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 KUPARUK RIVER UNIT WELL #3M-25 WELLBORE DIAGRAM 16" CONDUCTOR AT 121' CEMENTED TO SURFACE 9-5/8", 36#, J55 & 47#. W/SHOE AT 5150' Cemented with 1000 sx AS III and 550 sx Class G to surface L80 Kick Off Point: @ 5250' Cement plug for kick off: 140 sx Class G 5434' 5181' (Tagged 01/06/94) Top Kuparuk: 10,570' Base Kuparuk: +10,700' ARCO Alaska, Inc. KRU 3M-25 .,...,...,...,...,...,...,...,...,...,...,. .!.:.!.Li.:.L;.;.:.!.:.!.:.L:.i.;.L:.~. 11.5 PPG :i:iJ 8-1/2" OPEN HOLE ~ 15.8 PPG id Cement i}] lO,88o' TD = 10,888' Cement Plug: 15.8 ppg, Class G - 10,405' (200 sx) SDB, 1/94 ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 3M-25 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER ADL 25522 ALK 2558 50-029-22433 93-196 ACCEPT: 12/29/93 11:30 SPUD: 12/30/93 07:00 RELEASE: OPERATION: P & A DRLG RIG: PARKER 245 WO/C RIG: 12/30/93 (1) PARKER 245 TD: 121' ( 121) 12/31/93 (2) PARKER 245 TD: 1760'(1639) 01/01/94 ( 3) PARKER 245 TD: 4846' (3086) 01/02/94 (4) PARKER 245 TD: 5170' ( 324) 01/03/94 (5) PARKER 245 TD: 7300' (2130) 01/04/94 (6) PARKER 245 TD:10328' (3028) PU BHA 7"@ 8892' MW: 8.6 VIS: 54 MOVE RIG F/3M-23 TO 3M-25. PROBLEMS W/#2 TRACKING MOTOR. NU 20" DIVERTER & INSTALL DIVERTER LINES. FUNCITON TEST DIVERTER & ACCUM. JOHN SPAULDING W/AOGCC WAIVED WITNESSING TEST. MU BHA #1. DRILLING 7"@ 8892' MW:10.0 VIS: 66 FIN PU BHA & TIH. DRILL 12.25" HOLE F/121'-469' POOH. MWD FAILURE. LD MWD TOOL & DRESS NEW TOOL. MU NEW MWD TOOL-ORIENT & TIH. SERV RIG. ATTEMPT MWD SURV. TOOL FAILURE. CHECK SURF EQUIP-OK. POOH. LD MWD COLLAR. UNLOAD BAD 8" MWD COLLAR & UNLOAD GOOD 7" MWD COLLAR. RELOAD. MU MWD & TEST SAME. RIH. MWD & GYRO SURV. DRILL 12.25" HOLE F/469'-1760'. DRILLING 7"@ 8892' MW:10.0 VIS: 48 DRILL 12.25" HOLE F/1760'-2880'. CBU. POOH TO HWDP. TIGHT F/2020'-1810'. SERV RIG & TOP DRIVE. RIH. WASH 90' TO BTM-NO FILL. DRILL F/2880'-3442'. CHANGE OUT FROZEN AIR LINES ON TOP DRIVE. DRILL F/3442'-4846' ND DIVERTER 7"@ 8892' MW:10.1 VIS: 40 DRILL F/4846'-5170'. CBU. SHORT TRIP. TIGHT. TIH. WASH THROUGH BRIDGE. CIRC & COND MUD. POOH TO RUN 9-5/8" CSG. RU CSG EQUIP, HOLD SAFETY MEETING. RUN 9-5/8" CSG-TOTAL OF 60 JTS 47# L-80 & 63 JTS 36# J-55. CMT W/1000 SX ASIII 12.1 PPG & 550 SX CLASS G 15.8 PPG CMT. BMP PLUG, FLOATS HELD.. CIP @ 0500 HRS 01/02/94. ND DIVERTER. DRILLING 7"@ 8892' MW: 8.7 VIS: 33 FIN ND DIVERTER & LD LANDING JT. INSTALL 11-3/4" BTC X 11" 3M BRADENHEAD. NU BOPE & TEST TO 300/3000 PSI. JERRY SPAULDING W/AOGCC WAIVED WITNESSING. MU BHA #2, PROGRAM & ORIENT TOOLS, INSTALL RA SOURCE. TIH. TAG' FC @ 5070'. TEST CSG TO 2000 PSI-OK. DRILL FC, CMT, FS & 10' NEW FORM TO 5180' CBU. RUN LOT, EMW=12.6 PPG. DRILL 8.5" HOLE F/5180'-%300' DRILLING 7"@ 8892' MW:ll.0 VIS: 38 DRILL 8.5" HOLE F/7300'-10328' INCREASE MUD WT SLOWLY TO 11.5 PPG. SLOWED PMP RATE TO ~24 GPM-NO MUD LOSS. WELL: 3M-25 API: 50-029-22433 PERMIT: 93-196 PAGE: 2 01/05/94 (7) PARKER 245 TD:10888' ( 560) 01/06/94 (8) PARKER 245 TD:10888' ( 0) 01/07/94 ( 9) PARKER 245 TD: 5250'( 0) P & A Complete 3M-25 SIDE_T. RAC. M _TO 3M- ? KA POOH F/LWD DATA 7"@ 8892' MW:ll.5 VIS: 44 DRILL 8.5" HOLE F/10328'-10421'. SURV W/MWD, LOG W/LWD -- PMP PILL & SHORT TRIP TO SHOE @ 5150'. NO PROBLEMS. SERV TOP DRIVE WHILE FILLING PIPE. CONT IN HOLE. PRECAUTIONARY REAM 90' TO BTM. NO FILL. DRILL 8.5" HOLE F/10421'-10815'. SURV W/MWD, LOG W/LWD. CIRC. ANCHORAGE GOELOGY DETERMINED WE NEEDED TO DRILL DEEPER. DRILL 8.5" HOLE F/10815'-10888'. SURV W/MWD, LOG W/LWD. CBU. POOH TO CHECK RECORDED LWD DATA. WOC 7"@ 8892' MW:ll.5 VIS: 44 POOH. DOWNLOAD LWD. REMOVE RA SOURCE & LD SAME. CHANGE OUT DRILL LINE SPOOLS WHILE WOO. RIH W/OEDP TO 10880'. MU CMT HEAD & CIRC. LAY BALANCED PLUG W/5" OEDP HUNG @ 10880'. MIXED & PMP 200 SX CLASS G CMT. TESTED LINES TO 2000 PSI. PMP 20 BBLS WATER FOLLOWED BY 40.7 BBLS CMT, DISPLACED WATER, DROPPED 5" DP WIPER PLUG. DISPLACED W/172 BBLS 11.5 PPG MUD. CALC TOC @ 10300'. CIP @ 2151 HOURS 01/05/94. PULL UP TO 9770'. CIRC & WOC. WOC 7"@ 8892' MW: 8.7 VIS: 31 RIH W/OEDP, TAG & P&A PLUG @ 10405' W/25K. WITNESSED & APPROVED BY LOU GRIMALDI W/AOGCC. PULL UP TO 5808' SPOT 30 BBL HI-VIS PILL. PULL UP TO 5434'. CBU. RU DO'ELL. LAY BALANCED KICK OFF PLUG W/5" OEDP HUNG AT 5434'. MIXED & PUMPED 140 SX G CMT @ 17 PPG. PUMPED 20 BBLS WATER. TEST LINES TO 2000 PSI. PMP 25 BBLS CMT. DISPLACED W/8 BBLS WATER & 81 BBLS MUD. CIP @ 1151 HRS 01/06/94. CMT WAS BATCH MIXED. PULL UP TO 5059'. REVERSE OUT DP. POOH. CHANGE OIL IN TOP DRIVE WHILE WOC. MU BHA #3. RIH TO 5160'. CALC TOC @ 5100'. CIRC & REDUCE MUD WT TO 8.7 PPG & WOC. RIH, TAG SOFT CMT @ 5181'. POLISH CMT F/5181'-0'. DRILLED @ 60b'/HR TO 5207' POLISH CMT T/5228' W/5K & 50 SPM. NO ROTARY. DRILLED ~ 350'/HR. CBU & PULL TO SHOE. WOC. POLISH CMT F/5228'-5250'_ STARTED W/5K & 70 RPM, THEN FELL THROUGH. DRILL 350'-600' FPH. PLUG. PLUG WILL NOT SUPPORT MORE THAN 20K @ THIS TIME. ._ _ SIGNATURE: (drilli~uperlnte~nt) _- - ,~V/5L PAGE ::::::**** SCHU. MBB~:GBR ********** ----**************--***--************* AZI?~_,~H PROM R[~¥ ?AB~ TO TARGET IS TIE IN F'O!h~(T!P) : M~A~..~:ED DEPTH 12i TRt~ trE~.~:T D~'TH 121,00 !~LINATi[~.~ 0,00 AZiML~ 0,00 ~Tt~JDE(HY-S) 0,00 DEPARTL~:E(~/-W) 0,00 D~'(E/-W) 0.00 [E~1o85 MZAD_~,~:. I.N.~ ~:RV.~. ~ICAL DEPTH DEF'~H ft ft ft 121 ~00 0~0 12! ~C,O 34S',(K~ 228~0 349,~D 526,00 i79,0 527,~ 654,C~ i26,0 653,11 744,?1 ~0,~ 742,67 **.**~****.*** ANAL)KIL~ ******'******~ ~** RADIi_E: OF ~:t>AT~:£ ll~,~g*-*****-** TA:'R~"ZT DIMliU.~; AZII~H ~l S..,_.. ~ON I'.~.~, N/-S E/-W ft d~ deg ft ft 0,¢~3 0,00 0,0~ 0,00 0,00 0,3~, 0,~ 320,6~J -.,, 4.. -0, !7 6,51 3,75 304,~X~ 4,62 -4,79 20,23 8,76 2?4,37 11,.5'2 -!6,76 S5,52 t0,66 310,43 19.51 -29,69 DP.F Ar, ~UP~S DiS?LACEM'-D~T AZI~]TH DLS deg/ ft deg 10Oft 0,00 0,00 0,00 0,4? 340,00 0,11 6,.~., 313,% 1,96 20,24 304,00 4,06 35,53 303,31 3,62 1107,~4 1202,73 !?B6,06 1~,70 1483,24 1~6.26 1669,15 90,7 916,79 90.0 ~2.~ i0~4,~ 94,8 1185,61 93.3 i275,tl 94,6 1365,~ 92,5 1451,14 ~,0 1%5,25 92,9 1616,12 53,54 12,^~._ %::r.,,,., ,-,~ ~ ~, ~ -43,82 53,A3 . 305,21 2,31 75.!8 15.12 5<)6,72 .~...:.~-60.96 75.39 306.04 2.73 9".~. 26' 16.29 ~07 +91 57.45 -80.07 ?'?,73 306.60 1,33 124,53 15.51 309,01 ~,20 -99,87 1~,03 3~,97 0.91 149,76 15.~8 ~,01 ~1,01 -11~,76 150.42 307,23 176,12 I7,36 3Q5,48 106,~ -140,97 176.66 307,16 2.06 205._~,66 I9,05 302,31 123,3~ -165,50 206,40 306,6~ 2,07 ~-9.42 ~.76 301.19 141,09 -194.21 240,05 ~.~) 5.11 27%13 26,76 301,94 161,87 -228,05 279,66 305,37 3,27 .~1,¢Y~ 26,~ 5,01,03 163,76 -2E3.83 321.53 304.86 0.47 1762,t! 1857,65 !?_,2,60 2044,01 21~.34 73,8 170i,49 9!,4 1935,15 94,3 3ES,~ 27,56 ~.3.~ 2(~,70 -3~.72 364.35 304.37 0.74 410.45 31,20 [.`03.C8- 234,!4 -34~.24 410.76 304,07 4,0? 4.'.'.-2,8535,97 .307 ,P_3 2/'.4), 55' -383,00 463,25 304,23 5,73 vz,J, t.~ j(j y,Sj --,,.., ,~ 519,~ 304,71 4,52 59,0,91 43,49 :~:9,61 235,64 -475,37 %1,'K2 305,22 3,73 2324,73 24!?,70 ~--12 2605,40 2698,14 ~,~,3^ 3354,t3 3730,44 4105,C,2 4480,48 4761,38. 94.6 2071,90 9i,8 213t,~) 95,0 2189,81 93.1 2~2.02 ?2,7 2335,89 ~,-,.- 2373,?5 2601,79 2~.32 374,6 :" 280,9 3203,48 277,1 '" ~7,73 47,36 308,76 378.21 -527,57 649,15 ~5.64 4.13 716,5~. 51,16 311,~. 422,82 -580,73 715,51 306,05 4,56 791.C~) 53.53 308.97 471,16 -~38,51 7%.52 365,42 3,05 8~..60 SE.,61 305.~. 5i6,85 -67~,!2 869,43 306,48 4,60 945,~ 59,58 303,4..4 56i,33 -764,42 948,39 306,29 3,51 1027.20 63,74 3<J3.11 6~.,16 -832.71 1!!1,17 67.31 240,76 650,59 12~4~63 66,43 5¢JI.65 7~,4~ -1052,33 1627,67 65,29 301,60 ~0.40 -1344,43 196~.44 65.78 ~X),47 1096.62 -1637,28 23QS,_S4 64,01 300.62 1269,02 -1~9,38 2646,70 64,54 300,36 !440.66 -2220.66 2678,~ 62,94 300,83 1568..87 -2437.6? 1~,21 62.70 '- 2K)1,34 1716.37 3431.08 61,72 2~J,40 1843,06 -2894,27 1029,97 ~<~6.05 4,70 1113,74 305.74 4,3~ t256.74 ~:,13 0.63 1629.30 304,40 0,30 1~70.60 303,81 0,30 23~¢,~ 303,33 0.47 2647.21 302.97 0.15 2898.91 302.76 0,5? 3184,47 302,61 0,i6 3431.29 302.49 0,46 56.44,51 5927 =4 6204,42 6484.61 67~.,52 282,9 3616.34 283,0 3/'52,~ Z/.,,~ , ~ . 280.2 4016.15 281,9 41J~,60 ~78.77 60.79 ?~'7,71 1963.49 -3111.06 ~.78.86 302.26 0,89 3?26,56 61,67 3,.~0,49 ~O.AS, 13-3~7,83 3?26,58. 302,06 0.91 4i70.23 61.66 301.55 2209,71 -3536,67 4170,25 302.00 0,34 4416,15 61,10 St)O, 18 22F.~. 88-3747,81 44!6,15 301,93 0,47 4663,37 61,47 302,57 2464,61 -3955,68. 4663,37 301,90 0,75 '-') t-.- '? 'i''~ '~ ~ ~ ~ ~'" DEPTH 7324,76 279,6 ~24, 78~4, ~? 280,1 4~.9,!2 B16! ,73 276,7 8443.62 8724,84 9007,18 9287,50 9570.15 9~,5.18 9759 ~" 9853,26 9950.~6 1~K)42,42 ~ ~ ~4 103!~.14 1~i6,~ I0~7.67 107!~,46 10763,36 26!.9 4947.74 26!,2 5076,59 262,3 5210,79 2&9,3 53~9.27 282.6 ~91,87 ~.0 5540.52 94.1 55,90.36 94.0 5~42.57. 97.6 56~.91 9!,5 5;754.6I 94,3 5816,85 5Q.2 ~575,62 89,2 5940,20 97,I 6009.21 191.5 o14y,4o ******~*****~ ~:ILL ********~**** L~;vnI C~£~AT!ONS ***~* RADIUS O? ~:VA~RE M~T~D****~* THRu~ o:.~_,', AZI~H ~TIIUDE S~ INC~+ N/-S ft deg dq ~t 4907,49 60.9! ~2,54 LJ,2*77 ~97,J8 A9.%7 301,~- 2852.69 ~,45,24 62,03 30!,41 2?82,26 ~4,S9,99 62,~ 301,65 6140.35 63,00 300,¢~ ~38,65 ,~,,~,~~ ~ 6~,4o 302.15 oo ..... J 6~J~.67 60,77 301,70 3499,10 .~S2.34 ~,02 299,~5 3623.81 7126,22 59,~ 299,69 3744,97 7207.79 59.03 2$~/, 39 3785,22 7287,52 57, O0 299,16 38-24,25 7~5,56 55.49 29'--/, CiO~62.22 7~4.50 52.56 300.93 39.'01.67 7516,33 50,89 299,25 ~'37,70 DEPARTIJFLE DI._-,FL~:~.~N~ at E/-W ft ft -4164,65 4907.49 -4372.~ 5151.53 -4582,14 -4793,22 5645,24 -5001,&3 5~,~,9~ .-'.-~.8,79 49,68 ~79.48 ~73,26 7656,60 ~ ~z 4,..~, 29?,94 4007,BB 7723,07 45.29 2X)0.50 40.40,35 7791,33 44,11 5¢K),37 4074,94 7i~3,73 43.43 3,00,67 4142,~ AZIMUTH DLS deo/ deo lOOft 301,94 0,20 301,93 0,47 30i,91 0,61 301,89 0,12 ~,i,67 0,13 -5216,81 6140,35 301,83 0.56. -54~),83 6390,26 301,60 0,69 -564!,65 6638.67 301,61 0,62 -5B51,05 6662,35 301,77 0,64 -6062,86 7126,24 301,70 0,23 -6133,90 7207,62 301,~, 0,46. -6203,52 7287,56 301,65 2,16 -6271,80 7365,61 301,63 1,62 -6340,23 7444,57 301.61 3,40 -6402,42 7516,41 301,59 2,32 -./~..5,63 75&~.,~ 301,57 1,31 -6526,[<, 7655,70 301,55 2,51 -6562,03 7723,16 301,54 ,7.1,4~ 1,22 -6754,~ 792~,86. 301.52 0,37 1(~,~ 6~"~,61 7995,70 43,~, 90i,03 4 ..4179,11y-6~16,7~ 70,9 6275,17 &C44.,~ 43,34 3-0t,20 ~ 4204,26 7995.84 34,1,51 0.25 ~'.,44.~ )S1.51 0.16 6116.~ 43,34 Si)l,20 4241.59 -6919.8~ 6!16,36 301,51 0.02 z"; p C ! ,o?r:,. Al_A, . OIL AND GAS CONSERVATION COMMI',. ' N APPLICATION FOR SUNDRY APPROVALS Abandon_ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program X_~ Pull tubing _ Variance _ Perforate _ Other 5. Type of Well: 6. Datum elevation (DF or KB) Development X 1. Type of Request: 2. Name of Operator ARCO Alaska, Inc. Exploratory Stratigraphic Service 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 961.5' FNL, 1602' FEL, Sec. 25, T13N, R8E, UM At top of productive interval 2039' FNL, 2192' FWL, Sec. 23, T13N, R8E, UM At effective depth At total depth 1940' FNL, 2032' FWL, Sec. 23, T13N, R8E, UM Present well condition summary Total Depth: measured true vertical 1 0888' feet 6351 ' feet RKB 68' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3M-25 9. Permit number 93-196 10. APl number 50-029-22433 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Plugs (measured) 12. Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length 80' 5109' measured None true vertical Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None 1 0888' feet 6 3 51 ' feet Size 16" 9-5/8" Junk (measured) Cemented Measured depth True vertical depth 250 Sx AS I 121 ' 1000 sxAS III & 5150' 550 sx Class G 121' 3382' 13. Attachments Description summary of proposal_ Detailed operation program X BOP sketch -- 14. 16. Estimated date for commencing operation 1/5/94 If proposal was verbally approved Name of approver Blair Wondzell Date approved 1/5/94 15. Status of well classification as: Oil X Gas -- Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~/~,yy/J/~-~'/~~* 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 --~'equire - Original Signed By David W. Johnston Approved by the order of the Commission ,..,,.,l~proval No. Approved '-'~IF:~ Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE -- 6 1994 Gas Cons. Commission Anchorage KRU 3M-25 P & A 8-1/2" Production Hole Kuparuk River Unit Well 3M-25 was drilled to the planned Kuparuk Target location and TD was reached on 1/5/94. The open hole logs indicated that the well was not economic as a result of a thin pay interval. As a result, ARCO Alaska, Inc. requests approval to p.l~ug and abandon the 8-1/2" production hole. The surface hole of the well willkused in order to side track the well to an alternate Kuparuk target location. Attached is the detailed procedure for plugging the 8-1/2" section of the well. In summary, a cement plug will be placed from TD (10,888' MD) to a minimum of 100' above the top of the Kuparuk Formation (10, 570' MD). A copy of the open hole resistivity and gamma ray logs is also attached. A second plug will be set in the 8-1/2" open hole from 5450' MD to 5100' MD (50' inside 9-5/8" surface casing shoe). This plug will be used to kick off the well to the alternate location. Kill weight mud (11.5 ppg) will be left in the open hole in between the two plugs. Blair Wondzell verbally approved the P&A procedure attached on 1/5/94. Approval to side track the well to the alternate location will be requested via a Permit to Drill Form on 1/6/94. If you have any questions or comments regarding the attached procedure, please contact myself at 263-4962 or the Drilling Engineer working on the project (Steve Bradley) at 263-4243. Thank you for your expedient response to this request. RECEIVED ,JAN -'6 1994 u~l a Gas Cons. Commission Anchorage. KRU 3M-25A SIDETRACK PROCEDURE s D B Prepared by: Approved by: Drilling ~uperintendent Described below is a procedure to sidetrack KRU Well 3M-25. The proposed procedure has been approved by the AOGCC (verbal approval by Blair Wondzell, 1/5/94). 1. RIH with 5", open ended drill pipe to 10,880' MD. 2. Once pipe is on bottom, circulate bottoms up. , Lay a balanced cement plug in the 8-1/2" open hole from 10,880' - 10300' (top of Kuparuk = 10,570') as follows (batch mix cement): Pump: 20 bbls fresh water spacer 200 sx Class G cement* (40.7 bbls) 8 bbls flesh water flush Drop DP wiper plug (no catcher on DP) 173.8 bbls 11.5 ppg mud flush (consider over flushing by 1 - 2 bbls to ensure balance point is accurate) Cement Slurry (batch mix): Weight:. Yield: Additives: Volume: Class G 15.8 ppg 1.15 cu ft/sk 0.2% D46, 0.45 % D65, 0.5% D156, D800 retarder as required for 3 hr thickening time @ 130° (lab tests currently in progress) 200 sacks 5" DP capacity: 0.01776 bbl/ft 8-1/2" hole capacity: 0.0702 bbl/ft DP X Hole capacity: 0.0448 bbl/ft MW: 11.5 ppg Hole angle: 43.4° ,JAI~ "'6 1994 Gas Cons. Commission Anchoragt-: KRU 3M-25A SIDETRACK PROCEDURE (page 2) , POOH to _+9000'. Circulate and recipricate DP while WOC. After waiting on cement for _+6 hrs., RIH and tag cement plug (DS currently nmning lab tests to determine optimum WOC time before tag). Notify AOGCC representative in advance so that he may be on location to wihaess tag. , After tag, POOH to 5800' MD. Spot 30 bbl viscous plug. POOH to 5450', CBU. , Lay a balanced cement plug in the 8-1/2" open hole and 9-5/8" casing from 5450'- 5100' as follows (batch mix cement): 20 bbls flesh water spacer 140 sx Class G cement* (24.9 bbls) 8 bbls fresh water flush 81.8' bbls 11.5 ppg mud flush (consider over flushing by 1 - 2 bbls to ensure balance point is accurate) * assumes 8-1/2" hole in shoe joints. Cement Slurry. (batch mix): Type: Weight: Yield: Additives: Volume: Class G 17.0 ppg 1.00 cu fl/sk 0.1 gps D47, 1.3% D65, 0.45% D156, D800 retarder as required for 3 hr thickening time @ 110° (lab tests currently in progress) 140 sacks 5" DP capacity: 0.01776 bbl/ft 8-1/2" hole capacity: 0.0702 bbl/ft DP X Hole capadty: 0.04482 bbl/ft MW: 11.5 ppg Hole angle: 61 ° 7. POOH to +_5000' MD. Reverse circulate DP clean. Cont. POOH. ,JAI~ -' t~ i~- 6as Cons. Commission Anchorage KRU 3M-25A SIDETRACK PROCEDURE (page 3) . MU 8-1/2" BHA (6-3/4" Mach 1C motor with PDC bit, MWD, CDR, CDN). RIH to +5000'. Reduce mud weight to +9.0 ppg (save 11.5 ppg mud if possible). 9. WOC +12 hrs. before cleaning out cement. 10. 11. Cleanout and drill cement to KOP (5250' MD). Kickoff and drill 8-1/2" hole as per directional plan. New top Kuparuk Target: 1351' FSL, 1055' FEL, Sec. 23, T13N, R8E @ 6191' TVD. At 500' MD above the top of the Kuparuk, add +1/4 ppb Desco in order to ensure the mud is thin and in good shape and ECD's are minimized while weighting up. At approximately 300' MD above the top of the Kuparuk, begin raising the mud weight. The estimated BHP on 3M-25A is 3600 psi based on the pressure recorded at offset wells. By drilling the Kuparuk sands with an 11.5 ppg fluid, the Kuparuk sands are estimated to be overbalanced by 100 psi. Control drill the Kuparuk sands with penetration rates not to exceed +60 fph for LWD log quality. The TD of the well should be such that 100' MD of rathole exists between PBTD and the lowest future perforation. A Petr. Engr. representative will be onsite to determine the lowest future perf. while drilling through the Kupamk from the real time CDR log. After reaching TD, circulate the hole dean & short trip to the 9-5/8" casing shoe. Condition hole for casing. Run and cement T' casing as per original wellplan. If you ~,e~~ons~ ira ~v~ 1S~rei~le'~ g Engineer CC: Doug Stoltz Wayne McBride Richard Morgan Doug Ruckel Greg Starley Ron Marquez KRU 3M-23 Well File or comments, contact me at 263-4243. ATO 1402 ^TO 1448 ATO 1426 ATO 1420 ATO 1268 ATO 1270 ,./.~ Iu .. r.': ,,-,,.~.,,:.,..si~ ()ii & Oas (.;oils. Oommission Anchoragt¢ KUPARUK RIVER UNIT WELL #3M-25 WEL, EIORE DIAGRAM 16" CONDUCTOR AT 121' CEMENTED TO SURFACE 9-5/8", 36#, J55 & 47#. W/SHOE AT 5150' Cemented with 1000 sx AS III and 550 sx Class G to surface L80 Planned Kick Off Point: 5250' Cement plug for kick off: 140 sx Class G 5450' 5100' Top Kuparuk: 10,570' Base Kuparuk: +10,700' ARCO Alaska, Inc. KRU 3M-25 TD = 10,888' 8-1/2" OPEN HOLE Cement Plug: 15.8 ppg, Class G 10,880' - 10,470' (200 sx) ,JA.N -'6 ~994- Gas Cons. Commission Anchorage SDB, 1/5/94 10,~7D' 10500 10600 J~se t~ (~ 100 ROP FT/HR 1000 ................ 0 GR (T) 200 SLIDING TO:/t~, £g~o' DEPTH (ft) ~ID I).2 2000 ....... 2000 COMPANY ARCO ALASKA, 1NC. WELL FIELD KUPARUK RIVER UNiT . . COUNTY NORTH SLOPE BOROUGH STATE ALASKA CONTRACTOR PARKER ' R]~ G 24,5 K.B. 68.0 D.F, 68.0 __.. G.L. 27.0 START DEPTH END DEPTH 10000.0 ft .. 10888,0 ft MD F-~ TVD 10500 /o, g?o '. 10600 ~R (T) ROP FT/HR ~ ..................... (~R ('r) .AP! ~00 SLIDING ._ COMP ANY ARCO ALASKA, WELL 3M-25 100 DEPTH .... o (ft) MD 300 -1 lng. F'ZELD KUPARUK RIVER UNiT COUNTY NORTH SLOPE BOROUGH CONTRACTOR PARKER 0.2. 0,2 gTATE ALASKA 245 OHHH OHMM K,B, 68.0 D.F. 68,0 · . G,L. 27,0 START DEP l'l--t" END DEP TH 2000 2000 MD ~-~ TVD 10888,0 f t 10000. ~ f t ... 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 January 10,1994 Phyllis Billingsley ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Dear Ms Biilingsley: The Commission is compiling statewide drilling statistics for 1993. Attached is a list of outstanding Permits to Drill issued to your engineering group (permits for which no form 10-407 has been received by this o.ffice). Please review this list to determine if any of the wells were drilled in 1993. If so, please note the well name, total measured depth, and class (development, service or exploratory). If any wells were drilling as of 12/31/93, estimate the depth at 12:00 midnight. We would appreciate your reply by the end of January if possible. Thank you for your cooperation with this project. If i may be of any assistance, please call me at 279-1433. Yours very truly, Robert P Crandall Sr Petr Geologist encl joiA: RPC:\drlstats .110419¢ OPERATOR ARCO ALASKA INC ARCO ALASKA ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA INS ARCO ALASKA INC ARCO ALASKA INS ARCO ALASKA INS ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA iNC ALASKA WELLS BY ARCO PERMIT 93-0166-0 93-0152-0 93-0151-0 93-01~3-0 93-0144-0 93-0188-0 93-0179-0 93-0169-0 93-0104-0 93-0189-0 93-0174-0 93-0175-0 93-0187-0 93-0195-0 93-0196-0 93-0193-0 92-0040-0 WELL NAME KUPARUK RIV UNIT KUPARUK RIV %rNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV U~IT KUPARUK RIV UNIT KUPARUK RIV U~IT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT 2A-18 2A-19 2A-20 2A-22 2A-24 2E-04 2E-05 2E-06 2E-07 2~-08 2E-17 2E-18 3M-23 3M-24 3M-25 3M-26 3R-16 MEMORANDU V! State c. Alaska Alaska Oil and Gas Conservation Commission TO: David J o h n_h n_h n_h n_h n_h n_h~~n, Chairm,:ff.p?¢--- DATE: 1/6/1994 THRU: Blair Wondzell, P. I. Supervisor FROM: ~oou Grimaldi, SUBJECT: Petroleum Inspector FILE NO: NCXJAFBD.doc Open Hole wellbore plug Arco well # 3M-25 Kuparuk river field PTD # 93-196 Thursday, January 6, 1994: I traveled to Arco's 3-M pad in the Kuparuk river field to witness the open hole plug on well # 3M-25. This plug was verbally approved by the AOGCC for abandonment of the bottom hole location. The top of cement was found at 10,405 which gave 165 feet of cement on top of the shows at 10,570. The drill pipe was used to set down 25,000 lbs on the plug which appeared solid. Summary: I witnessed verification of placement of the open hole plug in well # 3M-25. Attachment STATE OF ALASKA ALASKA OIL AND GAS CONSER I~ATION COMMISSION Plug And Abandonment Report 7106 Operator: Arco Alaska Operator Rep.: Bobby Morrison/Donnie Lutrick Lease No.: Well No.: Total Depth: Well Name: 3M-25 PTD No.: 93-196 Sec. T-R 25,13N,8E 10,888 Elevation: Date: 1/6/94 Meridian: Umiat 41 Mud Wt.: ppg. CASING DATA: , Drive Pipe: Conductor: Intermediate: 16 O.D." Set6: ft. With Penetration O.D." Set 6: 121 ft. Surface: 9 5/8 O.D." Set 6: O.D." Set 6: ft. Prodctn: O.D." Set 6: 5149 PLUGGING DATA: 1. Open Hole Plugs: Tagged top of cement at 10,405 (top of show 10,570). SET 25k Down "OK". 2. Open Hole Isolation Plugs: 3. Perforation Plugs: 4. Annulus Plugs: 5. Casing Stub Plugs: 6. Surface Plug: Casing Removal: " Casing Cut 6 Feet " Casing Cut 6 Feet " Casing Cut 6 Feet " Casing Cut6 Feet REMARKS: Plu[I appeared solid, 25K set down. Distribution: orig - Well File c - Operator c- DNPJDOG c - Database c - Rpt File c- Inspector FI-000 (Rev. 3/93) Inspector (s): Louis R Grimaldi NCXJAFBD.XLS ALASKA OIL AND GAS CONSERVATION COMMISSION December 22, 1993 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 A. W. McBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 3M-25 ARCO Alaska, Inc. Permit No: 93-196 Sur. Loc. 961.5'FNL, 1602'FEL, Sec. 25, T13N, R8E, UM Btmhole Loc. 1940'FNL, 2032'FWL, Sec. 23, T13N, R8E, 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. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David ~ JohnstOn Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ,STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS~,ON PERMIT TO DRILL 2O AAC 25.005 la. Type of Work Drill X Redrill [] lb Type of Well Exploratory [] Stratigraphic [] Development Oil X Test Re-Entry E~] Deepen E] Service D Development Gas [~ Single Zone X Multiple Zone 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 68', Pad 27' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25522, ALK 2558 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20AAC 25.025) 961.5' FNL, 1602' FEL, SEC. 25, T13N, RdE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2039' FNL, 2192' FWL, Sec. 23, T13N, RdE, UM 3M-25 #U-630610 At total depth 9. Approximate spud date ~,¢,-~_~ Amount 1940' FNL, 2032' FWL, Sec. 23, T13N, RdE, UM ~ 12./2.-¢,~3 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in properly 15. Proposed depth (MD and TV•) property line 3M-14 10888' MD 2192' @ TD feet 12.3' @ 140' MD feet 2560 6436' TV• feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 450 feet Maximum hole angle 60.97° Maximum sudace 2006 psig At total depth (TVD) 3275 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' _+200 CF 12.25" 9.625" 36.0# J-55 BTC 5054' 41' 41' 5095' 3388' 580 Sx Arcticset III & HF-ERW 540 Sx Class G 8.5" 7" 26.0# L-80 BTCMOE 10847 41' 41' 10888' 6436' 150 SxClass G 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 Cemented Measured depth True ,Ve, rtLg,,al,.~depth Structural Conductor RECEI Vbt) Surface Intermediate Production DEC 1 -( 199,~ Liner Perforation depth: measured ,~,l~,Sk8 un ~, Gas Cons. C0mmissi01 true vertical Anchorage 20. Attachments Filing fee X Property plat [] BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [] Refraction analysis ~ Seabed report ~] 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed _/~.,~~ ~,~ Tille Area Drillin~l En~lineer Date Commission Use Only Permit Number ..r~._~ _,/?>~ IAPl number50.,~ ~_,-~, _-~---_~--.-~ :.7 ':J ~'-~ ~" ~-'> '~ IAppr°val date-/c'7~ - ~ ~ ~',-~ ISee c°ver letter f°rother requirements Conditions of approval Samples required ~ Yes ~ No 'Mud Icg required FI Yes J~] No Hydrogen sulfide FI Yes ,~] No Directional survey required ~ Yes FI No measures Required working pressure for BOPE ~ 2M J~ 3M Fi 5M r-I lOB ~ 15M Other: Original Signed By Approved by David W. Johnston by order of Commissioner the commission Date /~ '~'~ ~'~__ Form 10-401 Rev. 7-24-89 Submit in triplicate . , , 10 11 12 13 14 15 16 17. 18. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 3M -25 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (5095')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (10888') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & full opening valve for cased hole logging. Secure well and release rig. Run cased hole cement evaluation. ND full opening valve & NU tree assembly. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 7" casing to 3500 psi. 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. RECEIVED DEC 1 7 I99L5 Alaska Oil & Gas C0rls. Commission Anchorage DRILLING FLUID PROGRAM Well 3M-25 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.5 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 +10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 10.4 10-18 8-12 35-50 2-4 4-8 4-5 thru Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.O33. 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 2006 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 3M-25 is 3M-14. As designed, the minimum distance between the two wells would be 12.3' @ 140' MD. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. RECEIVED DEC 1 7 199~ Alaska Oil & Gas (~orJs. Commission Anchorage Created by ' jones For: S BRADLEY Dote plotted ' 7-Dec-95 Plot Reference is 2.5 Version #4. Coordinates ore in feet reference slot #25. True Vertical Depths are reference wellhead. Baker Hughes INTEQ --- A CO ALASKA Structure : Pod 5M Field : Kuporuk River Unit = = 7200 6800 6400 6000 ~¢6005200 4<3004400 40,003600 II II II iI I1 II II Ii II II Well: 25 Location : North Slope, Alaska West 3200 2800 2400 2000 1600 1200 800 1600l 2000t 24001 2800_ _ 32C~5 _ _ 5600_ _ 400,0_ _ 4400_ _ 4800_ 6200_ _ 5600_ 6400 -- 6800 4O0 ITD LOCATION: I 2 SEC. 23, T13N, RBE I '~. TARGET ~ TVD=6212 ~ TMD= 10596 DEP=7964 NORTH 4205 WEST 6766 RKB ELEVATION: ~a?,' ~ KOP TVD=450 TMD=450 DEP=O ~--.. MAXIMUM ANGLE 60.9? DEG 6.00 L1 2.00 18.00 BUILD .3 DE(; / 100' 24.00 ~nn30'O0 '~, ~'~nO B/ PERMC, FROST TVD=1638 TMD=i732 DEP=414 '%,, 54.00 OEP=lO70 '~.T/' W SAK SNDS TVD:2845 TMD=5972 DEP=2285 -... B/ W SAK SNDS TVD=3188 TMD=4685 DEP=2907 ~ PT TVD=3,388 TMD=5095 DEP=5268 ~-~"~' 9 5/8" CSG K-la 'P¢D=5488 TMD=5301 DEP=3448 '%~"'- TARGET ANGLE 40 DEG N 58.15 DEG tY ?g~' (TO TARGET) Scale 1 : 200.00 0 I I 400 4800 520'0 - /X _2800 I _ _2400 I _ _2000 Z - 0 - 53- _1200 _ 800 - ct, .. 0 © 400 0 ESTIMATED SURFACE LOCATION: 961.5' FNL, 1602.5' FEL SEC. 25, T15N. RBE RECEIVED K-5 TVD=4948 TMD=831~~ BEGIN ANGLE DROP TVD=5549 TMD=9547 DEP=7160 %-~. ~ 58b°4°. 00 DROP 2 DEG / 100' "%'~., 50.00 %, 46.00 TARGET - T/ ZONE C (EOD) TVD=6212 TMD=I0596 DEP=796,1 ".,, 42.00 T/ ZONE A TVD=6252 1MD=10622 DEP=798) ~ ~ B/ KUP SNDS ~70=6283 TMD=10688 DEP=8024 ':'.},~ TI) / 7" CSG PT TVD=6436 TMD=lOO88 DEP=8153 '~' 0 400 800 1 16 2000 2 Cv3 28 3200 360'3 40 4400 480'0 Scale 1 : 200.00 Vertical Section on 301,85 azimuth wilh reference 0.00 N, 0.00 E from sial ,~25 -,~--~,,~ ~,, ~ Gas Cons. Commissiorl Anchorage 56 0 6000 64 0 6800 7200 7 O0 8400 West ARCO AI ASKA Structure · Pad 3M Field · Kuparuk River Unit Well- 23-24-25-26 Location · North Slope, Alaska 21 O0 2050 2000 1950 I I I I I I I 1700 1900 1850 1800 1750 1700 I I I I I I I I I I 300 1500 1500 1500 1300 1300 1300 110o 1100 1650 1600 I I I I 2900 700 2700 1100 900 1550 650 _ 700 _ 750 800 0 I 850 ::D"- I 900 ] V 950 PROPOSED 500 1000 e 1 Casing Design / Cement Calculations 16-Dec-93 Well Number: Surface Csg MD: Surface Csg TVD: Production Csg MD: Production Csg TVD: Top of West Sak, TMD: Top of Target, TMD: Top of Target, TVD: Estimated Pressure: Surface Casing Choice: Production Csg Choice: Production Casing Frac. Pressure 3M-25 5,095 ft 3,388 ft 10,888 ft 6,436 ft 3,972 ft 10,596 ft 6,212 ft 3200 psi ** See Page 4 For Casing Choices 3,500 psi Maximum anticipated surface pressure TVD surface shoe = 3,388 ft {(13.5'0.052)-0.11}*TVDshoe =J 2,006 psiJ Estimated BH pressure at top of target zone Estimated Pressure= Top of Target, TVD = Overbalance, psi= Anticipated Mud Weight =L 3,200.0 ppg 6,212 ft 150 psi 10.4 ppgJ Surface lead: Surface tail' Top West Sak, TM D Design lead bottom 500 ft above the Top of West Sak Annular area Lead length * Annulus area Excess factor Cement volume required Yield for Permafrost Cmt Cement volume required TMD shoe (surface TD - 500' above West Sak) * (Annulus area) Length of cmt inside csg Internal csg volume Cmt required in casing Total cmt Excess factor Cement volume required Yield for Class G cmt Cement volume required = 3,972 ft = 3,472 ft = 0.3132 cf/If = 1,087 cf = 15% = 1,251 cf = 2.17 =1 58o = 5,095 ft = 508 cf = 80 ft = 0.4340 cf/If = 35 cf = 543 cf = 15% = 625 cf = 1.15 =1 540 sxl RECEIVEE Gas Cons. Ooramission Anchorage Casing Design / Cement Calculations Production tail: 16-Dec-93 TMD -- 10,888 ft Top of Target, TM D = 10,596 ft Want TOC 500' above top of target - 10,096 ft Annulus area (9" Hole) - 0.1745 (TD-TOC)*Annulus area = 138 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.2148 Cmt required in casing = 17 cf Total cmt = 155 cf Excess factor = 15% Cement volume required = 179 cf Yield for Class G cmt - 1.23 Cement volume required =1 150 sxJ TENSION - Minimum Design Factors are: T(pb)=l.5 and T(is)=l.8 Surface (Pipe Body): Casing Rated For: Tension (Pipe Body) - Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Length = Casing Wt (lb/fi)= Dead Wt in Air = Buoyancy - Tension (Pipe Body) = Design Factor =L 564000 lb 5,095 ft 36.00 Ib/ft 183420.0 ib 28145.3 lb 155274.7 lb 3.61 Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy - Tension (Joint Strength) = Design Factor =1 639000 lb 5,095 ft 36.00 Ib/ft 183420.0 lb 28145.3 lb 155274.7 lb 4.11 Production (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WVft) Buoyancy - Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft)= Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =1 604000 lb 10,888 ft 26.00 Ib/ft 283088.0 lb 44278.5 lb 238809.5 lb Production (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud REC£1V :.r] Casing Rated For: Length: Casing Wt (Ib/ft): Dead Wt in Air: Buoyancy = Tension (Joint Strength) = Design Factor =1 667000 lb 10,888 ft 26.00 Ib/ft 283088.0 lb 44278.5 lb 238809.5 lb :2.81 DEC ! 7 199~ AigSka 0il & Gas Cons. Commission Anchorage Casing Design / Cement Calculations BURST - Minimum Design Factor = 1.1 Surface Casing: Burst = Maximum surface pressure Casing Rated For: Max Shut-in Pres: Design Factor :[ Production Csg: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor COLLAPSE - Minimum Design Factor = 1.0 Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' 'I'VD with 9,0 # Mud 2. Ext. Pres=Mud Wt*0.052*'I'VD-(2000'TVD of 9# Mud) Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ Production Csg 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom- Design Factor =1 16-Dec-93 3520 psi 2005.7 psi 1.8] 7240 psi 6971 psi 2979 psi 3992 psi 1.8J 2020 psi 0.539 Ib/ft 891 psi 2.3] 5410 psi 0.539 Ib/ft 3471 psi 1.6J RECEIVEg DEC 17 199b Uil & Gas Cons. Commission Anchorage Casing Design / Cement Calculations 16-Dec-93 Surface Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength Collapse I 9.625 8.681 47 L-80 13.5724 sq. in. 1161000 lb 1086000 lb 4750 psi 2 9.625 8.835 40 L-80 11.4538 sq. in. 979000 lb 916000 lb 3090 psi 3 9.625 8.921 36 J-55 10.2545 sq. in. 639000 lb 564000 lb 2020 psi 4 10.750 9.950 45.5 J-55 13.0062 sq. in. 931000 lb 715000 lb 2090 psi Burst 6870 psi 5750 psi 3520 psi 3580 psi Production Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength Collapse I 7.000 6.276 26 L-80 7.5491 sq. in. 667000 lb 604000 lb 5410 psi 2 7.000 6.276 26 J-55 7.5491 sq. in. 490000 lb 415000 lb 4320 psi Burst 7240 psi 4980 psi RECEIVEg DEC 3 7 '199b Oil & Gas Cons. 6oramission Anchorage ~.JPARUK RIVER UNI~ 20" DIVERTER SCHEMATIC 5 HCR.I 6 4 3 2 DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION 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 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNULAR PREVENTER RECEIVED DEC 1 7 199~ 0il & Gas Cons. Commission Anchorage E D F 3/10/92 < I 5 4 13 5/8" 5000 BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 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 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 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'I-TOM PIPE RAMS. TEST BOll'OM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF 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 LINES 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 BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DALLY. 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" - 5000 PSI ANNULAR RECEIVED DEC 1 7 199; /d~ska Uil & Gas Oons. Commission Anchorage ** CHECK LIST FOR NEW WELL PERMITS Company Lease & Well ITEM APPROVE DATE (1) Fee (2) Loc [2 thru 8]'/ (3) Admin .[~.:~]. J ';: [ 10 '& 13] [14 thru 2 (5) BOPE [23 thru 2 YES 1. Is permit fee attached ............................................... ,,., 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ...................... 5. Is sufficient undndicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... ,.~ 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ '¢~, 9. Does operator have a bond in force ................................... 10. Is a conservation order needed ....................................... 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is administrative approval needed .................................... Is lease n~nber appropriate .......................................... Does well have a unique name $ n~nber ................................ 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 ~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... NO REMARKS (6) Other '[29 thru 31] (7) Contact [32] ' (8) Addl FOR EXPLORATORY & STRATIGRAPHIC WELLS: 29. Are data presented on potential overpressure zones ................... 30. Are seismic analysis data presented on shallow gas zones ............. 31. If offshore loc, are survey results of seabed conditions presented... 32. Name and phone nL~nber of contact to supply weekly progress data ...... 33. Additional geology' engineerinq' . rev 6~93 jo/6.011 requirements ............................................. Additional INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE * / /--.,? .:,,' MERIDIAN' UM, 2( SM /< :-L J:_:. ,/ remarks' WELL TYPE' Exp/k~ 7~ Redri l 1 In j, Rev 0 -4 ~0 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. COMPANY NANE : ARCO ALASKA~ INC, ~ELb NAME : 3M-25 FiEbD NAM~ : KUPA~UK R~¥~ BOROUGH- : NU~TH 8bOPE STATE : AbA~A AFl NUM~]R : 50-029-224113-00 RECEIVED MAY 0 9 1994 Alaska Oil & Gas Cons, Anchorage ,IS Tape Verification bistinq ;chlumberger Alaska Compursing Center 4-MAY-1994 11:39 DATE : 94/05/ 2 ORIGIN : FLIC T~PE ~A~E : 94027 CONTii~UATION ~ : 1 CONt~I~]NT : ARCO AI.ASKA, iNC.,KUPARUK RIVER Ui~IL[', 3M-25,50-029-22433-00 LOGCI~'~G CO~,iP&!s~: TAPF CREATIOa DA'IE: bit f{UN 1 .... ST, ~Mt3I,!R 2~D STRiNb 3M-25 500292243300 ARCO ALASKA. INC. SCHLUMBERGER ~E,bL SERVICE& 2-MAY-94 25 ~E 9Ol 27.V0 OPK~' NOUN CA~Ii~G DRILbt:R$ blt S!Zg (1N) S1LE (iN) OKP!'}~ (FT) 8.500 9.625 5151.C PAGE: ,I$ Ta~.,e Verliication bistlnq ;chlua~berc~er AlasKa Computlhq Center 3RD STRING ~ELb !'~A8 PBiJGGE, D AND Ai3ANDONED RG~ RP TO BIT: 68,73 FT i~DS RP TO BIT; 12W,06 FT RE~ TO BiT; ~5,5b PT DEN 'l'O 6IT; 1.29.0~ FT NEO'C '.tO BIT: 13~,04 FT D~.IbLED l~T~avaa: 51b1-10888 FT N(.,L,~; ANGLE AT I~D = 43.34 DEG,~ 10~8~ ~IAXIMUi',i HOL~E A~'¢GLE = 62,46 DEG.(a 8724.84 FT, ~i.D w~bh ~ 03152 JAN 5,1~9~ bI'S FORMAT DATA ~].~ FORMAT DATA PAGg: **g* FILE HEADER FILE NA~E : EDIT ,00i ~ERV!CE : FbIC VERSION : OOICOI DATE : 9i!05/ 2 MAX REC SIZ~ : FIL~ 7'tPE : bAST FILE : ~'ILE HEADER f' I LF, r~ U ~4tjER: i EDIT;£D /~ERGED Depth shl~tefl and clipped curves; all bit runs DEPTH I NCRE~IENT: 0.5000 FILE SO ~q~'4ARY I,OwG fOOL CODE C OR BASgbIi~E CURVE FO~ SHIFTS: CU~V~2 SHIFT DAI'A tMEASUREO 5151,U 51bl,O STOP WEPTM 10759.0 .......... E~t-IiVAL~:t,~'i: dNSHIFTEb DEPTH .......... .,iS Taue Verlilcation bistinq ~c.hlumberger Alaska Computing (_'enter 4'MAY-1994 i1:39 $ BIT' RU~'.~ dO. ~4~;RGE TOP ~ ~:b 'I' AND PAGE. 1 66 4 bb 1- 5 b 73 9 65 Fi' I1 b6 13 66 1~ 65 lb 6b lb 6~ 1- mmmmmmmmmm~m~mmmmmmmmmmmmmmmmm UNiT ~E:~V].C A I I AP F'II.,~ }~UMB NU~ C DEPT ~? b30258 00 OuO UO O I t 1 a b8 O0OU0uO0O0 RHOB ~1) G/C3 63o25~ OO o0o OO O I .i 1 ~ b~ O00000000O DRH[3 N~P G/CB b30256 O0 OD() O0 0 I 1 1 4 08 O00OOOOO00 PEF awD aN/E: ~3025S 00 OQ0 Vt) O i 1 1 ~ 08 OUoO0UO000 CAGN ~Vil,) IN b302ba 0() QUO 00 u 1 1 I 4 b8 VOOOO00000 NPHI ~D PO-8 b3025B vO OV0 OO O 1 1 1 q b8 O00UOOOOO0 RA ~1) OMeN ~3t)25b Oo O0O OO b 1 I 1 g b8 OOOOOOO000 RP N~O OH~ 03t)~5~ UO OOO gU u 1 ] 1 ~ 08 O00OO00000 DER Nwl) []H~,t.'! 530258 O0 OuO 0O 0 I ] 1 ~ b~ OOOOOOOO00 VRP ~[) OH~ik b30258 00 OVO O0 0 1 :i I g b8 oO000O~O00 f ,18 TaDe veri~!cation L, istlnq ~chiumDerqer AlasKa Computlnq Center 4-~A¥-19~4 1t:39 PAGE; NAME ~'C~T ~D CP~ 630 258 0'0 000 010 U I I ~ ~8 uOOOOo0000 258 O0 000 OU o 1 1 1 ~ Oa o000o00000 258 OO 0oo O0 0 ~ I I ~ od ~oo0000000 2~ O0 UOo O0 o i ~ 1 ~ oo oOvVoO0000 258 O0 000 OO 0 i t 1 ~ 08 O000OO0000 DEPT, DER.MWD GR,~wL) DEPT. ¥Ot)g.gg~ CAb~.MWD GR,~al) 1.11.i09 . . CAL~N.~D G~,M~L) i29.~20 CALiN,M~[) D~P'[. bgt)O.OUg CAbN,~wl) ~.bUO U~F]'. bUl4.bOu C A/.~N. N~!.) -~99.2bO '999,250 '999.250 -999.250 5.!10 '0,998 .... ..,. 2.962 4,225 34~,095 ....... · 2,721 3,8Z2 150,?B9 .... 2"15.Jb7 ~.273 - , 3.1~9 ~U7.2~3 -999.2b0 -9~9.260 $* i~ND U~' L)ATA ~ Tape verification bisttng ~c~lu~,Derger AlaSKa {.;.'omF~]tir~g uehter 11:39 bAST Fib6 : DATE : ~/Ob/ 2 MAX ~5C SIZe; : !U~ ~ILE~ T~P~ : bU bAS'l' Fib~ : C~.]rves and log header oata ~o~' each Di[ run iD separate DEPTri iNCREMErqT: O.bOt)O .~OWG 'lUOb CUI)~: STAR'[' UE~TH CU~ bUl4,b bUG ~iPjAI)~R !.)ATA 8LJb 'iwA~: - Tp DRILL~ZR' TOP L[)~ INT~f~VAb HL)b~ INCblNA'riUN [~AXIMUM ANGJ~: V~;NDOR TOOL CL3L,,E ~lOOb 'I'~PE ~ mmm~mM ~mmm m e C [) ~ R I T Y C i) f~ 1UUB'!,b ~6~022 N [.,bU .19 liles. Tape Veriilcation t,:isting ~cniu~berger AZasKa (:omPaclng Center $ B~R~HOhk; AND CA~Zi',iG DATi~ ~.[,J~ ~ HUbE CUND l'f IUJ'¢~ MUD D~N~iT~ Lb~/gJ: ,,, 1 b i o 0 1 i · 5 ' ) 1 ~ U ~U, 2, '/',dO . · 'IZ.u bU, U PAGE.' ~m ~mmmmm~mmm~m~mmmmmmmmmmmm.~m ~R O~UZ~ VV OuU vv u Z I ~ ~ O~ Uvuuvvv~UU Uvu vU v Z I Z ~ ~B VuUvvvvuVU mmmmmmmmmmmmmmmmmmmm~mmmm~mmmmm~mmmmm~immmmmmmmmmmmmmmm DFP'I', lt}vOO.OOO PEF.LWl 5.1!0 UCAG. PSR.b~I b.282 DER, HEN,~.[,~I 327.375 HEFA. PEF.L~I 2.962 DCA~, PfiR.L~I ~.225 DER. HFNA,L~I 292,500 HEiFA, bWl 2,bbl IJF'!~]., bW 1 h. OOU URHI.}, [,~ 1 bWl 0.290 T;~?~,bwi 3O.bSO AT~.Lwl bWl b,l~9 RL~mE,bwl bO,O5O GR,~.! bWl 8.3~4 ~/~G.bWl V,~98 TABL).L~I 6Wl 2,510 D}'~;i.GWl 8,300 URHO.L~I bWl (.),3~4 Tf..~?~i.b~l 32,900 ATR,!~I bWl 4,2i2 R(~.PE,LWl 342,095 GR.b*I hW! 6.905 ~iA~.bWl 0,298 TABD.b~I '999,2~0 -999.250 0.025 4,810 118,747 -2,098 0,025 4,184 111,109 0,598 ,,IS Tame Verification L£$tinq ;chlumberger AlasKa Computinq Center DFPT O0()O.000 RHOD.LWI ,LWI 2,72t DCAL,LW1 H~NA.Lw1 289.350 H~F.A. bWi DEPT. 70(')0.000 RI{OB.DWI PEF.L~t 2,94l DCAL.~LWl PSR,LW! 2 757 HFNh,LW1 28U,~49 HEFA DEPT. 6000.u00 PS~.LWI 5.776 END OF DATA ** 4-MAY-1994 i!;39 0,,234 7.1,88 2.335 D~.'Hi,LWl 0.000 Ti !~H,LW1 6,109 LtgB.LW1 0.000 5.955 '990.250 D}.Hi.LW1 '999.250 '099 ~50 Ri ~F !3.~00 DRB[J).L~I 30.450 ATR.L~I I50.789 GR.L~ 0.197 TABD.LWt 37.050 ATR.Lwl 275.367 GR.LW~. 0.273 TABD.SWl 3.400 DRHO.I~I ~6.qOO ATR.L..! 407,203 GR.L~i 0.362 TABD.LWl -999.250 DRHO.L~I -999.250 -999.250 GR.L~I -999.250 TABD.L~I PAGE: 668 129.526 0,478 0,022 2,692 97,246 0,485 ~0, :006 5 04 0,663 .~999,250 .999'250 .999 ~, 250 .99'9,250 **** FILE TRAiI,E~ **** FIbF MAgE ~ EDIT .002 SERVICE : FLIC VERSION : oOICOI D,aTF : O4/0~/ 2 MgX RFC STZF : ~0~4 FILF TYPE LAS~~ FILE **** TaP~ WRAI. I,EP DAT~ ~ o4/Os/ 2 O~I~IN TaP~ ~AUE ~ o4027 P~EVIOUS TAmE Cn~ENT : ~RCt3 ALASKA, INC,,KUDARUK RIVER U?TT, 3g-25,50-029-22433-00 **** ~FEI, TRglI, ER **** SF~VICE NAbtE : EDIT D~T~ : 94105/ 2 OD1CiN : FLIC CONTINUATTO~,~ ~ ~ PREViO[iS DE~L : CO~"E~T : ARCO ALASKA, INC,,KUDARUK RIVER IIIiIT, 3M-25,50-029-22433-00
