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189-073
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. /~_~ ~'~)~File Number of Well History File pAGES TO DELETE 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 Complete [] Other COMMENTS: Scanned by: Bevedy Bre(~~> Nathan Lowell TO RE-SCAN Notes: Isl Re-Scanned by: Bevedy Bren Vincent Nathan Lowell Date: Isl NOTScanned,wpd THE MATERIAL UNDER'THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTO.BER 24, 2000 E P M C:LOP,_I~LM. DOC L A T E R IA L TH-IS M A E W UNDER R K E R ~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate _ Repair well 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 344' FNL, 95' FWL, Sec. 2, T10N, R8E, UM At top of productive interval 1356' FSL, 1220' FWL, Sec. 34, T11N, R8E, UM At effective depth 1356' FSL, 1220' FWL, Sec. 34, T11N, R8E, UM At total depth 1453' FSL, 1287' FWL~ Sec. 34~ T11N, RSE~ UM 12. Present well condition summary Total Depth: measured 6 8 0 0' feet true vertical 6441 ' feet Plugs (measured) None 6. Datum elevation (DF or KB) 154' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2K-09 9. Permit number/approval number 89-73 10. APl number 50-103-201 08 11. Field/Pool Kul3aruk River Oil Pool Effective depth: measured 6689' feet true vertical 6638' feet Junk (measured) None Length Size Cemented Measured depth True vertical depth 115' 2986 Casing Structural Conductor Surface Intermediate Production 624 6' 7" Liner 6 5 3' 5" Perforation depth: measured 6532'-6558' true vertical 6193'-6217' Tubing (size, grade, and measured depth) 3.5" J-55 set at 6047' 1 6" 179 Sx AS I 1 15' 1 15' 9 5/8" 925 Sx AS III & 2986' 2920' 400 Sx Class G 200 Sx Class G 6 2 4 6' 5 9 2 7' 110 Sx Class G 6026'-6779--5726'-6422' EIV D 3.375" Casing Gun @ 4 SPF MAR - 4. 199 Alaska Oil & Gas Cons. Comm[ssio'a Packers and SSSV (type and measured depth) Anch0ra!3e Brown HB @ 5986', Camco TRDP-1A-SSA @ 1821' 13. Stimulation or cement squeeze summary Hydraulically fractured the A Sand with crosslinked gelled water and 12/18 Mesh Carbolite. Intervals treated (measured) 14. Treatment description including volumes used and final pressure Placed 201,383 # 12/18 Mesh Carbolite and 1723 bbl gelled water. Final WHTP -- 3030 psi. Representative I;)eily Average Production or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 429 242 0 860 262 Subsequent to operation 684 141 21 450 233 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned C (,~, ~ Form 10-404 Rev 09/12/90 Date ~,,,///~/f2,- SUBMIT IN DUPLIOATE .ARCO Alaska, In Subsidiary of Atlantic Richfield Compan. WELL I PBDT 2 F,.-q ITRACTOR l FIELD - DISTRICT - STATE iOPERATION AT REPORT TIME WELL SERVICE REPORT 1DAYS iDATE / DOW'ELL REMARKS P,.E F-P.A C, 03o 3~F'P-TY 115 T"e.~.~.p_.. 5AJAR.. PI~ODLEfA, - SOLUE. D STriCT P~D 2~ GP~ 3~ ps, AuG ~S~ ~O~ ~ S~~Y: l qq5 ~TA~ P~PP~NT : ~0Z57~ ~5 _ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ~ Temp. ' Chill Factor I Visibility ~Wind Vel. Report *F °Fi miles [ Signe~_.~ knotsI ' ~{Z STATE OF ALASKA ~ · - ALA'"..A OIL AND GAS CONSERVATION COM,v,~SSION WELL COMPLETION OR RECOMPLETION REPORT Ai D LOG 1 Status of Well Classification of Service Well OIL r-~ GAS ~ SUSPENDED ~ ABANDONED ['-] SERVICE [--"] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 89-73 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20108 4 Location of well at surface 9 Unit or Lease Name 96' F"~L, 94' Fy~L, SEC 2, T10N, R8E UM · KUPARUK RIVER At Top Producing Interval I'O ~ j~i~TE ~ i '. ' ' 10 Well Number At Total Depth i; 11 Field and Pool 1453' FSL, 1287' FEL, SEC T,J,~N, RSE UM KUPARUK RIVER FIELD 5 Elevation in ~eet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 154' ADL: 25588 ALK: 2674 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 116 No. of Completions 7/21/89. 7/25/89. 5/25/90. N A feet M SLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 6800' MD & 6441' TVD 6689' MD & 6638' TVD YES ~ NO E~ 1821' feet MD 1400' APPROX 22 Type Electric o~ Other Logs Run D IL/SFL/GR/S P/FDC/C N L/CAL/CBL/GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 179 SX AS I 9 5/8" 36# J-55 SURF 2986' 12-1/4" 925 SX AS III, 400 SX CLASS G 7" 26# J-55 SURF 6246' 8-1/2" 200 SX CLASS G 5" 18# N-80 6026' 6679' 6-1/8" 110 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 6047' 5986' 6532'-6558' 3-3/8" @4 SPF MD 6193' - 6217' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED SEE ATTACHED ADDENDUM 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ,,~ FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 24-HOUR RATE 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, aha time of each phase. KUPARUK C TOP 6474' 6139' NA KUPARUK C BOTTOM 6481' 6145' KUPARUK A TOP 6495' 6158' KUPARUK A Bo'FrOM 6637' 6286' · - 31. LIST OF ATTACHMENTS GYRO, FRAC 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed __~._~' ~/~~ ..... Title AREA DRILLING ENGINEER Da e '"-~//~'/¢~.~ , , / 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 el Operation: Flowing, Gas Lifl, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ARCO Oil anu Gas Company Well History - Initial Report - Dally Inltruotionl: Prepare and submit the "lnllili Rlllerl" on the first Wednesday after a well is spudded or workover operations are started, Daily work prior to spudding should be summarized on the form giving inclusive dates only. District I County. parish or borough I State ARCO ALASKA INC. I NORTH SLOPE I AK Field ILease or Unit IWa. no. KUPARUK RIVER 'UNIT I ADL: 25588 ALK: 2674 2K-9 Auth. or W.O. no. ITitle AK3641 I COMPLETIONS Operator I I IIARCO w.~. ARCO 55,8533 Spudded or W.O. begun IDate IHour Prior status if a W.O. SPUD 07/21/89 00:00 Date and depth as of 8:00 a.m. 04/05/90 (12) TD: 6800 PB: 6689 SUPV:GB 04/06/90 (13) TD: 6800 PB: 6689 SUPV:GB 04/07/90 (14) TD: 6800 PB: 6689 SUPV:GB 04/08/90 (15) TD: 6800 PB: 6689 SUPV:GB 04/09/90 (16) TD: 6800 PB: 6689 SUPV:GB Complete record for each day reposed NORDIC #1 TIH WITH 4-1/8" BIT 5"6 6779' MW:11.0 WBM MOVE RIG FROM 2K-26. ACCEPT RIG ON 2K-9 @ 1700 H.RS, 4/4/90. ND TREE, NU BOPE TEST BOPE TO 3000 PSI. PU BHA INCL 4-1/8" BIT, TIH TO DRILL OUT CEMENT IN LINER. DISPLACE BRINE OUT OF WELL WITH 11.0 PPG MUD. DAILY:S30,352 CUM:$1,029,211 ETD:S1,029,211 EFC:$1,236,000 POOH WITH BIT 5"@ 6779' MW:11.0 NaC1/NaBr FINISH TIH WITH BIT. TAG FILL @ 6013' (NORDIC RKB). DRILL CEMENT FROM 6013' TO 6040'. SET BACK KELLY, RIH DOWN TO 6420'. PU KELLY, WASH DOWN THRU STRINGERS FROM 6420' TO 6706'. (NORDIC RKB IS 12' LESS THAN DOYON SO 6706' IS AT THE LANDING COLLAR). DISPLACE MUD OUT OF HOLE WITH 11.0 NACL/NABR BRINE. STRAP OUT OF HOLE IN PREP FOR CBL. DAILY:S28,147 CUM:$1,057,358 ETD:S1,057,358 EFC:$1,236,000 POLISH LINER TIE-BACK P 5"6 6779' MW:11.0 NaC1/NaBr STRA1~ DP OOH, PBTD CORRECTED TO 6696'. RU HLS LOGGING UNIT. RUN CBL FROM 6707'-5956', CEMENT BOND OK, NO SQZ NECESSARY. RIH WITH GYRO, UNABLE TO GO BELOW LINER HANGER. LOG FROM LINER TOP TO SURFACE. REMOVE TOOL CENTRALIZER, RIH AND TOOL MADE IT TO BOTTOM , LOG GYRO FROM 6700' TO TOP OF LINER. RD HLS UNIT. PU BAKER POLISH MILL, RIH AND POLISH TIE-BACK RECEPTACLE ON LINER HANGER IN PREP FOR INSTALLING TIE-BACK PACKER. DAILY:S49,708 CUM=$1,107,066 ETD=S1,107,066 EFC=$1,236,000 WAIT ON 3-1/8" DC'S 5"6 6779' MW:11.0 NaC1/NaBr POLISH TIE-BACK RECEPTACLE ON LINER HANGER. TOL @ 6032' NORDIC RKB. POOH W/ MILL. RIH WITH BAKER TIE-BACK PACKER, SET PACKER INTO TIE-BACK RECEPTACLE. TEST ANNULUS TO 1000 PSI, GOOD. TEST THRU DP TO 1000 PSI, GOOD. ROTATE TO RELEASE RUNNING TOOL FROM PACKER. POOH WITH DP AND RUNNING TOOL. RU HLS PERF UNIT. RIH WITH 3-3/8" GUN #1, UNABLE TO GO BELOW LINER HANGER @ 6044'. POOH, REMOVE BOWSPRING, STILL COULD NOT GO BELOW 6044'. POOH, RD HLS. CALL TRISTATE TO RETURN 3-1/8" DC'S FOR CLEAN OUT TRIP. DAILY:S55,896 CUM:$1,162,962 ETD:S1,162,962 EFC:$1,236,000 RIH WITH PERF GUN %2 5"@ 6779' MW:11.0 NaC1/NaBr PU 3-5/8" MILL AND DC'S. RIH AND TAG BRIDGE @ 6030', PUSH TO BOTTOM. WASH OUT FILL FROM 6670' TO PBTD OF 6696'. CIRC HOLE CLEAN, POOH. RU HLS PEI~F UNIT. RZH WITH 3-3/8" GUN %1. SHOT 6542'-6558' @ 4SPF, 180 DEGREE PHASING. POOH. RIH WITH GUN 92, TOOL FAILURE, DIRECTIONAL READOUT NOT WORKING. POOH W/ GUN %2, REMOVE DIRECTIONAL TOOL. RIH WITH GUN %2 WITHOUT DIRECTIONAL TOOL. The above is ~,g.~rect DAILY: $28,807 Slgnatu re~~..~ ~ For form preparatioP/~r)~d ~istribution, ~ see Procedures Ma u~[.~l~, Section 10, Drilling, Pages 86 and 87. CUM: $1,191,769 ETD: $1t 191t 769 EFC:~1,236,000 AR3B-459-1-D Number all daily well history forms consecutively as they are prepared for each well. iPage no. ARCO O~ and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or wall is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District I State ARCO ALASKA I[qC. I AK Field County or Parish NORTH SLOPE Lease or Unit ADL: 25588 ALK: 2674 ITitle COMPLETIONS Well no. 2K-~ KUPARUK RIVER UNIT Auth. or W,O. no. AK3641 Operator A.R.Co. W.I. ARCO 55.8533 Spudded or W,O. begun Date SPUD 07/21/89 Date and depth as of 8:00 a.m. 04/10/90 (17) TD: 6800 PB: 6689 SUPV:GB Complete record for each day reported NORDIC #1 Iotal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our I Prior status if a W,O. I 00:00 RIG RELEASED 5"@ 6779' MW:11.0 NaCl/NaBr SHOT PERF GUN #2; 6532'-6558', 4 SPF, 180 DEGREE PHASING, NAVIGATION TOOL DID NOT WORK ON GUN #2. ALL SHOTS FIRED, GUN #1 HAD 4 SHOTS MISFIRE. GUN #1 HAD 139 DEGREE CCW FROM TOP OF HOLE ORIENTATION, TARGET WAS 137 DEGREE CCW. POOH AND RIG DOWN HLS. RUN 3-1/2" COMPLETION WITH MULESHOE TUBING TAIL @ 6042' (IN 5" LINER). RU SLICKLINE AND SET PLUG IN "XN" NIPPLE. PRESSURE TBG TO 2500 PSI AND ANNULUS TO 1000 PSI TO SET BAKER "HB" PACKER. PU AND SHEAR PBR, RELAND TBG. PRESSURE TEST ANNULUS TO 2500 PSI FOR 15 MIN, OK. PRESSURE TBG TO 1000 PSI AND CLOSE SSSV. BLED TBG TO 500 PSI TO TEST SSSV, OK. RETRIEVE PLUG, RD SLICKLINE UNIT. SET BPV, ND BOPE, NU TREE, PRESSURE TEST TREE, OK. DISPLACE ANNULUS WITH 6 BBL DIESEL, DISPLACE TBG WITH 3 BBL DIESEL. RD, RELEASE RIG @ 0530 HRS, 4/10/90. MOVE TO 2K-10. DAILY:S176,576 CUM:$1,368,345 ETD:S1,368,345 EFC:$1,236,000 Old TD New TD PB Depth Released rig Date Kind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method I Official reservo r name(s) I Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T,P, C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively ~ Page no. as they are prepared for each well. I Olvl'lon of AflantlcRIchfleldCompany ADDENDUM WELL: 2K-9 5/25/9O Frac KRU "A" Sand Perfs 6532'-6558' in 10 stages as follows: Stage 1: Pmp 200 bbls YF240 Gel H20 Pre Pad @ 25 bpm 6600-4300 psi 60 bbls YF240 Gel H20 Pre Pad @ 20 bpm 3900-4025 psi and 45 bbls YF240 Gel H20 Pre Pad @ 15 bpm 3645-3990 psi and 30 bbls YF240 Gel H20 Pre Pad @ 10 bpm 3575-3980 psi Stage 2: Pmp 55 bbls Slick Diesel Flush; @ 25 bpm 4185-4720 psi ISIP: 2435 frac grade .74 perf fric 472 Stage 3: Pmp 1201 bbls YF240 Gel H20 pad @ 25 bpm 4960-4200 psi Stage 4:112 bbls YF240 Gel H20; W/2 ppg 16/20 Carbolite @ 25 bpm 4175-4000 psi Stage 5:121 bbls YF240 Gel H20; W/4 ppg 16/20 Carbolite @ 25 bpm 4000-3910 psi Stage 6:140 bbls YF240 Gel H20; W/6 ppg 16/20 Carbolite @ 25 bpm 3910-3775 psi Stage 7:161 bbls YF240 Gel H20; W/8 ppg 16/20 Carbolite @ 25 bpm 3775-3750 psi Stage 8:100 bbls YF240 Gel H20; W/10 ppg 16/20 Carbolite @ 25 bpm 3750-3769 psi Stage 9:61 bbls YF240 Gel H20; W/12 ppg 16/20 Carbolite @ 25 bpm 3760-3760 psi Stage 10:59 bbls Slick Diesel flush @ 25 bpm 3760-4184 psi Fluid to recover: 2,147 bbls Sand in zone: 141,707 lbs Sand in casing: 659 lbs Average Press 3,800 psi Date/~/~ 3/F~ by GREAT LAND DIRECTIONAL DRILLING, INC. for GYRO/DATA, INC. 04/27/90 Client .... : ARco ALASKA, INC. Field · KUPARUK I · · · · · Well · 2K-9 i I . · . · · Section at: N,41,31,W Engineer·.: DAN ADAMS MICROFILMED Computation...: RADIUS OF CURVATURE Survey Date...: 4/06/90 RKB Elevation.: 154.00 ft Reference ..... : 0490G223 , S MEAS INCLN C DEPTH DEG MN '7 100 0 14 7 200 0 16 7 300 0 30 7 400 0 23 7 500 0 39 VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE DEG MIN FROM-WELL-HEAD 100.0 -54.0 -0.0 S 53 27 E 0.1 N 0.2 E 200.0 46.0 -0.4 S 10 50 W 0.3 S 0.3 E 300.0 146.0 -1.0 S 18 37 E 1.0 S 0.3 E 400.0 246.0 -1.7 S 37 7 E 1.6 S 0.7 E 500.0 346.0 -2.6 S 20 41 E 2.4 S 1.1 E CLOSURE DL DI STNCE DEG MIN /100 0.2 N 63 17 E 0.24. 0.4 S 44 17 E 0.02 1.0 S 19 45 E 0.24 1.8 S 23 13 E 0.12 2.7 S 25 7 E 0.27 7 600 0 28 7 700 0 37 7 800 0 19 7 900 0 10 7 1000 0 13 600.0 446.0 -3.5 S 26 53 E 3.3 S 1.5 E 700.0 546.0 -4.4 S 14 18 E 4.2 S 1.9 E 800.0 646.0 -5.1 S 39 40 E 4.9 S 2.2 E 900.0 746.0 -5.5 S 26 44 W 5.3 S 2.3 E 1000.0 846.0 -5.7 S 24 41 E 5.6 S 2.3 E 3.7 S 24 46 E 0.18 4.6 S 23 55 E 0.14 5.4 S 24 22 E 0.30 5.8 S 23 9 E 0.14 6.1 S 21 53 E 0.05 7 1100 0 13 7 1200 0 23 7 1300 0 21 7 1400 0 25 7 1500 0 10 1100.0 946.0 -5.7 N 48 44 W 5.8 S 2.0 E 1200.0 1046.0 -5.2 N 2 8 W 5.3 S 1.8 E 1300.0 1146.0 -4.7 N 3 15 E 4.7 S 1.8 E 1400.0 1246.0 -4.2 N 16 16 W 4.0 S 1.8 E 1500.0 1346.0 -3.7 N 69 34 W 3.7 S 1.4 E 6.1 S 19 27 E 0.01 5.6 S 18 55 E 0.18 5.0 S 21 22 E 0.04 4.4 S 23 34 E 0.06 3.9 S 21 13 E 0.24 7 1600 0 30 7 1700 0 25 7 1800 0 49 7 19OO 5 20 7 2000 7 59 7 2100 12 16 7 2200 15 35 7 2300 17 4 7 2400 21 34 7 2500 23 23 1600.0 1446.0 -3.2 N 67 35 W 3.5 S 0.9 E 1700.0 1546.0 -2.5 N 87 45 W 3.3 -S 0.1 E 1800.0 1646.0 -1.6 N 35 49 W 2.8 S 0.8 W 1899.8 1745.8 3.5 N 10 7 W 2.1 N 2.9 W 1999.1 1845.1 13,9 N 21 40 W 13.2 N 6.1 W 2097.5 1943.5 30.8 N 30 38 W 29.0 N 13.8 W 2194.6 2040.6 54.5 N 32 20 W 49.5 N 26.4 W 2290.5 2136.5 82.3 N 33 53 W 73.1 N 41.7 W 2384.9 2230.9 115.2 N 36 28 W 100.1 N 60.8 W 2477.3 2323.3 153.3 N 38 22 W 130.4 N 84.0 W 3.6 S 14 18 E 0.33 3.3 S 1 54 E 2.9 S 16 2 W 0,~ 3.6 N 53 57 W 4 14.5 N 24 34 W 2~7 32.1 N 25 26 W 4 56.1 N 28 1 W 84.1 N 29 43 W 117.1 N 31 16 W 4~,~2 155.1 N 32 46 W 1.84 ^Survey Codes: 7/GYRO ( 2K9 ) 2K-9 S MEAS INCLN C DEPTH DEG MN 7 2600 24 3 7 2700 24 20 7 2800 24 52 7 2900 25 10 7 3000 25 26 7 3100 25 34 7 3200 25 16 7 3300 25 16 7 3400 25 16 7 3500 25 5 7 3600 21 59 7 3700 21 59 7 3800 21 53 7 3900 21 53 7 4000 21 39 7 4100 21 34 7 4200 21 14 7 4300 20 57 7 4400 20 43 7 4500 20 52 7 4600 20 19 7 4700 20 10 7 4800 20 0 7 4900 20 12 7 5000 22 3 7 5100 22 4 7 5200 21 52 7 5300 21 36 7 5400 21 55 RECORD OF SURVEY VERTICAL-DEPTHS SECTION DIRECTION~ RELATIVE-COORDINATES BKB SUB-SEA .DISTNCE DEG MIN FROM-WELL-HEAD 2568,8 2414,8 193,5 N 38 5 W 162.1 N 108.9 W 2660.1 2506.1 234,4 N 38 19 W 194,2 N 134.2 W 2751,0 2597.0 276,0 N 38 10 W 226,9 N 160.0 W 2841,6 2687.6 318,2 N 37 7 W 260,4 N 185.8 W 2932.0 2778.0 360.8 N 38 18 W 294.2 N 211,9 W 3022,3 2868.3 403,8 N 38 9 W 328,1 N 238.6 W 3112,6 2958,6 446.6 N 38 55 W 361.6 N 265.3 W 3203.0 3049,0 489,3 N 39 17 W 394,8 N 292,2 W 3293,5 3139,5 531,9 N 39 37 W 427,7 N 319,3 W 3383,9 3229,9 574.5 N 39 45 W 460.5 N 346,5 W 3475,6 3321.6 614,4 N 41 22 W 490,8 N 372,5 W 3568,4 3414,4 651,8 N 41 22 W 518,9 N 397,2 W 3661,1 3507,1 689,2 N 40 58 W 547,0 N 421,8 W 3753,9 3599,9 726,4 N 41 24 W 575,1 N 446,3 W 3846,8 3692,8 763,5 N 41 38 W 602,8 N 470,9 W 3939,7 3785,7 800,3 N 41 59 W 630,3 N 495,5 W 4032,9 3878,9 836,8 N 42 36 W 657,3 N 520,0 W 4126,2 3972,2 872,8 N 42 43 W 683.7 N 544.4 W 4219,6 4065,6 908,3 N 42 50 W 709,8 N 568,5 W 4313,1 4159,1 943,8 N 43 2 W 735,8 N 592.7 W 4406.7 4252.7 979,0 N 43 39 W 761,4 N 616.9 W 4500,5 4346,5 1013,5 'N 44 9 W 786,3 N 640,8 W 4594,5 4440.5 1047,9 N 44 15 W 810,9 N 664,8 W 4688,4 4534,4 1082.2 N 43 15 W 835.8 N 688.5 W 4781.6 4627,6 1118,2 N 40 46 W 862,5 N 712,7 W 4874,3 4720,3 1155,8 N 40 45 W 891,0 N 737,2 W 4967,1 4813.1 1193,2 N 41 19 W 919,2 N 761.7 W 5060,0 4906,0 1230,2 N 41 7 W 947,1 N 786,1 W 51.52,8 4998,8 1267,2 N 43 17 W 974,5 N 811,0 W Page 2 04/27/90 CLOSURE DL DISTNCE DEG MIN /100 195.2 N 33 54 W 0.66 236,1 N 34 39 W 0,28 277,7 N 35 11 W 0,54 319,9 N 35 30 W 0,35 362,6 N 35 46 W 0.35 405,6 N 36 2 W 0.14I') 448.5 N 36 16 W 0.33 491,2 N 36 31 W 0,07 533,8 N 36 45 W 0,06 576.3 N 36 58 W 0,18 616,1 N 37 12 W 3,12 653,5 N 37 26 W 0,00 690,7 N 37 38 W 0.11 728,0 N 37 49 W 0,06 765.0 N 38 0 W 0,24 801,7 N 38 10 W 0,10 838,1 N 38 21 W 0,34 874.0 N 38 32 W 0,28 909,5 N 38 42 W 0,24 944.9 N 38 51 W 0.16 979.9 N 39 1 W 0.56 1014.4 N 39 11 ~ 0.15 1048.6 N 39 21 ~ 0.17 1082,9 N 39 29 ~ 0.23 1118.9 N 39 34 ~ 1.88 1156,4 N 39 36 W 0,01 1193,8 N 39 39 W 0,21 1230,8 N 39 42 W 0,26 1267,8 N 39 46 W 0,43 ^Survey Codes: 7/GYRO 2K-9 S MEAS INCLN C DEPTH DEG MN 7 5500 22 24 7 5600 24 14 7 5700 24 11 7 5800 24 17 7 5900 24 1 7 6000 23 44 7 6100 23 32 7 6200 23 29 7 6300 23 9 7 6400 21 55 7 6500 21 23 7 6600 21 10 7 6700 20 1 X 6808 20 1 RECORD OF SURVEY VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE DEG MIN FROM-WELL-HEAD 5245.5 5091.5 1304.9 N 44 10 W 1001.8 N 837.1 W 5337.3 5183.3 1344.3 N 49 32 W 1028.8 N 866.0 W 5428.5 5274.5 1384.9 N 49 45 W 1055.4 N 897.2 W 5519.7 5365.7 1425.5 N 50 25 W 1081.7 N 928.7 W 5610.9 5456.9 1465.9 N 50 42 W 1107.7 N 960.3 W. 5702.4 5548.4 1505.9 N 50 50 W 1133.3 N 991.6 W 5794.0 5640.0 1545.4 N 51 10 W 1158.5 N 1022.8 W 5885.7 5731.7 1584.9 N 47 25 W 1184.5 N 1053.0 W 5977.5 5823.5 1624.4 N 44 59 W 1211.9 N 1081.6 W 6069.9 5915.9 1662.7 N 42 14 W 1239.7 N 1108.0 W 6162.8 6008.8 1699.5 N 38 51 W 1267.7 N 1132.0 W 6256.0 6102.0 1735.7 N 35 48 W 1296.6 N 1154.0 W 6349.6 6195.6 1770.6 N 31 29 W 1325.8 N 1173.5 W 6451.1 6297.1 1807.0 N 31 29 W 1357.4 N 1192.8 W Page 3 04/27-/90 . CLOSURE DL DISTNCE DEG MIN /10Q 1305.5 N 39 53 W 0.51 1344.8 N 40 5 W 2.05 1385.2 N 40 22 W 0.06 1425.7 N 40 39 W 0.14 1466.0 N 40 55 W 0.27 1505.9 N 41 11 W 0.27 1545.4 N 41 26 W 0.22 1584.9 N 41 38 W 0.60 1624.4 N 41 45 W 0.50 1662.7 N 41 47 W 1.29 1699.6 N 41 46 W 0.70 1735.7 N 41 40 W 0.45 1770.6 N 41 31 W 1.26 1807.0 N 41 18 W 0.00 'Survey Codes: 7/GYRO X/EXTRAPOLATED 2K-9 SUBSEA DEPTH 0 100 2OO 300 400 50O 600 700 8OO 9OO 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 Page 4 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 04/27/90 MEAS BKB MD-TVD VERT DEPTH DEPTH D IFF CORRECT 154 154 0 0 254 254 0 0 354 354 0 0 454 454 0 0 554 554 0 0 654 654 0 0 754 754 0 0 854 854 0 0 954 954 0 0 1054 1054 0 0 1154 1154 0 0 1254 1254 0 0 1354 1354 0 0 1454 1454 0 0 1554 1554 0 0 1654 1654 0 0 1754 1754 0 0 1854 1854 0 0 1955 1954 i 0 2056 2054 2 1 2158 2154 4 2 2262 2254 8 4 2367 2354 13 5 2475 2454 21 8 2584 2554 30 9 2693 2654 39 10 2803 2754 49 10 2914 2854 60 10 3024 2954 70 11 RELATIVE COORDINATES FROM WELL HEAD 0.11 S 0.29 E 0.61 S 0.29 E 1.37 S 0.52 E 2.00 S 0.93 E 2.95 S 1.35 E 3.76 S 1.72 E 4.66 S 2.04 E 5.14 S 2.32 E 5.47 S 2.23 E 5.81 S 2.21 E 5.60 S 1.90 E 4.97 S 1.82 E 4.34 S 1.82 E 3.75 S 1.59 E 3.59 S 1.20 E 3.33 S 0.45 E 3.15 S 0.36 W 1.12 S 1.73 W 7.69 N 4.20 W 21.32 N 9.67 W 40.36 N 20.64 W 63.89 N 35.60 W 90.61 N 53.80 W 122.67 N 77.76 W 156.84 N 104.82 W 192.12 N 132.50 W 228.04 N 160.85 W 265.10 N 189.30 W 302.44 N 218.43 W 2K-9 Page 5 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 04/27/90 SUBSEA 'MEAS BKB MD-TVD VERT DEPTH DEPTH DEPTH DIFF CORRECT 2900 3135 3054 81 11 3000 3246 3154 92 11 3100 3356 3254 102 11 3200 3467 3354 113 11 3300 3577 3454 123 10 3400 3500 3600 3700 3800 3685 3792 3900 4008 4115 3554 131 8 3654 138 8 3754 146 8 3854 154 8 3954 161 8 RELATIVE COORDINATES FROM WELL HEAD 339.99 N 376.86 N 413.40 N 449.68 N 484.45 N 247.90 W 277.57 W 307.44 W 337.51 W 366.20 W 514.53 N 544.74 N 575.10 N 604.99 N 634.49 N 393.38 W 420.04 W 446.37 W 472.82 W 499.20 W 3900 4000 4100 4200 4300 4223 4330 4437 4544 4650 4054 169 7 4154 176 7 4254 183 7 4354 190 7 4454 196 7 663.31 N 691.56 N 719.41 N 747.23 N 774.12 N 525.56 W 551.60 W 577.37 W 603.20 W 628.83 W 4400 4500 4600 4700 4800 4757 4863 4970 5078 5186 4554 203 7 4654 209 6 4754 216 7 4854 224 8 4954 232 8 800.40 N 826.33 N 853.43 N 884.75 N 915.49 N 654.47 W 680.16 W 706.24 W 731.82 W 757.99 W 4900 5000 5100 5200 5300 5294 5401 5509 5618 5728 5054 240 8 5154 247 8 5254 255 8 5354 264 9 5454 274 10 945.18 N 974.85 N 1004.55 N 1033.73 N 1062.91 N 784.68 W 811.33 W 839.24 W 871.66 W 905.86 W 5400 5500 5600 5700 5838 5947 6056 6165 5554 284 10 5654 293 9 5754 302 9 5854 311 9 1091.63 N 1119.86 N 1147.72 N 1173.20'N 940.54 W 975.05 W 1009.10 W 1044.36 W 2K-9 Page 6 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA MEAS BKB MD-TVD VERT DEPTH DEPTH DEPTH DIFF CORRECT 58OO 5900 6000 6100 6200 04/27/90 6274 6383 6491 6598 6705 5954 320 9 6054 329 8 6154 337 8 6254 344 7 6354 351 7 RELATIVE COORDINATES FROM WELL HEAD 1203.34 N 1233.12 N 1262.72 N 1293.83 N 1327.21 N 1075.74 W 1105.41 W 1132.20 W 1156.00 W 1174.30 W 2K-9 Page 7 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL 04/27/90 MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DEPTH DEG MN BKB SUB-S DIST DEG MIN FROM-WELLHEAD DIST DEG MIN DL/ 100 2000 7 59 1999 1845 14 N 21 40 W 13 N 3000 25 26 2932 2778 361 N 38 18 W 294 N 4000 21 39 3847 3693 764 N 41 38 W 603 N 5000 22 3 4782 4628 1118 N 40 46 W 863 N 6000 23 44 5702 5548 1506 N 50 50 W 1133 N 6 W 15 N 24 34 W 2.7 212 W 363 N 35 46 W 0.3 471 W 765 N 38 0 W 0.2 713 W 1119 N 39 34 W 1.9 992 W 1506 N 41 11 W 0.3 by GREAT LAND DIRECTIONAL DRILLING, INC. for GYRO/DATA, INC. 04/27/90 Client .... : ARCO ALASKA, INCr. Field ..... : KUPARUK Well ...... : 2K-9 Section at: N,41,31,W Engineer..: DAN ADAMS Computation...: RADIUS OF CURVATURE Survey Date...: 4/06/90 RKB Elevation.: 154.00 ft Reference ..... : 0490G223 INTERPOLATED MARKERS REPORT Surface Location: 96 NSL 94 WEL S2 T10N R8E MARKER IDENTIFICATION MEAS INCLN DEPTH DEG MN VERT-DEPTHS SECT BKB SUB-S DIST DIRECTION REL-COORDINATES DEG MIN FROM-WELLHEAD 9 5/8" CASING 5" LINER BEGIN 7" CASING TOP KUPARUK C BASE KUPARUK C 2986 25 24 6026 23 41 6246 23 20 6474 21 31 6481 21 29 2919 2765 5726 5572 5928 5774 6139 5985 6145 5991 355 N 38 8 W 1516 N 50 55 W 1603 N 46 18 W 1690 N 39 44 W 1693 N 39 30 W 290 N 208 W 1140 N 1000 W 1197 N 1066 W 1260 N 1126 W 1262 N 1128 W TOP KUPARUK A BASE KUPARUK A PBTD 5" LINER END EXTRAPOLATED TD 6495 21 24 6632 20 48 6689 20 9 6779 20 1 6808 20 1 6158 6004 6286 6132 6339 6185 6424 6270 6451 6297 1698 N 39 1 W 1747 N 34 25 W 1767 N 31 57 W 1797 N 31 29 W 1807 N 31 29 W 1266 N 1131 W 1306 N 1161 W 1323 N 1171 W 1349 N 1188 W 1357 N 1193 W Snast Len Oirs£ty'onel Ory'lling, Marker Identification MO N/S E/N A) KB 0 0 N 0 E 9 5/8' CASING 2986 290 N 208 W 5' LINER BEGIN 6026 i140 N iO00 W D) 7' CASING 6246 ~97 N i066W TOPKUPARUKC 6474 ~260 N 1126, BASE KUPARUK C 648! t262 N ~28 W H) BASE KUPARUK A 6632 ~306 N ~16! W I) PBTD 6689 i323 N ~7! W J) 5' LINER END 6779 .~349 N ~lSB W K) EXTRAPOLATED TD 6808 ~357 N li93 W PLAN ARCO ALASKA, INC. 2K-9 CLOSURE ..... : 1807 ft N 41 t8 DECLINATION.: 0,0 E SCALE ....... : I knch= 300 feet DRAWN ....... : 04/30/90 ~950 1850 ~500 t350 1200 i050 900 750 600 450 300 i50 t50 i650 i500 1350 i200 i050 900 750 600 450 300 i50 0 i50 <- WEST ' EAST -> · , 8?sat Lan~ Z2/nsct/~nal L~n/iI~E, £nc. <KB>o 400 800 t200 i600 2000 24OO 2800 3200 ,T 3600 V D 4000 4400 4800 5200 56O0 6000 6400 6800 7200 40O VERTICAL SECTION VIEW ARCO ALASKA, INC. , - 2K-9 Section at: N 41 31 .... TVD Scale.' I inch: Dep Scale.' Drawn ' 04/30/9( -- Marker Identification I A) KB i......... B) 9 518" CASING C] 5" LINER BEGIN D] 7" CASING E) TOP KUPARUK C ~ ~ -' -- ...... F) BASE KUPARUK C G) TOP KUPARUK A H) BASE KUPARUK A I) PBTD J) 5" LINER END K) EXTRAPOLATED TD · , ,[ , ., w floo feet 8o0 feet MD TVD DEPRT ]NCLN 0 0 0 0.00 ]986 29t9 355 25.39 6026 5726 15t6 23.69 246 5928 1603 23.33 6474 6t39 t690 2i.52 648t 6i45 t693 21.48 95 6158 1698 2t.41 i32 6286 1747 20.80 i689 6339 t767 20. t5 6779 6424 1797 20.02 6808 645t 1807 20.02 0 400 800 1200 i600 2000 2400 2800 3200 3600 4000 4400 Departure I~E[IMIT # _.~ .- ,~-'~ WELL NAME ...,~/~ ~ COMPI_ETION DATE __, ~!. / ~'./ ~ ~ CO. C. ONTACT .__L~hcck off or li~t data as it is ~cccivcd ! ...... - ' ~orcd int¢~~%ls .... d'r~'ditCll i,,t.,~' '--~~ '1 disital data .......... ........ , ............ I .... LO~ 1YI:,E ......... ~Ui'] .... '::'::: ......... ':'::::-:I':i-'~Itv~'LS' ' sCALE NO. I ~'i .............. / , .... , .. ~ ~ ~~ ' ., , 4) / .. ~., ~ ~., -, .... ~B~ ................... ........... ............................... . ............. ~ ....... ~. ~ . ...... , .................. ....... , ..... .......... ................... ..... ........ · .... · ~ ~} ...... . .... . ............. .... ......... , .............. .... , .... ........... 19} ,,, ~1~ i ~ ~ , ~,, , ,, ......... ·. ~,,, ARCO Alaska, Inc. Date: May 18, 1990 Transmittal #: 7762 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 K - 1 9 Pulse Echo Cement Evaluation PET 4 - 3 0 - 9 0 81 0 0-1 0 4 6 6 2 K - 1 8 Acoustic Cement Bond Log 4 - 2 4 - 9 0 7 1 0 0 - 7 7 8 0 2 K - 0 9 Acoustic Cement Bond Log 4 - 6 - 9 0 5 9 5 6 - 6 7 0 7 2K-09 Collar Log 4-8-90 6000-6685 Receipt Acknowledged' - .... ~Date' DISTRIBUTION: Drilling NSK state of Alaska(.i. Sepi~!.j., MEMORAND,JM State of Alaska ALASKA OIL AA!D G~ CONSEPJ~ATIOM CO~V~ISSION T: ' .~ - ~1~ TO: ~..,.onnle C. Smz~? DATE: April ll 1990 COmmissioner / ..... ~/ , roLE NO: JT. HH. 411.3 TELEPHONE NO: THRU: SUBJECT: BOP Test AAI KRU 2K-09 Permit. No 89-0073 Kuparuk R3z Field FROM: Harold R. Hawkins Petroleum Inspector Wednesda-f_~A_p~il 4, 1990: I witnessed the BOP test on AAI KRU 2K-09. T~~B~0-~test was ~ with one failure. i filled out an AOGCC field report which is attached. In summary, the BOP Test on AAI KRU 2K-09 was satisfactorily performed. Attachment 02-001A (Rev. 8/85) r 5/84 Inspector STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Well ' / ' Operator Wen · Location: Sec T R M Drilling Contractor Representative y~asing Set Representative Location, General ~/~ Well Sign General Housekeeping__ l~ Rig Reserve Pit Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE S tack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Test Pressure J66~ 3~~ ACCUMULATOR SYSTEM ' '~ ' Full Charge Pressure psig~~'-~ Pressure After Closure psig pump incr. clos. pres. 200 psiR "-- mingJ sec. Full Charge Pressure Attained: / min ~J sec. N al p s.KA y Remote ~ ~linds switch cover ,, Kelly and Floor Safety Valves Upper KellM Lower KellM Ball Type Inside BOP Choke Manifold Test Pressure ~.~ Test Pressure ~ Test Pressure .~z~ Test Pressure No. Valves / ~x ' Kill Line Valves Check Valve Test Results: Failures. No. flanges ~ ~ Adjustable Chokes Hvdrauicall~ .erated choke Test Time Repair or Replacement of failed equipment to be made within ~ days and Inspector/ Commission office notified. Remarks: '/ p'/~,~,f ~.,~; ~C~ ~,ttf&~L~ ~.~//"~.D ~ ~ ~~[~ ~ V ~~.~/~ W Distribution orig. - AO&GCC cc - Operator cc - Supervisor ~ OIL AND GAS CONSERVATION COk 31ON APprlCATION FOR SUNDRY APPROVAL I{ 16 IN A [ 1. Type of Bequest: Abandon Suspend _ Operation Shutdown X Re-enter suspended well _ .~ Alter casing _ Change approved program _ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK Plugging _ Repair well _ Pull tubing_ 5. Type of Well: Development X Exploratory _ I Stratigraphic _ 99510 Service _ 4. Location of well at surface 96' FNL, 94' FWL, Sec. 2, T10N, R8E, UM At top of productive interval Time extension _ Stimulate Variance Perforate _ Other _ 6. Datum elevation (DF or KB) 1366' FSL, 1173 FWL, Sec. 2, T10N, R8E, UM At effective depth 1448' FSL, 1252' FWL, Sec.2, T10N, R8E, UM At total depth 1447' FSL, 1280' FWL, Sec. 2, T10N, R8E, UM 12. Present well condition summary Total Depth: measured (approx) true vertical Effective depth: measured (approx) true vertical 6800' 6441' 6689' 6338' (approx) (approx) (approx) feet Plugs (measured) feet None feet Junk (measured) feet None RKB 154 7. Unit or Property name Kuparuk River Unit feet 8. Well Number 2k-9 9. Permit number 89-73 10. APl number 50-1 03-201 08 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 80' 2950' 6213' 753' measured None true vertical None Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) Size 16" 9 5/8" 7" 5" Cemented 179 Sx AS I 925 Sx AS III & 400 Sx Class G 200 Sx Class G 110 Sx Class G Measured depth True vertical depth (approx) 115' 115' 2986' 2920' 6246' 5925' 6026'-6779' 5723'-6422' RECEIVED AUG 2 1989 Alaska .0il & Gas Cons. Commission ~ ~nnhnr~n" 13. Attachments Description summary of proposal _ Detailed operation program X B~'I~'~'I~'~I~_ 14. Estimated date for commencing operation October, 1989 16. If proposal was verbally approved Name of approver 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 ~)~ '~-~~..,-~ Title Area Drilling Engineer FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance B Mechanical Integrity Test_ Subsequent form require ORIGINAL SIGNED BY Approved by the order of the Commission LONNIE C. SMITH Form 10-403 Rev 06/15/88 10- q~/-/ Commissioner IApproval No. SUBMIT IN TRIPLICATE Approved Copy Returned ARCO-,.,.. and Gas Company ~, Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District J County, parish or borough ARCO ALASKA INC, - J NORTH SLOPE I Lease or Unit KUPARUK RIVER I ADL: 25588 AKL: 2674 ~Title I DRILLING IStat~%K IWell no. Field Auth, or W.O. no. AK3641 Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 07/22/89 ( TD: 2588'( 2 SUPV:JR/TM 07/23/89 ( TD: 3011'( SUPV:JR/TM 07/24/89 ( TD: 5318'( 2 SUPV:JR/TM 07/25/89 ( TD: 6236'( SUPV:JR/TM 07/26/89 ( TD: 6253'( SUPV:JR/TM IDate JHour 07/21/89 12:00 Complete record for each day reported DOYON 14 1) 588) 2) 423) 3) 307) [) )18) ~) 17) The ab~)-i~ correct , For form properatlo~{ a~it'~:t~diStribution, ~ see Procedures Ma~.ual,JSection 10, Drilling, Pages 86 an~.87. rARCO w.I. 55.8533 Prior status if a W.O. DRLG F/2588 9-5/8"@ 2986' MW: 9.2 VIS: 75 MIRU, ACCEPT RIG AT 0730 7/21/89, NU DIVERTER SYSTEM, RU FLOOR, PU BHA, CUT & SLIP DRLG LINE, FUNCTION TEST DIVERTER SYSTEM, DRLG F/115-2588 DAILY:S68,300 CUM:$68,300 ETD:$68,300 EFC:$1,236 NU BOPE STACK 9-5/8"@ 2986' MW: 9.3 VIS: 76 DRLG F/2588-3011,CIRC BTMS UP, PUMP DRY JOB, SHORT TRIP TO HWT, TIH, CIRC, DROP SINGLE SHOT, PUMP PILL, TOH, LD BHA, RU & RUN 77 JTS 9-5/8" CASING, RU CMT HEAD, WASH 30' TO BTM, CIRC. 2 VOLS, PUMP 80 BBLS H20, TEST LINES,PUMP 320 BBL SLURRY (9258KS ASIII 12 PPG), DROP PLUG, PUMP 83 BBL SLURRY (400 SKS G) DROP PLUG, DISPLACE W/224 BBL H20, BUMP PLUG, FLOATS HELD, 9.8 PPG RETURNS,ND DIVERTER SYSTEM, DO TOP JOB, NU CASG SPOOL, NU BOPE DAILY:S206,264 CUM:$274,564 ETD:S274,564 EFC:$1,236 DRLG F/5318 9-5/8"@ 2986' MW: 9.2 VIS: 35 RU BOPE, TEST 3000, INSTALL WEAR RING, PU BHA, TIH, CIRC AT FC, DRLG FC AND CMT TO 2970, TEST CSG TO 2000, DRLG FS AND 10' NEW HOLE, CHANGE OVER TO LSND MUD (8.4 PPG), PERFORM OPEN HOLE LEAKOFF TO 12.5 PPG, DRLG FROM 3021 TO 5318 DAILY:S48,441 CUM:$323,005 ETD:S323,005 EFC:$1,236 DRLG FZ6236 9-5/8"@ 2986' MW:10.2 VIS: 45 DRLG F/5318 TO 6130(10 BBL/HR FL), MONITOR WELL(FL INC TO 50 BBL/HR), TOH, LD TURBINE AND BHA, PU ROT BHA, TIH TO CSG SHOE, CBU, TIH TO 5170, MONITOR WELL (FL 60 BBL/HR), TIH TO TIGHT SPOT AT 5830, REAM F/5830 TO 6130, INC MW TO 10.1 AND ADD LCM TO SYS(FL DOWN TO ZERO), REAM F/6130 TO 6236 DAILY:S83,207 CUM:$406,212 ETD:S406,212 EFC:$1,236 POH LD DP 7"@ 6246' MW: 9.5 VIS: 39 DRLG F/6236-6253,CIRC & MIX LCM, SPOT LCM PILL, MONITOR WELL(STABLE),POH TO CSG SHOE, CIRC(STABLE),TIH, CIRC(50 BBL/HR FL),CONT. TIH, TIGHT SPOT AT 6020, REAM F/6020-6253', CIRC & CONDITION MUD TO 9.5 PPG (PREP FOR 7" CSG), DROP SURV, TOH TO CSG SHOE, PUMP UP SURV, TIH, REAM F/6230-6253, CIRC, PUMP DRY JOB POH LD DP DAILY:S76,165 CUM:$482,377 ETD:S482,377 EFC:$1,236 TESTING BOPE 7"@ 6246' MW: 9.5 VIS: 40 CONT. POH LD DP & BHA, PULL W/B, RU & RIH W/159 JTS 7" 26# J55 BTC CSG, SET AT 6246, CIRC. & RECP CSG, PUMP 20 BBL SPACER 3000, 200 SX CL G CMT W/ 3%KCL +.9%D127+.3%D13+.2%D46 AT 15.8 PPG (41 BBL SLURRY).,.DISPLACED W/9.5 PPG MUD, BUMP PLUG TO 3500 PSI, FLOATS HELD, FULL RETURNS, ANNULUS FLOWED SLIGHTLY BUT STOPPED, PU BOP STACK, SET SLIPS ON 7", NU TBG AR3B-459-1-D Number ail daily well history forms consecutively , no. las they are prepared f ..... h wel. IPage I 1 ARCO ~... and Gas Company Daily Well History--Interim Instn~ctiona: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number ail drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lnlerim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District Field Date and depth as of 8:00 a.m. I County or Parish IState ARCO ALASKA INC. I NORTH SLOPE AK ! I Lease or Unit KUPARUK RIVER I ADL: 25588 AKL: 2674 Complete record for each day while drilling or workover in progress DO¥ON 1 4 SPOOL, TEST TO 3UUU PSI, NU DOUBLW. STUDDED ADAPTER," CHANGE RAMS TO 3-1/2", RU & TEST BOPE TO 3000 PSI DAILY: $171,555 CUM: $653,932 ETD: $653,932 EFC:$1,236 07/28/89 ( TD: 6416'( SUPV:CD 07/29/89 ( TD: 6765'( SUPV:CD 07/30/89 ( TD: 6800'( SUPV:CD 07/31/89 ( TD: 6689'( SUPV:CD 7) 163) DRILLING F/6416 7"@ 6246' MW:10.3 VIS: 39 CONT. TEST BOPE TO 3000 PSI, INSTALL W/B, PU 4-1/4 KELLY, PU BHA & 3-1/2 DP, TIH, TAG FC @6165, TEST 7" CSG TO 3500 PSI OK, DRLG FC, FS, AND 10' NEW HOLE, TO 6263, CBU, PERFORM LEAKOFF TO 12.7 PPG EMW (NO LEAKOFF), CIRC AND INCR MW TO 10.3 PPG, DRLG F/6263-6416 DAILY:S50,725 CUM:$704,657 ETD:S704,657 EFC:$1,236 8) 349) DRLG F/6765 7"@ 6246' MW:10.6 VIS: 38 DRLG F/6416-6496, CIRC. GAS CUT MUD OUT, DRLG F/6496-6528, CIRC GAS CUT MUD OUT, RAISE MW F/10.3 TO 10.5, DRLG F/6528-6646, CBU, TOH, PU BIT #5, TIH, CIRC OUT GAS CUT MUD, DRLG F/6646-6765 (INCR MW F/10.5 TO 10.6 WHILE DRLG) DAILY:S54,177 CUM:$758,834 ETD:S758,834 EFC:$1,236 9) 35) TIH W/5" LINER 7"@ 6246' MW:ll.0 VIS: 38 DRLG F/6765-6800, CBU, SHORT TRIP 7 STDS, CIRC GAS CUT MUD OUT, DROP SINGLE SHOT SURV, SPOT DIESEL PILL, TOH, RU SOS, RIH TO 6808 WLM, LOG DIL/SFL/GR/SP F/6800 TO 975, POH, RIH & LOG FDC/CNL/CAL F/6776-6255, POH, RD SOS, TIH W/ DP, CIRC OUT GAS CUT MUD, SPOT DIESEL PILL, TOH, RU CASING TOOLS & TIH W/5" LINER DAILY:S99,631 CUM:$858,465 ETD:S858,465 EFC:$1,236 CIRC./WOC 5"@ 6779' MW:ll.0 VIS: 39 CONT. TIH W/5" LINER (17 JTS 5" 189 NS0 LTC W/BAKER HYFLOW II HGR), PU CMT HD, TAG FILL @6770, WASH TO 6778, CIRC OUT GAS CUT MUD, PUMP 10 BBL SPACER 3000, FOLLOWED BY 110 SXS (23 BBL) CL G CMT, DISPLACED W/ 56 BBL (DID NOT BUMP PLUG) RELEASE FROM LINER, TOH 15 STDS, REV CIRC ON DP VOL, TOH, PU BIT #6, TIH TO 4972, CIRC, TIH, TAG LINER TOP AT 6019, NO CEMENT, CIRC. OUT MUD & CMT CONT MUD DAILY:S94,644 CUM:$953,109 ETD:S953,109 EFC:$1,236 IWell no. The above is c~r~ct For form preparation and dj~-t~ution see Procedures Manual Se~tio~ 10, Drilling, Pages 86 and 87 XJ AR3B-459-2-B Number ail daily well history forms as they are prepared for each well. consecutively IPage no. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test date. in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District ] State ARCO ALASKA INC. ~ AK' County or Parish NORTH ST,O?E Lease or Unit KUPARUK RIVER I ADL: 25588 AKL: 2674 2K-9 I Title I DRILLING Field Auth. or W.O. no. AK3641 IWell no. Operator I A.R.Co. W.I. ARCO I 55.8533 Spudded or W.O. begun ~ Date SPUD I 07/21/89 Date and depth as of 8:00 a.m. 08/01/89 ( 1 TD: 6689'( SUPV:CD Complete record for each day reported DOYON 14 Iotal number of wells (active or inactive) on this, ost center prior to plugging and J bandonment of this well J our I Prior status if a W.O, 12:00 I RIG RELEASED 5"@ 6779' MW: 0.0 VIS: PT LINER LAP TO 2500 PSI, BLED TO 1300 PSI IN 30 MIN., RETEST TO 2500, BLED TO 2400 PSI IN 30 MIN, TOH (STD BACK 2000') LD DP, TIH TO 2000', DISPLACE WELL TO 11.0 PPG BRINE F/2000'-0', TOH LD DP, PULL W/B, CHANGE RAMS TO 5", NU LOWER TREE, RIG RELEASED 2400 7/31/89 DAILY:S45,750 CUM:$998,859 ETD:S998,859 EFC:$1,236 Old TD New TD Released rig Date PB Depth Kind of rig Classifications (oil, gas, etc.) ~ Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date- Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per clay Pump size, sPM X length Choke size ' T.P. C.P. Water'% GOR Gravity Allowable Effective date corrected Signature ( J 0--7'~,,4 ~ sF~ fpO;~ ,~ruer Pe ~ r a~l 'aO~u aa,~: inb u~ ~)o,n, ~ ' Drilling, Pages 86 and 87, AR3B-459-3-C INumberall daily well history forms consecutively no. Page as they are prepared for each well. I I I Dl,~lalon of Atl&ntlcRIchfleldCompan¥ ARCO Alaska, Inc. Date: August 4, 1989 Transmittal #: 7531 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 K - 0 9 OH EDIT Tape and Listing .8 - 0 1 - 8 9 # 7 3 4 1 3, Receipt Acknowledged' DISTRIBUTION' State of Alaska Craig Suchland ARCO Alaska, Inc. Date: August 4, 1989 Transmittal #: 7532 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. 2K-09 2K-09 2K-09 2K-09 2K' 09~ Cyberlook · 5" Dual InduCtion - SFL ,. 2" Dual Indcution - SFL 2" & 5" Raw FDC 2" & 5" Porosity FDC Please acknowledge receipt and return 7-30-89 6400-6730 7-29-89 975-6800' 7-29-89 ' 975-6800 7-29-89 6255-6776 7-29-89 6255-6776 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Franzen D&M State of Alaska(+sepia) L. Johnston(vendor package) AL/''--~''~, OIL AND GAS CONSERVATION COMM' APPLICATION FOR SUNDRY APPHOVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program X Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate m Pull tubing _ Variance _ Perforate _ Other 6. Datum elevation (DF or KB) 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 96' FSL, 94' FEL, Sec. 2, T1ON, R8E, UM At top of productive interval 1320' FSL, 1200' FEL, Sec. 2, TI ON, R8E, UM At effective depth At total depth 1407' FSL, 1278' FEL, Sec. 2, TI ON, R8E, UM RKB 154' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2K-9 9. Permit number 89-73 10. APl number 5o-1 03-201 08 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical feet Plugs (measured) feet feet Junk (measured) feet Casing Length Size Cemented Structural Conductor Surface 2951 ' 9 5/8" To Surface Intermediate 621 8' 7" Up to 5000' Production Liner 697' 5" 6750'-6053' Perforation depth: measured '.~.a~[f~d~dePt~ ~True vernal ~pth 2986' 2943' 6253' 5936' 6750' 6392' 13. true vertical Tubing (size, grade, and measured depth Due to lost circulation problems encountered above the Kuparuk sands, 7" intermediate casing will be run to Packers and SSSV (type and measured depth) to isolate these zones. A 5" liner will then be run through the Kuparuk. Attachments Description summary of proposal _ Detailed operation program ~ BOP sketch _ 14. Estimated date for commencing operation S.131,1dded well 7/22/89 16. If proposal was verbally approved Russ Douglas Name of approver 7/26/89 Date approved 15. Status of well classification as: Oil __ Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~'~~--~"~~,,,v-' Title Area Drilling Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test m Location clearance ~ Mechanical Integrity Test_ Subsequent form require ORIGINAL SIGNED BY Approved by the order of the Commission LONNIE C. SMITH Commissioner IApproval No.~. Returned ...... Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE July 7, i989 Telecopy No. (907) 276-7542 P J Archey Area Drilling Engineer ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2K-9 ARCO Alaska Inc Permit # 89-73 Surf Loc 96'FSL, 94'FEL, Sec 2, T10N, RSE, UM Btmhole Loc 1407'FSL, 1278'FEL, Sec 2, T10N, RSE, UM Dear Mr Archey: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not ~xempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pe~itting dete~inations are made. To aid us in scheduling field work, please notify this office 24 hours prior to co~encing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Very truly ~~, ~'~ . I' ~' / ,~,~" ~ ~ / / ...... . ........ C V Chatterton Chairman Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO~ISSION jo Enclosure C: Department of Fish & Game, Habitat Section - w/o encl Department of Enviro~nental Conservation - w/o encl .,----. STATE OF ALASKA ..--, ALASKA'~ L AND GAS CONSERVATION C~, ,MISSION PERMIT TO DRILL 20 AAC 25.005 Redrill Zl lb. Type of well. Exploratory ~ Stratigraphic Test ~ Development Oil ~ Deepenr-I Service _- la. Type of work Drill Re-Entry Developement Gas ~_ Single Zone ~, Multiple Zone 2. Name of Operator ARCO Alaska, Inc, 3. Address p:n_ Rn~ 10{3~,R13; Annhorage; AK 99510-0360 4. Location of well at surface 96' FSL, 94' FEL, Sec. 2, T10N, R8E, UM At top of productive interval 1320' FSL, 1200' FEL, Sec. 2, T10N, R8E, UN At total depth 1407' FSL~ 1278' FEL~ Sec. 2~ T10N~ R8E~ UM 12. Distance to nearest ! 13. Distance to nearest well property line J 2K-8,2K-10 Conductors _ '~R7~, ' ~ TI') feet 25' at: .~,,rface feet 16. To be completed for deviated wells Kickoff depth1950 feet Maximum hole angle 240 18. Casing program size Hole Casing 24" 16" 12~+" 9-5/8 8½" 7" Specifications Weight I Grade [Coupling i Length 62.5#JH-40 J Weld J 80 1 I HF-ER~ 26'0#1J-551 BTClHF-ER" !6716 , MD 35' 35' 34' 5. Datum Elevation (DF or KB) RKB 154' Pad 118' 6Lfeet 6. Property Designation ADL 25588, ^LK 2674 7. Unit or property Name Kuparuk River Unit 8. Well number 2K-9 9. Approximate spud date July 10, 1989 10. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 11. Type Bond(see 20 AAC 25.025) Statewi de Number # U630610 Amount $200,000 14. Number of acres in property 15. Proposed depth (MD and TVD) 6750 ' ND 2560 6392' TVD .... feet 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface I 661 psig At total depth (TVD)3158 psig Setting Depth Top Bottom i Tva ] MD I TVa 35' ! 115'I 115' 3 '1 I Quantity of cement (include stage data) ±200# CF 6755x ASZZ! & 400sx Class G 200Sx Cl'a's's~--~-{i~ Io~ or G 5UU' ab'o'~ K~aruk 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 Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented measured true vertical Measured depth True Vertical depth RECEIVED JUL. 6 ]989 Alaska 0il & 6as Cons. C0mmissi0~ Am;h0rage 20. Attachments Filing fee .1~ Property plat [] BOP Sketch I~ Diverter Sketch ~ Drilling prograrn ~ Drilling fluid program ,~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Commission Use Only pD1/5 "~"/~/~ Permit Number I APl number ]Approval date ~'" 7 ? 5 0--/O,.~ - 4~_P/~ ¢ 0 7 / 0 7 8 9 Conditions of approval Samples required. [] Yes ']~No Mud log require~ [] Yes No Hydrogen sulfide.measures [] Yes 5;~"No Directional survey required ~,~.Yes [] N6 Required working pre~,~ure for BO~--~ E32M; J~ 3M; [] 5M; [] 10M; [] 15M Other: /'~/~.)//,/~ ~ ,// ~ Approved by (~._. ,,/~', L ~"~, ~ Commissioner by orderof the commission F~rm 10-401 Rev.'"f2:~-l-~5 ~ ' ' / Date ISee cover letter for other requirements ~:tbem i~t~l~n~e ARCO' ALASKA, Ineo Pad 2K. Well Not g Pr'opoeed Kupar~uk Field, Not'th Slope, Alaeka O RKB ELEVAI'[ONt 154' Ill r'll 1 000 _ 2000 _ :3000 _ 4000 _ 5000 _ 6000 _ 7'000 B/ PERMAFROST TVD--1424 T/ UGNU SNDS TVD=1544 KOP TVD-1950 TMD-1950 DEP'O 3 T/ W SAK SNDS TVD=2163 TMD=2163 DEP=12 BUILD 3 DEG 15 PER 100 FT 21 EOC TVD=2715 TMD=2737 DEP=160 B/ W SAK SNDS TVD=273;4 TMD-2758 DEP-168 9 5/8" CSG PT TVD=293;4 THD~2976 DEP=2S6 K-lO TVD-3;ISO TMD-3;245 DEP-3;63; AVERAGE ANGLE 23 DEG 36 HI N K-5 TVD-4559 TMD-4749 DEP~g66 RECEIVED Alask.~ Oil & ~as Cons. T/ ZONE C TVD,,6041 TMD=6367 DEP=1613; ZONE A TVD"'6087 TMD"'6417 DEP-1633 ~TAROET CNTR TVD=6125 TMD"6458 DEP-1650 B/ KUP SNDS TVD=6209 TMD'"6550 DEP-1686 TD (LOG PT) TVD=63;92 TIgD=6750 DEP-1766 I I 1 000 2000 VERTICAL SECTION HORI ~N T ^L S~,LE 1 IN. PROJECTION = 1000 FEET ARCO ALASKA. Ine. Pad 2K. Well No, 9 Kuperul~ Field, North Propomed Slope, Alemkm TARGET CENTER TVD-6125 THDm6458 DEP" ! 6,50 NORTH 1224 WEST 1 ! O~ ;3OOO 2OO0 ;3000 2000 I c3 , 1000 _ O ~ 1 000 _ TARGET LOCATION' 1320' FSL. 1200' FEL SEC. 2. TION. RSE TD LOCATION~ 1407' FSL. 1278' FEL SEC. 2. TION. RSE N 42 DEG 1650' (TO WEST-EAST 1000 0 I I 1000 I ~SURFACE ! SURFACE LOCATION, 96' FSL. 94' FEL SEC. 2, TION. RBE 6 MIN W TARGET) 400 _ I ! 350 _ ! 300 2~ 2SO ~x 200 _ 150 _ 100 _ 50 _ ~ 250 200 1 50 100 900 ~'~ :300 \ \ %2700 "kl O0 \ \ '" ~500 \ \ \ 100 50 0 I I I 700 70/500 500 700 500 '"",~00 ~"' 500 --"T3oo ,. xa3oo ~.~,~o / / 2500 '/2300 / ' 500 / / / / -- ¢'1 500 '~ / / "2700 I 250 ! 200 I 150 ' ~oo 100 50 5O I I - 5O 400 350 300 250 2O0 150 100 5O DRILLING FLUID PROGRAM Spud to 9-5/8" Drill out to Weight up surface casing weight up tO TD Density 8.8-9.0 8.7-9.2 10.0 PV 15-30 5-15 1 1-16 YP 20-40 8-12 8-12 Viscosity 70-80 35-40 35-50 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 APl Filtrate 10-15 10-20 6 pH 9- 1 0 9.5-1 0.5 9.0-10.5 % Solids 10 +/- 4-7 12-15 Drilling Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators J U L "'" 6 Notes: - 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 13.0 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. - There are no wellbores within 200' of the proposed well as it is the sixth well to be drilled on the pad. The first five wells are at least 50' away at the surface, which would be the closest point to date. - Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1) MIRU. 2) Install FMC diverter system. 3) Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. 4) Run and cement 9-5/8" casing. 5) Install. and test BOPE. Test casing to 2000 psig. 6) Drill out cement and 10' new hole. Perform leak off test. 7) 'Drill 8-1/2" hole to logging point according to directional plan. 8) Run open hole logs. 9) Continue drilling 8-1/2" hole to provide 100' between PBTD and bottom of Kuparuk sands. 10) Run and cement 7" casing. Pressure test to 3500 psig. 11) Downsqueeze Arctic pack' and cement in 7" x 9-5/8" annulus. 12) ND BOPE and install temporary Xmas tree. 13) Secure well and release rig. 14) Run cased hole logs. 15) Move in Workover rig. NU BOPE. 16) PU 7" casing scraper and tubing, TIH to PBTD. Circulate hole with clean brine and TOH standing tubing back. 17) Perforate and run completion assembly, set and test packer. 18) ND BOPE and install Xmas tree. 191 Change over to diesel. 20) Flow well to tanks. Shut in. 21) Secure well and release rig. 22) Fracture stimulate. DEGASSERI SHALE STI STIR STIR SHAKERS TYPICAL MUD SYSTEM SCHEMATIC KUPARUK RIVER UNIT 20" DIVERTER SCHEMATIC !. DESCRIPTION 1. 16" CONDUCTOR 2. FMC SLIP-ON WELD STARTING HEAD 3. FMC D IVERTER ASSEMBLY WFFH TWO 2-1/16' 2000 PSI BALL VALVES 4. 20" 2000 PSI DRILLING SPOOL WI10" OUTLETS 5. 10" HCR BALL VALVES WI10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTI:tOM.ED TO ACHIEVE DOWNWIND DIVERSION. 6. 20" 2000 PSI ANNULAR PREVENTER ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC2S.035(b) MAINTENANCE & OPERATION 2 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. . CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND R E C ElY E D DO NOT SHUT IN UNDER ANY CIRCUMSTANCES JG 4/26/88 -7 6 AOiLMJLATCR CAPACITY TEST I. Cl.~ AI~ FILL ~?OR LEVEL MITH I-IYORN. LI¢ FLUID. ~ THAT ~'rl~ ~ I$ )l:)lX) I~I MIl'l.t 1500 I~I I:X:IMNBI'REA~ 3. CI~ERV~ TIt4~ TI,,EN ~ ALL UN]I'"3 SIMJ. TAI~OUSLY AI~ I~CICRD ~ 1'I1~ AN) ~ I~INI~ AFTER 4. RECORD ON !~ ~E~o ~ AC~A~I.E LC~ LIMIT 5 4 3 2 I~-5/8' B(~ STACK TEST I. FILL BCP ST/IQ( AI~ ~ I, IINiFCLD WXTH ARCTIC 2. O.ECK THAT ALL LO0( ~ ~ IN NB.U-F.~ A~ FLL. LY RE'I'~ SEAT TEST PLUG IN IMELLI. EAD WITH la.N~ll~ aT AM). lan IN LO(:I(IX:IM~ ~ LII~ V~LV~..S tl)JA~ TO ~ 5TACK, ~ 4. PI~SSI. BE UP TO ~ ~ AN) 1431.D FOR IO I~N, I1~. ~ ~ TO liX)O PSI AI~ ~ ~ IO~N, ~ ~D I~fi)OU~ TO 0 I~l. LII~ VALVI[5, CLO~ T(P PlI~ ~ ~ HCR VALVES ~ KI~ ~ O0(E LII~. ~ TO 250 I~I AI~ ~ ~I AS 7.~IN~ TESTII~ ALL VALVI)~ LII~.,~ AM) WITH A aSO PSI LO~ A~ ;tO(X) I~I HIO~ I0. Cl. Oi~ BLII~D P. Ak~ ~ 'l-r.~T TO 2~0 PSI P~I. kWillrO. O AN3 LII~.~ Al~ FU.I. CF' I'~I~ FLUID. SET ALL VALVE~ IN CRILLING I:<~ITIC~ 12.. I~ST 5'TAMiIPIPE: VALVIi~, KE1J. Yo I~I.I.Y ~ PIPE SAFETY VALVE, AI~ II~8It~ BOP TO ~ PSI. §i006400J ARCO Alaska, Inc. Post Office Bo~-~ 100360 Anchorage, Alaska 99510.0360 Telephone 907 276 1215 December 12, 1988 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- Conductor As-Built Location Plat- 2K Pad ~ (Wells 1 - 24) Dear Mr. Chatteron' Enclosed is an as-built location plat for the any questions, please call me at 263-4618. Sincerely, subject wells. If you have D. Martin Engineering Aide DM:hf Enclosure RECEIVED DEC 1 1988 Alaska 0il & Gas Cons. Commissi0r~ Anchorage GRU13/010 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldComp,3ny N.'I',S. SECTION ,,~ ,,,= .... IECTION I ! WELLS 1'12 ARE LOCATED IN SECTION 2, T, I0 N., R. 8 E., UMIAT MERIDIAN. WELLS 13'24 ARE LOCATED IN SECTION I I, T. I0 N., R. 8 E., UMIAT MERIDIAN. SECTION I PROTRACTED SECTION CORNER Notes: I. COORDINATES ARE A. SP. ZONE 4. SECTION ?. ALL DISTANCES SHOWN ARE TRUE. 3. ELEVATIONS ARE B.P.M.S,L. RECEIVED DEC 1 1988 4. O.G. ELEVATIONS FROM CED- RIXX-$311, re~4. 5. HORIZONTAL POSITION BASED ON 2-K CONTROL MONUMENTS PER LOUNSBURY ~ A~OClATE$, 6. REFERENCE FIELD BOOK: L 88-40, pgs. 55,56, 58,59, 65 8 66. ~ ................. i uJi & C.,.[~ ~$uii$. ~0;~ ~,'q;3:;;'::: ........ r Well ASPs , , A~s~,,a Dist. Dist. O.G. Pod X L~'~;'~dlD~ LONGITUDE F.S.L. £ E.L. Elev. Elev.. I 5,938,600.18''' 498'"3i0;I7 ..... 70°i4"36.519" ~i50000'49.-/33''' 296' 94' !14.0 118.5 2 5,938,575.14 498,310.28 70°14'36.273'' 150°00'49.130" 271' 113,.9 3 5,938,550.30 498,3t0.35 70©14'36.029'' 150°00'49.128'' 246' 113,.8 4 5,938,525.46 49B,310.06 70014. 35.784" 150°00'49.~ 36'' 2::>2, 113.8 5 5,938,500.19 498,310.1Z 70°14'55.536" 150°00'49.154'' 196' 11~.8 6 5,938,475.14. 49 8~310.35 70°14' 35.289" 150o00'49.17'8" 171' I I.'3.8 , 35.0 150°00' 49.1P7'' I46' 113.8 7 5 938,450.36 498,310.36 70014' 46" 8 5,938,425.30 498,310.18 70° 14' 34. 799'' 150°00'49.132:" 121' !1:5.8 9 5,938,400.30 498~309.98 70o14' 34.553," 150°00'49.137'' 96' 113.8 , 4' " 3" ' I I 13,9 I0 5,938,375.19 498,510.14 70014, 34.306 150 °00'49. 133,' 71 I I 5,938,350.22 498,310.14 70°1 34.061 " 150°00'49.13 46' i 113.9 IE 5,938,325.Z0 498,$10.17 70°14' 33.815" 150°00'49.151" ~1' 94' 113.9 118.5 FN.L, 13 5,938,235.$1 498,310.37 70°14'32.930" 150°00'49.125'' 69' 94' 113.7 118.5 14 5,938,210.14 ~ 498,310.16 70 °14' 32.683'' 150°00'49.151'' 94' 113.7 15 5,938,185.12 498,310.16 70°14' 32.437'' 150°00'49.131" 119' 113.8 16 5,938, 160.11 ] 498,310.20 70°14' $2. 191" 150° 00' 49. 130'' 144' 115.8 17 5,938,135.21 498~510.18 70°14'$1.946'' 150°00'49.130'' 169~ 115.9 18 5,938, 110.19 i 498,310.29 70°14'$1.700'' 150°00'49.1Z7'' 194' 114.0 19 5,938,085.20 498~310.Z7 70°14' 31.454" 150°00'49.127" 219' I 1t4.0 20 5,938,060.14 498,310.22 70°!4' 31.207'' 150° 00'49. 128'' 244' i 114.1 21 5,938,035.16 498,310.16 70°14 30.962 150° 00'49. 130'' 269 !' 114.0 22 5,938,010.40 498,310.19 70°14' $0.718 150°00'49. 129" 294' 94' 114.0 23 5,937,985.3~ 498,3,0.,~ 70 °,4' 30.47,'' ,50° 00'49. ,30'' 3, 95' ,,4.0 24 5,93.7,i96.0:..29 498,$,0.08 70 °,4' 30.225" ,50° 00'49. ,3 344' 95' I .... ,,3.9 ,,8.5 I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO ,. ARCO A ska STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE ~ DRILL SITE 2.K BY ME OR UNDER MY DIRECT SUPER- ~. v~SION ANO THAT ALL O*~NS~ONS *~' ~"'~~:~ CONDUCTOR AS'BUILT8 c scK LIS FOR Nm PE Z S ( 1 ) Fee /~./~t"_ 7//~/~.~; 1. (2 thru (8) %9 thru 13) ' 10. 11. (10 and 13) 12. 13. (4) Cas~ (14 thru 22) (23 thru 28)' Company /~;~_m, Lease & Well No. YES NO Is the permit fee attached .......................................... ~ . P, EMARKS 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 undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force .................................. ~ . Is a conservation order needed ...................................... Ss administrative approval needed ................................... Is the lease number appropriate ..................................... ~_ Does the well have a unique name and number ......................... 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 and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate/~t Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~dP~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (29 thr~ 31) (6) Add: Geology: Engi~neerin$: rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ....................................... , ..... INITIAL GEO. UNIT oN/OFF POOL CLASS STATUS AREA NO. SHORE /- o Additional Remarks: ~z Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. MICROFILMED CDMP~NY N~ME : A~CO ALASKA INC. WELL N~M2 : ZK-9 ~:I-EL.O N..&ME : KUiPARUK i~OROUGH : NO~TH SLOPE .STAT~ : AL,~SK~ ~PI NUMBER : 50-103-20108 R~E~ENC~, :_: NO'. 73413- .IS 'TAPE. VERIFI'C&TION LIS'T.iNG iCHLUMSERG'ER ALASKA Cg~PU~,ZNG NT~ *~* REEL HEADER '~"~' SERVICE N~ME : ~GIT DATE ORIGIN : FLZC R=cEL NAME : T3~13 CONTINUATIGN # PREVIOUS REEL C~MMENT : ARCO~ ~UPARUK, 2~.-9, API ~50-103-20105 'SERVICE N~E : DATE : ~9/g~/ 1 GRIGIN : :LIC TAPE NAME CONTI, NUATIgN ~ = 1 PREVIOUS T~PE COMMENT : ARC~, ~U~APUK, ZK-9, AP~ ~50-103-ZOlg8 FiLE N~M'E : ~DiT .00! S~RV'ICE : ~L~C VERSION : DATE : 89/03/ MAX REC SIZE : 1096 FILE TYPE : LAS'T FILE : CDMPANY N&M2: ~RCO ALASK~ Z~C. WELL: ~ROUSH: N~T~ SLgP~ STATE: ~L~SK~ API NUM~: 5g'-I0~-2010~ LOCATION: 9~' :SL ~ 94' reEL SECT.ISN: 02 T.,SWNSHIP: 'ION P~RMANENT DA'TU~: MSL iELEV~TZg:N: 0 .i.S TAPE V:~RIFiC~.TIr~N L'ISTZN-$ iCHLUMBERG=_R ALASK:& COMPU'TING CENTER i-~US-19B9 !3:35 LOG MiEASUREO FRgM RK~ 154 ASOVE P~R~NENT OA'TU~ ELEVATIgNS K~: CF: 153 GL: 113 DATE LDGGED: ID-JUL-89 RUN NUMSER: gN5 TD DRILLE~: 6800 C~SING: 7" 26 L8 @ D~ILLE~ DEPTH 3F 6246 AND LOGGER DEPTH OF 6255 8iT SIZe: 6 TYP5 '~LUIO .IN HOLE: W~IGHTED POLYMER DENSITY: !I VI:SCGSITY: PH: 9.5 FLUID LOSS: ~UD RESISTIVITY: FILTRATE RESISTIVITY: MUD CAKE 2ESISTIVITY: :2.96 @ ? 2 .2.6.4 ~ '? i ;3. :83 @~ 70 TiME CIRCULATION ENDED: 12:30 2g-JUL TIM5 LOGGER CN BOTTOm: lg:'16 2g-JUL MAXIMUM TEMP REC~DE~: 148 ~ STR LOGGiN. gI lC'T: ~LOGGiNG ENGINEER: WITNESS: P~UDHOE F~ITZKE ~IXON/SMALLWOO~ 'TOOL NU~,EERS: I EM 134 T SGC 2625 CNC 123 8 DIC 1006 N L P 137 ~ P;SS 508 CIS llOO FIELD RENARKS: NO STANDOFFS US58 ON THE git ~]ECAUSE 0-~ THE SMALL HOL,~ SIZEo ~.,!TRiX ~ENSITY : 2.65 G/CC., ~LUIO DENSITY : 1.0 G/CC. NEUTR3~.; M~TRiX = S.ANO, HOLE CORRECTION = CALIPER:. P~D ELEV~TIg~ = 118 FEET. M'IGH qES~LUTiDN P.&SS LC$GEO ~UT NOT P~ESSNT5D ON FILMS. ND BOWSPRIN$ USeD CN ONE BSC.aUS5 DF HOLE SIZE. THE SP RESPONDED V~RY PSD-RLY ON ALL LOGGING ~TYEM~TS ~.NO W.aS NOISY .AND ERRaTiC. PD~R R~OSAT'IBZLITY OU~5 TO HCLE CONDITIONS. TH~ LOGGING TOOLS WErE STICKING, C&US!NG A YQ-Y~ EFmECY ON THE L~GS. SEVSR~L EXTra ~TTEMPTS WErE MA~5 TO OBT,~IN ~,ETTER D:TA. TO IMPq~VE THE DIT aND D~CP~SE STICKING, THE MAIN DIT P~SS WaS ~aO5 WITH THE CALIPE~ CESSED. DATE JOB STARTSD: JOB REFERENC,~ NJ, 7~413 LOP/ANd: J. KDMRING .IS TAPE V5RIFICATICN LISTING 1-A. UG-1989 13:35 ;CHLU~RERG'ER ALASKI CCMPUTING C,.:N,ER FIL;~- 5OiT.OOl. A'~ C O K U P A R U K 5 O- 103- MAIN DATA SAMPLED ERY 5000 F~ET DATA INCLUgED - TOOL :EX'TENS ION TOOL * TYPE USED NAME .,,- glT-g .OiL DU~L INOUCTION :$FL 6300' TO 6255' ',- GR .CSG GANM~ R~Y 613,~0' TO 970' '" FOC . FOC FORM' 'Tv -,- A, ~ON gENSITY 6776~' TO 6255' ~ CN'T-A/C/H CNL CgMP~N~A D N~UTRON 6T60' 'T~ 6255' P ~ G E.' T,~BLE TYPE : CCNS TUNI VALU CN ~CO .,,~L.~,SKA INC. FN K.U~A~UK WN 2X,-9 ~IN 50-103-20108 FL SEC'T TOWN IgN RANG 8E COUN NORTH SL~PE STAT ALASK,~ NATI ENGI ~ RiTZKE WITN D Z ~gN/S MALLWO gD SON 5~48364 POAT MSL EP~ FT 0. LMF APD ~ ~ 154. EK~ =T 154. EOF FT 1 53. EGL FT 113. TDC, F'T 6~00. ELI FT F EL C ~FI COMPANY NAME FIELD NAME WELL NAME API SERIAL NUMBER FIELD LOC,~TI ON SECTICN 'TOWNSHIP RANGE COUNTY S'TATE OR PRCV"NC~ NATION EN$INEER'S N~M5 WITNESS'S N~ME SERVICE OROER NUMBE~ PERMANENT O~TUM LCG MEASU~;=D FROM 80'TTO~ LOG INT=RVAL .iS 'TAPE V!ERIFI:CATION LISTING ;CHLUM!BERGFR, .,. ~LASKA cr, MPUTING~ ,. T L I T C S T 'L A B TUNI FT TABLE 'TYPE : CURV 1-AUG-19:~9· 13:35 V~LU 9?5. 12:30 29-JUL I'9:16 .2'9-jUL D EF i DEPT DEPTH CHANNEL ILO !L'-~ ~EP ~ESISTIV!TY ILM iL.-~EDIU~ i~E SIS'T.iV IT Y SFLU SFL U~AVERAGiED SP .S~ON'TANE~.US PO~c~TZ~L GR G~M~, RAY TENS TENSION GR GAM~A RAY TENS TENSION DPH'! DENSITY D~RgS!TY RHO~ ~ULK D,EN S!'TY DRHO DELT~ RHO FFOC FAR :mDC COUNT RATE NFDC NE~R"FOC COUNT RATE C~L Z C~Li ~E,R GR G&M~A RAY 'TENS TENS~m NPHI NEUTRON POROSITY TNPH THER~4AL N=~ , ;,.UT~CN ~gR~SITY TNRA CALISR~TED THERMAL NEUTRON R~TI,O NPOR NEUTRON POROSITY OUTPUT :ROM AN APPLIC.&TtCN DROGR~,M RCNT RAW CORRECTmD NEAR TH=RMAL C~UNTS RCFmT RAW CCRR~;CT,5O... .,=~R TH :RMALL. .. ~rC:UNTS CNTC CORRECTEO N~R THERMAL COUNTS CFTC COR~ECTEO :~.R TH~ERM~L CCUNTS GR GAMMA CALT~ ,~rALIPE~, , TENS TENS ION DATA FOR~XT.~ SPECIFiCATIC-N R~ErORO:~ ..~:~ ~* SET 'TYPE - 6~E5 *~ TYPE REPR C~OE I 65 2 66 66 PAGE: 4 VALUE 0 O !II 1 TOP LOS 'INTERVAL TiME CI ~ TI ST PP-D R~ULA ON 0 = TI~E LgGG~ AT BgT'T~M .IS TAPE VERI~IC~TZgN ~LIST!NG ~CHLUM~BERGER ~LA:SKA COMPUTING CENT!ER I-:~UG-1989 13:35 DA~E: TYoE R,EPq V ,a L U E NAME ~'~ 'S ~ T T Y PE- CHAN ~:~ SERV UNIT ,~-_RVICE D E P T F T 5 ILD DIL CHMM 54~36~ ILM DiL CHMM 5A~364 SFLU OIL OHMM SP DiL ~V 548364 GR OIL G~PI 548364 TENS DIL L3 GR CSG GAPI TENS CSG LB 54a364 DPHI FDC gU 548354 RHgB FDC G/.C3 DRHg FOC G/C3 F483:6~ FF~C ~DC CPS 5~354 NF~'C FgC CPS 548364 C~LZ F~C IN GR FDC GAPZ TENS FDC L:B 545364 NPHZ CNL PU ~4~364 TNPH CNL PU TNRA CNL 54~364 NP~ CNL PU RCNT C~L C~S RCFT CNL CPS CNTC CNL CPS C~TC CNL C~S GR CNL GAPZ ~54~ ~64 CALI CNL iN YENS CNL [B 548~64 ~Pl ~:PI :~,~I :~,P'I FIL~ NUMB NUMB LOG TYPE CL&:SS MOO NUMB S~MP ELEM CODE OO 000 GO 0 1 1 1 4 68 07 120 46 0 1 1 1 ¢ 68 07 120 44 0 I 1 1 4 68 07 220 O1 0 1 I ! ,~. 68 07 O 10 0 1 0 1 1 1 :4 6 8 07 310 O1 0 1 I I ~ 68 07 535 2 ! 0 I ! I 4 68 07 310 O I '0 ~ 1 I 4 68 07 635 21 O 1 ! 1 4. 68 07 635 2! 0 1 1 I ¢ 68 07 350 O ?_ O 1 1 1 ~ 68 07 .356 Oi 0 I 1 1 4 68 0 7 3 E .4 O 2 0 ! 1 1 .4 68 07 35-~ Ol 0 ! 1 1 ,~ 68 07 280 Ol 0 1 1 1 4 68 07 310 Ol 0 1 t I 4, 68 07 635 21 O 1 I i ~ 68 07 890 O0 0 1 t 1 4 68 07 890 CO 0 I 1 1 4 68 07 .420 Ot 0 I 1 1 4 69 07 890 O0 O ~ I 1 4 68 07 42 O 01 0 ! I I 4 68 07' z, 2O Ot O 1 '1 1 4 68 07 420 gl O ! I I 4 68 07 ~,20 Gl 0 ! t 1 4 68 07 310 Ol C 1 I I 4 68 07 280 O1 0 ! 'I I 4 68 07 635 21 O 1 1 1 a 6'8 PROCESS (HEX) OOOO000000 0000000000 0000000000 O00000OO00 O00000OOOO 0000000000 0000000000 0000000000 O00000OO00 O00000gOgO 0000000000 OOO0000000 0000000000 0000000000 O0000OO000 O0000000OO OOO0000000 O00000OO00 O00000OOOO O000OO0000 0000000000 0000000000 OOOO000000 0000000000 0000000000 0000000000 O00000000O O000000000 'I:S T~PE V~RiFIC~T'IgN SCHLUMbERGeR ALASKA COmPUTiNG CENTiER DEPT 6816.000 .ILO - .S P. O,"[L -9~9.2..50 GR.,. OIL ,,-_NS C, SG -999.2:50 gPHI FgC FFDC.FOC 4~8.750 NFgC.FDC T~NS.!FOC 2670.000 NFHI.CNL NP:OR.CNL 36.7 73 ~CNT. CNL CFTC.CNL 7'72. 397 G~. CNL DEPT, 5800. 000 I:LD, OiL SP.OIL -67.000 GR.,OIL TENS.CSG -'999.2 50 DPHI. F gC FFDC,FDC 488,7~0 NFOC.FOC T~NS.FDC 3~O~.O00 NPHI.:CNL NPgR.CNL 36.773 RCN'T.CNL C F T C. C N L 772. ~ 97 ~] ~ · C N L EPT. 6700. 000 ILC.. D'IL SP.OIL 7. 352 G~.DIL TENS.CSG -999~. 2:50 OP HI.~O~C FFDC. :DC 485.500 NFOC.FDC TENS.FOC 3980.000 NPHI.CNL N~OR.CNL 40.2~! ~CNT.CNL FTC. CNL 727 DEPT. 5500.000 ILO.OiL SP. OIL .-14. 664 G~. C IL TENS.CSG -99'9.250 DPHI,FDC FFDC,FOC 459,750 N~DC,FSC TEN.S. FDC 3810,000 NPHI,CNL NPOR.CNL 3~.919 ~CNT.CNL C'~TC. CNL ~41,991 GR.CNL DEPT. 65 gO. O O0 ILO. g IL SP. OIL 5. ~ 05 GR. O IL TENS.CSG' -999.250 DPHI.'FOC FFDC.FDC 451.000 NFDC.FOC TENS D,~ 3~,O.gOO NPHI.CNL N POR. CNL 2 ~. 645 RC NT. C NL CFTC.CNL 11 ~8. 671 GR. CNL DEPT. 5400.000 ILO.C!L SP.DIL 9.5!6 G~.DiL TENS.CSG 34S&.000 OPHI.FOC F~DC.FDC 739,000 NFDC.~OC 'TENS. ~0C 3400.000 NPHI. CNL NPOR.. CNL 45.149 ~C NT. CNL CFTC.CNL 503,9 55 GP.CNL DEPT. 63 00. OOO ILO.OIL S~ OiL 7 ~0~ '~. ,~. OiL TENS.CS~g 3514. O 00 DPHI. FOC FFDr,~. ~DC. 5qE.OOO,. NFnC.FDC~ TENS.FOC 3590.000 NPHI.CNL NPgR.CNL 4~.850 RCNT.CNL 1-,~UG'-!?sg 13'35 - 9'99. - 99'9. I0. 616. 38. 2272. llO. ! 23. 10. 616. 2272. 105. 12. 589. 40. 104. . 104. !0. :586. 37. 105. 3. 9. 597. 29. 3110. 85. i38. 19. 713, 45. 1767. 141, . 187. 17. 515. 43. 1980. 250 I tM. D IL 250 TENS.OIL 637 RHCB. FOC 500 CALI. FOC 195 'TNPH.CNL 88:3 R C F T. C N L 625 CALI.CNL 6t& ILM.DIL 688 TENS.OIL 637 RHOB.FDC 500 CALI.FDC 195 TN!~H.CNL 383 RC~T.CNL 625 ,CALI.CNL 729 I L M. 01 L 563 'TENS. C IL 532 RHOB.FDC 500 CALI.FDC 606 TNPH. CNL 5.50 ~C:T. CNL 063 C~,L~.CNL 320 ILM.D!L 500 TENS.DIL 484 RHOB.~OC 500 C~':LI.~gC 684 T N P H. C N:L 36'7 RCFT.:CNL .~75 C~.L I.:CNL 995 ILM,O!L 625 TENS.DIL 828 RHOE.FDC 500 CA'LI.FDC ~! TNPH.CNL ]18 RCFT.CNL 250 CALI,CNL 150 ILM.OIL 625 TENS.OIL 71,% RHOB.FOC 000 Ca, LI.FDC 423 TNPH.CNL 065 RCFT.CNL ZEO CALI.CNL 130 !LM.DIL 875 TENS.OIL 151 RHOB.FOC 000 CILI.FDC 647 TNPH.CNL 368 RC!:T.CNL -99 9.25 O '- 99 9, Z 50 2,474 6,125 36.773 681,173 6.1.25 2. 778 3824.000 Z. 474 5.902 36. '773 681.t73 5. 2. 816 3734.000 2..443 6. 148 39,892 644.900 6.148 3. 376 3724.000 2.477 6.398 36.785 727./,60 6. 7398 4.118 363 O, 000 2..4S 8 :5.27 O 3 0.01 Z 1065,856 6.270 2.487 3520.000 2.325 6.855 W5,Z16 450.989 6. 855 3.184 3490.000 2.367 5.48 0 40.923 544.709 SFLU. O~L G R. C S G O R H O. F D C TNR.~. CNL CNTC.CNL TENS.CNL S=LU.DIL GR.CSG DRHO. ~DC TNR A.CNL CNTC.CNL TENS.CNL SFLU. OIL GR.CSG DRHO. FDC GR.FDC TNRA.CNL CNTC .CNL T~NS.CNL S~LU. ~glL GR.CSG G',q. FOC TNR,~,.CNL CNTC .CNL 'T E N .S. C N L S~LU,.DIL 6R.CS,3 D~HO. FDC GR. FDC TNRA.CNL CNTC.CNL T,ENS.CNL S~LU.OIL GR.CSG DRHO.mDC GR.FDC TNR~..CNL CNTC.CNL TENS.CNL SFLU.OIL GR.'SG~ DRHO.FDC TNR~A.CNL CNTC.CNL -999.250 -999. 250 0.050 !10. 625 3. 054 2322.4'75 2670.000 3.170 ,-999.250 0.050 110.625 3.034 2322.475 3504,000 3.242 -999.250 0.020 I04.'063 3.201 2332.5?6 3980.000 3.688 -999.2.50 105.8'75 3.056 2544.019 3810.000 5.965 -999.250 0,040 86.2:50 2,574 3063,558 3870.000 2,746 136.500 0,069 141.250 3.506 1803,206 3400.000 3.904 196,750 0,015 183.000 ~ ~7 2063.7~6 LIS TAo~ ...... VERI=iC:~TION LIST'~N~G CFTC.CNL 627.357 G~. CNL DEPT. 5200. 0 O0 ILD.OIL SP.DIL -999. 250 GR.DIL TENS.CSG ~4~O.OOO DPHI.FDC FF~C.FOC 23~.000 NFDC.FOC TENS.FgC 349.4.000 NPHI..CNL NPO~.CNL ~7.~09 ~CN'T.CNL CPTC.CNL 4,22, lO0 CNL DEPT. 6100.000 ILO.£-IL SP.DIL -999.250 GR..D~L TENS.CSG 34~0.000 DPHI.FDC FFDCoFDC -999.250 N~gC.FDC TENS.FDC -999.250 NPHZ.CNL NPO~,.CNL -999.250 RCNT.CNL C ~TC. CNL '-ggg. 250 GR. CNL D EP'T. 5000. 000 ZLg. DI:L SP. OIL -999. 250 GR. gIL TENS.CSg 3400.000 .3P'ql. FOC FFOC.:FOC -999.250 NFDC.FDC T~N$.FDC -999.250 NPHZ.CNL NPCR:.CNL -999.250 RCNT,CNL C :TC. CNL -999.2 50 SR.CNL DEPT.. 5900.0 O0 ILO. O ZL SP. OIL ,-999.250 GR:.OIL TENS.CSG 3~350.000 DPHI.FOC FFgC.FDC -999. 250 NFgC.FOC TENS. FOC -999.250 NPHI.CNL NPDR.CNL -999.250 RCNToCNL C~TC. CNL -999.250 G~, CNL DEPT. 5P. O0.O00 ILD..gIL SP.D~L -999.250 GR.DiL T~NS.CSG 32~4.000 DPHI.FDC F:FDCoFOC -999.250 NFOC.~OC TENS.FDC -999.250 NPHI.CNL NPCR.CNL -999.250 RCNT.CNL CmTC. CNL -999 . .2 50 GR .CNL D EP'T. 5700. 000 ILD. DIL SP.DiL -999. 250 GR.DIL TENS.C:SG 3250.090 DP~i. FDC F~CC.FDC -S99.250 NFOC.FDC TENS.FDC -999.250 NFHI.CNL NPOR.CNL -999.250 RCNT.CNL C=TC.CNL -999.250 gR.C NL DEPT. 5600.000 ILO. DIL SP.OIL -999.2 ~0 S~.CIL TEN'~.~CSG '~200, .00'",,- nPHI~ . FDC F~CC.~DC -999.2~0 NFDC.~gC TENS.'FDC -999.2~0 NPHI.CNL !-~UG-1939 13:35 -99 g. -999. 20. 196. 50. 1461. 13 '9. -999. _~ ~-- -999. -999. - 999. - 999. -999. -999. -999. - 99'9. -999. -~99. -999. '-999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. - 999. -999. -999. - 99:9. -999. - 99'9. -999. -999. -'~99. oOo CALI.:CNL 25 O I t M. D I L 250 TENS.DIL 8.48 RMOB.FDC gO0 CALI. FDC 362 TN~H, CNL 045 RCFT.CNL ~,~75 CALI.CNL 250 ILM.DIL 2150 T E N S. g I L 250 RHOB.FOC 250 C~LI.FDC 250 TNPH. CNL 250 RCFT.CNL 250 C~LI..CNL -99 9.250 - 999.250 2.306 6 219 45. 381 .38 6. 347 $.219 -999.250 -999.250 -999.250 - 999.250 .-999.250 -999.250 -999.250 250 I:LM. DIL - 999. 250 250 TENS.DIL -999.250 250 RHOB. FDC '-999.250 250 CALI.FDC -'999.250 '250 TNPH.CNL -999.1250 250 R:CFT.CNL - 999. 250 .2.50 CALI.CNL -999.250 ,250 ILM.DIL 250 T~NS.CIL 250 RHOB.FOC 250 CALI.FDC 250 'TN PM. CNL ~5'0 RC~T.CNL 250 C.~LI.CNL -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.")-50 250 ILM.CIL -999.250 250 'TENS.DIL -999.~50 250 RHOB.FDC -'999.250 ZSO C~LI.FDC -999.250 250 TNPH.CNL -999.250 250 RCFT.CNL -999.250 250 C~LI.CNL -999.250 250 ILN.DiL -999.250 250 TENS.DIL '-999.250 250 ~HOB.FDC -999.250 250 CALI.FDC -999,.250 250 TNPH.CNL -999.250 '250 i~CFT..CNL -999.250 250 C~LI.CNL -999.250 250 ILM.DIL ZSO TENS.DIL 250 RHDB.FDC 250 C~LZ.FDC 250 TNPH.CNL -999.250 -999.250 -'999. 250 -999.250 -999.250 'TENS.~''''~NL SFLU.OIL GR.CSG D~HO.FDC GR.FDC TN~A.CNL CNTC.CNL T~NS.CNL SFLO.DIL GR.CSG Gq. FDC 'TNRA.CN:L CNTC.CNL TENS.CNL SFLU.DIL GR.CSG ORHO.FOC GR.FDC TNRA.CNL CNTr CN'L TENS.CNL S~LU.OIL gR.CSG DRMO.FDC gR.~DC TNRA.CNL CNTC.CNL TENS.CNL SFLU.DIL GR.CSG DRHO.FDC GR.FDC TNR4.CNL CNTC.CNL TENS.CNL SFLU.DIL GR.CSG DRHO.FDC GR.FDC TNRA.CNL CNTC.CNL TENS.CNL SFLU.DIL GR.CSG DRHO.FDC TNRA.CNL PAGE: 3590.000 -999.2:50 !60.750 -0.421 139.875 3.738 1:~ 79 3494.000 -999.250 93.375 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 64.125 -999.250 -999.250 -999.2150 -999.250 -999.250 -999.250 84.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 78.125 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 84.375 -999.250 -999.250 -999.250 -999.250 -999.250 -999.2:50 74.875 -999.250 -999.250 -999.250 ' IS TAPE VF_RIFiC~TiON LISTIN~ SCHLUMBErGeR ~LASKA CgMPUTING CENT~ NPOR.CNL ,-999. 250 ~CNT.CNL CFTC CNL -.:~9 250 GR CNL DEPT. 5500. O0 O iLO. gIL SP.DIL -999.250 gR.~IL TEN]S.CSC~ 3170.000 OPHI.FOC F~D.C. FDC -~99.250 NFOC.FDC TENS.FCC -9~9. 250 NPHZ.CNL NPOR.CNL -999.250 ~CNT.CNL C ~TC. CNL -~99.2 50 G~~.CNL DEPT. 5300. 000 iLO. OIL SP.OIL -999.2 50 GR.rOIL 'T6NS.CSG 30~4.000 OPHI.FOC FFDC.~'DC -999.250 NFDC.FDC TEN:S. FDC -999,250 NPHI.CNL NPOR.CNL -999.250 RC NT.CN:L CFTC oCNL -999.2 50 GR. CNL DEPT. 5200.000 ILO.OIL SP:.OIL -99:9. 250 GR.OiL TENS.CSG 2994,000 OPHI.FOC ~FDC.FDC -999.250 NFOC.FOC 'TENS.FDC -999.250 NPHI.CN'L NPO2.CNL -999.250 RCNT.CNL CFTC.CNL -~ 99.2 50 G~.CNL DEPT. 5100. OOO ILO. g't~L SP. OIL -999.250 GR. CIL TENS.CSG 2970.000 OPHI.FDC FFDC.i~DC -999.250 NFOC.FOC TENS.FDC -999.259 NPHI.CNL NPGR.CNL -999. 250 RCNT.CNL C~TC. CNL -999.250 GR. CNL DEPT. 5000.000 ILO.CIL SP.OIL -999.250 GR.SIL TENS.CSG 29!0.000 OPH!.FDC FFGC-Fg~ ~9c 2:0 NPDC.FOC T ENO. FDC - ~99.25 O NpHI. CNL NPOR.CNL -999.250 ~CNT.CNL CFTC. CNL -999 . 250 gR. CNL SEPT. ~900,gO0 ILS.OiL SP.OIL -999.250 GR.OiL .TENS.CSG 2890.000 OPHI,FDC FFgC.FOC -999.250 NmOC.~DC !-4UG-1989 1~.35 - 99 '9. -999. 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DIL 250 TENS.OIL 250 RHOB.FDC 250 CALI.FDC 250 TNPH.CNL 250 RCFT.CNL 250 CALI.CNL 250 ILM..C, IL 250 TENS.OIL 250 RHg~.FDC 250 CALI.FDC 250 TNPH.CNL 250 RCFT.CNL 250 CALI.CNL 250 ILM.OZL 250 TENS.OIL 250 RHOB.FOC 250 CALI.FDC 250 TNPH.CNL 250 RC=T.CNL 250 C~LI.CNL -999.250 -999. 250 -999.250 .-999.250 -999. 250 -999.250 -99 9,250 -999.250 -99 9.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 .-999.250 -999.250 -999.250 - '9'99.250 -999.~50 250 ItM.g!t -999.250 250 TENS.OIL -999.250 250 RHOB.FOC -999.250 250 CAtI.FDC -999.250 C N T C. C N L T ::~. N S. C N L SFLU.OIL GR.CSG 6R.FDC TNR~.CNL CNTC.CNL T~NS.CNL SFLU.OIt GR.CSG DRHO.FDC GR.FDC TNR;a. CNL CNTC.CNL TENS.CNL SFLU.OIL GR.CSG DRHO.FOC GR.FDC TNRA.C. NL CNTC.CNL TENS.CNL SFLU.OIL GR.CSG DRHO.FDC GR.FDC TNRA.CNL CNTC.CNL T~NS.CNL SFLU.DIL GR.CSG ORHO.mDC GR.FDC TNRA.CNL CNTC.CNL TENS.CNL S:LU.OIL GR.CSG D~HO.mDC GR.FDC TNRA.CNL CNTC.CNL TE~S.CNL SmLU.DiL GR.CSG GR.FDC P~GE: -999.250 -999.250 -999.250 69.125 -999.250-999.2~ -999.250 -999.250 -999.250 -999. 250 68.000 -999..250 -999.250 -999.250 -999.250 -999.250 -999.250 62.!88 -999.250 -999.250 ,-999.250 -999.250 -999.250 -999.250 '?5.8?5 -999.250 -999.250 -999.250 -999.250 -999.250 -~99.2:0.. ~ -999.250 -999.250 -999.250 -999.250 -999.2~0 --999.250 86.875 -999.250 -999.250 -999.250 -9'99.250 -999.250 -999.250 80.875 -999,250-999.250 LiS TAPE VERZFZCATZDN LISTING ;SCHLUMi5ERGER ~LA. SKA CO~qPUTZNG TENS.FDC -999.250 NPHI.CNL -999. NPOP.CNL -999.250 qCNT.CNL -999. C FTC. CNL -999. Z 50 ,SR.CNL - 999. DEPT. ~gO. OOO SP.gtL -999.250 TENS.CSG ,282~.0g0 FFDC. FDC -999.Z SO NFOC. ~OC TENS. FgC -~99.2 50 NPHI.CNL NPOR.CNL -999.250 ~CNT.CNL C FTC. CNL -999.2 50 G~. CNL DEPT. ~'700.0 O0 ILD. 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CNL I-AUG-19~9 13:135 - - 99 ~9. -999. -99 '9. -999. -999. - 999. '-999. -999. - 99'9. -999. --999. -999. -999. -99'9. -999. -'999. -959. -'999. -999. -999. '-'999. -999. -999. -999. -'99 9. -999. -999. -999. -999. -999. -999. - '9 '99. -999. -999. -999. -999. -999. -999. - ~.~99. -'999. - 999. 250 TNPH.CNL Z 50 R C F T. C N~L 250 iC,~LI.CNL 250 ILM.DIL 250 'TENS.OIL 250 RHOB. FDC 250 C~LI.FDC ,~50 TNPH.CNL Z FO RCFT.CNL Z 5 O C A L I. C N :L .250 ILM.DIL ZSO TENS.DIL 250 RHOB.FDC 250 C~LI. FOC 250 TNPH.CNL 'ZSO ~-~CFT.C NL 250 C~LI.CNL ILM.DIL TENS. DIL ZEO C~LI.FOC Z 50 T N P H . :C N L ~50 RCFT.CNL !50 C~LI.CNL 250 ILM.DIL ZE.O TENS.OIL 250 RHOB. FDC :250 C~LI.FDC 250 TNPH.CNL 250 RCFT.CNL 250 C~LI.CNL ZEO ILM.DIL ZEO TENS .OIL 250 RHOB.FDC 250 C~LI. FOC ZEO TNPH.CNL 250 RCFT.CNL 250 C~Li.CNL ZEO ILM.glL 250 TENS.DIL 250 RHOB.FOC 250 CALI.FDC 250 TNPH.CNL 250 RCFT.CNL '~50 CALI.CNL -999.Z50 -999.250 -999.250 -999.250 - 999.2 50 -999.250 -999.250 -999.250 -999:. 250 -999.Z 50 -999.250 -999.250 -999. 250 -999.250 -9 '99. Z 50 -999.250 -999. ~50 '-999.250 - 9 99. Z 50 - 99 9. Z 50 -999.250 -~) 9 9.250 - 99 9..2:50 -999.250 -999.250 -999.25.0 -999.250 ' -999.250 - 999. 250 .-999.250 -999.250 -999.250 -999.250 -999.250 -99'9.250 -999.250 -999.250 -999.250 -999.250 -999.250 -39 9.250 -.~9 9.250 -999.250 -~99.250 -999.250 TNRA.CNL CNTC.CNL TENS.CNL SFLU.OIL GR.CSG DRHO. FDC GR.FDC, T NR ~'~... CNL CNTC .CNL TENS..CNL SFLU.OIL GR.CSG DRHO.FDC GR.FDC TNRA.CNL C NT C. CNL TENS.CNL SFLU. G R. C S G ORHO.FDC GR. FDC TNRA.CNL CNTC.CNL TENS.CNL SF.LU. OIL GR.CSG ORMO. FDC GR.FDC T NR ~&. CNL CNTC.CNL TE~S.CNL SFLU.OIL GR.CSG 9RHO. FD:C GR.FDC TNRA.CNL ~CNTC. CNL TENS. CNL SFLU.DIL GR.CSG DRHO.mOC GR.FDC TNR4.CNL CNTC.CNL TENS.CNL -9'99.250 '-9'99.250 -999.250 -999. 250 -999.250 -999. 250 -999.250 .-999.250 -999 . Z 5 O -999.250 &3.219 -999.250 -999.250 -999.250 -999.,250 -999.250 -9'99.250 93.500 -999.250 .-999.250 -999.250 -999.250 -999.250 -999.250 5.~.158 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 49.6~8 -999.250 -999.250 --999.250 -999.250 -999.250 -999.250 53.656 -999.250 -999.250 -9~9.Z50 -999.2:50 -999-255 ~IS TAPE VERIFICATION L!S'TZN~ SCHLUMBERGER ALASK~ SO)4PUTING C~NTE~ DEPT. 42 00. 000 'LO. C-IL SP. OIL -999.2 50 GO. git TENS.CSG 255q.000 DDHI.~DC FFDC:.FGC -999.250 'TENS. F~C -999.250 NP=~.CNL -999.250 RCNT.CNL C~'TC CN~ -999 2~0 ~R CNL D~PT. ~100. 000 !LO. DiL SP.~It -'999.2 50 GR.D!L TENS.~CSG 2510.0~Q OPHI.FDC FFDC.FDC --999.250 NFDC.FDC TENS.FDC -999.250 NPHI.CNL NPOR.CNL -999.250 ~CNT.CNL CFTC.CNL -999.2 50 GR.CNL DEPT. 4 GO0. 000 ILD.DIL OP. OIL -999. 250 GR. DZL TENS.CSG 2450.000 ~HI.FDC FFGC.FDC -999.2D0 NFOC.FOC TENS.FgC -999.250 NPHI.CNL NPOR.CNL -9gg. 250 ~CNT. CNL CFTC. CNL --999.2 50 GR. CNL DEPT. 3900,, 000 ILO.OIL OP. OiL -999.2 50 GR. Di:L TENS.COG 2410.000 DP~I.FDC FFOC.'~' C , g~ -999 250 NFDC.FDC TENS.FDC -999.250 NPHI.CNL NPOR.CNL -999. 250 RCNT.CNL CFTC. CNL -999. 250 G~.CNL DEPT. 3800.000 ILO.D~L SP. OIL '-999.250 G~.OIL TENS.COG ,2370.000 gPH~.FgC FmDC.FDC -999.250 NFDC.FDC TENS.FOC -999.250 NPHI.CNL NPCR.CNL -999,250 ~CNT.CNL CFTC.CNL -999.2 50 G.R. CNL DEPT. 3700.000 ILO.OIL SP.DIL -~99.250 GR,OiL TENS.CSG 2324.000 DPHi. PDC F~DC.FDC -9-~9.250 NFDC.~OC TENS. FDC -999.2.50 NPHI.CNL NPOR.CNL -999.250 RCNT.CNL C ETC. CNL -? 99.2 50 GR.CNL DEPT. 3600.000 ILO.OIL SP. OIL -99~. 2 50 GR. C IL TENS.CSG 22~.000 C'~Hi. FOC F FCC. FOC --999.250 NF DC. F~C TENS.FDC -999.250 NPHI.CNL NPOR.CNL -999.250 RCNT.CNL CFTC. 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C NL T ~ N S. C N L SFLU.OIL GR.CSG DRHg. FDC GR. FDC TNR4.CNL CNTC.CNL T E NS. CNL SFLU.gIL GR.CSG TNRA.CNL C NTC. CNL T E N ,S. C N t ,S FLU. OIL GR.CSG DRHO. FDC GR. FOC T NR ,~. CNL CNTC. "'",.,. N L' TENS.CNL SFLU.DIL GR.CSG DRHg. FDC GR.FOC TNR~.CNL CNTC.CNL TENS.CNL SFLU.OIL GR.CSG ORHO. mDC GR.FDC TNRA.CNL CNTC.CNL TEN'S. CNL SmLU.DZL GR. CSG DRHO.FDC GR.FOC TNR~.CNL CNTC .CNL TENS .CNL -999.. 250 81 -999.250 '-999. Z 50 -999.250 -999.250 -999.250 -999.250 69.500 -999.250 -999.250 -999. 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.2 -ggg .250 .-999.250 -999. 250 77.250 -999.250 -999. 250 -gg9. 250 -999.250 -999.250 -'999.250 68.813 -999.250 -999.250 -999.250 -999.250 -999.2:50 -999.250 50.125 -999.250 -999 -999. 250 -9'99.250 -999.2~0 -999.250 67.750 -999.2.50 -999.250 -999.250 -999.250 -999.250 LIS 'r~.PE~ V~RiFICATInN,., LIST'~NG,: ~.~ SCHLUFSERGER AL~,SKA C g:~.PU'TiNG CENTiER D~SP'T. 3!500. OCO ILD. git SP. OiL -999.2 50 GR.D iL TENS.CSG 7204.000 gPHI.FOC FFEC.FDC -999.250 NFDC.FOC TENS.FgC -999.250 NPHI.CNL NPGR.CNL -999.250 RCNT.CNL CFTC.CNL -999.250 G~.CNL DEPT. '3400. 000 !LD.g !~L SP. OIL .-999· 2 SO GR. OIL TENS.CSG 2174.000 gPHI.FOC FFSC.FDC -999·250 NFgC.. FgC 'TENS. FDC --99'9. 250 NPH~.CNL NPDR.CNL -999.250 ~CNT.CNL CFTC. CNL -999.2 50 GR.CNL DEPT. 3300. 000 ILD. D]L SP.DIL -999.250 'TENS.CSG 2114.000 DPHIo'FgC FiFDC. ~DC -99~.250 NFDC.FDC TENS.FDC -999.Z50 N~H~.CNL NPOR.CNL -999. 250 RCNT.CNL ~C FTC. CNL - 999.250 G~. CNL DEPT. 3290. gOO ILO. S~. OIL -9 99.2 50 :GR ogZL TENS.CSG .Z:gSO· 000 DPHI.FOC FFDC.FDC -999· 250 NF'OC. FDC TENS.i=DC -999.250 NPHI.CNL NPOR.CNL '-99~.250 ~CNT.CNL CFTC. CNL -999. Z'.S O G~. CN:L OEPT. 3100.000 ILO. OIL S Po DIE -999.2~5 O GO. OIL T~N.S.CSG 2020.000 FFDC.FDC -999.250 N~DC.FOC TENS.FEC -995.250 NPM!.CNL NP~.CNL -999.250 gCNT.CNL CFTC· CNL -999.2 50 G~. CNL DEPT. 3000.000 ILO.OIL SP.DIL -999.250 S~.OIL TENS.CSG 1975.000 DPHI.F$C FFEC.FDC -999.250 NFDC.~OC TENS.FDC -999·250 NPHI.CNL NPGR.CNL -999.250 RCNT.CNL C ~:TC.CNL -999.2 ~0 G~.CNL I-~U~-!'989 13:35 · -999. 750 ILM. O'it -999. 250 -999.250 TENS.OIL -999.250 -999.250 RMgB.FDC -99'9.250 -999. 250 C~LI.FDC -999.2:50 -999. 250 T:NPH·CNL -999. 250 · - 999..2.50 ~ C F T. C N iL - 99 9.250 -999. 250 C~L~.CNL -999. 250 '-999.250 ILM.DIL -999.£50 - 999.250 TENS. OiL -99'9..250 -999.250 RHOB.FDC --999.250 -999.250 CALI·~DC -999.250 - 9'99.250 T N P H .. C N t - 99 g. 250 -999° 7_50 RCPT.CNL -999.25C, -999.250 C~Li.CNL -999.Z50 - ') 99.250 I t M. D I ~L - 9'9 9.250 -999.250 TENS.OIL ,-999.250 -999.250 RHOB.FDC -999.250 -'999. i~=0-.;, rAtI,, ·FDC .-999. 250 - 999. 250 TNPH.C NL -9:99.. 250 -999.250 ~CFT.CNL -999.250 -999.250 C~LI.CNL -999.250 -999. 250 ILM. OIL - 999. 250 TSNS.DIL -999. 250 RHOB.FDC -999. 259 C~LI. FDC · - 999..25 O T N ~ H. C N t -999. ?50 RC~=T.CNL -999·259 C,aLI.CNL -?99. 250 !LM.DIL -999..25S TENS.OIL -999.250 RHOB. FDC -999.250 C~LZ.FDC -999.250 TNPH.CNL -999.250 RC~T.CNL -999.25-0 C4LI.CNL -999.250 -999.250 -999.250 - 99 9..2 '50 -'999.250 -999.250 -999.250 -999.250 -999. 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -- 99 '9. Z 50 -999.250 ILM.DIL -999.250 -999.250 TENS.OIL -999.250 -999.250 RHOB.FDC -999.250 -9'99.250 CALI.FDC --999.250 -999.250 TNPH.CNL -999.250 -999.~50 RCFT.CNL '-999.2~0 SFLU.OIL G R. C S G GR.FDC TNRA.CNL C NTC. CNL TENS.CNL S~LU.DIL GR.CS5 GR.~OC TNRA.CNL CNTC.CNL T~NS.CNL SFLU.DIL GR.CSG DRHO.FOC GR.FOC T NR ~. CNL CN'TC.CNL ~:NS CNL SFLU..DIL GR.CSG DRHO.:FDC GR. FOC T NRA .C NL CNTC.CNL T'~NS. CNL SFLU.OIL G~.CSG DRHO.~DC GR.FOC TNR,4.CNL CNTC "NL TENS.CNL SFLU.DIL GR .COG ORHO.FDC GR.FDC TNRA.CNL CNTC.CNL TENS..,.." NL S~LU.DIL GR.CSG DRHO.FDC GR.FDC TNR,&.CNL CNTC.CNL -999.250 72. '? 50 -999. 250 -999,250 -999.250 -999. 250 -999. -999.250 66. 125 -999 · -999.250 -999.250 -999.250 -999.250 -999. 250 55 · :969 -999. 250 -999.250 '-999. 250 -999. 250 -999.250 -999.2'.50 72.750 -999.250 - 9 g 9.250 -999. 250 -999.250 -999.250 -999.250 61.313 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 50.969 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 35.094 -999.250 -999.250 -999.250 -999.250 LIS TAiPE VERIFICATION LISTING SCH:LUMOERGiER ~iLASK:4 CGMPUTING CENTiER CFTC.CNL -999.2 ~0 GR.CN:L DEPT. 28 gO, 000 ILO. C IL SP, OIL -999,250 GR, OIL TENS.,CSG 1890.000 OPHI.FOC FFOC.. !FOC -999.250 NFOC.FOC T~NS.FDC -~99.250 NP~I.CNL NPg~.CNL -999.250 ~CNT.CNL C FTC. CNL -999,2 50 GR,CNL DEP'T. 2700. 000 ILO. OIL SP.OIL .-999.2 50 5P,. OiL TENS.CSG 1~35,090 OPHI.FDC FFDC.FOC -999,.250 NFOC.. FDC TENS.FDC -999,250 NPHI,CNL NPOR.CNL -999.250 RCNT.CNL CFTC, CNL -999. 259 SR. CNL DEPT, !6gO, 00C ILD, SD, DIL -9 TENS.CSG 1810.000 D~HI.FDC FFCC. FDC -999.250 NF DC. FOC TENS:. FDC -999. ~. 50 NPHI.CNL NPO~.CNL -999.250 RCNT.CNL CFTC. CNL -999. 250 GR.CNL DEPT. 25 DO. 000 ILO. OIL SP. OIL -999. 250 GR.gIL TENS.CS~ 1745.000 gPHI.FDC FFDC.FDC -999.250 NFOC,FDC TENS,FDC -999, .250 NPHI.CNL NPOR,CNL -999.25~ RCNT,CNL C:TC. CNL -999.2'50 GP ,-CNL DEPT. 2400.. 000 iLO. OiL SP. OiL -999. Z 50 GR. GIL TENS,CSG 1715.000 gPHI,FOC FFDC,FDC -999.250 NFDC.FQC TENS.FDC -999.250 NPHI.CNL NPCR.CNL -999.250 ~CNT.CNL CFTC,CNL -999,250 SR.CNL DEPT. 2300.0 O0 ILO. CIL SP. OIL '-999.2 50 GR. Eit T ENS.CSG 1~70. gO0 DPHI. FgC FFDC.FOC -999.250 NFQC. FOC TENS. :DC -$99.2~O NPHI.CNL NPOi~. CNL -999.250 RC NT.CNL CFTC. CNL .-9 9~. 250 ~R. CNL DEPT 2200 000 " ~ _ . . .=Lu.niL Sm. OIL -999.250 .SR. OiL TENS.CSG 1610.OOO OPHI.~=gC F~D'C.~CC -'99a 250 ...,,i:mC ~=mr ~ENS.FDC -999.290 NPHI.CNL 1-~UG-1959 13:3!5 - 999. - 999. - 99'9. -999. -999. - 9~99. -999. -999. · - 999. -999. -999. - 999. - 999. -999. -999. -999. -999. -999. -999. - 999. - 99'9. -999. -:999. -999, .-999, - 999, -999. - 999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999, -999. - 99 '9. -999. - 99 '9. -999. -999. -999. -999. 250 CaLI.CNL 250 ILM..OIL 250 TEiNS.DIL 250 RHOB.FDC 25 O: C ~ L I. F O C 250 TNPW.CNL 250 RC~T.CNL ~50 CALI.CNL ,-999,250 -999.250 -999. 250 -999.250 -999.250 · -99'9. 250 - 9'99 250 -999. 250 250 ILM.DIL -999.250 250 'TENS,OIL -999.250 250 RHOB.FDC -999.250 250 CALI,FOC '-999.250 ',~50 TNPH.CN:L -999.250 250 R C F T. C N L - 999. ,250 250 C,~LI. CNL -999.250 250 ILM.OIL -999.250 250 TENS.OIL -999.250 250 RHgB.FD~C -999,250 250 C a t I. F O C -999. :250 250 TNPH,CNL -999.250 ~50 ~C :T.CNL -999, ~50 .250 C .~ L I, C N L - 999. Z 5 O 250 ILN.DIL 250 TENS.DIL 250 RHOB.FDC 250 C~LI.FDC 250 T N P H. C N~L 250 RCFT.CNL 250 CALI,CNL -999.250 -'999. 250 -999.250 -999.250 -999.250 -999.250 -999.250 250 ILM.DIL -999.250 250 T~ENS.DIL -999.250 250 RHOB. FD'C -999,250 250 CALI.FDC -999.250 250 TNPH,CNL -99'~.250 250 RCFT,CNL -999.250 250 C~.LI,CNL -9~9,250 :!50 ILM.O!L -999.250 250 TENS.DiL -999.250 250 RHDB.FDC -999.250 250 C~LI.FDC -999.250 250 TN=H.CNL -999.250 250 RCFT.CNL -999.250 259 C~LI.CNL -99'9.250 250 ILM.DIL 250 TENS.OIL 250 RHOB.FOC 250 CALI.FOC 250 TNPH.CNL -999.250 -999.250 -99 9.250 -99 9.250 - 999. 250 TSNS.CNL SFLU.DIL GR.CSG TNR ,~ .CNL CNTC.CN~ TENS.CNL, S FLU, OIL GR,C ~q $ ~ DRHO.FDC G~. ~DC TNRA.CNL ,C N TC. C NJ_ T~NS.CNL SFLU.DIL GR.CSG O RHO. GR.FDC TNR,~.CNL CNTC .CNL TENS.CNL SFLU.DIL GR.CSG gRJig. FDC GR. FDC TNRA.CNL C NT C. C NL TENS.CNL SFLU,OIL GR,CSG ORHO.FDC GR,FOC TNRa,CNL CNTC,CNL TENS,CNL S~LU.DIL GR.CSG DRHO.FDC GR.FDC TNRA.CNL CNTC.CNL TENS.CNL SFLU.OIL GR.CSG DRHO.=DC GR,FDC TNR&.CNL P~GE: 12 -999.250 -999.Z50 32.781 -999.250 -999.250 -999.250 - 999'. 2:50 -999. 250 -999.250 40.969 -999.250 -999.250 -99'9.290 -999.250 ,-999.250 -999.250 30.813 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 26.250 -999.250 -999. Z 50 - 999.250 -999.250 -999.250 -999.250 32.875 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 31.078 -999.250 .-999.250 -999.250 -999.250 -999.250 -999.2:50 33.698 -9'99.250 -999,250 -999.250 SCHLUMBERGER ALAS~,~. ~PUTiNS CENT::E~ NPO~.CNL -999.2',.50 ~CNT.CNL CFTC,. CNL -$99.2 50 GR. CNL DEPT. 21 O0 SP.DIL -999. 250 GR. D IL TENS.CSG 1~50.000 DPHI.FgC FF~C. i=DC -999,250 NFgC.F~C TENS.FDC -999.250 NPHi. CNL NP~R.CNL -999. 250 RCNT.CNL CFTC. CNL -999.250 G~. CNL DEPT.. Z S o. D I L -'999.250 iS R :. D Z L TiENS.CSG 11460. gOO O:.PHL.FgC' FFDC.FDC -9~9.250 NFOC.FOC T ENS.i~DC -9 99, 250 NPHI:.CNL NPOR.CNL -999,250 RCNT.CN~ CFTC.CNL -999.2:50 GR.CNL D!EPT. 1900,. OOO ILD, OIL SP. DIL -9'99.250 GR. DIL TENS.CSG 1400,000 DPH~.~OC FFD:C.iFDC -999, TENS. ~DC --'~ 99. 250 NPHI.CNL NPDR.CNL .-~gg. ZEO ~CNT.CNL C~TC. CNL -999.2 50 GR.CNL DEPT. 1800. OOO ILO. OIL SP. OIL -999. 250 GR~. OIL TENS.C'SG 1360.000 ~PH.Io FDC F:FDC.FDC -999.250 NFOC.FDC TENS.~mDC -9~9.250 NPH~.CNL NPGR.CNL -999.250 ~CNT.CNL CFTC.CNL -99S. 250 ~R. CNL DEPT. 1700.0 O0 ILO. S~.DIL -999.250 GR.DiL TENS.CSG 13t5.00~ 'DPH.I. FDC FFDC.FDC -999. 250 NFgC.FDC TENS.i:DC -'999,250 N~HI.CNL NPDR.CNL -999.2~0 ~CNT.CNL C~TC. CNL -999.2 50 ~. CNL -999. - 999. -999. -999. ] 99. -'99 '9. · -999. -999. I-~UG-1989 13::3:5 -999, .-999, -999. -999, -999. -999, - 999, -999. -'999. -999. - 99'9. -'999. -999. -- 999. - ')99. -999. -999. -999. -999. -999. -999. '-999. -999. -999, -'999, -999. -999. - 999. DEPT. 1600. gOO iLg. CIL -999. SP. OIL -9'99. Z 5 g GR. OIL -999. TENS. CSG 1Z 70.0 O0 g~Hl .FDC - 999. FFDC.FDC --999. 250 NF:DC.FuC~ - 999. TENS. ~CC -999. 250 NPH'I.CNL -999. NPCR.CNL -999. ~ CFTC. CNL -9 99.2 50 5R DEP'T. 15 00. ~ O 0 ILD. ~ IL - S~.OIL -999. 250 GR. C'IL -999. TENS..CSG 1235.000 O~HI.~DC -999. FFDC.FDC -999.250 NFgC.FQC -999. ;;' '~ O ~CFT CNL ,250 C~LI.CNL -999,250 -999,.250 259 I L M. D ii L - '999. ,250 259 TENS. OIL -999.Z50 250 i~HOB, FDC -999.250 250 C ~, L I. ~ D C - 999.250 250 T N PH. C N:L ,-99 9.2,50 250 RCFT.CNL -999.250 250 C~LI.CN~L -999.250 250 ILM.DI<L -999.250 250 TENS.OIL -999.250 Z 50 ~ H: g B. ~ g C -999. ,250 250 CALI.FDC .-999.250 ~50 TNPH.CNL -999.250 ~50 RCIFT.CNL -999.,250 ~5~ C~LI.CNL -999.2,50 250 ILM. DIL 250 TENS.DIL 350 RHOB.FDC 250 C ~ L I. F O C .~50 TNPH. CNL 250 RC~T.CNL 250 C~,LI.CNL -999,250 -999,250 -999,250 -- 99 9.250 -999.250 -999.250 - 99 9. Z 5 O 250 ILM.DIL -999.250 250 TENS.OIL -999.250 250 RHO~, ~O,C -999.250 250 C~LI.FDC -99'9.250 250 TNPH.CNL -999.250 250 RCFT.CNL -999.250 ~50 CALI.CNL -999.250 250 ILM.DiL ,250 TSNS.OIL 250 RHO8. ~:OC 250 CaLI.FOC 250 TNPH.CNL ~50 RC~:T.CNL ~0 rALI.CNL 250 iLM.DIL 250 TENS.OIL 250 RHOB.FgC 250 C~LI.FOC '~:O TNPH CNL 2~g ~C=T.CNL 250 CAL'I.CNL -:999,250 -999,250 -999,250 -999,250 -999,250 -999,250 - 99 '9.2 50 -999,250 -999,250 -999,250 - )9 9.250 -999,250 -'999.250 -999.250 250 ILM.DIL -999.250 250 TENS.OIL -)99.250 250 ~H3B.FDC -999,250 250 CALI.F~C -99'9.250 CNTC.CNL 'T 'E N S. C N L SFLU'DIL GR.CSG DRHO, FDC GR.FDC T N R ,.&. C N L CNTC .CNL T~;~S. CNL SFLU.OIL GR. CSG D~HO,. FDC G~R. ~gC TNR ~. CN~ CNTC.CNL T EN.S. CNL SFLU.OIL GR.CS6 GR:.FOC T NRA. C NL CNTC.CNL TENS,CNL S F L U. O I L GR.CSG DRHO.. ¢DC GR.'FDC TNRA,CNL C N TC. 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CNL - 9~9.250 GR.CNL END OF DATa :k~ I-~UG-tgB9 13::35, -999. -999. -999. -999. - 99'9. - 999. -999. -999. -999. - 9'99. 999. - 99 <9. -999. -999. - ') 99. -999. · -999. -999. -999. - ~99. - 999. - 99 '9. - 999. - 999,. - 9!99 . - 999. -999. -999. - 999. -999. - 99:9. -'999. -999. - 999. -999. -999. -999. -999. - 999. - 999. - 999. -999. - 99 9. -999. - 999. 250 TNPH. CNL Z 5 O R C F T . :C N L 250 CALI.CNL ,- 9 '99. Z 50 .-9'99.250 -999 . 250 150 ILM.DIL -999.250 250 TENS.DIL -999.250 250 R:HOB.FOC -999.250 250 CALI.FOC -99'9.250 2:50 TNPH.CNL -999.250 250 ~CFT.CNL -'9'99. 250 250 CALI.CNL -999.250 250 IL~..DiL 250 T E N S. O 'I L ZSO RHOB.FDC 250 CALI. FOC ZSO TNPH. CNL ;~-50 RCF'T.CNL 250 CALI.CNL 250 ILM.DIL 250 TENS.DIL 250 RHOB.FDC 250 CAiLI.FDC Z50 TNPH.CNL 250 RC~T.CNL !50 CALI.CNL -999.250 -999. ,250 · -99 9. 250 -999.250 -999.250 -999. 250 · -'99 9.250 -999.250 - 9 ~99.. 250 -'999.250 .-999.250 -999.25,0 - 999.250 -999.250 250 ILM..DIL -999.250 ZED TENS.DIL -999. 250 250 RHgBoFDC -999.250 250 CALI.FDC -'999 250 250 TNPH.CNL -999.250 250 ~CFT.CNL -999.250 25'~ CALZ.CNL 250 ILM.DIL -99.9.250 250 'TENS.DIL -999.250 250 RHOB.FDC -999.250 :0 CALI FDC -999 250 250 TNPH.CNL -'999.250 259 RC~T.CNL -999.250 250 CALI.CNL -999.2.5.0 ZSO iLM.CIL -999.250 '~_50 TENS. D IL -999. Z50 ZEO RHgB. FDC -999.250 250 CALI.FDC -99'9.250 250 TNPH.CNL -999.250 250 RCFT.CNL -999.250 250 Ca'LI. CNL -999.25~ TNRA.CNL CNTC.CNL TeNS.CNL SF,LU.DIL GR.CSG DRHO.FDC GI.FDC TNRA.CNL CNTC.CNL T~NS.CNL SFLU.OIL GR.CSG DRHO.~DC GR.FDC TNRA..CNL CNTC.CNL TENS.CNL SFiLU.DIL GR.CSG DRHO. FDC GR.FDC TNRA.CNL CNTC.CNL TENS.CNL SFLU.DIL GR.CSG DRHO. FDC TNR~.CNL CNTC.CNL TE~.S.CNL SFLU.DIL GR.CSG DRHO.FDC GR.FDC TNRA.CNL CNTC.CNL TENS.CNL SFLU.DIL GR.CSG D2HO.FDC u~.~DC TNRa. CNL CNTC.CNL TENS.CNL P i~ ~i.~ E: :14 -999.250 - 999.250 -999.2'50 -999.250 27.625 -999.250 -999.250 -999.290 -999.250 -999.250 -999.250 22.719 -999.250 -999.250 -999.250 -999.250 -999.250 .-999.250 27.6'72 -999.250 -999.250 -999.250 ,-999.250 -999.250 -999.250 20.9,22 -9'99.250 -999.250 -999.250 -999.250 -999.250 -999.250 38.656 -999.250 -999.250 ,-999.250 -999.250 -999.250 -999.250 22.594 -999.250 .-999.250 -999.250 -999.,250 -999,250 .IS TAPE VERIFICATION LISTING ~ ~K COHPUT ~CHLUM~,GER ALA~:.~ ING 1-&UG-lg89 13:35 PAGE: 15 ~ FILE TR~ILE~ ~ FILE NAME : 'EDIT .001 SERVICE : FLIC VE~SION : OgleD2 DATE : 89/08/ 1 MAX REC SIZE : 1096 FILE TY~E : LO LaST ~ILE : F'IL~ NAME ' ~EDIT .002 S:ERVICE ' ~:LiC V ~ =RSI3N D AT ~,E : ~ 9./0 ~/ MAX R~C SIZE : 1096 F!L~E TYP~E : LO L~ST FILE FILE - EDIT.OO2 aRCS ALASK~ INC. KUPARUK 2K '- 9 50-103-20108 M:~IN P~SS LOG OA'TA DATA SAMPLED EVERY -.lOgO ~EET DATA iNCLUg~Eg - TOCL iEXTENSiCN TOOL TYPE US ~g N,~ME mDC F~H FORMATION C, FNSITY 6776' u T 0 625,5 ' CNT-~/~/H .CNH CON°ENSATED~. NEUTRON 6760' TO 6255' .IS TAFE V,ERIFZCATION LISTING ;CHLUM~ERGER ALASKA COMPUTING CENTER I-~UG-198g 1'3: P~GE: 16 TABLE 'TYPiE : CONS T UN 'Z VALU OEFZ CN FN WN A P IN FL SECT T OWN RANG COUN ST.~T NATI ENGI W Z'TN SON PDAT EPD LMF EK9 EDF EGL TDD F ~T F T F'T FT FT A~CO ~L~SKA !NC. KUPARUK 2K-9 96~ FSL & 94' FEL 02 ION NOR'TH .~LASKA USA F R .IT Z ~ E D ZXONISq~LLW:ODD 54~364 ! 54. 1~4. 1 13. 6.~00. COMP.~NY NAME ~IEL3 NAME WELL NAME ~PI SERZ,~L F I EL :'3 LOC/~.T t ON S ~E C T i D N TOWNSHIP R~NGE COUN'T~ STATE O:R PROVINC~ N,~TIO-N ENGINEER~ S WITNESS~S NAME SERVICE ORDER NUMBER eERMANENT DATUM LOG MEASURED FROM TABLE TYPE : CURV D~FI DEPT DPHI RHg5 DRHO FFDC NFDC CALI GR TENS NPHI TNPH TNRA NDOR RCN T RCFT CNTC CFTC GR CALI TENS ,DEPTH CHANNEL NA~E DENSITY POROSITY BULK D~NSITY FA~ F~C COUNT ~TE NEA~ F~C COUNT RATE CALIPE~ GAMMA TENSION NEUTRON ~OPOSI TY T~E2MAL NEUTRON P[RCS!TY CALI~ATE~ THErMaL NEUTRON R~TIO NEUTRON ~RG~ITV ~W CORRECTED NEaR THErMaL COUNTS RAW CC~R~CTE~ F~&P T~ER~L COUNTS CORRECTE~ N~EAP THErmAL COUNTS rmRREC~ED~ ,~A~ TH~RMAL COUNTS GAMMA RAY C~-LIPE~ 'TENSION ' ,_ ~ ''r'ON LI~TING .IS TA=F SCHLUMBERGiER ~LA. SK~ CgMPUTING CENTER I-,aUG-1989 113:3,5 1 ? ** S~:T,. TYPiE -CH,~N ~'~.~ NAM;,. SFRV_ UNI*~ SERV~rE.~ /1PI AP'T.. ,~:.PI API. ~IL~,.. NUMB NUMB SIZE REPR ID CRO=R :~ LOG TYPE CL~,SS MOO NUMB S~MP ELEM CODE P R 0 C E S S (H E X ) DEP:T FT 548384 OD DPHI FDH PU 548'364 07 RHO8 FDH G/C3 5-483.64 07 DRMO FDH G/C3 54~364 OT FFDC FDH CPS 54:~ 36~ 07 NFgC FDH CPS 548364 OT CALI FgH IN 548364 CT GR FDH G~PI '543364 07 TENS ~OH L8 543364 07 NPHI CNH PU 54~364 07 TNPH GNH PU 54~3~4 07 TNR~ CNH 543364 07 NPOR CNH PU 548364 OT RCNT CNH CPS 5~3364 07 RCFT ~. CPS 5~64 OT CNTC CNH C~S 548364 07 CFTC CNH CPS 54~254 07 GR CNH GAPi 54~364 07 CALI CNH IN 54,33 6~ 07 TENS CNH LB 548384 07 DOg O0 0 Z t i 4 68 635 21 0 Z I 1 4 68 356 OI 0 2 t I 4 68 354 O! O 2 1 I 4 68 35~ O1 0 Z I ! 4 68 ZSO 01 0 2 I 1 4 68 310 O1 0 2 I 1 4 68 83.5 Zl O Z I 1 4 68 890 OD 0 Z 1 1 ~ 68 890 O0 0 2 ! 1 4 68 420 O1 O 2 1 1 4 68 890 OD 0 Z 1 I 4 68 42 O 0 1 0 Z 1 1 4 68 420 O1 O 2 t 1 4 68 420 O1 0 2 I 1 4 68 z, 20 Ol 0 2 I t 4 68 310 O1 O 2 I 1 4 6,8 ZSO O1 O 2 :I I 4 68 635 21 0 2 I 1 4 68 9000000000 0000000000 O00000OO00 0000000000 O0000OOOOO 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 OOOO000000 OOOO000000 0000000000 0000000000 O000OO0000 O00000OOOO OOOOOOO000 IS TAPE, VERIFiCATiCN LI.STiNG SCHLU~ERGiER ~LfiSK~ CCMPU'TINS CENTER DATA DEPT. ~5806.800 gPHI.FDH FFDC.FDH .436..750 NFgC.FDH TENS.FDH 3984,000 NPHI.CNH NPDR.CNH 38.026 ~CNT.CNH CFTC.CNH 758.145 GR.CNH DEPT. 6800.000 OPHI.FDH FFDC.FDH 436.750 NFDC.FDH TENS.FDH '39:~4.0 O0 NPHI.CNH NP~R.CNH 38.026 RCN'T,. CNH CFTC. CNH 758. 145 GR. CNH DEPT. 6700,000 9PHI,FOH FFDC,FDH 4~2,500 NFDC.¢OH TENS.FDH 39134.000 NPHI.CNH NP0~.CNH 36.~92 RCNT.CNH CFTC,CNH 763.242 ~R.CNH DEPT. 6600,000 DPHI,FDH FFDC.FDH 478.250 NFOC,FDH Ti=_NS. ~DH 3~04.000 NPH~.CNH NPgR.CNH 35,B35 ~CN'T.CNH CFTC.CNH iB2 9, 730 GP,.CNH DEPT. 6DOO. 000 gPH!.FDH F~DC.FDH 459.000 NFDC.FOH TENS.FDH 3804.000 NP!HI.CNH NPCR.CN!H 28,576 RCNT,CNH CFTC,CNH 1 ! 83.00~: GR, CNH DEPT, 540g,000 OPHI.FgH FFDC.FDH 73~,000 NFDC,FOH TENS.FDH 3700,000 NPHI.CNH NPC~.CNM 43.036 ~CNT.CNH CFTC.CNH 522.3~4 GR.CNH DEPT. 5300.000 OPHi.FDH F~:DC.FDH 5&9.500 NFDC.FDH TENS.PDH 359~.000 NPHI.CNH NPOR.CNH .~Z..3 53 ~CNT,CNH C FTC,. CNH 605.'796 GR . CNH DEPT. ,5200.000 DPHi.~DH FFOC.FDH 230.375 NFDC.FDH TENS.FDH 3530.000 NPHI.CNH N~g~.CNH ~7.046 RCNT.CNH CFTC..CNH 419.!~7 G~.CNH DEPT. 6190.399 DPHI.FDH FFCC.FCH 245,375 N~:DC.FDH T~NS. ~DH 34 90.000 NPHI. CNH NPOR. CNH ~9.3 34 ~C NT.CNH CFTC. CNH 3'7~. 9 30 GR. CNH I-~UG.-l~89 13:35 54 7 39. 2 29'7 12.2 39. 2297. ~22. 590. 38. 2261. 112. 37. 2 506. 96. 12. 51. 28. 945. 8'7. 22. 6TO. 1860. I!!. 14. 627. 43. 2!01. !91. 203. 53. 1588. 14, 0. 21. 204o ~*ST ~29. 979 RHOB. FDH 500 CALI.~DH 3'9.4 TNPH.CNH 279 RCFT.CNH 875 C~,LI.CNH 979 RH0~.FDH 500 C~tI. FDH 394 TNPH.CNH 279 RCFT.CNH 37~ CALI.CNH 806 RHOB.FOH 500 C A~L I. F g H 942 TNPH.CNH ~3 9 RC~FT. CNH 62'5 'C.~LI. CNH 373 RHO8,FgH 500 CALI,FgH 536 TNPH,CNH 320 ~C~T,.CNH 125 C~LI.CNH 317 RHOB,FDH 1500 :CALI.FOH 520 TNPH,CNH 827 RCFT.CNH 938 CALI.CNH 199 RHOB,FDH OOg CALI.FDH 553 'TN~'H,CNH 556 RCFT.CNH 68B C~iLI.CNH 253 ~HOS.FDH 500 CALI.:DH 362 TNPH. CNH 713 RCFT.CNM 125 CALI.CNH 910 RHOB.FDH 500 CALI.FDH 319 TNPH.CNH 753 RCFT.CNH ~75 CALI.CNH 303 RHOE.FOH 125 C~LS.FDH ~ B B TNPH. C NH 156 RCFT.CNH 750 CALI.CNH 2. 469 6.305 38.026 66 8. ,503 6.305 2.4-:69 6.305 38.02.6 66 8. 603 6.305 Z. 505 5.2 Z7 3.6. 952 672.7~.1 6. 227 2.462 6.33;2 35.544 745.170 6. '3~ ) 2.447 6.305 29.5.28 978.268 6.305 2. 284 6.617 ~4.679 479.462 6.61T 2.415 6.488 42,29'7 509.759 6.488 2,338 6,242 47.478 37!,035 6,242 2.zgB 6.250 49.210 333.462 6. 250 DRHO.;DH GR.FDH 'TNRfi.CNH CNTC.CNH 'TENS.CNH DRHO.FOH GR.FDH TNRA.CNH CNTC.CNH TENS.CNH DRHO.FDH TNRA.CNH CNTC.CNH TENS.CNH DRHO.FDH GR.~DH TNRA.CNH CNTC.CNH TENS.CNH DRHO.FDH GR.mOH TNRA.CNH CNTC.CNH TENS.CNH ORHO.FDH GR.FDH 'TNRA.CNH CNTC.CNH TENS.CNH DRHD,.~DH GR.FDH 'TNR~.CNH CNTC.CNH TEN$.CNH ORHO. FCH GR.FOH TNR,~. CNH CNTC.CNH TENS.CNH DRHO.FDH GR.mDH TNRA.CNH CNT ~ ~,CNH T~NSoCNH P~E: 18 -0.001 122.8'75 3.144 23~7.402 3984.000 -O,.OOl 122.875 3.144 2347.402 3984. 000 0.040 112.625 3.1t5 2307.719 393~.000 0. 029 96.1.25 3.0,44 2~3B.1'70 3804.000 -0.003 $7.938 2.4'93 30t3.789 3804,000 0.025 111.688 3.608 1~45.607 3700.000 0.038 191.125 3.399 20a5.773 3594.000 -0.39Z 140.875 3.928 1547.483 3530.000 -0.404 129.750 4.189 1428.570 3~90.000 LIS TAPE VERIFZCATZDN :LZS'TING SCH'LUM~ERGER AL~SK~! COMPUTING CENTER t-~UiS-1989 !3:35 ;~ ~-X-'~'~ FILE FIL~-E NAME *- ~mlr~- . .002 SERV~C:~ V:ERSION : OOiA02 DAT~ : BD/08/ 1 MAX R'~EC SIZ~ : 1096 FIL~ TYP~ : L A S T F I L E ~-~--~ SERVICE NA~E DATE ~ R I G I N TAPE NAME CONTINUATIgN PREVIOUS TAPE COM~MENT :~-~ REEL TR AIiLE~ e.~.-.~ SERVICE NAM~ : EDIT DATE ': 89/0.~! i ORIGIN : FLiC REEL N~ME : 7.3~I'3 CONTINUATIC..N ~ : PREVIOUS REEL COMMENT : ~.PC~, KUm4RUK, 2K--9, .A'~I ~SO-IO]-ZOI08
