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Home My WebLink About188-075Image Project Well History File Cover Page XHVZE This page identifies those itemS that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organization RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: o Diskettes, No. [] Maps: Grayscale items: Poor Quality Originals: Other: [] Other, No/Type D Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds TOTALPAGES: ~)7 NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: [] Other ISl Project Proofing By: Staff Proof Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl SCANNED BY~ BEVERLY BRE~ SHERYI MARIA LOWELl ReScanned (done) RE SCANNED BREN VINCENT SHERYL MARIA LOWELL DATE' ~SI General Notes or Comments about this file: PAGES: Quality Checked (do.el v ,015 • • snAo2 DATA LOGGED WELL LOG TRANSMITTAL 0A0/2013 M K BENDER To: Alaska Oil and Gas Conservation Comm. September 30, 2013 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 c; our 2013 RE: Multi Finger Caliper(MFC): 30-03 ;`` '7X- Run Date: 9/26/2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Matthew Cook,Halliburton Wireline&Perforating, 6900 Arctic Blvd.,Anchorage,AK 99518 matthew.cook@halliburton.com 30-03 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-21838-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Matthew Cook M E i El, a. 0 t 0`i y 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: pik 3 Signed: ) 6a2e.42z • • ConocoPh i I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 30, 2008 ~~ ' AU G ~. ~~ 208 Mr. Tom Maunder ~, Alaska Oil & Gas Commission ~ Q 333 West 7~' Avenue, Suite 100 ~ ~f ~ ~ /' Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 27, 2008. The corrosion inhibitor/sealant was pumped July 3 and July 30, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ~~ M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) a Date Kuparuk Field 7/30/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1Y-06A 197-134 6" NA 6" NA 1 7/3/2008 1 Y-08 183-062 6" NA 6" NA 1 7/3/2008 1Y-18 193-106 15" NA 15" NA 1.7 7/3/2008 1 Y-19 193-107 25" NA 25" NA 4.25 7/3/2008 1 Y-23 193-071 14" NA 14" NA 1.7 7/3/2008 1 Y-25 18$-089 12" NA 12" NA 2.5 7/3/2008 30-01 188-073 SF NA 16" NA 3.5 7/30/2008 30-02A 207-158 SF NA 15" NA 3.1 7/30/2008 30-03 188-075 SF NA 16" NA 3.2 7/30/2008 30-06 188-060 18' 4.90 18" 7/27/2008 5.25 7/30/2008 30-08 188-064 9' 4" 9.50 36" 7/27/2008 25 7/30/2008 30-10 188-059 15' 3.00 16" 7/27/2008 6.3 7/30/2008 30-11 188-042 53' 5.90 46" 7/27/2008 12 7/30/2008 30-13 188-040 SF NA 12" NA 2 7/30/2008 30-15 188-031 32' 5.80 23" 7/27/2008 5.3 7/30/2008 30-18 188-026 39' 5.30 18" 7/27/2008 10 7/30/2008 I I' MEMORANDUM TO: Julie Heusser, Commissioner THRU: State of Alaska Alaska Oil and Gas Conservation Commission DATE: January 26, 2001 Tom Maunder, P. I. Supervisor FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Kuparuk River Unit 30 Pad F. riday, January 26, 2001: I traveled to the Kuparuk River Field and witnessed the 90-day retest of the safety valve systems on 30 Pad. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 12 wells and 24. components With one failure observed. The Low pressure pilot on WAG injector 30-05 tripped below the required set point. This pilot was retested and passed at the the time of this .test. Eamie Barndt conducted the testing today he demonstrated good test procedure and was a pleasure to work with ,All. the wellhouses entered at this location were clean and all related equipment appeared to be in good. condition. Summary: I witnessed the 90-day SVS testing at 30 Pad in the Kuparuk River Field. KRU 30 Pad, 12 wells, 24 components, 1 failure ~4.1% failure rate 12 wellhouse inspections Attachment: SVS KRU 30 Pad 1-26-01 CS X Unclassified Confidential (Unclassified if doc. Removed) SVS KRU 30 Pad 1-26-01 CS.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator:, .P, h, il!~ps Operator Rep: Eamie Barndt _ AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Field/Unit/Pad: Kupamk / KRU / 30 Separator psi: LPS 67 Date: 1/26/01 HPS i . i L I I I I III _ I I1[~! ~i ~~.~..' . , I Well Permit Separ Set L/P · Test ..Test Test Date Oil, WAG, GINJ, Number .Number .... psi.,.. PSI' Trip- Code Code Code Passed GAS or CYCLE 30-01 - 1880730 "67 '70 80'' 'P P' .......... OIL 30-02'' 1}180740"'' 67 '70 60 P p, .. OIL 30-03" ~.~i~ .-.67' i'.' "' ' . ' ......... 70 60 P P OIL 30-04 . ~-~0620 ' 67 70 '" 65 e .... P .... OIL 130-06 1880600: ' .'- '" , ....... 30.08' ' 1880640 · 67! " 70 - 70 - " P P OILI 30.09. .. 1880610 6,7 70 40 P , ,P .......... 0iL 30-I1 1880420' ',67~ · 70' 60 P 'P · 0'IL ' _ , 30-13'' 1880400 ' ' 67 70 60 P ,P' .......... ................. OIL 30-14 1880390 30-15 .... 1'880310 '"-" 67 '70 '.";/0 V ' P ........ OIL 30'-'18 ' '1880260 .... 6;/ 70 "55 ' P - P .... OIL . 30-20 19704~0 '- 67 " '~'(]''' 60' "P 'P OIL · 30'08,, . "~88o7~o 3.750 ' 9.0,o,0! ,', ~io6" '3 ,'V" .... , "i' ' ~/2~,)o~ '., ,, WA~, Wells: 12 Components: 24 Failures: 1 Failure Rate: 4.17% 1:19o Oay Remarks: Pilot on WAG injector 30-05 tripped below,required set pr, ess~e...Pilo, t was r,etested .an,d passed, t..his dat~e., ... RJF 1/16/01 Page 1 ofl SVS KRU 30 Pad 1-26-01 CS.xls MICROFILMED 10/12/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE /'--'" STATE OF ALASKA ~ ~ OIL AND GAS ~RVATION ~MIS~iON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Pull tubing Alter casing , Repair well ii 2. Name of OperatOr 15. Type of Well: I Development :X ARCO Alaska. Inc. Exploratory 3. Address I Stratigraphic P. O. Box 100360, Anchomn~e, AK 99510I service _ 4. Location of well at surface 767' FNL, 1867' FWL, Sec. 22, T13N, R9E, UM At top of productive interval 1512' FSL, 948' FEL, Sec. 15, T13N, R9E, At effective depth 1238' FSL, 909' FEL, Sec. 15, T13N, R9E, At total depth 1184' FSL, 839. FEL~ Sec. 15~ T13N, R9E, 12. Present well condition ~ummary Total Depth: Operatio~ Shutdown Stimulate X' ' Plugging Perforate .. Other __ ,. 6. Datum elevation (DF or KB) feet UM UM U,M measured 91 4 2' true vertical 7025' feet feet Plugs (measured) 59' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 30-03 9. Permit number/approval number 88-75 10. APl number 50-029-21838 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 9 01 5' feet true vertical 6 923' feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 115' 16" 51 49' 9 5/8" 9116' 7" measured 8611'-8621 ', true vertical 6602'-6610', Cemented Measured depth True vertical depth 193 Sx AS I 1 1 5' 1 1 5' 1250 Sx AS III & 5149' 41 1 1' 350 Sx Class G & Top Job w/150 sx AS I 225 Sx Class G 91 1 6' 6 9 9 6' 8658'-8673', 6636'-6653', 8680'-8704', 8720'-8740' Tubing (size, grade, and measured depth) 2 7/8" 6.5# J-55, EUE 8 RD, ABMOD, 8538' Packers and SSSV (type and measured depth) sssv: OTIS "F.MX" r 1792', packer: AVA "RHS",. 8466' 13. Stimulation or cement squeeze summary 14. 6655'-6677°, 6684'-6690°c Intervals treated (measured) Perforated interval. Treatment description including volumes used and final pressure Refractured A San.d..w/174.5 M L__R.S proppan~ & 2196 BBL gelled sea water. Final treating Pressure 6200. Re_Dre_~,e_ntative Daily Average Production or Inlection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 900 530 0 - 1200 Subsequent to operation 1 5 5 6 / 8 21 / 0 - 9 0 0 15. Attachments ! 16, Status of well classification as: Copies of Logs and Surveys run -- I Water Injector ._. Daily Report of Well Operations __ Oil X Gas Suspended 17: I hereby certify that the foregoing is true and correct to the best of my knowledge. 125 130 :orm 10-404 Rev 09/12/90 Title Operations Engineer Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. ' 'Subsidiary of Atlantic Richfield Company WELL ¢ 'RACTOR REMARKS PBDT IFIELD - DISTRICT- STATE IOPERATION AT REPORT TIME WELL SERVICE REPORT I DAYS/ DATE I /o--/'-~/ 1103' //,3? /(, ~ o /f' D wJ o ,r'"i CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Report I °F aFi miles -.. REMARKS CONTINUED: ~.. CAMCO OTIS SCHLUMBERGER DRESSER-ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER B. J. HUGHES Roustabouts Diesel Methanol Supervision Pre-Job Safety Meeting DESCRIPTION ACCUM. TOTAL TOTAL FIELD ESTIMATE DAILY Jls'gned AFE ~'""~ STATE OF ALASKA '~"~ ~ ' ALASKA~OIL AND GAS CONSERVATION coMMIsSION WELL COMPLETION OR RECOMPLETION REPORT AND LOCI 1. Status of Well Classification of Service Well OIL ~.~ GAS ,r-] SUSPENDED ~J ABANDONED ~ SERVICE [] .... 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 88-75 3. Address 8. APl Number P.0. Box 100360, Anchorage, AK 99510-0360 50- 029-21838 4. Location of well at surface 9. Unit or Lease Name 767' FNL, 1867' FWL, Sec. 22, T13N, RgE, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1512' FNL, 948' FEL, Sec. 15, T13N, R9E, UM 30-3 ... At Total Depth 11. Field and Pool 118/4" FNL, 839' FEL, Sec. 15, T13N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 59" ADL 2551:3 ALK 2554 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 08/29/88 09/05/88 0:3/1:3/89*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey ! 20. Depth where SSSV set 121.Thickne~s of Permafrost 9140'MD/7023'TVD 9025'MD/6931 'TVD YES [] NO [] 1792 feet MD 1700' (approx.) 22. Type Electric or Other Logs Run D IL/FDC/CNL/GR/Cal, CBL/GR,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" ~2.S# H-b,O .~,,rf 11~' ?4" !9_~ _~x .A_$ ! q-~/R" ~.n~ .I-~R R,,rf 51/~q' !~_-!/4" !~_50 _~X .A_$ !!! & 350 _~X C.~_ss O _ Tnn {nh w/l~l'l ev Gq I 7'" ?R.O# I-RR .c:;,,r.f cl11¢;' R_-1./2,! 22R ~Y I~lnnc~ ~,, 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) ... Perforated w/8 spf 2-7/8" 85~8 8':57' 8720-8740 'MD/6688 ' -6704 'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8574'-8576" 100 SX C] ass G See attached Addendtm dated 4/6/89, for fracture data. , , 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) N/A . I Date of Test Hours Tested iPRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO :TEST PERIOD e I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE e 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. .on RECEI.VED Note: Drilled RR 9/7/88. Perforated well and tubing run 10/1/88. Fractured we]~][a,~kc!.Oii.&.Gas.Corl$,C;.~,.%~ Form 10407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ,, · · GEoLOGIc MARKERS FORMATION TESTS · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 8572' 6572' N/A Base Kuparuk C 8621' 6610' Top Kuparuk A 8646' 6630' Base Kuparuk A 8784' 6738' 31. LIST OF ATTACHMENTS Addendum {dated 4/6/89) , 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals 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 (D.F, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 9/17/88 3/13/89 30-3 Rn GR/JB to 9014' WL PBTD. Rn CBL/GR f/9015'-8000'. Rn gyro f/9000' to surf. Frac Kuparuk A-1 perfs 8720'-8740' MD in five stages per procedured dated 2/24/89 as follows: Pre-Pad: 200 bbls gelled diesel @ 5 - 20 BPM, 6100-5100 psi Pad: 450 bbls gelled diesel @ 20 BPM, 5100-4750 psi Stage 1: 45 bbls gelled diesel w/2 ppg @ 20 BPM, 4750-4850 psi Stage 2: 50 bbls gelled diesel w/2-4 ppg @ 20 BPM, 4850-4700 psi Stage 3: 60 bbls gelled diesel w/4-6 ppg @ 20 BPM, 4700-4750 psi Stage 4: 70 bbls gelled diesel w/6-8.3 ppg @ 20 BPM, 4750-5200 psi Stage 5: 50 bbls gelled diesel, 8.3-10.9 ppg @ 20 BPM, 5200-5600 psi Flush w/53 bbls gelled diesel @ 20 BPM, 5600-5300 psi. Fluid to Recover: 899 bbls diesel Sand in Zone: 51,577# Sand in Csg: 1260# Avg Pressure: 5200 psi RECEIVED October 10, 1988 Mr. Randy. Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska '99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-80098 Well: 3-o-3 Field: Kuparuk Survey Date: September 16, 1988 Operator: T. McGuire Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosure NL Sperry. SunlNL Industries, Inc. RO. Box 231649. Anchorage, Alaska 99523-1649 Tel. (907) 522-1737 ARCO ALASKA, INC. 3-0-3 KUPARUK FIELD ALASKA SPERRY-SUN WELL SURVEYING A::OMPANY PAGe_ 1 ANCHORAGE ALASKA DATE OF SEPTEMBER 19, 1988 dOB NUMBER AK-BO-80098 COURSE DOG-LEG DIRECTION SEVERITY DEGREES DEG/100 VERTIc. AL ~EcTION CALCO~~ii,¢ii~LONL~ CLOSURE KELLY BUSHING ELEV. = 5.g. O0 FT. OPERATOR-MCGU I R..E,. ~Y~ ~,: . : ........ ~' iiii:~..!L.¢~:.A~i~i~ ~;;!~!~.;, ~ RECTANGLILAR COORD I NATES VERT I CAL NORTH/SOUTH EAST/WEST SECT I C 100 100.00 41.00 0 20 200 200. O0 141. O0 0 1 .~ N 0 ,-' ij)"-E ................ 0':, '66 .................... -~-, '66" N 16. 0 W 0.34 0.'~ .--~ N N 33.80 W ...... .Q._J.~ ..... 0.80 N 300 300.00 241.00 0 16 N 24.19 W 0.07 400 399.99 340.99 0 31 N 18.6.g W O. 24 450 449.99 390.99 i I N ._~.'--' 80 E 1 . 15 0. O0 O. O0 0.08 W 0.21 ..... _0_._82 W O. 56.., ...... 1.26 N 0.57 W 0.84 1.91 N 0.82 W 1.30 2.57 N 0.86 ..~..... 1.87 4.26 N 0.28 W 3,63 7.23 N 1.11 E ..1!.08 N ............... 3.15 E .... 11.27 . 16.36 N 6.51 E 17.51 23.07 N 11.30 E 25.67 30.53 N 16.93 E_ 34.90 _ 4.38 2.~,2 2.3.~ 6.60 2.73 500 499.~5 440.95 3 7 N 23.80 E 550 549.84 490,84 4 25 N 26.10 E ~00 599.~4 .............. ~0,64 ....... 5 34 N 29,30 E 650 649.24 590.24 8 49 N 34.50 E 700 ~98.5~ &39. S& 10 8 N 3&.39 E 750 747.&7 &SS.&7 11 23 N 37.&0 E 800 796.56 737,56 ~2:4~ N:::38-:3~ £ 2:'8& 38'7~ N '23.3~ E 45.23 850 845'I0 78~,10 14 47 N 38'&0 E ~'94 48. I3 N 30.81 E 56.~5 ~00 8~3.2~ .... 834, 24 ......... 16 32 . N 38.10 E 3' 51 ..... 58- 72 N .... 3~. I ·.E ....... 70---2~''~I ~38 ~2~.55 870.55 17 43 N 38,8~ E 3,1~ 67,48 N 46.1~ E 81.,~/ 1000 ~88.23 ~29,23 1~ 55 N 38. b0 E 3.54 83.08 N 58.68 E 100,88 1050 1035.02 ~76.02 ~1 18.. ~ ~mSO. E 2.7~ . ~&.84 N &~.&4 E 118~ : :: ":i08i:~ 47:':: ::' ': .i0~21:4~' '::::': 22 :': :::7:: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :': ::::::::::::::::::::: 20' E. ...... . :: .:: :: .~:-::: ..... . :: : .... ., . 1200 1173.13 1114.13 24 58 N 3J.30:E 2,85 142.31 N 106.37 E 175,54 1300 1262.5~ 1203.56 28 10 N. z~O, 50 1350 1306.39 1247.39 29 19 N 40.10 1400 1349.71 1290.71 30 33 N 38.30 1500 1434.&0 1375. b0 33 15 N 3b. 10 l&O0 151&.55 1457.55 3& 38 N 35.80 1700 .1595.24 153b.24 39 32 N 35.89 1800 1&71.34 lb12.34 41 21 N 33.30 1900 1746.18 1~87.18 41 46 N 28.60 2000 1820.48 1761.48 42 15 N 24.80 .............. ~¢.~2 .... ~.~, .7~ ...... 1814.78 42 15 N 25,19 I~ .. 3.25 17~,:.&0 N E 2.33 1 ':24.95 N E 3.05' 214.29 N E 2.9 N. ·: .::-:..~.-.:, E .:::: . :::!::ii::i.:~ii~:..40 302.77 N E ::i~<.........~~:89 352.77 N E =============================== _~_Q_6._17 N E 3.15 463.04 N E 2.5'~ 522.82 N 135._0.~_E 21~.28 .... 150.&4 E 242.78 1~.41E 267.25 198.32 E .......... 31~.40 231.94 E 376.11 268.07 E 437.21 __.304.87_~,__ 501 . 61 ....... 338. ~7 E 5~7.83 3~9.02 E ~34.72 ARCO ALASKA, 3-0-~_ KUPARUK FIELD ALASKA INC. SPER,~Y-$UN ,WELL :~URVEYING COMPANY ANCHORAGE ALASKA COMPUT/L. TjON DATE SEPTEMBER 19, 1988 VERT I CAL SECT I ON CAI:'~U~i~ii!ii~LONG CLOSURE MEASURED VERTICAL VERTICAL INCLINATION COURSE DOG-LEG DIRECTION SEVERITY DEGREES DEG/IO0 PAGE DATE OF SURVEY SEPT~iHBER:;,.!6, 19:88 .BOSS GYROSCOPIC ,_lOB NUMBER AK-BO-80098 KELLY BUSHING ELEV. = 59.00 FT. OPERATOR-MCGU I RE '::: .,.::~t.>.~8 .',.:::::::~:~::~:: ~ P.~: ::.... RECTANGULAR NORTH/SOUTH EaST/WEST SECTIO' ) 21 oo *t-e' ' 76g ..... 1835.56 41 54 2200 1969.44 1910. 44 41 6 2300 2045.28 1986.28 40 14 N 25.10 E 1.27 583.68 N 397.4~ E 701.82 N 25.39 E 0.82 643.62 N 425.72:E 768.02 N 25.60 E 0.88 702.45 N 4.53.78 E 833.1'4 2400 2120.77 2061.77 41 43 2500 2194.08 2135.08 43 57 2600 2266.47 2207.47 43 16 N 25.60 E 1.48 761.59 N 482.12 E 898.66 N 25.80 E 2.24 822.84 N 511.60 E 966.59 N 26.60 E 0.88 884.74 N 542.05 E 1035.54 2700 2339.68 2800 2413.99 2900 2489.13 3000 2564.20 3100 2637.76 3200 2709.99 3300 2782.22 3400 2854.74 3500 2927.78 3600 3001.37 3700 3074.89 2280.68 42 35 2354.99 41 24 · 2430.13 41 10 2505.20 41 51 2578.76 43 44 ~6~0.99 43 46 N 27. 0 E 0.74 945-54 N N 217.80 E 1:..~0 1004.95 N N 28, !? E ..... _O_i~ 1063,_2~. N N 28.80 E 0.53 1121.26 N 666.05 E N 28.80 E 2.22 1180.60 N 698.67 E N 29~50 E 0,49 1241,00 N 732,36 E 0.1~ 1301.13:~N 766.52 E 0.69 1360.70 N 801,04 E 0.50 .......... t419'46 N 835,B~ E 0.57 1477.47 N 870.79 E 0.63 1535.51N 905.80 E 2723.22 27~5.74 .... _2_868.:78 2942.37 3015.89 43 43 N:29,6~ :E 43: 18: :N 30.50 E 42; 51.L.::m : N 30-80E 42 23 N 31.30 E 42 57 N 30.89 E 3800 3147.78 ~ 4000 4100 4200 4300 4400 ..... 3294.89 3235.89 3369.0~ ........ 3310.02 3443.21 3384.21 3516.53 3457.53 3588.12 3529.12 43 26 N.30..3~ E 0,60 1594.40 N 940.70 E ~7:5' 57 E 1710.39 N 1010.72 E 4500 4600 4700 3658.56 3599.56 .3728.60 3669.60 3798.34 3739.34 4800 4900 5000 3868.13 3809.13 3938.00 3879.00 4007.76 3948.76 N 31"69 E 0.35 N 31.60 E ,, 0-33 N 31.80 E 0.28 N 31.39 E 1.25 _ N. 30,60 .. E .... : 1:~.75 45 N 30:0 E 45 48 N 30,60 E::;?i;?! +15 __. 45 40 N 30.80 E 0.20 45 41 N 31.19 E 0.29 45 4':2 N 31.1~ E 42 18 4!.,. ~9, 42 13 43 26 45 6 1767.51 ~____i045.93 E 1824.58 N 1081.17 E 1882.48 N 1116.79 E 1942.32 N !152.Z.4_E 2003.47 N 1188.76 E 2065.03 N 1224.88 E 2126.79 N _ 1261.26 E 2188.37 N 1297.82 E 2249.69 N 1334.67 E .._O.J_i.~~..~!,._O,?7 N_ .....1371.78 E 572"76 E 11'03'65 · -603" 55 E 1170" 55 ~4, 53 E ......... 1236.54 1302.59 1370.30 1439.44 1508.56 1577.37 l&45..5~xr__ 17 3.: 1780.87 1849.2& ... 1984.52 2051.49 2118.39 2186.24 ..... 2255.95 2326.85 2398,1~ 2469.7~. 2541.29 2612.73 .... 2684.25 ARCO ALASKA, !NC. KUPARUK FIELD SEPTEMBER 19, 1'~'~8:~ '~' ALASKA VERTICAL .SECT ION CALCU~~iiii!iiii~ONG CLOSURE ' MEASURED 9ERTICAL 9~RTIOAL INCLINATION BIRECTION SEgERITY DEPTH DEPTH DEPTH DE6 M I N DEGREES DE6/1 O0 5100 4077.42 4018.42 5200 4147.10 4088.10 5300 4216.45 4157.45 .........45~ .................... 51 N~;~1,19~SE ................ i),O~ 45 48 N 30.50 E 0.51 46 22 N 30.39 E 0.58 5400 4285.34 4226.34 5500 4354.09 4295.09 5600 4422.66 4363.66 46 31 N ~". ~0 50 E 0.17 46 37 N 30.39 E 0.11 46 47 N 30.19 E 0.22 JOB NUMBER AK-BO-80098 KELLY BUSHING ELEV. = 59.00 FT. O~OR-MC:GU I RE .~ ~ ~,~ ........ RECTANGULAR COORD I NATES VERT I CAL NORTH/SOUTH EAST/WEST SECTIO! '~ · 2372.34 N 2433.92 N 2496.03 N. ~ ..... ~.51 N 2621.12 N 2683.~6 N 1408'95E 1445'73. E .. !482'24 E. 1518.97 E 155~.78 E 1592.50 E 2755.88 2827,51 2899.48 2971.89 3044.44 3117.1~ 5700 44~0,94 4431,94 5800 4559,00 4500,00 5900 4628,52 4569,52 6000 4699.80 4640.80 6100 4771.23 4712.23 6200 4842.38 4783.38 630'0 4913.2t 4854.21 /)400 4984.50 4925, 50 &500 5056.79 49~7.79 6600 5129.36 5070.36 6700 5201.57 5142.57 47 5 N 30.30 E 47 7 N 29.60 E 44 45 N 29.10 E 44 19 N 28.69 E 44 29 N 28.69 E 44 48 N 28.50 E N:.28.39 E' 44 3 N 2~, 10 E 43 ..... 21 N 23'89.E 43 36 N 24. 0 E 43 55 N 24. 0 E 0.31 2747.08 N 1629,31 E 3190.17 0.51 2810,56 N 1665.89 E 3263'38 2.41 2'873, 18_ .N 1701.10 ~E . 3335- 21 O. 51 2934.58 N 1735. O0 E 3405.33 0.16 2995.96 N 1768.61 E 3475.31 0,84 3057.66 N _1802.25 E_ 3545,57 0'22 3119' 73 ~N 1835, 88 E 3616' · 1.88 3182.05 N 1867-~ E 368~,27 o. 1 "" O. 32 3370.73 N 1953.26 E 3892.92 6800 5273.63 521.4.63 ,, 6900 5345. ~,6 528~. ~,~ 7000 5418.25 5359.25 7100 5491.34 5432.34 7200 5564.21 5505.21 7300 5636.81 5577.81 7400 5708.91 5649.91 7500 5780.68 5721.68 7600 5852.71 5793.71 7700 5924.89 5865,89 7800 5997.26 5938.26 7900 6070.04 6011.04 8000 6143.33 ...... ~4.33 43 58 N 24. I0'E ' :i:0't3 ~ i;i~3497'31 N 43 51 N 24.19 E 0.16 3434.02 N. 1981.57 E 39A2.10 ' 4031, :311 ~ ! i ~!!'.: 43 21 43 32 44 13 44 3 43 47 43 47 43 29 43 6 N 27.89 E 2.80 3559.13 N N 29,60 E 1.17 .. 3618.96 N _ N 29.69 E 0.26 3678.48 N N 29.39 E 0.28 3738.30 N N ~5 19 E 2 99 ~799.87 N N 24.39 E .,~i.i~i!i':iii~iiii!i~ii58 3863.08 N N 23 80E ii~~,~49 3926.40N N 22.39 E 0.69 4053.43 N N 22.10 E 0.44 4116.90 N 42 38 N 21.39 E 0.66 2009.95 E 2040.07 E __2072.90 E 2106.78 E 2140.69 E 2172.45.~ ........ 2201.66 E 2229.99 E 2257.63_E 2284.43 E 2310.40 E 4100,04 . 4168.27 4236.73 43O5.46 4374.74.~ 4444,27 4513.48 4582.49 4651.23 4719.47 _~_!..~Q.,._Q~._N_ ........ 2335.61 E ..... 4787.11 ..... 42 58 43 6 ARCO ALASKA, 3-0-3 KUPARUK FIELD ALASKA SPERRY-SUN WELL S/J~VEYING COMPANY ANCHORAGE ALASKA C._~PUTATION DATE INC. SEPTEMBER 19, VERTICAL SECTION " ,~:~,,~,'~.~,~,,'~i~,~- .... _-. ,~.AL CLt~!~:~Qii~:~i::i~LONO L;L O~.URE ..,.::::,~UB::::.::SEiq ......... J;;,OL!R.,, E ' COURSE ~E~SURED VERT ~ C:~L VERT ~ C~L DOG-LEG INCLINATION DIRECTION SEVERITY PAGE DATE Of SURVEY SE~PTENBER..!6, !988,_.__~ ..... 8 ..!iYROScOPIc SuR¢ iii ::.i ......... i ,.' .... ._lOB NUMBER AK-BO-80098 KELLY BUSHING ELEV. = 59.00 FT. OPERATOR-MC:GU I RE ... ......... ¥4: .~ ,...,.. ;... + ...~..:,..,... :::::::~ .:: :::::::::::::::::::::::: -:.:....'. ~×'.:.:.:.:..:+:.:,:,:,.'+ :.:, .:.x-:.:. TOTAL ...... ,:..:...: ;:;?~.:: ;?,:,.., ..... RECTANGULAR cooRD'INATES VERTICAL. DEPTH DEPTH DEPTH DEG MIN DEGREES DEG/1 00 NORTH/SOUTH EAST/WEST SECT ......... ~'i~ .... i~"'~- 6157.~3 42 35-- N 20.69 E 0.48 8200 6290.81 6231.81 42 8 N 20.30 E 0.52 8300 6365.31 6306.31 41 32 N 19.89 E 0.66 8400 6440.66 6381.66 40 40 N 19.50 E 0.90 8500 6516.88 6457.88 39 59 N 19.50 E 0.69 4243.27 N 4306.39 N 4369.03 N 4430.93 N 4491.94 N 2359.93 E .485.4.34 2383.: 53 E 4921 . 16 2406,45 E 4987. 25 ....... 2428.62 E 5052.32 2450.23 E 5116.35 8600 6593.89 6534.89 39 16 N 19. 0 E 0.78 8700 6671. 8800 6750. 8900 6830. 82 6612.82 38 19 N 16.60 E 0.98 77 6691.77 37 22 N 18.10 E 1.00 58 .... ~771.58 36 43 N 18.10 E 0.66 05 6838.05 36 51 N 18.19 E 0.18 68 6851.68 36 36 N 18.39 E 1.63 95 6931.95 36 36 N 18.39 E 0.00 8983 6897. 9000 6910. 9100 6990. 4552.16 N______~47!.26 E 5179.41 46! 1.48: N 2491.45 E 5241,29 , 4669.72 N 251 O, 78 E 5301.80 4726, ~._._N 252,~.. 4.9.~ E .... ~.3 . 1 ' ,18 4774.23 N 2544.98 E 5410.17 4783.88 N 2548.17 E 5420.1.9 4840.46 N 2566.99 E 5479.01 .9140 7023.05 6964.05 36 :36 N 18'39 E 0'00 4.863' 10 N 2574.52 E 5502.54' HORIZONTAL DISPLACEMENT = 5502.54 FEET, AT NORTH 27 DEG. 5~_M!N. EAST AT MIL=,,, 9140 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD. ARCO ALASKA, INC. 3-0-3 KUPARUK FIELD ALASKA SF'ERRY:~.~!N.W_~~~NG COMPANY~ ANCHORAOE ALASKA SEPTEMBER 1.9, 1.988 F'AGE 5 DATE OF SURVEY SEPTEMBER 16, 1988 JOB NUMBER AK-BO-80098 KELLY BUSHING ELEV. = 59. O0 FT. _OF'ERATOR-MCGU I RE INT~~O~;TED VALUES FOR EVEN I000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASURED VERTIC:AL VERTICAL RECTANGULAR C:OORD I NATE:_~ MD-TVD VERTIC:AL .DEPTH_ ~!EPTH .............~!~_PTH ............. ~ 0_~ T_~H_/_~;~ ~! T.H ......... E__A~_;T_~ WE ST DIFFERENCE 0 0.00 -59.00 0.00 0.00 0.00 1000 988.23 929.23 83.08 N 58.68 E 11.77 !1.77 2000 1820.48 1761.48 522.82 N 36~.02 E 179.._~ 167.74 3000 2564.20 2505.20 1121.26 N 666.05 E 435.80 ~._,o~'='. 28 4000 3294.'~ ....... ........................... ~ ........ ~.8.9 1710.39 N .,10.~.~_..~ .............. 705.~~!~. 26.9~_, 5000 4007,76 3948.76 2310.97 N 1371.78 E 992.24 287.12 6000 46~9.80 4640.80 2934.58 N 1735.00 E 1300.20 307.96 ............ ~0~0 . 54!8.~ .... ~3~?,.~ .................. ~9_...._~.. N 2040,..Q? 8000 6143 33 6084 33 4180.09 N . . ~3~.61E 1856.67 274.~2 9000 6910.68 6851.68 4783.88 N 2548.17 E 208.9.32 232.66 ~140 7023.05 6~64.05 4863.10 N 2574.52 E 2116.~5 27.62 THE CALCULATION PROCEDURES ARE BASED ON THE LISE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD. ARCo ALASKA, INC. KUPARUK FIELD ALASKA SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE SEPTEMBER 19, ,..~._, PAGE ~ DATE OF SURVEY SEPTEMBER 16, ~I988 ~ ' · dOB NUMBER AK-BO-80098 KELLY BUSHING ELEV. = 59.00 FT. ~ TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL ._~!~PTH DEPTH ...... B~PTH_.___ ....... ~~.~S_~,~.H ....... ~.~T/~.~ ........ ~E~~E ............ ~ORRECTION 0 0. O0 -59. '00 O. O0 0. O0 0. O0 ......... 59. 59. O0 (!.,.99 .9.._t)5 N .......... 0,..0~_~ ................ ¢~,._(LO_ . 159 159.00 loo. oo 0.61 N 0.19 W 0.00 0.00 ..'5 Y 259. O0 '-'~: '. . ~'.)¢.) O0 1 07 N 0.49 W 0.00 0.00 359 359 00 300.00 1. N O. 00 . 56 ....................... Q..70 W ............... 0.00 459 459. O0 400.00 2.73 N O. 85 W O. O1 O. 01 559 559.00 500.00 7.87 N 1.42 E 0.19 0,18 ................... _,_6__5? .... 65_9'.......0_~ .......... ~Q~J..,..C)~O ................... 17.61 N ...... 7.87 .._.E .......................... _o_,._.,~7 ......................... o. 68 761 759. O0 700. O0 32.35 N 18.33 E 2.56 1 . 68 864 ~-'= - 8~,~. O0 800. O0 51.02 N 33.12 E 5.38 2.82 968 959. O0 900. O0 74.96 N 52.19 E 9.98 4.60 O. O0 1075 1059. O0 1000. O0 104, 20 N. 75.51 E 16.76 6.78 1184 1159. O0 1100. O0 137.28 N 102' 26 E 25.44 8.69 1295_ .......1259. O0 .... ! 2~0_,,.~0.-- 1410 1359.00 1300.00 218.65 N 169.82 E 51.82 14.84 1529 1459.00 1400.00 269.61 N 207.94 E 70.37 18.55 1653 1559.00 1500.00 329.13 N 250,97. E .. 94.,~7 24, 10 1783 1659. O0 1600. O0 397' 09 N 298-91 E 1'24- 57 30.10 1917 1759. O0 1700. O0 473.15 N 344.39 E 158.21 33.64 KUPARUK FIELD ALASKA SPERRY-~Ub[ WELL SUSVEYING ANCHORAGE ALASKA. __ PAGI~ 7 ............ ,._~ I. · ~iii:: .~iii. : ~i ' "~. :: · DATE OF ~RVEY SEPTEMBER 1988 COMPUTATION DATJ~ SEPTEMBER 19, 1°~'°.o~, JOB NUMBER AK-BO-80098 KELLY BUSHING ELEV. = 59.00 FT. MEASURED DEPTH VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE S.UB-SEA TOTAL VERT I CAL VERT I CAL RECTANGULAR COORD I NATES MD- TVD DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERT I CAL Go~~!.! 0.N 2052 1859. O0 1800. O0 2186 1959' O0 1900. O0 2317 2451 2589 2726 2859 2993 3129 2659.00 3267 2759.00 3405 2859.00 2059.00 2000.00 2159.00 2100.00 2259.00 2200.00 2359.00 2300.00 2459.00 2400,00 ............ ~_~5_?.,.~ ........ ~9 ~ oo 2600.00 2700.00 2800.00 3542 2959. O0 2~00, 00 3678 3059. O0 3000. O0 3815 3159.00 3100.00 3951 3259.00 3200.00 4086 3359.00 3300.00 4221 3459.00 3400.00 355~.' O0 ' 3500,"~0 · 4500 3659. oo 3600. oo 554.55 N 383.7~ E 193.04 635'40 N 421.82 E 227.15 712.92 N ~."=° 80 E 258. g8. 792.59 N 496.~9 E 292.43 878.45 N 53~.~o E 330.74 961 · 37 N 1039.99 N 1117.22 N 580.83 E 367.24 622.08 E 400.98 663,83_E__ 434,05 708.46 E 470.39 755.51 E 508.87 803.08 E _ 54~.85 1198.41N 1281.84 N 1364,!5 N 1444' 3:1 N 850' &9 E 583.57 1522,181 .N 898, 20 E 619.29 ! 603, 57 N ...... .. ~46~.,08. E ~56.46 .... 1682.57 N 993.57 E 692.47 1759.83 N 1041.21E 727.51 1~36,75 N 1088.72 E 762.32 200:3.85 N 1188.99 E 841.62 ...... 34,11' 31."'-~3 33.45 ............. .38.31 36.50 33.73 _~3.08 ...... 36.34 38.47 37.~8 36.72 35.72 37.17 36.01 ~'= 05 34.81 37'43 41.8& :---; FLE_ R_.~_Y~.~P~! ._~iL..L_ .,~ ~ !~;~B!v_EY!b~ ANCHORAGE ALASKA ARCO ALASKA, INC. 3-0-3 KUPARUK ALASKA F'AGE 8 DATE OF SURVEY SEPTEMBER :16, 1988 dOB NUMBER AK-BO-80098 KELLY BUSHING ELEV. = 59.00 FT. OPERATOR-MCGU I RE Z: :::::::::::::::::::::::::::::::: i::::3 VERTICAL ) CORRECT I ON INTE~O~TED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD _..K.,E_P__TH_ .......................... _D_E P T.H_ D.~.P. TH NORTH/SOUTH EAST/WEST D I FFERENCE 4643 3759.00 3700.00 2091.95 N ............ 4Z~ ...... 385~,00 ........3809.,00 ........... ~1__8.0_~.~_.~ ......... 4930 3959.00 3900.00 2268.10 N 5073 4059.00 4000.00 2356.10 N 5217 4159.00 4100.00 2444.46 N 5361 4259.00 4200.00 2534.56 N 5507 4359.00 4300.00 2625,61N I558.41 ............ 5~5~ ............ 44~_~, ~9 ......... 4~00 ~..gQ ............. ~ !.Z.,..~ _.~_ 1611.99 5800 4559.00 4500.00 2810.56 N 1665.89 5942 4659.00 4600.00 2899.57 N 1715.78 6082 4759.00 4700.00 ~98.J,42 N 1762.84 1240.68 E 884.57 42.95 .~78..,0~...~ ............ ~7,~ 4~.,_~6 1345.82 E 971.07 43.13 1399.11 E 1014.55 43.48 1451.94 E I058..~7 43.~c~_ 1504.87 E 1102.70 44.63 E 1148.15 45.45 ~.~ .~ ............................ E 1241.00 46.89 E 1283.90 42.~0 E .... 1323.85_~ ..... 39.~ 6223 4859.00 4800.00 3072.16 N 6364 4959.00 4900.00 3159.~1 N 6640 5159.00 5100.00 3333.34 N 677~ 525~.00 5200.00 3421.20 N 6918 5359, Q~ 5300.00._ 3508.98 N 7055 545~.00 5400.00 3592.63 N 71~2 5559.00 5500.00 3674.20 N 18!0.12 E 1364.42 40.57 1857.14 E 1405.53 41.11 _~_I_8~9~D_,3_E .......__1_~44.04 ............... __diS~.~L__ .......... 1936.61E 1481.95 37.91 1975.81E 1520.71 38.77 201S, 26E ........... 15~9.,50 38,79 2057'99 E 1596.71 37.21 2104.34 E 1633.83 37.12 ARCO ALASKA, INC. 3-0-3 KUPARUK FIELD ALASKA ANCHORAGE ALASKA ........................... ~I_LLTATI_ON..._D~ TE .................. SEPTEMBER 19, I'.-.?E:8 DATE OF SURVEY SEPTEMBER 16, 1988 "' . JOB NUMBER AK-BO-80098 KELLY BUSHING ELEV. = 59.00 FT. OPERATOR-MC:GU I RE ..................... ' ........ :~::.' ':i."::'?!:':!:{:~:i 'Z?~!?:' ' . ........ ........ ::' ::::::::::::::::::::::::::::::::::::::::::::::::::::::::: INTERPretED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH .......................................TR'i JE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGLILAR COORDINATES MD-TVD VERTICAL .... _[..!.E_P T_H ...................... E!E_ P_TH ....... _D._EPTH NORTH/SOUTH EAST/WEST DIFFERENCE C: 0 B_R_LE_~.' T_I~,]~ ................... 7330 5659.00 5600.00 7469 5759.00 5700.00 7608 =R='~'~,~ ~, 7. O0 5800.00 7747 5959.00 5900.00 7884 6059.00 6000.00 8021 6159.00 6100.00 8157 6259,00 6200.00 e27! ...... ............. 9o.,,0o ............. 3756,86 N 2150,85 E 1671.66 37.83 3843.99 N 2193.00 E 1710.84 39.1~' 3931.92 N 2232.42 E 1749.72 38.88 4019.86 N 2270.52 E 1788.23 38.51 4107.32 N 2306.51 E 1825.87 37.65 4193,52 N 2340.88 E 4279.38 N 2373.53 E 4363,77 N 2404.55 E 1862.30 36.43 1898.09 35.79 1932 ..._~.7__ ..................... ~...4_. ~_~,L 8424 6459.00 6400.00 4445.79 8554 6559.00 6500.00 4525,14 8683 6659.00 6600.00 4601.88 8810 6759.00 6700.00 4675,70 8935 6859,00 6800.00 4747,14 9060 6959.00 6900,00 4817,~5 9140 7023.05 6964.05 4863.10 N 2433,88 N 2461.94 N ~488.22 N 25!2,73 N 2536,08 N ..... 255~.50 N 2574,52 E 1965.19 32.62 E 1995.90 30.71 E 202¢.66 ,,,28.76 E 2051,36 26.70 E 2076.45 25,10 E ......... 21_0_~.2.Q__ ...... ~.5 E 2116.95 15.75 THE CALCULATION PR. OCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS ARCO ALASKA, KUPARUK FIELD ALASKA INC. ............ SPER~Y,,-SUN WELL SURVEyI~O ¢OMPEIEY_. _ ANCHORAGE ALASKA ~RUTfi.T~I_O~ DAlq~ SEPTEMBER 19, 1.988 PAGE 10 DATE OF SURVEY SEPTEMBER 16, 1988 INT~~~ED VALUES FOR SPECIAL SURVEY POINTS JOB NUMBER AK-BO-80098 KELLY BUSHING ELEV. = 5.9.00 FT. OPERATOR-MCGUIRE ::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::: TRUE MEASURED VERT I CAL DEPTH DEPTH ,B57~ 6572.22 8621 6610.15 8646 662.9.50 8784 6738.06 · ~000 6.910,.68 .9025 6930.74 9140 7023.05 SUB-SEA VERTICAL TOTAL RECTANGULAR COORD I NATES NOR TH / SOUTH .,E_ A S__~T_/_W .,E.E~ ..T .............. MA~ .K_EE ................... DEPTH / = 22 ~_~J 13. 4535.40 N 655_1 .,..!~ 4_~__6.4_'-..7_3 N 6570.50 4579.70 N 6679.06 4660.4.9 N 2465.49 E TOP KUPARUK C ~_.4...75, ~? ~ .......... B.A_SIE....t!:_L. IP._A~L_I~.. _C.: °-,% I_~, - <40:0, 74 E TOP KUPARUK A 2507.76 E BASE KUPARLIK A ................................ ~._~__ '~-'__? ................. L.?_. '_-. S_L ..... 6851.68 478~.~. ,:,~. N 2o4:~. 17 e ....... .=,1_ RVEY ..~EPT~ 6871. 74 4798.03 N ,-'~='="-"..,..,~. 88 EPLUG BACK TD 6964.05 48/_-3.10 N 2574.52 E TOTAL DEPTH ARCO ALASKA, INC. DERIVED USING D IL DEPTHS AND SPERRY SUN SURVEY DATA COiDRD I N~TR_:; DEPTH ......... TVD THICKNESS BKB SUB-SEA VERT I CAL ( ORI G I N- ~N~?'1867FWL ) 'l ' TOP K JPARUK C 8572 6;:,7~_= '-,. '~'-, = '- '-'--, =~.= '~ = ._D' - ~.~. 6.., 1 :_~. '~= 4~,~,. 40N -=46..,. 4 .. BASE KUPARUK C ...... s, 6-- 1 ~,~:_1!..'.~._ 1__~5. ................................................................. 6~.~.! d..,,_,: ~D.6_~.,_Z~ ............ ~ EZra< TOP KUPARUK A 8646 662'.~. 50 6570. =' . . ~,0 457.g 70N 2480 74E BASE KUPARUK A 8784 6738.06 667¥~. 06 46&0.4~N 2507.76E ............ .F_~L_..U__G.,__D,_A..CK TD_ :~0~_ ....................................... __6~3¢)...__7_.4_ ........ _6__.~_8_7__!_._7.4_ _4..2'~8. O'~.~l 2~~ ...... TOTAL DEPTH 9140 7023.05 6964.05 4863.1 ON 2574.52E 1) FROM LINEAR EXTRAPOLATION BELOW DEEPEST STATION, ' ~ ' .... 2) COMPUTER PROORAM - SPERRY SUN THREE DIMENSIONAL RADIUS OF CURVATURE, DATA CALCULATI_DN____A__N_D_._IN_TERPOLATION BY RADIUS OF CURVATURE COMPUTATION DATE SEPTEMBER 1~, 1~88 DATE OF SURVEY SEPTEMBER .......... ~-F :-" ' ............ . JOB N~AK]BO-80098 .............. KE__L.L'~'::~IN~._ELE~Z,__ --_. ~_~...00 FI SPERRY -,SUN 5CRLE :- 1 INCH TO I000.00 / 1000.0 KUPARUK FIELD 3 -0 -3 AK -80-80098 TRUE NORTH RRCO RL~$~R. INC. SEPTEMS~.i6. 1988 · 0.00 O0 O0 l_lO00. O0 1 O0 20O~.O0 HOBIZONTF~L PROJECTION O, OO 2000. O0 SPERRY'SUN .. 5CRLE :- t INCH TO 2000.00 / KUPRRUK FIELO 3 -0 -3 RK-BO-80098 4000. O0 8000. OO ~ ?023. OIiI -VERT I CRL 9140 ~ol~o. oo ';ol~o. oo 6oI~o. oo PROJECTION ID:KRU.,..'CI/NU/DR!LLING ,I AIL WELLS LOCATED IN SEC, 22 T. t3 N., R. 9 F.., UMIAT MERIDIAN· TE~ N0:~07-26~-6218 ~5~5 I HEREBY CERTIFY T14&T I Aid PROPERJ..Y REGISTERED AND t.~;,NSED TO P~elO* ?lee LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PI. AT REPRESENTS A .lOCATION SURVEY IdADE BY ME OR UNDER. MY 8UPERVISIONt AND THAT AiL DIMENSIONS MtO OTHF. R OETAJI.3 ,e.qE COl~l~gC1' AS Of t/t/O.O. ....... ' ............ .,sT. OiST. -'P~D Well Y ASPs X. LATITUDE LONGITUDE ENL. ..F. WL~J~v. ---- iq _ _ .u,~-~_ - I 6i022,095.27 525,478.27 7~'~8' 17,358' 149047' $0.897" '~4' 1642' 17.5~ 23.9' 2 6,022,073.89 52.5,490.94 ?OO 2.8' 17.128" 149o474 o ,** 3'0.626",, 745~ 1655' I17, 3 6,022,052.15 525,505.67 70028', 16.915" t 9 4? 30 154, 767' 1867' 4 6,022,030.55 525,515.$8 70e28; 16.70I 149 47,29.ec6,, 18.9: 183'9; 66 e,022,008. 67'e,0:, ,907, 12 525,540.7:5525'528'387°°26'~2286, 16.27,316'4852:, 149o 47 149047229,07120'432.'. 81032.;i, 1092.;i 9.0,~_; 10.18' i;23..6223'6' 7 6~021,965,9 525,$53.46 16.059 149=47 28.699 05_4; 1917, 18.2, · , IK A4. Kt' J 1,02lo~12~, 12 $25,576,27 i5,632 149 47 2;'.974 .SOT 1941 18.4 23,2 I0 6~021 ~844. 09 525 )625,'61 ?0°29' 14.865" 149e 4T'26.646" 975' 1966' 18.?' l I 6,021,822. ~ 525,636.7l 70e28' 14,651" 149e 47'26,29§" 997' 1998' 18.0' i~ 6,o2!,8~.87 526,648.~ 706.28', 14/457" t49047',25, g~2~ lOtS' 20i1' to.o' 2st: t3 6,021,779. IG 525 166t .20 'K~928, t4, 223" i49°47,26.550. 1041', 2024', 18.9'~ 23.0, 14 6,0Z ,757.48 5Z5,67'5.C~ ~)~8' I&oOlO',: .140047,~5,~. i0_6~. 2035, lO.O, I$ 6,021 76 5;[5 ~686.12 15.'/'95 149°47 24.822 !064~ 2048, I~.0, 16 6,021,?14. 15 525,698.17 70628' 13.583' 149047'24.470" 1106' 2060, 19.1 22.9 17 6tOZl ,692.48 525,710.85 ' 7002~' l$,$6~" 149°47'24.099'' 1 t27~ 2073, i9.0' t8 6,021,670.97 525 ~7~:3.36 ~28' 15. j57' 149°47'~$,755" 1149' 2085' 19.0' 23.$' __ ii i · , .,i,l_;, ! , .__ i _ NOTES I. ~ ¢OOROINATES ARE A.$.R, ZONE 4. 2. ALL DISTANCES SHOWN ARE TRUE. ~. ELEVATIONS ARE B.P,M.&L. 4. REFER. FIELD ~ I.-~-:~ 20-33. 5. 0.~ ELEVATIONS YROM CED-RIXX-$365& 6. HORIZONTAl,. POSITION BASED ON 3'0 MONUMENTS ~ I,OUNS8UR¥ & ARCO Alaska, Inc. Date: March 24, 1989 Transmittal #: 7447 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. ""=- 30-16 ---, 30-10 -'-- 30-13 .,.,,,~ 3 O- 03 --~ 30-15 ,,,,=~ 2G- 14 ~ 2G-13 -',,~ 2G-09 '""~ 1E-03 ~ 1 E-05 30-18 '"'~ 3H-10 ~3A-03 '~'~ 3H-04 '~-2 B- 14 "~ 30-13 "'~- 30-16 ~1B-07 '"'"'~1B-03 '~- 1B-05 "'"'"~1B-07 '~1L-08 ~,,,~1 L- 04 '"~3 H- 10 '~--3M-01 Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk .Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk KuparUk Well Pressure Report Well Pressure Report Well Pressure Report Well Pressure Report Well Pressure Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Kuparuk Fluid Level Report Sub-Surface Pressure Survey Sub-Surface Pressure Survey Sub-Surface Pressure Survey Kuparuk Fluid Level Report Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Sand 'A' Sand 'A' Sand 'A' Sand 'A' 1-3-189 2-04-89 2-08-89 I -09-89 3-04-89 3-11-89 3-11-89 3-11-89 3-09-89 3-09-89 3-09-89 3-09-89 3-09-89 3-04-89 3-13-89 :2-08-89 2-04-89 1 -31 -89 3-31 -88 I -27-88 1 -27-88 4-27-88 1 -27-88 2-12-88 2-12-88 3-17-89 Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing #72665 #72655 #72655 Casing Tubing Tubing Tubing Tubing Tubing Tubing Report 3-1~~EI Kuparuk Fluid Level ~ ~lasw~ ,,,, '-' oa.~ cons. Commission ' ~ - Anchorag~ ~ O- 09 Kuparuk Fluid Level Report 3 - 1 8 - 89 Casing ""~30-18 Kuparuk Fluid Level Report 3 - 1 8 - 89 Casing ~ O- 18 Kuparuk Fluid Level Report 3 - 1 7- 89 Casing ~='~i~'~~O~09 Kuparuk Fluid Level Report 3-1 7-89 Casing 13 Kuparuk Fluid Level Report 3-1 7-89 Casing Receipt Acknowledged' . .......................... Date' - ........... DISTRIBUTION: D&M State of Alaska SAPC Chevron Unocal Mobil ~ Armhorage ~ ' , STATE OF ALASKA . ALA--. ~ OIL AND GAS CONSERVATION COM MISt'S.~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdoWn Stimulate __ Plugging __ Perforate'~._ Pull tubing _,.. Alter casing __ Repair well __ Pull tubing ..._ Other "~ COMPLETE 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 767' FNL, 1867' FWL, 5ec.22, T13N, R9E, UM At top of productive interval 1512' FNL, 948' FEL, Sec.15, T13N, RgE, UM At effective depth 1249' FNL, 860' FEL, Sec.15, T13N, RgE, UM At total depth 1184' FNL, 839' FEL, Sec.15, T13N, RgE, UM 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB 59' 7. Unit or Property name Kuparuk River Unit 8. Well number 30-3 9. Permit number/approval number 88-75 / 8-775 10. APl number 50-- 029-21838 11. Field/Pool Kuparuk River Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9140 ' MD 7023 ' TVD feet feet Plugs (measured) None Effective depth: measured 9025 'MD true vertical 6931 ' TVD feet feet Junk (measured) None Casing Length Size Structural Conductor 80 ' 16" Surface 5114 ' 9-5/8" Intermediate Production 9083 ' 7" Liner Perforation depth: measured 8720 ' -8740 ' MD true vertical 6688'-6704'TVD Tubing(size, grade, andmeasureddepth) 2-7/8", J-55, tbg w/tail @ 8538' PackersandSSSV(typeand measureddepth) AVA 'RHS' pkr @ 8467' & Otis 'FMX' $S$V.~ 1792' Cemented Measured depth True vertical depth 193 sx AS I 115'MD 1250 sx A$ III & 5149'MD 350 sx Class G - Top Job w/150 sx AS I 225 sx Class G & 9116'MD 175 sx CS I 13. Stimulation or cement squeeze summary ll5'TVD 4111'TVD 7004'TVD Intervals treated (measured) 8574 ' -8576 ' Tr~ea~t.,ment ~.escrip~on including volumes Used and final presSure /UU SX class b 14. N/A Representat)ve Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys ru,,''~,, Gyro Daily Report of Well Opeiation;'~,N Oil '~' Gas SUspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Area Drilling Engineer Form 10-404 Rev 06/15/88 (Dan i ) SW03/044 *NOTE: Completion Well History Service Date SUBMIT IN DUPLICATE ARCO Oil and Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial Repo~l" on the first Wednesday after a well is spudded or workover operations are started. Dally work prior to spudding should be summarized on the form giving Inclusive dates only. District ~D, CO Alaska, Inc. Field KURPARUK RIVER UNIT Auth. or W.O.R;~2955 Lease o~1~: 25513 Title COMPLETE IStat~ 30-3 IWell no. API: 50-029-21838 Operator ARCO I Date 09/26/88 IH°u' 1430 HRS Prior statu, if a W.O. Spudded or V~[il[~ Date and depth as of 8:00 a.m. 09/27/88 ( 1] TD: 9140 PB: 9031 SUPV:MDDEEV 09/28/88 TD: 9140 PB: 9031 SUPV:MDD 09/29/88 TD: 9140 PB: 9031 SUPV:MDD 09/30/88 TD: 9140 PB: 9031 SUPV:ZR 10/01/88 ( 15 TD: 9140 PB: 9031 SUPV:JI.I The ab~ i~s~correct Complete re~l~OtJ~l~l~chlday reported RO TO SQUEEZE 7"g 9116' MW:10.0 NACL ACCEPT RIG g 1430 HRS, 9/26/88. NO AND TEST BOPE. W/SQUEEZE GU AND PERF 8574'-8576'. SET WL SET BP AT 8591'. RIH W/SQZ PKR AND RU TO SQZ. DAILY:S26,176 CUM:$956,222 ETD:S956,222 EFC:$1,355,000 DRLG CMT 7"~ 9116' MW:10.0 NACL SOZ 7" ABOVE C SAND W/100 SX CLASS G. CIP ~ 0900 HRS. FIN SQZ PRESS 3000 PSI. WOC W/ CMT UNDER PRESSURE FOR 4 HRS. REV CIRC. POH W/PKR. GIH AND DRILL OUT CMT. DAILY:S54,132 CUM:$1,010,354 ETD:S1,010,354 EFC:$1,355,000 CIRC HOLE CLEAN 7"~ 9116' MW:10.0 NACL DRILL OUT SQZ AND TEST SAME TO 2500 PSI - OK. DRLD OUT BP AND PUSH SAME TO BOTTOM ~ 9003'. CBU. POH. GIH W/BIT AND SCRAPER TO PBTD. PUMP SWEEP FOLLOWED BY CLEAN BRINE. DAILY:S27,237 CUM:$1,037,591 ETD:S1,037,591 EFC:$1,355,000 RIH W/COMPL. 7"g 9116' MW:10.0 NACL CIRC HOLE TO CLEAN BRINE. POH LDDP. RU AND PERF 8720'-8740' W/ 8 SPF, 45 DEGREE PHASING. RIH W/ COMPL. (NOTE: 8 SHOTS OUT OF 120 SHOTS MISFIRED) DAILY:S47,500 CUM:$1,085,091 ETD:S1,085,091 EFC:$1,355,000 RIH W/ COMPLETION STRING 7"~ 9116' MW:10.0 NACL ATTEMPTED TO RUN COMPLETION STRING, SET PACKER, SHEARED PBR, UNABLE TO STAB BACKINTO PBR, POH, MODIFIED BOTTOM LOCATOR, RIH WITH COMPLETION STRING DAILY:S47,500 CUM:$1,132,591 ETD:S1,132,591 EFC:$1,355,000 Date / ] Title 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 workovere when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ARCO Alaska, Inc. Field KURPARUK RZVi?.R UNIT Auth. or W.O. A~K2955 I County o%~.~L.~H SLOPE Lease or ]11.~[. ·' 25513 Title coMP'I'-ET~'- A~I: 50-029-21838 IAccountlng cost center code St at (l!k,~,~ 30-3 I Well no. Operator ARCO A.R.Co. ~.6.. 0000 ITotal number of wells (active or inactive) on thisI Icost center prior to plugging and labandonment of this well I Spudded or W$1~l~' Date 09/26/88 IHour 1430 HRS Date and depth Complete re~~c~day reposed as of 8:00 a.m. 10/02/88 ( 1 ;) RIG RELE~ED 7"6 9116' ~= DIESEL TD: 9140 CONT. RULING CO~LETION STRING, L~ATED INTO PBR, TEST PB: 9031 TUBING TO 2500 PSI, TESTED SSSV TO 1500 PSI, SHE~ OUT B~L SUPV:JH AT 3500 PSI, SET BPV, NU TREE, TESTED TO 5000 PSI, DISPLACED ~LL WITH 310 BBLS OF DIESEL, ~LEASE RIG ~ 2145 ~S, 10/1/88. DAILY:S158,817 C~: $1, 291, 408 ETD:S1,291,408 EFC:$1,355,000 NOTE: OTIS 'F~' SSSV ~ 1792', AVA '~S' P~ ~ 8467', & TT ~ 8538'. Old TD New TD I PB Depth I Released rig Date IK~d of rig I Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Offlcla rese~olr name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production OII 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 W~6'6Xrect I/ ,ff- STATE OF ALASKA AL,-,oKA OIL AND GAS CONSERVATION COMM k,,~tON APPLICATION FOR SUNDRY APPROVALS 1. ~'ype of Request: Abandon __ Suspend Operation shutdown ~ Re-enter suspended well Alter casing __ Repair well __ Plugging __ Time extension Change approved program Pull tubing __ Variance __ Perforate __ Other 2. Name of Operator ' I 5. Type of Well: 1t' 6. Datum elevation (DF or KB) ! Development ARCO Alaska. Inc. Exploratory 3. Address ! Stratigraphic ~ 7. Unit or Property name P. O. Box 100360~ Anchora~e~ AK 99510,~03 60 Service__ Kuparuk River Unit 4. Location of well at surface 8. Well number 30-3 767' FNL, 1867' FWL, 5ec.22, T13N~ RgE~ UM At top of producbve interval 9. Permit number 1320' FNL, 792' FEL, 5ec.15~ T13N~ RgE~ UN (appr,ox) RR-75 At effective depth 10. APl number 50-- 1303' FNL~ 783' FEL, 5ec.15, T13N~ RgE, UN (appr,ox) 029-21838 At total depth 11. Field/Pool 1239' FNL, 762' FEL, $ec.15~ T13N, RgE~ UN (approx) Kupar'uk River' 0il Pool _. 12. Present well condition summary Total depth: measured 91 40 ' M D feet Plugs (measured) N o n e true vertical 7033 ' T V D feet Effective depth: measured 9025 ' M D feet true vertical 6939 ~ TVD feet Casing Length Structural Conductor 80 ' Surface 511 ~ ' Intermediate Production 90 83 ' Liner Perforation depth: measured true vertical Junk (measured) None Size Cemented Measured depth True vertical depth 16" 193 sx AS I 115'MD 9-5/8" 1250 sx AS III 5149'MD & 350 sx Class G - Top job w/150 sx AS 7" 225 sx Class G 9116'MD ll5'TVD 4114'TVD 7013 ' TVD None None Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None 13. Attachments Description Summary of propOsal Well Histor,y ' ~'. :i"! ;!;.!~:'!:-! Detailed operations program __ BOP sketch 14. Estimated date for commencing oPeration ! 15. Status of well classification as: September,~ 1988 I 16. If proposal was verbally approved Oil ~ Gas Suspended Nameof appro~r~,.m ~h-~ /~- ~- Datcd/-~/D~aye-appr°vedI' Service: 17. I hereby certify tFi~t~t-~ foregoing is true and correct to the best of my knowledge, Signed ~~..~~~, Title ~s.~{;)ciat-.,. Enoineer a~ FOR COMMISSION USE ONLY - Conditions of provah Notify Commission so representatiVe may witness ( D a n ~ ) 5 A 3 / 0 o 51 Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test_ Subsequent form require~dnln0¢r~f~:~ Returned ' ORIGINAL SIGNED BY __ /~ Approved by order of the Comml_~ C. SMITH Commissioner Form 10-403 Rev 06/15/88 Date I Approval NO. {~ - ~,,~-- Date ./~ '/',¢.~ --~,,~ SUBMIT IN TRIPLICATE feet ARCO Oil and Gas Company~,~' Well History - Initial Report - Dally 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 iCounty, parish or borough ARCO Alaska, Inc. I NORTH SLOPE Field JLease or Unit KUPARUK RIVER UNIT [Title ADL: 25513 Auth. or W.O. no. [ ' AK2955 I DRILL JStatL 30-~ iWell no. Operator ARCO API: 50-029-21838 IARCO W.I. Prior status if a W.O. IDate IH°ur 08/29/88 2230 HR$ Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. Complete record for each day reported DOYON 14 08/30/88 ( TD: 970'( 70) SUPV:EEV 08/31/88 ( ) TD: 3758'(2788) SUPV:EEV 09/01/88 (3) TD: 5169'(1411) SUPV:DL 09/02/88 ( 4 TD; 5169'( 0) SUPV:DL 09/03/88 ( 5 TD: 5169'( 0) SUPV:DL DRILLING MW: 8.8 VIS: 75 MOVE FROM 30-2 TO 30-3. RU DIVERTER, PO BHA RND MIX MUD. STATE WAIVED WITNESSING DIVERTER TEST. SPUD WELL 8 2230 HRS 8/29/88. DRILL AND SURVEY 115'-970' DAILY:S56,415 CUM:$56,415 ETD:S56,415 EFC:$1,355,000 DRILLING MW: 9.5 VIS: 68 DRILL AND SURVEY 970'-1949'. PUMP SURVEY, CIRC BOTTOMS UP AND TOH. CHANGE BIT AND BHA, TIH. DRILL AND SURVEY 1949'-3758'. DAILY:$58,513 CUM:$114,928 ETD:S114,928 EFC:$1,355,000 POH MW: 9.5 VIS: 96 DRILL AND SURVEY 3758'-5169'. CIRC AND CONDITION WELL AND SHORT TO HWDP. TIH, WASH AND REAM 2320'-2480' AND CONTINUE IN HOLE. CIRC AND CONDITION WELL, DROP SURVEY AND TOH. PIPE STUCK @ 750'. WORK FREE AND TOH SLOW WHILE CIRC. AT 471' AT REPORT TIME. DAILY:S44,341 CUM:$159,269 ETD:S159,269 EFC:$1,355,000 POH MW:10.1 VIS:136 FINISH TOH. SLIP AND CUT DRILL LINE. MU NEW BHA, TIH, WORK PAST LEDGE ~ 602'. TOH, LD BHA, RU AND START RUNNING 9-5/8" CASING. UNABLE TO GET PAST LEDGE AT 602'. POH AND LD CASING. PU NEW BHA AND TIH. WASH AND REAM PAST LEDGE. HOLE MAY HAVE SIDETRACKED. TOH, CHANGE BHA AND RIH WITH MOTOR.. ORIENT TO ORIGINAL HOLE AND DRILL APPROX 60'. RIH TO 750' WO PUMP. TOH, CHANGE BHA , TIH AND REAM PAST LEDGE AT 602'. TIH TO 5169'. CIRC AND CONDITION WELL. TOH. DAILY:S52,136 CUM:$211,405 ETD:S211,405 EFC:$1,355,000 FINISH MU BHA 9-5/8"@ 5149' MW: 8.4 VIS: FINISH TOH AND LD BHA. RU AND RUN 133 JTS 9-5/8", 36#, J-55, BUTT CASING. SHOE @ 5149', COLLAR @ 5070'. HAD TO ROTATE OFF LEDGE AT 602'. RU CEMENT HEAD AND CIRC 1.5 CSG VOLUMES @ 10 BPM. CEMENT AS FOLLOWS, PUMP 80 BBLS WATER, 1250 SX AS III AND 350 SX CLASS G, DISPLACED WITH 392 BBLS WATER. HAD FULL RETURNS FOR 238 BBLS AND 50-75% RETURNS FOR REST. BUMPED PLUG WITH 2000 PSI. CASING TEST OK. FLOATS HELD OK. CIP 1930 HRS 9/2/88. RD LANDING JOINT AND DIVERTER. PERFORM TOP JOB WITH 150 SX AS I. CIP 2230 9/3/88. NU CASING HEAD AND BOPE. TEST BOPE TO 3000 PSI. WITNESS WAIVED BY STATE. MU BHA, CALIBRATE LOGGING TOOLS AND ORIENT MWD. DAILY:S219,946 CUM:$431,351 ETD:S219,946 EFC:$1,566,405 The above is correct Signature For form preperationfi~nd distribution, see Procedures Man~. !, Section 10, Drilllnn P.n~e RR =n~ RT IDate I Title ASSOCIATE ENGINEER ARCO Oil and Gas COmpany Daily Well History---Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name. In d.e. scrlb, ln,~ w. ork performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reporteo 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 string until completion. ARCO Alaska, Inc. ~__ NORTH SLOPE Field I [.~a~ or Unit KUPARUK RIVER UNIT ] 30-3 Complete record for each day while drilling or workover in progress Date and depth as of 8:00 a.m. 09/04/~8 ( TD: 7274'( SUPV:DL 09/05/88 ( TD: 8606'( SUPV:DL 09/06/88 ( TD: 9140'( SUPV:DL · 09/07/88 ( TD: 9140 ?B: SUPV:DL DOYON 14 ;) 2105) POH, MWD FAILURE 9-5/8"% 5149' MW: 9.2 VIS: 32 FINISH TIH. DRILL OUT FC AND SHOE JOINT. TEST CASING TO 2000 PSI, OK. CONTINUE DRILL OUT TO 5179'. DISPLACE WELL TO NEW MUD AND PERFORM LEAK OFF TEST TO 12.5 EMW. NO LEAKOFF. DRILL AND SURVEY 5179'-7274'. MWD FAILURE. DROP SURVEY AND POH. DAILY:S50,350 CUM:$481,701 ETD:S481,701 EFC:$1,355,000 7) 332) DRILLING 9-5/8"@ 5149' MW: 9.8 VIS: 36 CONTINUE TOH. RETRIEVE SS, REMOVE SOURCE FROM BAROID TOOL, CHANGE OUT MWD. ORIENT NEW MWD, RELOAD LOGGING SOURCE AND TIH. PUMP MWD SURVEYS TO VERIFY HOLE LOCATION ON TIH. DRILL AND SURVEY 7274'-8606'. DAILY:S59,088 CUM:$540,789 ETD:S540,789 EFC:$1,355,000 3) ~34) RIH W/ LOGGING TOOLS 9-5/8"@ 5149' MW:10.0 VIS: 47 DRILL AND SURVEY 8606'-9112'. LOST PUMP PRESSURE, TOH FOUND WASHOUT 48 JTS FROM SURFACE. CONTINUE TO SHOE. CUT DRILL LINE AND TIH. DRILL 9112'-9140'. CIRC AND CONDITION WELL, SPOT PILL, TOH. REMOVE LOGGING SOURCE AND LD BHA. RU SCHLUMBERGER. RIH W/ LOGGING TOOL. DAILY:S52,442 CUM:$593,231 ETD:S593,231 EFC:$1,355,000 RIH W/7" CASING 9-5/8"@ 5149' MW:10.1 WBM' RIH W/ SCHLUMBERGER TO 9142'. LOG W/ DIL/FDC/CNL/GR/CAL TO 8300. GR TO SURFACE RIH WITH DRILLING ASSEMBLY. CIRC AND CONDITION WELL. SPOT PILL, POH, LDDP. LD BHA. RU AND RIH W/ 7" CASING. DAILY:S130,757 CUM:$723,988 ETD:S723,988 EFC:$1,355,000 Well no. The above is correct Signature ~~~~~~J Date For form preparation a/l~l distribution - see Procedures Manu~'Section 10, Drilling, Pages 86 and 87 ASSO~A~ ENGINEER 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 ia Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations ere suspended for an indefinite or appreciable length of time. On workovere when an official teat la not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation 'if space is available. District . ~]C°unty or Parish I State ARCO Alaska, Inc. J NORTH SLOPE AK Field Itease or Unit KU~XA~K RIVER UNIT I ADL: 25513 Auth. or W.O. no. ITitle AK2955 J DRILL /%PI= 50-029-21838 Operator ~ A.R.Co. W.I. ARCO I 56. 0000 Spudded or W.O. begun Date SPUD 08/29/88 Date end depth aa of 8:00 a.m. Complete record for each day reported DOyoN 14 09/08/88 (11) TD= 9140 PB= 9031 SUPV=EEV Accounting cost center code 30-3 I Well no. otalnumber of wells (active or Inactive) on this cst center prior to plugging end I bandonment of this well I IHour IPrlor statu~ If a W.O. / 2230 HRS RIG RELEASED-MAZNT .7"e 9121' MN=10.0 NACL FINISH RUNNING 217 JTS 7" 26# J-55 BUTT CASING. SHOE e 9116', COLLAR ~ 9025'. RU DOWELL AND CIRCULATE 2 CASING VOLUMES. CEMENT AS FOLLOWS= PUMP 5 BBL WATER AND TEST LINES TO 4000 PSI, DROP PLUG PUMP 10 BBL CW 100, 20 BBL SPACER 3000, DROP PLUG AND PUMP 225 SX (46BBL) CLASS G CEMENT, DROP PLUG AND DISPLACE W/ 343 BBLS 10.00 PPG BRINE. LOST RETURNS AS CEMENT ROUNDED SHOE. BUMPED PLUG W/ 3500 PSI, OK. FLOATS HELD OK. BLOW BRINE FROM CASING, RAISE STACK, SET SLIPS AND CUT OFF PIPE. INSTALL PACKOFF AND TBG HEAD. TEST TO 3000 PSI, OK. INJECT 190 BBL DIESEL IN ANN AND RELEASE RIG ~ 2400 HRS, 9/7/88. MOVE RIG TO SIDE OF 30 PAD AND BEGIN MAINT AND MODIFICATION AT 0400 9/8/88. DAILY=S206,058 CUM=$930,046 ETD=S930,046 EFC=$1,355,000 Old TD Released rig Classifications (oil, gas, etc.) Producing method tNew TD ! PB Depth t Type completion (single, dual, etc.) Of~ ~ name(s) Potential test data Well no. Date Reservoir Producing Interval Pump:;. size; SPM:~ X length. ;hoke size ~Water % , . ~ The above Is correct . For form preparation ~d distribution, "~ see Procedures Manual, Section 10,' , Title · . Drilling, Pages 86 and 87. Test time Production OII on test per day Gravity Allowable Effective date corrected A~4:)ClATE ENGINEI~ ARCO Alaska, Inc. Date: September 21, 1988 Transmittal #: 7289 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. ~~-~ OH LIS Tape and Listing 9 - 1 3 - 8 8 # 7 2 9 2 6 -30-02 OH LIS Tape and Listing 9- 1 0-88 #72902 Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION: Lynn Goettinger State of Alaska ARCO Alaska, Inc. Date: September 21, 1988 Transmittal #: 7287 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. "3 0 - 2 2" Dual Induction 8 - 27 - 88 5932 - 10363 · 3 0 - 2 5" Dual Induction 8 - 27 - 88 5932 - 10363 ° 30-2 2" & 5" Raw FDC 8-27-88 9395-10334 ° 3 0 - 2 2" & 5" Porosity FDC 8 - 27 - 88 9395 - 10334 '~' 3 0 - 2 _ Cyberlook 8 - 27 - 88 ~ '3o - 3 2" Dual Induction I 0 - 6 - 8 8 5 1 4 9 - 91 3 6 e 3 0 - 3 5" Dual .Induction I 0 - 6 - 8 8 5 1 4 9 - 91 3 6 '30-3 2" & 5" Raw FDC 10-6-88 8300-9113 · 3 0 - 3 2" & 5" Porosity FDC I 0 - 6 - 8 8 8 3 0 0- 91 1 3 e 3 0 - 3 Cyberlook I 0 - 6 - 8 8 Receipt Acknowledged: 0il & Gas Cons. ........................... Date- - ........... DISTRIBUTION- NSK Drilling Franzen D&M State of Alaska(+sepia) ,' July 18, 1988 Telecopy~ (907)276-7542 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 A~nchorage, Alaska 99510-0360 Re: Kuparuk River Unit 30-3 ARCO Alaska, Inc. Permit No. 88-75 Sur. Loc. 767'FNL, 1867'FWL, Sec. 22, TI3N, RgE, UM. Btmhole Loc. l154'FNL, 700'FEL, Sec. 15, T13N, R9E, UM. Dear Mr. Kewin z Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commissionmay 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. Vervtruly yo~s, C. V. Chat~to~~ ~ Chaiman of Alaska Oil and Gas Conservation Co~isston BY OPJ)ER OF THE COMbIISSION dlf Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ' STATE OF ALASKA ALASKA O.P~ AND GAS CONSERVATION COt,."-~ISSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~ Redrill []1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] DeepenE31 Service [] Developement Gas [] Single Zone ~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 59', PAD 24'GLfeet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pc P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25513~"'ALK 2554 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o AAC 25.O25) 767'FNL,1867'FWL,Sec.22,T13N,RgE,UM Kuparuk River Unit Statewide At top of productive interval(~ target) 8. Well nurpber Number 1320 ' FNL, 792 ' FEL,Sec. 15,T1 3N,RgE,UM 30-3 #8088-26- 27 At total depth 9. Approximate spud date Amount 11 54 ' FNL, 700' FEL,Sec. 1 5, T1 3N,RgE, UM 08)~1 7/88 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD) property line DS 30-2, DS 30-4 9157'MD 700' ~ TD feet 25' ~ surface feet 2560 6936'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth 500 feet Maximum hole angle 45° Maximum surfaoe 243 8 psig At total depth (TVD) 3264 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80 35 35' 115 115' +200 # cf 12-1/4" 9-5/8" 36.0# J-55 BTC 5158 35 35' 5193 4119' 1250 sx AS Ill & -IF-ER~ 350 sx Class G 8-1/2'~ 7" 26.0# J-55 BTC 9123 34 34' 9157 6709' 100 sx 50/50 Poz Lea ~F-ERV 200 sx Class G tail 19. To be completed for Redrill, Re-entry, and Deepen Operations.~up ,-u~"°'i~a°-'f'kG 500' above Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor SurfaceRECEIVED Intermediate ProductionJUN 2 ? ]988 Liner Perforation depth: measured AlsSka. 0il & Gas Cons. Commission true vertical ' Anchorage 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program I~ Drilling fluid program 1~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25,050 requirements [] 21. I hereb~certify that th~ foregoing is true and correct to the best of my knowledge Signed ~~_ (.,/(~~L_....--.7~ ~.Tj~,~ ~,,, Date Title ~..,,~,..~ n,.~,,,," I....] Z Permit Number ~ APl number I Approval date See cover letter ~-"/'5" 50-- c)~c).~;~lS_~E~ J 07/18/88 for other requirements Conditions of approval Samples required [] Yes [] No Mud log required L-] Yes I~'No Hydrogen sulfide measures [] Yes [] No Directional survey required ~ Yes [] No .,,J~.M;~ 3M; [] 5M; [] 10M; [] 15M Required working p re.~,~,s~ re forABOPE Other: ~/.~~~~ by order of Approved by Commissioner the commission Date Form 10-401 Rev. 12-1-85 Submit in ' riplicate 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 loggi'hg point according to directional plan. 8) Run open hole logs. - 9) -Continue drill.ing 8-1/2" hole to provide 100' between PBTD and bottom of Kuparuk sands. 10) Run and cement 7" casin~, 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. 19) Change over to diesel. 20) Flow well to tanks. Shut in. 21) Secure well and release rig. 22) Fracture stimulate. RECEIVED DEGASSERI MUD CLEANER JUN 2 7 1988 Alask~ Oil & Gas Cons. Commission ,, Anchorage TYPICAL MUD SYSTEM SCHEMATIC Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 ~eight Up tO TD 10.3 15-30 5-15 9-13 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 '- 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drtlltn~ Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators JUN 2 7 1988 Alaska 0il & Sas tlons. Commission Anchorage 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 13.5 ppg EMW and a gas gradient of .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 our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this .proposed well. In accordance with Area Injection Order No. 2, 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 shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. LWKE/ih RIVER UNIT 20' DIVERTER SCHEHATIC 4 AACO ALASKA, INC,, ~1,~S1~ OF THIS OIVERTER SYS~ AS A VARIANCE Fr~0n 20AAC2S.~) I"I,~|I~TENANCE. & OPERATION RECEIVED JUN 2 7"1988 Alaska 0il & Gas Cons. Commission Anchorage e . UPON INITIAL INSTALLATION, CLOe~., I~[V[NTER ,NC VERIFY THaT VALVE 09rd~ ~¥. CLOSE ANNULAR. PqLn~]~l'~A AN0 ~l. Ol, t AIR I"HR~G, OlVERTER LINES [VL~ 12 H(XII~. CLOSE ANNI. N, AR PREV~NI"~R IN THE EVENT iNFLUX OF WE:LLIS(3RE FLUIDS 0R GAS IS DETECTE0. OPEN API3ROI3RIATE VALVE TO ACHIEVE ~lNO DIVERSION. DO NOT. SHUT INWI:LL UNDER ANY CIRCUHSTANCES · . · ' .:..e,. ~ * .', ~ ~. 7 6 I i DIAGRAM #1 1::5-5/8' ~ PSI Rg:31~A ~ STACK !. 16" - 21330 PSI T.aI~CD ~l~ ~ K~ L~ 7. 1~5/8~ - ~ ~I ~ ACOJvU_ATCR CAPACITY TEST I. (I-ECl( ~ FILL AOI. M.LA'rc~ REI~I~OIR TO ~ I. EVEL WITH ~IC FLUID. 2. ASSURE THAT ACCUkIJLATCR PRESSURE IS tliX30 PSI WI'tH 1500 PSl ~TREA~ (lr T~.I~ REGLLA'rC~. 3. (]~ERVE TIbE., TI-EN ~ ALL UNI'r~ SIM, LT~E(IMSLY ALL LI~IITS ARE CL(]~:~) WITH CHAI~]:NG FU~ CFF'. 4. RE(XII~ C~I ~ REPORT. TI~ ~ABLE LCIM~R LIMIT IS 45 SE~ CLOSIN~ TII~ AI~ 1200 PSl REI~INING 5 4 2 1~-5/8" BOP STACK TEST I. FILL ~ STACK AN3 043<E IVlN~FCLD WITH ARCTIC DIESEL. 2. CI~ THAT /iLL LOCK ~ SCRE~ IN V~LLFE/ID ARE FLLLY RETRACTED. SEAT TEST PLUG IN WITH RLI~dING JT ~ ~ IN L(X]<IXII~ SCRE~ 3. CLL'J~'__ ~ PREVENTER ~ MIINJAL KILL AN~ CHCKE LIllE VALVES ADJACENT TO BCP STACK. ALL OTI-ER VALVES A~) (]~3(ES SH~LLD BE ~ 4. PRESSLRE UP TO 250 PSI ~ H~I.D F(~R lO MIN. IN- (]~EASE PRESSLRE TO ~ PSI ~ H~LD FCR I0 MI~i BLEED PRESSLRE TO 0 PSI. 5. CFEN AN~JLAR PREVENTER ~ ~ KILL AN3 CHCKE LIllE VALVES. CLOSE TCP PIPE RAIVB ~ HCR VALVES CN KILL ~ CHOKE LI~E~. 6. TEST TO 250 PS I /tI~)~PSI AS INSTEP4. ?. 03~II~[E TESTING ALL VALVES, LII~S, /¥0 (]43(ES WITH & 250 PSI LOW/t~l} ~300 PSl HIGH. TEST AS IN 8. (lIEN TCP PIPE RAI~ ~ CLC~E BOTTOM PIPE RAMS. TEST BOTTCM PIPE RAIV~ TO 250 PSI ~ ~4:X]O PSI. 9. CPEN BOTTCM PIPE RNVB, BAO( OUT ~1~3 J7 ~ I0. CLOSE BLIN3 RNv6 ~ TEST TO 250 PSI ~ 50C~ PSI. II. CPEN BLII~) RNVB ~ RETRILrV£ TEST PLUG, MJIKE SURE MM~D AN3 LIltS A~ FLU. (~F I~E-ZING FLUID. SET ALL VALVI~ IN ERILLING POSlTI~ 12. TEST STAI~PIPE VALVES, KELLY, KELLY COCKS, [:RILL PIPE SAFETY VALVF.~ AN3 IN~I~E BI~ TO 250 PSI ~ ~ PSI. 4. RECCRD TEST IhFCRM~TIC~I CN BLOVOJT ~ER TEST ~ ~ C ~iV ~ FORt& SIGN, AI~ ~ TO ERILLING ~PERVI~. VEEI<LY THERE~ FLI~ICNN.LY OPERATE BCPE ~RILY. JUN 2 7 198 Gas Cons. Commission _ SlOO~4OOIJ ARCO ALASKA. ]:n o · Pad 30. Well No, :3 Proposed Kuparuk Field. North Slope. Alaska RI~ ELEVATION' $~' KOP: TVD-SO0 TtlD-$O0 DEP-O 3 a BUILD 3 1 -t~.-.- PER tOO : %~ ,39 B/ PERHAFROST TVD-1719 TtlD-1822 DEP-440 2000. . '~.EOC TVD-1844 THD-1991 DEP-5$3! '~: ' '~ T/ UGNU SNDS TVD--2?I g THD-3222 DEP-1419 m 3000 m o 4000 I'rl SOO0 6000 ?000 ~ TVD=4119 Tt'ID-5193 DEP-2806 AVERAGE ANGLE' RECEIVED 44 DEG 43 HI N ~ _ · -~ JUN 2 7 1.,988 ~Alasl'~ Oit & Gas Con°. Commission A -Anchorage · _ · K_$ TVD.$909 T.D'Z71'2 DEP"4578 ~ T/ ZONE D TVD=6539 THD-8598 DEP-5202 ~ T/ ZONE C TVD-6629 THD-SZ2$: DEP-5291 % T/ ZONE A TVD=6694 TtID-ee~e .DEP-5356 ~. TARGET CNTR TVD-5744 Tt'ID-8887 DEP-5405 B/ KUP SNDS TVD-6794 THD-8957 DEP-5455 ,.,,, x. ,.. TD (LOG PT) TVD-6936 THD"g15z DEP-5595 ~, 1000 2000 3000 4000 5000 6000 VERTICAL SECTION HOR I ZON?~-~ PROJEOT ION SCALE · - 1000 FEET ARCO ALASKA, !no, Pod 30. Wel I No, 3 Proposed Kuperuk Field. Nont:h Slope. Aleoke 5000. ~ _400Q_ - ;5000 _ Z , 2000 - '1 000 - ~ 1000 _ WEST-EAST 1000 0 ! 000 2000 I TD LOCAT! ON · 1154.' FILL. 7.00. FEL SEC. 15, TI3N.. RgE 3000 TARGET CENTER TVD,,G?44 TIID-~? DEP-S40S HORTH 4?2? EAST 2621 TARGET LOCATION' 1320' FNL. 7'92' FEL SEC. 15. T13N. RgE SURFACE S1JRFAC~ LOCAT [ ON, TeT' FNL. 18eT' FI, IL SEC. 22, T13N, RgE JUN ~ 7 198~ 'Al~Sk~ Oil & Gas Cons. Commission N 29 DEG E 5405' (TO TARGET) 750 1 800 1 850 1 900 1 ~,.,0 2000 2050 I I I I I I I 600. I ~' -' '-- I ~'1300 \ I I / ~ / I \ I 1500 I / '~ 900 ! _ 65C I / \\\ I , I ~ ~ ~'~7 O0 I ~' 1I1 O0 ~ / I 70C ?OO.. ~ I / I - i'I ' ' ' "~,oo ~ ~oo~ '1 '~.~00 oo ! 750 ~ ~'. $o0// 4:soo / / 75( I "'~'r'oe.,, oo / roo~ ~ '- . 'soo ~oo ' /~roo i ~~ sqo I // I _ 80~ "' LS~O0 1' 900 I coo. I ~ ,,,. · ,oo ~ ~ co /,'2,oo ~ I · ,t300 I soo ~..,.~ ~ooI _ I I - I ;soo I I I ~o 900 . ° ~e.._ - Anchorage _10 ~ooo ..... -- I I I I I I I 1 750 1 800 1 850 1 900 1 950 2000 2050 CHECK LIST FOR NEW WELL PERMITS Company /~R~C-~ Lease & Well No. ~ ~ ~ ITEM APPROVE DATE YES NO (1) Fee ~ ~[~9/~ 1 Is the permit fee attached ~ ,,,,,,,, · · · · · · · · · · · · · · e e e e e e e · e e e e e e e e e e e e e e e e e e e e e REMARKS <2> Loc fzg/ <2 thru 8)' (8) (3) Admin~ 6[29/~ 9. (9 thru 13) 10. ,~, ~. ~'. ~ -,~-~ 11. (i0 and 13) 12. (4) Casg ~,~.~, ~-S-8~ (14 thru 22) (5) SOPE (23 thru 28) (6) OTHER ~ ~/~ (29 thru- 31) 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 ...................... ~ 13. Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... ~ Is administrative approval needed ................................... ~ Is the lease number appropriate ..................................... d~ Does the well have a unique name and number ......................... ~ -- 14. 15. 16. 17. 18. 19. 20. 21. 22. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... ,, 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 ............................ 23. 24. 25. 26. 27. 28. For 29. 30. 31. Is a diverter system required ....................................... ~ Is the drilling fluid program schematic and list of equipment adequate/f~f Are necessary diagrams and descriptions of diverter and BOPE attached. ~,~ Does BOPE have sufficient pressure rating - Test to ~O~O psig ...~ Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: . Are data presented on potential overpressure zones? ................. / z-~-. Are seismic analysis data presented on shallow gas zones ......... .~ If an offshore loc., are survey results of seabed conditions presented 32. Additional requirements ............................................. Engi]~e~ering: INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Xf~o ~ c~o 2P~= V - £ o/l_ ~qO It/6 0 Ol,~ Additional Remarks: rev: 02/17/88 6.011 Well History File APPENDIX Information of detailed nature that is not particUlarly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No 'special 'effort has been made to chronologically organize this category of information. ALASKA COMPUTING CENTER ....... SCHLUMBERGER ....... ............................. COMPANY NAME WELL NAME FIELO NAME STATE BOROUGH API NUMBER REFERENCE NO : ARCO ALASKA INC. :30-3 : KUPARUK : ALASKA : NORTH SLOPE : 50-029-21538 : ?2928 TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 13-SE~-1988 14:43 PAGE' $~$~ REEL HE~DER ~$$~ SERVICE NAME : EDIT DATE : 88/09/13 ORIGIN : mLIC REEL NAME : 72925 CONTINUATION ~ : PREVIOUS REEL : COMMENT : LIS TAPE, ARCO KUPARUK 3 0-3, API e50-029-21838 · ~ TAPE HEADER ~ SERVICE NAME : EDIT DATE : ~8/09/13 ORIGIN : :LIC TAPE NAME : 72926 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : LIS TAPE, ARCO KUPAPUK 3 ~-3, API a50-029-21838 m$~$ FILE HEADER ~$~ FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001A02 DATE : 88/09/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST ~ILE : ARCO ALASKA INC. 3 0-3 KUPARUK ALASKA NORTH SLOPE U.S.A. 50-029-Z183~ 22 13N 9E ?6T~ FNL & 1867~ FWL ONE MSL 59,, 59. 58. 24. 9140. 9142. 8 1/2" 9140. 9 5/8" ! COMPANY NAME ! WELL NAME ri FIELD NAME ! STATE ! BOROUGH ! NATION !API NUMBER ! SECTION ! TOWNSHIP ! RANGE .i LOCATION ! RUN NUMBER ! PERMANENT DATUM ! ABOVE PERMANENT DATUM ! LOG MEASURED FROM ! KB ELEVATION ! D~ ELEVATION ! GL ELEVATION :! TO ORILLER ! TO LOGGER ! BIT SIZE 1 ! BIT SIZE DEPTH 1 ! CASING SIZE i IS TA~E VERIFICATION LISTING CHLUMBERGER ALASK~ COMPUTING CENTER 13-$Ev-1988 14:43 PAGE: 5149. 5149. LSND 10. 9.5 4.8 41. 4.15 66. 4.47 66. 2.91 66° PRUDHOE BAY 0715 6SEPT 80. 145. MALLARY BEAL 1.5" STANDOFFS ON OIL SONDE GRcLMDEN=~65, ~RSH=IooMATRIX:SAND, POUT=SAND RWF:.12~ RWB:.Z DIS 111~ DIC 1422 SET 34 CNC 123B SGC 2626 6 SEP'T 8B lO-SEP-88 72926 J. KOHRING ! C~SING DRILLER ! C~SING LOGGER ! DRILLING FEUID 'TYPE ! DRILLING FLUID OENSITY ! DRILLING FLUID PH ! DRILLING FLUID LOSS ! DRILLING :LUID VISCOSITY ! MUD RESISTIVITY !MUO SAMPLE TEMP ! MUD FILTRATE RESISTIVITY ! MUD FILTRATE SAMPLE TEMP ! MUD CAKE ~ESISTIVITY ! MUD CAKE SAMPLE TEMP ! LOGGING DISTRICT ! TIME LOGGER ON BOTTOM ! SURFACE TEMP ! MAXIMUM RECORDED TEMP ! LOGGING ENGINEER ! WITNESS ! FIELD REMARKS ! FIELD REMARKS ! TOOL NUMBERS ! LOG DATE ! DATE JOB STARTEO ! JOB REFERENCE NUMSER ! LOP/ANALYST COMPUTING CENTER ~EMARK.S: 'TOP 6' OF OIL AND CASEO HOLE GR DATA WAS NOT RECORDED ON TAPE IN FIELD. TOP 3' OF 1.2" FDC/CNL DATA. W&S NOT RECOROEO ON TAPE IN FIELD. THIS DA'TA H,~S NOT BEEN DEPTH 'SHIFTED - OVERLAYS FIELD PRINTS SCHLUMBERGER LOGS INCLUDED WITH THIS FILE (EDIT.OOl): <SEE FILE EDIT.OO2 FOR 1.2" SAMPLED FDC/CNL DATA> DUAL INDUCTION SPHERICALLY FOCUSED LOG C.OIL) FIRST TQ LAST READING: 8935' TO 514'9' FORMATION DENSITY COMPENSATED LOG (.FDC) FIRST TO LAST RE~gING' 9113' TO 8546' COMPENSATED NEUTRON LOG (.CNL) FIRST TO LAST READING: 9095' TO 8546' GAMM.~ RAY IN CASING (.CHL) FIRST TO LAST READING: 5149' TO 990' IS TAPE VERIFZC&T[DN LISTING CHLUMBERGER ALASKA COMPUTING CENTER 13-SEP-1988 14:43 PAGE: T~BLE TYPE : CONS ,~H TUNI CN FN WN NATI STAT COUN SECT T OWN RANG FL OPER SON APIN VALU DEFI ARCO ALASKA INC. COMPANY NAME KUPARUK FIELD NAME 3 0-3 WELL NAME U.S.A. N~TION ALRSKA STATE OR PROVINCE NORTH SLOPE COUNTY 22 SECTION 13N TOWNSHIP gE RANGE 767' FNL & 1867e FWL FIELD LOCATION MALLARY CPERATOR~S CODE 539802 SERVICE ORDER NUMBER 50-029-21838 API SERIAL NUMBER TABLE TYPE : CURV AH DEPT TENS SFLU ILM ILO SP GR TENS DPHI DRHO RHOB CALI GR TENS NPHI TNRA RTNR RCFT RCNT CFTC CNTC GR TENS GR DE~I DEPTH CHANNEL NAME TENSION SFL UNAVERAGED IL-MEDIUM RESISTIVITY IL-DEEP RESZSTIVITY SPONTANEOUS POTENTIAL GAMMA RAY TENSION DENSITY P~ROS:TY DEL'TA RHO BULK OENS'[TY CALIPER GAMMA R~Y T'EN.SION NEUTRON POROSITY CALIBRATED T'HERMAL NEUTRON RATIO RAW THERMAL NEUTRON RATIO RCFT RCNT C~TC CNTC GAMMA R~Y TENSION GAMMA R~Y IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 13-SEP-1988 14:43 PAGE: DATA FORMAT SPmCIFICATION RECORD SET TYPE - 64EB ~ TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 96 4 66 1 $ 68 0.5 9 65 FT 11 66 10 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ~ SET TYPE - CHAN '~ NaME SERV UNIT SERVICE APl RPI API API FILE NUMB NUMB SIZE REPR ID ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE DEPT FT 539802 TENS 9Il LiB 539802 SFLU OIL OHMM 539802 ILM Oil OHMM 539802 ILD OIL OHMM 53'9802 SP OIL MV 539802 GR DIL GAPI 539802 TENS FDC LB 539802 DPHI FDC PU 539802 DRHO FDC G/C3 539802 RHOB FDC G/C3 539802 CA'LI FDC IN 539802 GR FDC GAPI 539802 TENS CNL LB 539802 NPHI CNL PU 539802 TNRA CNL 539B02 RTNR CNL 539802 RCFT CNL CPS 539802 RCNT CNL CPS 539802 CFTC CNL CPS 539802 CNTC CNL CPS 539802 GR CNL GAPI 539802 TENS CHL LB 539802 GR CHL GAP[ 539802 PROCESS CHEX) 1 1 1 4. 68 1 1 1 4 68 1 1 1 4 6~ 1 1 1 4 68 1 1 1 4 68 1 1 I 4 68 I I 1. 4 68 I 1 .1 4 68 1 1 1 4 68 1 I I 4 68 I I I 4 68 1 1 1 4 6 B 1 I I 4 68 I 1 I 4 68 I I 1 4 6,~ 1 I I 4 68 I 1 1 ¢ 68 1 I 1 4 68 1 1 1 4 68 I I I 4. 6 B I I 1 4 68 I I 1 4 68 t I 1 4 68 I I 1 4 68 000000:0000 0000000000 0000000000 0000000000 0000000000 DO00000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASK& COMPUTING CENTER 13-$EP-1988 14:43 PAGE: DEPT. 8946.500 TENS.OIL ILO.OIL 4.300 SP.OIL DPHI.FDC 58.682 DRHO.FDC GR.FDC 93.563 TENS.CNL RTNR.CNL 3.226 RCFT.CNL CNTC.CNL 2046.868 GR.CNL DEPT. 8900.000 TENS.OIL ILO.OIL 3.060 SP.DIL DPHI.FDC 11.447 DRHO.FDC GR.FDC 93.563 TENS.CNL RTNR.CNL 3.493 RCFT.CNL CNTC.CNL 2095.450 GR.CNL DEPT. 8800.000 TENS.OIL ILO.OIL 2.692 SP.DIL DPHI.FOC 14.148 DRHO.FDC GR.FDC 103.813 TENS.CNL RTNR.CNL 3.484 RCFT.CNL CNTC.CNL 1861.422 GR.CNL DEPT. 8700.000 TENS.OIL ILD.DIL 16.661 SP.DIL DPHI.FDC 21.427 DRHD.FDC GR..FDC 76.125 TENS.CNL RTNR.CNL 3.457 RCFT.CNL CNTC.CNL 2270.691 GR.CNL DEPT. 8600.000 TENS.DIL ILO.DIL 3.610 SP.OIL DPHI.FDC 11.076 DRHO.FDC GR.FDC 106.500 TENS.CNL RTNR.CN, L 3.124 RCFT.CNL CNTC.CNL 2298.346 GR.CNL DEPT. 8500.000 TENS.OIL ILO.OIL 2.651 SP.DIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 'RCFT.CNL CNTC.CNL -999.250 GR.CNL 3090.000 SFLU.DIL -26.219 GR.DIL 0.018 RHOB.FDC 3090.000 NPMI.CNL 611.461 RCNT.CNL 93.563 TENS.CML 5280.000 SFLU.DIL -23.500 GR.DIL 0.066 RHOB.FDC 5280.000 NPHI.CNL 589.692 RCNT.CNL 93.563 TENS.CHL 5248.000 SFLU.OIL -22.984 GR.OIL 0.046 RHOB.FOC 5248.000 NPHI.CNL 486.071 RCNT.CNL 103.813 TENS.CHL 5124.000 SFLU.DIL -30.984 GR.DIL 0.047 RHOB.FDC 5124.000 NPHI.CNL 679.227 RCNT.CNL 76.125 TENS.CHL 5208.000 SFLU.DIL -32.719 GR.OIL 0.042 RHOB.FDC 5208.000 NPMI.CNL 775.221 RCNT.CNL I06.500 TENS.CHL 4944.000 SFLU.OIL -]35.125 GR.DIL -999.250 RHOB.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 'TENSoCHL DEPT. 8400.000 TENS.OIL 4972.000 SFLU.DIL ILO.OIL 1.720 SP.DIL -18.156 GR.DIL DPHI.FDC -999.250 DRHO.FDC -999.250 RHD~.FDC GR.FDC -999.250 TENS.CNL -999.250 NPHI.CNL RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL DEPT. 8300.000 TENS.gIL ILO.OIL 2.056 SP.DIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL 4980.000 SFLU.OIL -28.719 GR.DIL -999.250 RHOS.FDC -999.250 NPHI.CNL 3.570 93.563 1.682 38.309 1999.014 -999.250 3.074 93.563 2.461 38.647 1997.693 -999.250 3.0~4 103.813 2.417 42. 170 1831.197 -999.250 15.444 76.125 2.296 34.693 2140.279 -999.250 3.697 106.500 2.457 29.460 2276.435 -999.250 3.713 132.500 -999.250 -999.250 -999.250 -999.250 1.705 123.313 -999.2.50 -999.250 -999.250 -999.250 2.551 102.625 -999. 250 -999 ILM.DIL TENS. mDC CALI.FDC TNR~.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FOC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC C~LI.FDC TNRA. CNL C~TC.CNL GR.CML IL~'4.OIL TE'NS. FDC C,&LI.FDC TNRA.CNL C FTC. C NL GR.CML ILM.DIL TENS. FDC CALI. FDC TNRA.CNL CFTC.CNL GR. CHL !LM.OIL TENS.FDC C~LI.FDC TNRA..CNL 3.662 3090.000 4.785 2.994 695.929 -999.250 3.135 5280.000 8.391 3.262 655.255 -999.250 2.817 5248.000 9.031 3.487 566.318 -999.250 15.626 5124.000 8.352 3.023 745.261 -999.250 3.537 5208.000 9.836 2.813 823.941 -999.250 2.752 -999.250 -999.250 -999.250 '-999.250 -999.250 1.733 -999.250 -999.150 -999.250 -9'99.250 -999.250 2.174 -999.250 -999.250 -999.250 IS TaPE VERIFICATIgN LISTING CHLUMBERGER ALASKA SOMPUTING CENTER 13-5EP-!gB8 P~GE: RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL DEPT. 8200.000 TENS.OIL ~912.000 S=LU.DIL ILO. OIL 2.787 S P. OIL - 25. 500 GR. OIL DPHI.FDC -999.250 DRHO.FDC -999.250 RHDS.FDC GR.FDC -999.250 TENS.CNL -999.250 NPHI.CNL RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNE CNTC.CNL -999.250 GR.CNL -999.250 TENS.CML DEPT. 8100.000 TENS.DIE 4864.000 SFLU.DIL ILO.OIL 1.B$7 SP.OIE -21.703 GR.DIL DPHI.FDC -999.250 DRHO.FDC -999.250 RHOB.FOC GR.FDC -999.250 TENS.CNL -999.250 NPHI.CNL RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL DEPT. 8000.000 TENS.DIE ~764.000 SFLU.DIL ILD.DIL 2.466 SP.OIL -21.453 GR.DZL DPHI.FDC -999.250 DRHO.FDC -999.250 RHOB.FDC GR.FDC -999.250 TENS.CNL -999.250 NPHI.CNL RTNR.CNL -999.250 RCFT.CNE '-999.250 RCNT.CNL CNTC.CNL -999.250 GR.CNL -999.250 TENS.CML DEPT. 7900.000 TENS.OIL 4812.000 SFLU.OIL ILD.DIL 2.737 SP.DIL -24.672 GR.DIL DPHI. FDC -999.250 DRHD.FOC -999.250 RHOB.FDC GR.FDC -999.250 TENS.CNL -999,250 NPHI.CNL RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL CNTC.CNL -999.250 GR.CNE -999.250 TENS.CHL DEPT. 7800.000 TENS.OIL 46~0.000 SFLU.DIL ILD.DIL 2.274 SP.DIL -23.438 GR.DIL DPHI.FDC -999.250 DRHO.FDC -999.250 RHOB.FDC GR.FDC -999.250 TENS.~CNL -999.250 NPHI.CNL RTNR.CNL -999.250 RCF'T.CNL -999.250 RCNT.CNL CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL DEPT. 7700.000 TENS.OIL 4732.000 SFLU.DIL ILO.OIL 3.316 SP.OIL -26.734 GR.OIL DPHI.FDC -999.250 DRHO.FDC -999.250 RHOB.FDC GR.~DC -999.250 TENS.CNL -999.250 NPHI.CNE RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL CNTC.CNL -999.250 GRoCNL -999.250 TENS.CHL DEPT. 7600.000 TENS.OIL ~5¢4.000 SFLU.DIL ILD. DIL 2.582 SP.DIL -30.156 GR.DIL DPHI.FDC -999.250 DRHO.FDC -999.250 RHDB.FDC GR.FDC -999.250 TENS.CNL -999.250 NPHI.CNL RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL -999.250 -999.250 2.932 1¢7.500 -999.250 -999.250 -999.250 -999.250 1.751 351.750 -999.250 -999.250 -999.250 -999.250 2.222 82.250 -999.250 -999.250 -999.250 -999.250 2.911 123.000 -999.250 -999.250 -999.250 -999.250 2.336 110.563 -999.250 -999..250 -999.250 -999.250 3.570 85.313 -999.250 -999.250 -999.250 -999.250 2.681 101.563 -999.250 .-999.250 -999.250 -999.250 CFTC.CNL GR.CHL ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC CALl .FDC TNRA.CNL CFTC.CNL GR.CHL ILM.DIL TENS. FDC CALI.FDC TNRA.CNL CFTC .CNL GR.CHL ILM.DIL TENS.FDC CALZ.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC C~LI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC CA:LI.FDC TNR~.CNL CFTC.CNL GR.CHL -999. -999. . -999. -999. -999. -999. -999. I . -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. 250 250 788 250 25O 250 250 25O 875 250 250 25O 25O 25O 429 250 25O 25O 25O 250 2.797 -999.250 -999.250 -999.250 -999.250 -999.250 . -999 -999 -999 -999 -999 . -999. -999. -999. -999. -999. . -999. -999. -999. -999. -999. 330 250 25O 250 250 250 626 250 250 250 25O 250 685 250 25O 250 250 25O IS TAPE VERIFICATION LISTING CHLUMBERGER ~LASK* COMPUTING CENTER 13-SEP-1988 14 · 4~ PAGE: DEPT. 7500.000 TENS.OIL ILO. OIL 2.920 SP.OIL DPHI.FDC -999.250 DRHD.FDC GR.FDC -999.250 TENS.CNL RTNq.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 7400.000 TENS.OIL ILO.OIL 2.364 SP.DIL DPHI.FDC -999.250 DRHD.~OC GR.FOC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 7300.000 TENS.OIL ILO.OIL 3.062 SP.DII DPHI.FDC -999.250 DRHO.FOC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 7200.000 TENS.OIL ILO.OIL 2.515 SP.gIL DPHI.FDC -999.250 ORHO.FDC GR.FOC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 7100.000 TENS.OIL ILO.OIL 2.653 SP.DIL DPHI.FDC -999.250 DRHD. FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 7000.000 TENS.OIL ILD.DIL 2.965 SP.OIL DPHI.FDC -999.250 DRMO.FDC GR.FDC -999.250 TENS.CN:L R~TNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 6900.000 TENS.OIL ILO.OIL 3.459 SP.OIL DPHIoFDC -999.250 DRHO. FDC GR.~DC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT:.CNL CNTC.CNL -999.250 GR-CNL DEPT. 6800.000 TENS.OIL ILO.OIL 3.112 SP.OIL DPHI.FDC -999.250 DRHD.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.Z50 GR.CNL 4360. -25. -999. -999. -999. -999. 4264. -32 · -999. -999. -999. -999. 4280. -29. -999. -999. -999. -999. 4268. -39. -999. -999. -999. -999. 4268. -30. -999. -999. -999. -999. 4268. -Z7. -999. -999. -999. -999. 42 64. -34. -999. -999. -999. -999. 4034. -36. -999. -999. -999. -999. 000 453 25O 25O 25O 25O 000 469 25O 25O 25O 25O 000 984 250 250 250 250 000 438 2.'50 250 25O 25O O00 203 2,5O 250 25O 25O 0 O0 719 25O 250 250 250 000 469 25O 25O 250 250 000 906 250 25O 25O 250 SFLU.DIL GR.DIL RHOB.FDC NPHI.CNL RCNT.CNL TENS.CHL SFLU.DIL GR.DIL RHO~.FDC NPHI.CNL RCNT.CNL TENS.CHL SFLU.DIL GR.DIL RHOB.FOC NPHI.CNL RCNT.CNL TENS.CHL SFLU.DIL GR.DIL RHOB.FDC NPHI.CNL RCNT.CNL TENS.CHL SFLU.OIL GR.DIL RHOB.FDC NPHI.CNL RCNT.CNL TENS.CHL SFLU.OIL GR.DIL RHOB.FOC NPHI.CNL RCNT.CNL TENS.CHL SFLU.DIL GR.DIL RHOB.FDC NPHI.CNL RCNT.CNL TENS.CML SFLU.DIL GR.OIL RHDB.FDC NPHI.CNL RCNT.CNL TENS.CHL 2.795 108.875 -999.250 -999.250 -999.250 --999.250 2.311 101.938 -999.250 -999.250 -999.250 -999.250 3.058 104.625 -999.250 -999.250 -999.250 -999.250 2.481 103.18B -999.250 -999.250 -999.250 -999.250 2.638 109.625 -999.25:0 -999.250 -999.250 -999.250 2.8'74 111.8T5 -999-250 -999.250 -999.250 -999.250 3.358 99.625 -999.250 -999.250 -999.250 -999.250 2.975 89.563 -999.250 -999.250 -999.250 -999.250 ILM.OIL TENS.FDC C~LI.FDC TNR~.CNL CFTC.CNL GR.CHL ILM.glL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC CALI .FDC TNR~ .CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CN'L GR.CHL I:LM.OIL TENS.FDC CALI.FOC TNR~.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL G~.CHL ILM.DIL TENS.FDC C~'LI.FDC TNRA.'CNL CFTC.CNL GR.CHL 2 -999 -999 -999 -999 -999 2 -999 -999 -999 -999 -999 3 -999 -999 -999 -999 -999 2 -999 -999 -999 -999 -999 2 -999 -999 -999 -999 -999 2 -999 -999 -999 -999 -999 3 -999 -999 -999 -999 -999 3 -999 -999 -999 -999 -999 .966 .250 .250 .250 .250 .250 .404 .250 .250 .250 .250 .250 .096 .250 .250 .250 .250 .250 .536 .250 .250 .250 .250 .6,~1 .250 .250 .250 .250 .250 .964 .250 .250 .250 .Z~O . ,250 .465 .250 .250 .250 .250 .250 .115 .250 .250 .250 .250 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASK~ SOMPUTING CENTER 13-SEP-1988 14:43 PAGE: DEPT. $700.000 ILD.DIL 2.619 DPHI.FDC -999.250 GR.FDC -999.250 RTNR.CNL -999.250 CNTC.CNL -999.250 TENS.DIL 4094.000 SFLU.DIL SP.DIL -29.438 GR.DIL DRHO.FDC -999.250 RHDB.FDC TENS.CNL -999.250 NPHI.CNL RCFT.CNL -999.250 RCNT.CNL GR.CNL -999.250 TENS.CHL DEPT. 6600.000 TENS.DIL 3970.000 SFLU.DIL ILO.OIL 2.778 SP.DIL -40.969 GR.DIL DPHI.FDC -999.250 DRHO.FDC -999.250 RHDB.FDC GR.FDC -999.250 TENS.CNL -999.250 NPMI.CNL RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL DEPT. 6500.000 TENS.DIL ILO.OIL 3.089 SP.OIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 6400.000 TENS.DIL ILD.DIL 2.632 SP.DIL DPHI.FDC -999.250 DRHD.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 6300-000 TENS.OIL ILO.OIL 3.141 SP.DIL DPHI.FDC -999.250 'DRHO.FOC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 6200.000 TENS.OIL ILO.OIL 2.424 SP.DIL DPHI.FDC -999.250 DRHQ.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL OEP'T. 6100.000 TENS.OIL ILO.OIL 3.331 SP.DIL DPHI.FDC -999.250 DRHD.FDC GR..FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 6000.000 TENS.OIL ILO. OIL 2.635 SP.DIL DPHI.FDC -999.250 DRMO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL 3960.000 SFLU.DIL -32.969 GR.DIL -999.250 RHOB.FOC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CHL 3734.000 SFLU.DIL -41.938 GR.DIL -999.250 RHOB.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CHL 3680.000 SFLU.DIL -41.688 GR.OIL -999.250 RHOB.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CHL 3550.000 SFLU.OIL -39.844 GR.DIL -9'99.250 RHOB.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CML 3630.000 SFLU.DIL -39.906 GR.DIL -999.250 RHOB.FDC -999,250 NPHI.CN:L -999.250 RCNT.CNL -999.250 TENS.CHL 3514.000 SFLU.DIL -43.438 GR.DIL -999.250 RHOB.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL 1.367 72.875 -999.250 -999.250 -999.250 -999.250 2.782 102.313 -999.250 -999.250 -999.250 -999.250 2.887 96.813 -999.250 -999.250 -999.250 -999.250 2.278 104.93B -999.250 -999.250 -999.250 -999.250 3.389 85.188 -999.250 -999.250 -999.250 -999.250 2.331 100.375 -999.250 -999.250 -999.250 -999.250 3.050 100.313 -999.250 -999.250 -999.250 -999.250 2.433 83.813 -999.250 -999.250 -999.250 ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.DIL TENS. FDC CALI.FDC TNR.~.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CML ILM.DIL TENS.FDC CALI.FDC TNR&.CNL CFTC.CNL GR.CML ILM .OIL TENS .F~C CALI.FDC T NRA. CNL CFTC.CNL GR .CHL ILM.DIL TENS.FDC C~LI .FDC TNRA.CNL CFTC.CNL GR.CHL ILMoDIL TENS.FDC C~LI.FDC TNRA. CNL CF'TC.CNL GR.CHL ILM. OIL TENS. FDC CALI.FDC TNRA.CNL C FTC. CNL 2.535 -999.250 -999.250 -999.250 -999.250 -999.250 2.799 -999-250 -999.250 -999.250 -999.250 -999.250 3.052 -999.250 -999.250 -999.250 -999.250 -999. 250 2.591 -999.250 -999.250 -999.250 -999.250 -999.250 3.221 -999.250 --999.250 -999.250 -999.250 -999.250 2.426 -999.250 -999,250 -999.250' -999.250 -999.250 3.252 -999.250 -999.250 -999.250 -999.250 -999.250 2.582 -999.250 -999.250 -999.250 -999.250 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKa COMPUTING CENTER 13-SEP-1988 14:43 PA~E: 9 CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL -999.250 GR.CHL -999.250 DEPT. 5900.000 TENS.OIL 3424.000 SFLU.OIL 3.315 ILM.DIL 2.838 ILO.OIL 2.931 SP.OIL -~1.656 GR.DIL 91.813 TENS.FDC -999.250 DPHI.=DC -999.250 DRHO.FDC -999.250 RMOB.FDC -999.250 C~LI.FDC -999.250 G~.~DC -999.250 TENS.CNL -999.250 NPHI.CNL -999.250 TNR~.CNL -999.250 RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL -999.250 CFTC.CNL -999.250 CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL -999.250 GR.CHL -999.250 DEPT. 5800.000 TENS.OIL 3414.000 SFLU.DIL 2.872 ILM.OIL 2.939 ILO. OIL 2.969 SP.DIL -47.625 GR.OIL 93.688 TENS.FDC -999.250 DPHI.FDC -999.250 DRHOoFOC -999.250 RHOS.FOC -999.250 C~LI.FOC -999.250 GR.FDC -999.250 TENS.CNL -999.250 NPHI.CNL -999.250 TNR~.CNL -999.250 RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL -999.250 CFTC.CNL -999.250 CNTC.CNL -999.250 GR.CNL -939.250 TENS.CML -999.250 GR.CML -999.250 DEPT. 5700.000 TENS.OIL 3290.000 SFLU.OIL 2.605 ILMoDIL 2.879 ILO.OIL 2.983 SP.DIL -¢$.BT5 GR.DIL 83.875 TENS.FDC -999.250 DPHI.FDC -999.250 DRHO.FDC -999.250 RHOB.FOC -999.250 CALI.FDC -999.250 GR.FDC -999.250 TENS.CNL -999.250 NPHI.CNL -999.250 TNRA.CNL -999.250 RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL -999.250 CFTC.CNL -999.250 CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL -999.250 GR.CHL -999.250 DEPT. 5600.000 TENS.OIL 3130.000 SFLU.OIL 3.942 ILM.OIL 3.726 ILO.OIL 3.763 SP.DIL -55.875 GR.DIL 96.438 TENS.FDC -999.250 DPHI.FDC -999.250 DRHO.FDC -999.250 RHDB.FDC -999.250 C~LI.FOC -999.250 GR.FDC -999.250 TENS.CNL -999.250 NPHI.CNL -999.250 TNRA.CNL -999.250 RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL -999.251'0 CFTC.CNL -999.2510 CNTC.CNL -999.250 GRoCNL -999.250 TENS.CHL -999.250 GR.CHL -999.250 DEPT. 5500.000 TENS.OIL 3204.000 SFLU.OIL 3.501 ILM.DIL 6.244 ILO.OIL 6.015 SP.OIL -48.469 GR.DIL 67.000 TENS.FDC -999.250 DPHI.FDC -999.250 DRHO.FDC -999.250 RHOB.FDC -999.250 CALI.FDC -999.250 GR. FDC -999.250 TENS.CNL -999.250 NPHI.CNL -999.250 TNRA.CNL -999.250 RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL -999.250 CFTC.CNL -999.250 CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL -999.250 GR.CHL -999.250 DEPT. 5400.000 TENS.OIL 3084.000 SFLU.DIL 2.794 ILM.DIL 3.080 ILO.DIL 3.175 SP.DI'L -~6.375 GR.DIL 81.6B$ TENS.FDC -999.250 DPHI,FDC '-9'99.250 D~RHO.FDC -999.250 RHDB.FDC -999,250 CALI.FDC -999.250 GR.FDC -999.250 TENS,CNL -999.250 NPHI.CNL -999.250 TNRA.CNL -999.250 RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL -999,250 CFTC.CNL -999.250 CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL -999.250 GRoCHL -999.250 DEPT. 5300.000 TENS.OIL 3044.000 SFLU.DIL 2.856 ILM.DIL 3.125 ILO.OIL 3.250 SP.DIL -~6.406 GR'DIL BS.000 TENS.FDC -999.250 DPHI.FDC -999.250 DRHQ.FDC -999.250 RHOB.FOC -999.250 C~LI.FDC -999.250 GR.FDC -999.250 TEN.S.CNL -999.250 NPHI.CNL -999.250 TNRA,CNL -999.250 RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL -999.250 CFTC,CNL -9'99.250 CNTC,CNL -999.250 GR.CNL -999.250 TENS.CHL -999.250 GR.CHL -999.250 DEPT. 5200.000 TENS.OIL 3120.000 SFLU.DIL 1.4~3 ILM.DIL 1.765 ILO.OIL Z.~57 SP.DIL -~¢8.18B GR.DIL 94.063 TENS.FDC -999.250 DPHI.FDC -999.250 DRHO.FDC -999.250 RHOB,FDC -999.250 CALI.FDC -999.250 GR.FDC -999.250 TENS.CNL -999.250 NPHI.CNL -999.250 TNR~.CNL -999'250 IS TAPE VERIFIC&TION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 13-SEP-19B8 14:43 PAGE: 10 RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL -999.250 CFTC.CNL -999.250 CNTC.CNL -999.250 GR.CNL -999.250 TENS.CML -999.250 GR.CHL -999.250 DEPT. 5100.000 TENS.DIL -999,250 SFLU.DII -999,250 ILM,OIL -999.250 ILO.OIL -999.250 SP.DIL -999.250 GR.OII -999.250 TENS.FDC -999.250 DPHI.FDC -999.250 DRHO.FDC -999.250 RHOB.FOC -999.250 CALI.FDC -939.250 GR.FDC -999.250 T~NS.CNL -999.250 NPHI.CNL -999.250 TNR&.CNL -999.250 RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL -999.250 CFTC.CNL -999.250 CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL 3030.000 GR.CHL 62.656 DEPT, 5000,000 TENS, OIL -999,250 SFLU.DIL -999,250 ILM,DIL -999,250 IlO.OIl -999.250 SP.DIL -999.250 GR.DIL -999.250 TENS.FDC -999.250 DPHI.FDC -999.250 ORHO.FDC -999.250 RHOB.FDC -999.250 C~LI.FDC -999.250 GR.FDC -999.250 TENS.CNL -999.250 NPMI.CNL -999.250 TNRA.CNL -999.250 RTNR.CNL -999.250 RCFT. CNL -999.250 RCNT.CNL -999.250 CFTC.CNL -999.250 CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL 2980.000 GR.CHL 61.93B DEPT, 4900,000 TENS,DIE -999.250 SFLU,DIL -999,250 ILM,DIL -999,250 ILD.OIL -999.250 SP.DIL -999.250 GR.DIL -999.250 TENS.FDC -999.250 DPHI.FDC -999.250 DRHO. FDC -999.250 RHOB.FDC -999.250 CALI.FDC -999.250 GR.FDC -999.250 TENS.CNL -999.250 NPHIoCNL -999.250 TNR~.CNL -999.250 RTN~.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL -999.250 CFTC.CNL -999.250 CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL 3010.000 GR.CHL 47.656 DEPT. 4800.000 TENS,OIL -999,250 SFLU.DIL -999,250 ILM,DIL -999,250 ILO,OIL -999,250 SP,OIL -999,250 GR,DIL -999,Z50 TENS,FDC -999,250 DPHI.FDC -999.250 DRHD.FDC -999.250 RHOB.FDC -9'99.250 CALI.FDC -999.250 GR.FOC -999.250 TENS.CNL -999.250 NPHI.CNL -999.250 TNRA.CNL -999.250 RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL -999.250 CFTC.CNL -999.250 CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL 2910.000 GR.CHL 52.938 DEPT, 4700,000 TENS,OIL -999.250 SFLU,OIL -999,250 ILM,OIL -999,250 ILO.OIL -999.250 SP.OIL -999.250 GR.DIL -999.250 TENS.FDC -999.250 DPHI.FDC -999.250 DRHO.FDC '-999.250 RHOB.FDC -999.250 C~LI.FDC -999.250 GR.FDC -999.250 TENS.CNL -999.250 NPHI.CNL -999.250 TNRA.CNL -999.250 RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL -999.250 CFTC.CNL -999.250 CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL 2870.000 GR.CH~L 58.625 DEPT, 4600,000 TENS,OIL -999,250 SFLU,DIL -999.250 ILM,DIL -999,250 ILD.DIL -999.250 SP.DIL -999.250 GR.OIL -999.250 TENS.FDC -9'99.250 DPHI.FDC -999.250 ORHO.FOC -999.250 RHOB.FOC -999.250 CALI.FDC -999.250 GR.FDC -999.250 TENS.CNL -999.250 NPHI.CNL -999.250 TNRA.CNL -999.250 RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL -999.250 CFTC.CNL -999.25:0 CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL 2800.000 GR.CHL 36.469 DEPT, 4500,000 TENS,OIL -999,2.50 SFLU,DIL -999,250 ILM,DIL -999,250 ILO,OIL -999,250 SP,DIL -999,250 GR,DIL -999,250 TENS,FDC -999,250 DPHI.FDC -999.250 DRHO.FDC -:999.250 RHOB.FDC -999.250 CALI.FDC -999.250 GR.FDC -999.250 TENS.CNL -999.250 NPHI.CNL -999.250 TNRA.CN:L -999.250 RTNR,.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL -999.250 CFTC.CNL -999.250 CNTC.CNL -999.250 GR.CNL -999.25'0 TENS.CHL 2780.000 GR.CHL IS TAPE VERIFICATION LISTING CHLUMBERGER ALASK~ COMPUTING CENTER DEPT. 4400.000 TENS.OIL ILD.DIL -999.250 So. OIL DPHI.mDC -999.250 DRHO.mDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTCoCNL -999.250 GR.CNL DEPT. 4300.000 TENS.OIL ILO.OIL -999.250 SP.DIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 4200.000 TENS.OIL ILO.OIL -999.250 Sm. OIL DPHI.FDC -999.250 DRHO.~DC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 4100.000 TENS.OIL ILO.OIL -999.250 SP.DIL DPHI.FDC -999.250 DRHO.FDC GR.FOC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 4000.000 TENS.OIL ILO.OIL -999.250 SP.OIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 3900.000 TENS.OIL ILO.OIL -999.250 SP.OIL DPHI.FDC -999.250 DRHD. FDC GR.FDC -999.250 TENS.CNL RTNRoCNL -999.250 RCF'T.CNL CNTC.CNL -999.250 GR.CNL 13-SEP-1958 14:~3 -999.250 SFLU.DIL -999.250 GR.DIL -999.250 RHDB.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CHL -999.250 SFLU.DIL -999.250 GR.DIL -999.250 RHOB.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CHL -999.250 SFLU.DIL -999.250 GR.DIL -999.250 RHOB.FDC -999.2~0 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CHL -999.250 SFLU.DIL -999.250 Gl.OIL -999.250 RHOB.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CHL -999.250 SFLU.DIL -999.250 GR.DIL -999.250 RHOB.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CHL -999.250 SFLU.OIL -999.250 GR.DIL -999.250 RHOB.FDC -999.250 NPH'I.CNL -999.250 RCNToCNL -999.250 TENS.CHL DEPT. 3800.000 TENS.OIL -999.250 SFLU.DIL ILO. OIL -999.250 SP.OIL -999.250 Gl.OIL DPHI.FDC -999.250 DRHO.FDC -999.250 RHDB.FDC GR.FDC -999.250 TENS.CNL -999.250 NPHIoCNL RTNR.CNL -999.250 RCFT.CNL -999.250 RCN'T.CNL CNTC..CNL -999.250 GRoCNL -999.250 TENS.CHL DEPT. 3700.000 TENS.OIL -999.250 SFLU.OIL ILD.DIL -999.250 SP.DIL -999.250 Gl. OIL DPHI.FDC -999.250 DRHO. FDC -999.250 RHO~.FDC GR.FDC -999.250 TENS.CNL -999.250 NPHI.CNL RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL -939.250 -999.250 -999.250 -999.250 -999.250 2710.000 -999.250 -999.250 -999.250 -999.250 -999.250 2664.000 -999.250 -999.250 -999.250 -999.250 -999.250 2654.090 -999.250 -999.250 -999.250 -999.250 -999.250 2630.000 -999.250 -999.250 -999.250 -999.250 -999.250 2560.000 -999.250 -999.250 -999.250 -999.250 -999.250 2474.000 -999.2510 -999.250 -999.250 -999.250 -999.250 2420.000 -999.250 -999.250 -999.250 -999.250 -999.250 2430.000 ILM.DIL TENS.FDC C~LI.FDC TNR~.CNL CFTC.CNL GR.CHL ILM.DIL TENS.mDC C~LI.FDC TNR~.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC C~LI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM. DIL TENS.FDC :CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.OIL TENS.FDC C~LI.FOC TNR~.CNL CFTC.CNL GR.CHL ILM.OIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL PAGE: 11 -999.250 -999.250 -999.250 -999.250 -999.250 47.156 -999.250 -999.250 -999.250 -999.250 -999.250 56.000 -999.250 -999.250 -999.250 -999.250 -999.250 49.688 -999.250 -999.250 -999.250 -999.250 -999.250 39.844 -999.250 -999.250 -99'9. 250 -999.250 -999.250 49.125 -999.250 -999.250 -'999.250 -999.250 -999.250 40.094 -999.250 -999.250 -999.250 -999.250 -999.250 )4..906 -999.250 -999.250 -999.250 -999.250 -999.250 30.906 IS TAPE VERIFICATION LISTING CMLUMBERGER ALASKA COMPUTING CENTER 13-SEP-1988 14:43 PASE: 12 DEPT. 3600.000 TENS.OIL ILO.OIL -999.250 SP.9IL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC. CNL -999.250 GR.CNL DEPT. 3500.000 TENS.OIL ILO.OIL -999.250 SP.DIL OPHI.FDC -999.250 D~HO.mDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 3400.000 TENS.OIL ILO.OIL -999.250 SP.DIL DPHI.FDC -999.250 DRHD.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. '3300.000 TENS.OIL ILD.DIL -999.250 SP.DIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL -999.250 SFLU.DIL -999.250 GR.DIL -999.250 RHDB.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CHL -999.250 SFLU.OIL -999.250 GR.DIL -999.250 RHOB.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CML -9'99.250 SFLU.DIL -999.250 GR.DIL -999.250 RHO~.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CHL -999.250 SFLU.DIL -999.250 GR.DIL -999.250 RHO~.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CHL -999.250 -999.250 -999.250 -999.250 -999.250 23Z4.000 -999.250 -999.250 -999.250 -999.250 -999.250 2290.000 -999.250 -999.250 -999.250 -999.250 -999.250 2254.000 -999.250 -999.250 -999.250 -999.250 -999.250 2190.000 ILM.DIL TENS.FDC C~LI.FDC TNRE.CNL CFTC.CNL GR.CHL ILM.OIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM. DIL TENS.FDC CALI.FDC TNRA .CNL CFTC.CNL Gl .CHL ILM.DIL TENS.FDC CALl. FDC TNR,~.CNL CFTCoCNL GR.CHL -999.250 -999.250 -999.250 -999.250 -999.250 39.313 -999.250 -999.250 -999.250 -999.250 -999.250 40.594 -999.250 -999.250 -999.250 -999.250 -999.250 29.641 -999.250 -999.250 -999.250 -999.250 -999.250 45.313 DEPT. 3200.000 TENS.OIL -999.250 SFLU.OIL -999.250 I~LM.OIL -999.250 ILD.DIL -999.250 SP.DIL -999.250 GR.DIL -999.250 TENS.FDC -'999.250 DPHI.FDC -999.250 DRHO.FDC -999.250 RHDB.FDC -999.250 C~LI.FDC -999.250 GR,.FDC -999.250 TENS.CNL -999.250 NPHI.CNL -999.250 TNRA.CNL -999.250 RTNR.CNL -999.250 RC'FT.CNL -999.250 RCNT.CNL -999.250 CFTC.CNL -999.250 CNTCoCNL -999.250 GR.CNL -999.250 TENS.CHL Zl?O.O00 GR..CHL 50-4.38 DEPT. 3100.000 TENS.OIL -999.250 SFLU.DIL -999.250 ILM.DIL -999.250 ILO.OIL -999.250 SP.DIL -999.250 GR.DIL -999.250 TENS.FDC -999.250 DPHI.FDC -999.250 DRHO.FDC -999.250 RHOB.FDC -999.250 CALI.FDC -999.250 GR.FDC -999.250 TENS.CNL -999.250 NPHI.CNL -999.250 TNRA.CNL -999.250 RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL -999.250 CFTC.CNL -999.250 CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL 2054.000 GR.CHL 42.906 DEPT. 3000.000 TENS.OIL -999.250 SFLU.DIL -999.250 ILM.DIL -999.250 ILO.OIL -999.250 SP.DIL -999.250 GR.DIL -999.250 'TENS.FDC -999.250 DPHI.FDC -999.250 DRHO.FDC -999.250 RHO~.FOC -999.250 C~LI.FDC -999'250 GR.FDC -999.250 TENS.CNL -999.250 NPHI.CNL -999.250 TNRA.CNL -999.250 RTNR.CNL -999.250 RCFT.CNL -999.250 RCN'T.CNL -999.250 CFTC.CNL -999.250 CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL 2000.000 GR.CHL 35.031 -999.250 SFLU.OIL -999.250 -999.250 GR.DIL -999.250 -999.250 RHDS.FDC -999.250 -999.250 NPHI.CNL -999.250 -999.250 RCNT.CNL -999.250 ILM.DIL TENS.FDC CALI.FDC TNR~.CNL CFTC.CNL DEPT. 2900.000 TENS.D!L ILO.OIL -999.250 SP.DIL DPHI.FDC -999.250 D~HO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL -999.250 -999.250 -999.250 -999.250 -999.250 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKa COMPUTING CENTER CNTC. CNL -999. 250 GR. CNL 13-SFP-1988 14:43 -999.250 TENS.CHL DEPT. 2BO0.O00 TENS.DIL -999.250 SFLU.OIL ILD.DIL -999.250 SP.DIL -999.250 GR.DIL DPHI.FDC -999.250 DRHO.FDC -999.250 RHOB.FDC GR.FDC -999.250 TENS.CNL -999.250 NPHI.CNL RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL DEPT. 2700.000 TENS.OIL -999.250 SFLU.OIL ILO. DIL -999. 250 SP.DIL -999. 250 GR.DIL DPHI.FDC -999.250 DRHO. FDC -999.250 RHOB.FDC GR. FDC -999.250 TENS.CNL -999.250 NPHI.CNL RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL DEPT. 2600.000 TENS.OIL ltD.OIL -999.250 SP.DIL DPHI.FDC -999.250 DRHg.~DC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL -999.250 SFLU.DIL -999.250 GR.DIL -999.250 RHOB.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CHL DEPT. 2500.000 TENS.OIL -999.250 SFLU-DIL ILD.DIL -999.250 SP.DIL -999.250 GR.DIL DPHI.FDC -999.250 ORHg. FDC -999.250 RHOB. FDC GR.FDC -'999.250 TENS.CNL -999.250 NPHI.CNL RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL 1985.000 -999.250 -999.250 -999.250 -999.250 -999.250 1975.000 -999.250 -999.250 -999.250 -999.250 -999.250 1930.000 -999.250 -999.250 -999.250 -999.250 -999.250 1880.000 -999.250 -999.250 -999.250 -999.250 -999.250 1780.000 GR.CHL ILM.DIL TENS.FDC C&LI. FDC TNRA .CNL CFTC.CNL GR.CHL ILM .OIL TENS.FDC CALI.FDC TNR&.CNL CFTC.CNL GR .CHL ILM.OIL 'TENS .FOC C~LI.FDC TNRA .CNL CFTC. CNL GR.CHL ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL DEPT. 2400.000 TENS.OIL -999.250 SFLU.DIL -999.2510 ILM.DIL ILO.OIL -999.250 SP,OIL -999.250 GR.DIL -999.250 TENS.FDC DPHI.FDC -999.250 DRHO.FDC -999.250 RHOB.FDC -999.250 CALI.FDC GR.FOC -999.250 TENS.CNL -999.250 NPHI.CNL -999.250 TNRA.CNL RTNR.CNL -999.250 RCFT.CNL -999'250 RCNT.CNL -999.250 CFTC.CNL CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL 1775.000 GR.CHL DEPT. 2300.000 TENS.OIL -999.250 SFLU.DIL ILD.DIL -999.250 SP.OIL -'999.250 GR.OIL DPHI.FDC -999.250 DRHO. FDC -999.250 RHOB.FDC GR.FDC -999.250 TENS.CNL -999.250 NPHI.CNL RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL -999.250 -999.250 -999.250 -999.250 -999.250 1'740.000 -999.250 -999.250 -999.250 -999.250 -999.250 1685.000 DEP'T. 2200.000 TENS.DIL -999.250 SFLU.DIL ILO.OIL -999.250 SP.DIL -999.250 GR.DIL DPHI.FDC -999.250 DRHO.FDC -9:99.250 RHO~.FDC GR.FDC -999.250 TENS,CNL -999.250 NPHI.CNL RTNR.£NL -999.250 RCFT.CNL -999.250 RCNT.CNL CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ItM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL DEPT. ZlO0-O00 TENS.OIL -999.250 SFLU.DIL -999.250 ILM.DIL ILO.OIL -999.250 SP.DIL -999.250 GR.DIL -999.250 TENS.FDC OPHI.FDC -999.250 DRHO. FDC -999.250 RHOB.FDC -999.250 CALI. FDC GR.FDC -999.250 TENS.CNL -999.250 NPHI.CNL -999.250 TNRA.CNL PAGE: 13 38.438 -999.250 -999.250 -999.250 -999.250 -999.250 52.594 -999.250 -999.250 -999.250 -999.250 -999.250 39.031 -999.250 -999.250 -999.250 -999.250 -999.250 40.563 -999.250 -999.250 -999.250 -999.250 -999.250 37.625 -999.250 -999.250 -999,250 -999.250 -999.250 31.781 -999.250 -999.250 -999.25:0 -999.250 -999.250 41.156 -999.250 -999.250 -999.250 -999.250 .-999.250 37..281 -999.250 -999.250 -999.250 -999.250 IS TAPE VERIFICATTON LISTING CHLUMBERGER ALASKA SOMPUTING CENTER 13-SEP-19~J8 14:43 PAGE: RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.2 50 GR.CNL OEPT. ZO00.O00 TENS.OIL ILO.OIL -999.250 SP.DIL DPHI.FDC -999.250 DRHO.=DC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 1900.000 TENS.OIL ILO.OIL -999.250 SP.DIL DPHI.FDC -999.250 DRHO.=DC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 1800.000 TENS.OIL ILO.OIL -999.250 SP.DIL DPHI.FDC -999.250 DRHD.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 1700.000 TENS.DIL ILO.OIL -999.250 SP.OIL DPHI.FDC -999.250 DRH'D.FDC GR.FDC -999.250 TENS.CNL RTNR'CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 1600.000 TENS.OIL ILO.OIL -999.250 SP.DIL DPHI.FDC -999.250 DRHD.FDC GR.FDC -999.250 TENS.CNL RTN~.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 1500.000 TENS.OIL ILO. OIL -999.250 SP.DIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 1400.000 TENS.OIL ILO.OIL -999. 250 Sm. OIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999. 250 GR.CNL -999.250 RCNT.CNL -999.250 TENS.CHL -999.250 1630.000 CFTC.CNL GR.CHL -999.250 ~1.156 -999.250 SFLU.DIL -999.250 ILM.OIL -999.250 -999.250 GR.DIL -999.250 TENS.FDC -999.250 -999.250 RHDB.FDC -999.250 CALI.FDC -999.250 -999.250 NPHI.CNL -999.250 TNRA.CNL -999.250 -999.250 RCNT.CNL -999.250 CFTC.CNL -999.250 -999.250 TENS.CML 1565.000 GQ.CHL 25.375 -999.250 SFLU.DIL -999.250 -999.250 GR.OIL -999.250 -999.250 RHDB.FDC -999.250 -999.250 NPHI.CNL -999.250 -999.250 RCNT.CNL -999.250 -999.250 TENS.CHi 1540.000 -999.250 SFLU.DIL -999.250 GR.DIL -999.250 RHOB.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CHL -999.250 -999.250 -999.250 -999.250 -999.250 1490.000 -999.250 SFLU.DIL -999.250 -999.250 GR.DIL -999.250 -999.250 RHOB.FDC -999.250 -999.250 NPHI.CNL -999.250 -999.250 RCNT.CNL -999.250 -999.250 TENS.CHL 1455.000 -999.250 SFLU.DIL -999.250 -999.250 GR.DIL .-999.250 -ggg.250 RMOB.FOC -999.Z50 -999.250 NPHI.CNL -999.250 -999.250 RCNT.CNL -999.250 -999.250 TENS.CML 1410.000 -999.250 SFLU.DIL -999.250 -999.250 GR.DIL -999.250 -999.250 RHDB.~DC -999.250 -9'99.250 NPHI.CNL -999.250 -999.250 RCN'T.CNL -999.250 -999.250 TENS.CHL 1395.000 ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM. DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CML ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR .CHL ILM.DIL TENS.FDC CALI.FDC TNRA.CNL C FTC. ~C NL GR.CHL ILM.OIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL -999.250 SFLU.OIL -999.250 -999.250 GR.OIL -999.250 -999.250 RHOB.FDC -999.250 -999.250 NPHI.CNL -999.250 -999.250 RCNT.CNL -999.250 -999.250 TENS.CHL 1350.000 -999.250 -999.250 -999.250 -999.250 -999.250 47.18B -999.250 -999.250 -999.250 -999.250 -999.250 22.875 -999.250 -999.250 -999.250 -999.Z50 -999.250 35.0,00 -999.250 -999.250 -999.250 -999.250 -999.250 33.063 -999.250 -99'9.250 -999.250' -999.250 -999.250 19.328 -999.250 -999.250 -999.250 -999.250 -999.250 30.7~1 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASK~ COMPUTING CENTER 13-SEP-1988 14:~3 t5 DEPT. 1300.000 TENS.OIL ILO. OIL -999.250 SP.DIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 1200.000 TENS.OIL ILO.OIL -999.250 So. OIL DPHI.FDC -999.250 DRHO.FOC GR.~DC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 1100.000 TENS.OIL ILO.OIL -999.250 SP.DIL DPHI.FDC -999.250 DRHD.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 1000.000 TENS.OIL ILO.OIL -999.250 SP.gIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT.. 994.500 TENS.OIL ILO.OIL -999.250 SP.DIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999,250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL END OF DATA -999.250 SFLU.DIL -999.250 ILM.DIL -999.250 -999.250 GR.DIL -999.250 TENS.FDC -999.250 -999.250 RHDB.FDC -999.250 CALI.FDC -999.250 -999.250 NPHI.CNL -999.250 TNR~.CNL -999.250 -999.250 RCNT.CNL -999.250 CFTC.CNL -999.250 -999.250 TENS.CHL 1300.000 GR.CHL 24.125 -999.250 SFLU.OIL -999.250 -999.250 GR.DIL -999.250 -999.250 RHOB.FDC -999.250 -999.250 NPHI.CNL -939.250 -999.250 RCNT.CNL -999.250 -999.25'0 TENS.CHL 1255.000 -999.250 SFLU.OIL -999.250 -999.250 GR.DIL -999.250 -999.250 RHOB.FDC -999.250 -999.250 NPHI.CNL -999.250 -999.250 RCN'T.CNL -999.250 -999.250 TENS.CHL 1215.000 -999.250 SFLU.DIL -999.250 -999.250 GR.DIL -999.250 -999.250 RHOB.FDC -999.250 -999.250 NPHI.CNL -999.250 -999.250 RCNT.CNL -999.250 -999.250 TENS.CHL 11T0.000 -999.250 SFLU.DIL -999.250 -999.250 GR.DIL -999.250 -999.250 RHDB.FDC -999.250 -999.250 NPHI.CNL -999.250 -999.250 RCNT.CNL -999.250 -999.250 TENS.CHL 1170.000 ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC .CNL GR.CHL ILM.DIL TENS.FDC CALi .FDC TNRA .CNL C FTC. CNL GR .CHL ILM.DIL TENS.FDC CALI. FDC TNRA.CNL CFTC.CNL GR.CHL -999.250 -999.250 -999.250 -999.250 -999.250 37.375 -999.250 -999.250 -999.250 -999.250 -999.250 51.688 -999.250 -999.250 -999.250 -999.250 -999.250 ¢8.125 -999.250 -999.250 -999.250 -999.250 -999.250 50.781 ,'~ FILE 'TRAILER FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001A02 DATE : 88/09/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE IS TAPE VERIFICATION LISTING CHLUM~ERGER ALASKA COMPUTING CENTER 13-SEP-1988 14:43 PAGE: 16 *~=* FILE HEADER ~, ~- FILE NAME : EDTT .002 SERVICE : FLIC VERSION : 901A02 DATE : 88/09/13 MAX AEC SIZE : 1024 FILE TYPE : LO LAST FILE : THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS SCHLUMBERGER LOGS INCLUDEO WITH THIS FILE (EDIT.O02): (SEE FILE EDIT.O01 FOR 6" SAMPLED DIL/FOC/CNL/GR DATA'> FORMATION DENSITY COMPENSATEO LOG (.FOH) FIRST TO LAST READING: 9113' 'TO B296:' COMPENSATED NEUTRON LOG (.CNH) FIRST TO LAST READING: 9095' TO 8296~' TABLE TYPE : CONS ,AH TUNI V~LU CN ~RCO ALASKA INC. FN KUPARUK WN 3 0-3 N~TI U.S.A. STAT AL~SKA COUN NO~TH SLOPE SECT 22 TOWN 13N RANG 9E FL 767' FNL & 1867' FWL OPER MALLAR'Y SON 539802 APIN 50-029-21838 OEFI COMPANY NAME FIELD NAME WELL NAME NATION STATE OR PROVINCE :COUNTY S~CTION TOWNSHIP RANGE FIELD LO:CATION OPERATOR'S CODE SERVICE ORDER NUMBER API SERIAL NUMBER IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA :OMPUTING CENTER 1 3-SEP-19:88 14:43 PAGE: 17 TABLE TYPE : CURV AH OEFI DEPT DEPTH CHANNEL NAME TENS TENSION DPHI DENSITY POROSITY DRHO DELTA RHO RHOB BULK DENSIT'Y CALl CALIPER GR GAMMA RAY TENS TENSION NPHI NEUTRON POROSITY TNRA CALIBRATED THERMAL NEUTRON RATIO RTNR RAW THERMAL NEUTRDN RATIO RCFT RCFT RCNT RCNT CFTC CFTC CNTC CNTC GR GAMMA RAY DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ~ TYPE REPR CODE VALUE I 66 0 2 66 O 3 73 64 4 ~6 8 68 0.099 9 65 FT tl 66 16 1'3 56 0 14 65 ~T 15 66 16 66 1 0 66 I *~ SET TYPE - CHAN ~ NAME SERV UNIT SERVICE API AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR ID ORDER ~ LOG TYPE CLRS$ MOO NUMB SRMP ELEM CODE DEPT FT 53g$02 2 I I 4 6~ TENS FDH LB 539802 2 I I 4 68 DPHI FOH PU 539802 2 1 1 4 68 DRHO FDH G/C3 539802 2 1 1 4 68 RMOB FDH G/C3 539802 2 I 1 4 68 PROCESS (HEX) 0000000000 0000000000 0000000000 0000000000 O00000OO00 IS TAPE VERIFICATION LISTTNG CHLUMBERGER ALASK,~ COMPUTING CENTER 13-SEP-1988 14:43 PAGE: 18 NANE SERV UNIT SERVICE API API Ami API mILE NUMB NUMB SIZE REmR ID ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE CALI FDH IN 539802 2 ! 1 4 68 GR FDH GaPI 539802 2 1 1 4 68 TENS CNH LB 539802 2 1 1 4 68 NPHI CNH PU 539802 2 I 1 ¢ 68 TNRA CNH 539802 2 1 I 4 68 RTNR CNH 539802 2 I I 4 68 RCFT CNH CPS 539802 2 I I 4 68 RCNT CNH CPS 539802 2 I I 4 68 CFTC CNH CPS 539802 2 I I 4 68 CNTC CNH CPS 539802 2 I 1 4 68 GR CNH GaPI 539802 2 ! i 4 68 PROCESS (HEX) 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 DEPT. 9162.000 TENS.FDH 2684.000 DPHI.FDH 77.557 RHOB.FDH 1.370 CALI.FDH 2.305 GR.FDH 110.813 NPHI.CNH 47.326 TNRA.CNH 3.337 RTNR.CNH 3.596 RCNT.CNH 1875.973 C~TC.CNH 585.928 CNTC.CNH 1920.882 DEPT. 9100.000 TENS.FDH 5628.000 DPHI.FDH 49.265 RHOB.FDH 1.837 CALI.FDH 7.418 GR.FDH 107.750 NPHI.CNH 42.432 TNRA.CNH 3.377 RTNR.CNH 3.680 RCNT.CNM 1838.069 CFTC.CNH 569.558 CNTC.CNH 1220.905 DEPT. 9000.000 T~NS.FDH 5392.000 DPHI.FDH 13.302 RHOB.FDH 2.431 CALI.FDH 8.633 GR.FOH 101.813 NPHI.CNH 38.703 TNRA.CNH 3.265 RTNR.CNH 3.346 RCNT.CNH 1873.:520 CFTC.CNH 636.0'35 CNTC.CNH 11954.306 DEPT. 8900.000 TENS.FDH 5524.000 DPHI.FDH 12.038 RHOB.FDH 2.451 CALI.FDH 8.648 GR.FOH 96.813 NPHI.CNH 35.649 TNRA.CNH 3.099 RTNR.CNH 3.290 RCNT.CNH 2082.340 CFTC.CNH 696.699 CNTC.CNH 2103.439 DEPT. 8800.000 TENS.FDH 5352.000 DPHI.FOH 11.316 RHOB.FDH 2.463 CALI.FDH 8.844 GR.FDH 92.938 NPHIoCNH 43.175 TNRA.CNH 3.526 RTNR.CNH 3.720 RCNT.CNH 1997.778 CFTC.CNH 551.054 CNTC.CNH 1903.283 DEPT. 8700.000 TENS.FDH 5384.000 OPHI.FDH 22.928 RHOB. FDH 2.272 CAL'I. FDH 8.164 GR.FDH 77.750 NPHI.CNH 32.211 TNRA.CNH 2.859 RTNR.CNH 3.051 RCNT.CNM 2398.675 CFTC.CNH 822'887 CNTC.CNH 2300.936 DEPT. 8600.000 TENS.mDH 5244.000 DPHI.mDH 10.447 RHDB. FDH 2.478 CALI.FDH 9.766 GR.FDH 100.500 NPHI.CNH 29.798 TNRR.CNH 2.830 RTNR.CNH 3.000 RCNT.CNH 2166.186 ' CFTC.CNH 743.711 CNTC.CNH 2198.304 DRHO.FDH TENS.CNH RCFT.CNH GR.CNH DRHO.FDH TENS.CNH RCFT.CNH GR.CNH DRHO.FDH TENS.CNH RCFToCNH GR.CNH DRHO. FDH TENS.CNH RCFT .CNH GR.CNH DRHO.FDH TENS.CNH RCFT.CNH GR.CNH DRHD.FOH TENS.CNH RCFT.CNH GR.CNH DRHO.FDH TENS.CNH RCFT.CNH GR.CNH -0.037 2684.000 514.810 110.813 O. 079 5628.'000 497.363 I07.750 0.092 5392.000 5~8.315 101.813 0.033 5524-000 615.920 96.813 0.112 5352.000 527.887 92.938 0.001 5394.000 636.597 77.750 0.057 5244.000 615.920 100.500 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 13-SEP-1985 14'43 PASE: DEPT. 8500.000 TENS.FOH RHOB.FDH 2.472 CALI.¢DH NPMI.CNH 32.3B7 TNRA.CNH RCNT.CNH 2250.603 CFTC.CNH DEPT. 8490.000 TENS.FDH RMOB.FDH 2.261 C~LI.FDH NPHI.CNH 47.837 TNRA.CNH RCNT.CNM 1701.011 CFTC.CNH DEPT. 8300.000 TENS.FDH RHOB.FDH 2.490 CALI.~DH NPHI.CNH 43.686. TNRA.CNH RCNT.CNH 1953.139 CFTC.CNH DEPT. 8297.100 TENS.FDH RHOB.FDH 2.362 CALI.FDH NPHI.CNH 44-335 TNRA.CNH RCNT.CNH 1806.644 CFTC.CNH 5068.000 OPHI.FDH 9.484 GR.FDH 2.979 RTNR.CNH 761.362 CNTC.CNH 5112.000 OPHI.FDH 8.680 GR.FDH 3.767 RTNR.CNH 465.845 CNTC.CNH 5124.000 DPHI.FDH 8.953 GR.~DH 3.564 RTNR.CNH 521.203 CNTC.CNH 5092.000 DPHI.FDH 8.688 GR.FDH 3.577 RTNR.CNH 518.537 CNTC.CNH 10.762 117.563 3.679 2198.653 23.571 119.688 4.350 1686.862 9.714 93.938 4.105 1817.047 17.424 110.500 4.045 1821.501 DRHS.FDH TENS.CNH RCFT.CNH GR .CNH DRHO.FDH TENS.CNH RCFT.CNH GR.CNH DRHO.FDH TENS.CNH RCFT.CNH GR.CNM DRHO.FDH TENS.CNH RCFT.CNH GR.CNH 0.012 5058.000 605.484 117.563 0.012 5112.000 455.516 119.688 0.104 5124.000 481.320 93.938 0.027 5092.000 380.221 110.500 END OF DATA *4** FILE TRAILER **4* FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001A02 DATE : 88/09/13 MAX AEC SIZE : 1024 FILE TYPE : LO L~ST FILE : · ~ TAPE TRAILER SERVICE NAME : EDIT DATE : 88/:09/13 ORIGIN : FLIC TAPE NAME : 72926 CgNTINUATION ~ : 1 PREVIOUS TAPE : COMMENT : LIS TAPE, ARCO KUP~RUK 3 0-3, ~50-029-21838 ~.~. R E E L 'T R A I L E R SERVICE NAME : EDIT DATE : 38/09/13 ORIGIN : FLIC REEL NAME : 72926 CONTINUATION ~ : P~EVIOUS REEL : COMMENT : LIS TAPE~ ~RCO KUP~RUK 3 0-3, API