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Home My WebLink About190-117 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /~;~)'//7 File Number of Well History File PAGES TO DELETE RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Complete COMMENTS: Scanned by: Bevedy B~Nathan Lowell D ate .'~-,~,_~ Is/ (~ TO RE-SCAN Notes: Re-Scanned by:~Bren Vincent Nathan Lowell NOTScanned.wpd oN oR B FOR oCTOBER 2,7 2000 E PLUGGING~ ~z LOCATION CLEARi_dCE REPORT State of Alaska .ALASKA 0IL & GAS CONSERVATION COHMISSION · . Memcrand'~'.m To File: APi No. Well }fa_me Review the well file, and-c~e~t on plugging, well head s uatus, and location c!$aranc~e - orovide !o . clear, code. Well head cut off: Harker ~os= or plate: Location Clearance: ~'o3---- "Ao I 3 K_ --~ / ., Code 7 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 20, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3G-14 (Permit No. 90-117, 397-230) Well Completion Report Dear Mr. Commissioner: ORIGINAL Enclosed is the well completion report for the recent abandonment of KRU 3G-14. This well was sidetracked and re-drilled to an alternate bottom hole location and renamed 3G-14A. Sincerely, W. S. Isaacson Drilling Engineer Kupamk Drill Site Development WSI/skad t 'E E, IVE:D STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [] GAS ~-~ SUSPENDED ~-~ ABANDONEI~ SERVICE ~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-117 & 397-230 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20138 4 Location of well at surface , 9 Unit or Lease Name 2538' FNL, 20' FEL, Sec. 23, T12N, RSE, UM ~i Kuparuk River Unit At Top Producing Interval~! 10 Well Number 1308' FSL, 1334' FEL, Sec. 23, T12N, RSE, UM 3G-14 At Total Depth 11 Field and Pool 1041' FSL, 1536' FEL, Sec. 23, T12N, R8E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. Kuparuk River Oil Pool RKB 90', Pad 53' GL ADL 25547 ALK 2661 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 16 No. of Completions 21-Aug-90 25-Aug-90 04'May'9~P&A1 NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 7040' MD & 6162' TVD 6947' MD & 6096' TVD YES U NO X~ N/A feet MD 1600' APPROX 22 Type Electric or Other Logs Run 23 CASING, LINER AND CEMENTING RECORD ,,. SETTING DEPTH MD I CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENTRECOI~D 16" 62.5# H-40 SURF. 115' 24" 216 sx AS I 9.625" 36.0# J-55 SURF. 3115' 12.25" 715 sx AS III, 400 sx Class G 7" 26.0# J-55 SURF. 7031' 8.5" 200 sx Class G bridge plug @ 5812' 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) )acker @ 6386' MD with bridge plug in all perfs abandoned tubing tail at 6402' MD 26 ACID, FRACTURE, CEMEr, DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED lay balanced 15.8#, Class G cement plug from 6075' to 6386' MD 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I N/A Date of Test Hours Tested PRODUCTION FO OIL-BBL GAS-MCF WATER-BB[ (~HOKE SIZE J GAS-OIL RATIO I TEST PERIOI: Flow Tubing Casing Pressure CALCULATED iOIL-BBL GAS-MCF WATER-BBl. OIL GRAVITY-APl (corr) Press. 24-HOUR RATE: 28 CORE DATA Brief description of tithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL N,A MAY 2£ 1998 Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GaR, and time of each phase. Top Kuparuk C 6563' 5822' Bottom Kuparuk C 6576' 5831' Top Kuparuk A 6576' 5831' Bottom Kuparuk A 6733' 5944' N/A 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge, Prepared by Name/Number Sharon AIIsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21- Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 . '' ch0rage Date: 5/20/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:3G-14 WELL_ID: 999055 TYPE: AFC: 999055 STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD: START COMP:04/25/98 RIG:NORDIC BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20138-00 04/25/98 (Cl) TD: 0' PB: 0' MOVING RIG TO 3G-14 SUPV:MC/DB Moving rig from 2T-202 to 3G-14. MW: 0.0 04/26/98 (C2) TD: 0' PB: 0' MOVING RIG TO 3G-t4 MW: 0.0 SUPV:MC/DB Move rig from 2T-202 to 3G-14. Move over well and attempt to level rig. Incurred structural damage above drillers side rear hydraulic jack. Move off well to evaluate damage. Waiting on Nordic assessment of damage. 04/27/98 (C3) TD: 0' PB: 0' RIG REPAIR SUPV:MC/DB Rig repair. MW: 0.0 04/28/98 (C4) TD: 0' PB: 0' 04/29/98 (C5) TD: 0' PB: 0' 04/30/98 (C6) TD: 0' PB: 0' 05/01/98 (C7) TD: 0' PB: 6947' 05/02/98 (C8) TD: 0' PB: 6947' RIG REPAIR MW: 0.0 SUPV:DH Rig repair. Install braces between cantilever beams. Build wind break. RIG REPAIR SUPV:DH Continue to repair rig. MW: 0.0 RIG REPAIR SUPV:DH Rig repair. MW: 0.0 RIG REPAIR. MW: 0.0 SUPV:DH PJSM. DS ON FOOT AND BEAM FOR MAG PARTIAL INSPECTION. SPOTTING RIG OVER WELL. SUPV:DH PJSM. COMPLETE 'MAGNAFLUX OF ALL BEAMS. MW: 0.0 05/03/98 (C9) TD: 0' PB: 6947 ' RIH W/TBG TO LAY CMT PLUG MW: 9.6 LSND SUPV:DH RIG REPAIR. PJSM. ACCEPT RIG @ 0600 05/03/98. TEST BOPE TO 3500#. 05/04/98 (CI0) TD: 0' PB: 6947' RIH, PICKING UP 3.5" DP MW: 9.6 LSND SUPV:DH Circ, ensure well is dead. RIH with tubing. POH, laying down tubing and jewelry. Set bridge plug @ 5812' 05/05/98 (Cll) TD: 0' PB: 5820' RIH W/BHA #2 MW: 9.6 LSND SUPV:DH Test casing to 3500#, ok. Mill window off whipstock from 5789 to 5820' Perform EMW test. 05/06/98 (C12) TD: 6380' PB: 5789' CBU F/WIPER TRIP 8 6654' SUPV:DH DRLG AND SURVEYS F/5820 T/6654' MW: 9.6 LSND 05/07/98 (C13) TD: 6380' PB: 5789' POH F/LINER SUPV:DH Drilling from 6380' to 7470' MW:ll.5 LSND 05/08/98 (C14) TD: 7470' PB: 7370' CUTTING DRILLING LINE SUPV:DH Run 3.5" liner. Pump cement. MW:ll.5 LSND 05/09/98 (C15) TD: 7470' PB: 7370' CLEANING MUD TANKS SUPV:DH Run 3.5" tubing. MW: 0.0 LSND 05/10/98 (C16) TD: 7470' PB: 7370' RIG RELEASED @ 0600 HRS 5 MW: 0.0 SUPV:DH Nipple down BOPE, NU tree and test. Release rig @ 0600 hrs. 5/10/98. End of WellSummary for We11:999055 Prepared by: S. ALLSUP-DRAKE STATE OF ALASKA , ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _~X Suspend _ Alter casing _ Repair well _ Change approved program _ Operation Shutdown __ Re-enter suspended well _ Plugging X Time extension_ Stimulate_ Pull tubing _ Variance_ Perforate_ Other .~.X Plugback for Redrill 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2538' FNL, 20' FEL, Sec. 23, T12N, R8E, UM At top of productive interval 1308' FSL, 1334' FEL, Sec. 23,T12N, R8E, UM At effective depth At total depth 1041' FSL, 1536' FEL, Sec. 23, T12N, RSE, UM 5. Type of Well: Development _~X Exploratory _ Stratigraphic _ Service 6. Datum elevation (DF or KB) 90' RKB, Pad 53' GL 7. Unit or Property name Kuparuk River Unit 8. Well number 3G-14 9. Permit number 90-117 10. APl number 50-103-20138 11. Field/Pool Kuparuk River feet 12. Present well condition summary Total Depth: measured (approx) true vertical Effective depth: measured (approx) true vertical Casing Length Structural Conductor 80' Surface 3078' Intermediate Production 6994' Liner 7O4O 6162 6947 6096 Size 16" 9.625" 7" feet feet feet feet Plugs (measured) None Junk (measured) Cemented 216 sx AS I 715 sx AS III & 400 sx Class G 200 sx Class G Measured depth 115' 3115' 7031' True vertical depth 115' 3115' 6156' Perforation depth: measured 6564'-6576', 6588'-6604', 6620'-6654' true vertical 5823'-5831', 5840'-5851' 5863'-5887' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 6481' Packers and SSSV (type and measured depth) 0J I INAL Camco HRP-I-SP Retr. Pkr @ 6386' MD RECEIVED DEC 19 1997 Oil & Gas Cons. C0mmJssJc Allchoraae 13. Attachments Description summary of proposal X Contact William Isaacson at 263-4622 with any questions. Detailed operation program __ BOP sketch __ 14. Estimated date for commencing operation January 1, 1998 Oil X 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify tJJ~at the/fpre&ing is true and correct to the best of my knowledge. // Signed J~" /~J.J Title Drilling Superintendant Conditions of approval: No~ti~ommission so represental~Oe RmaC?wiMtnMels~SION USE ONLY 15. Status of well classification as: Gas _ Suspended _ Plug integrity L~ Mechanical Integrity Test BOP Test ~ Location clearance __ Subsequent form require 10- Approved by the order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED. BY RoDer[ N. Cnnstenson IApproval No,~..~,~.....~ ~ I Date /o~, "' ~/'--- FY SUBMIT IN TRIPLICATE KRU 3G-14 SUNDRY OBJECTIVE to P & A WELL FOR SIDETRACK OPERATIONS (reference attached plugback schematic) CURRENT WELLBORE STATUS: The 7" casing across the perf interval is believed to be damaged, allowing rock and sand production from the well. A rock screen was run and set in the landing nipple at 6469' MD to control the sand and rock production. After four months of production, the rock screen was to be pulled and inspected. While attempting to pull the rock screen, it parted and approximately 4' of screen was left in the hole. Further attempts to fish or push the rock screen to bottom were unsuccessful, and the decision was made to sidetrack the well. The remaining portion of the rock screen is stuck in the tubing tail below 6469' MD eliminating access to the perforations. Attempts to inject into the well were also unsuccessful due to junk / sand / fill plugging the screen. Without access to the perfs or the ability to inject into the well, down squeezing cement into the perfs is not possible. Therefore, the plan to P & A the well for the upcoming sidetrack will be to set a bridge plug in the tubing at the production packer and spot a cement plug on top of the packer and bridge plug. PRE-RIG WORK: 1. RU E-line unit. RIH with 3-1/2" Baker 'N-2' bridge plug for 9.3#/ft tubing and set at 6402' MD RKB (in middle of 15' pup below packer). Once bridge plug is set, bleed wellhead pressure to 0 psi and verify positive set of bridge plug. RDMO E-line. 2. RU slickline unit. RIH and pull dummy valve from GLM at 6314' MD RKB, leaving an open pocket. WORKOVER RIG WORK: 1. MIRU Nordic Rig 2. Lay hard-line to tree. 2. Verify well is dead. Load pits w/water. Circulate well to water. 3. Set BPV. ND tree. NU and test BOPE. . Screw in landing joint. Pull tubing hanger to rig floor. Spot a 250' cement plug on top of production packer and bridge plug in 3-1/2" tubing. Pull above cement plug top and reverse circulate tubing clean. POOH standing back tubing and laying down all jewelry. . PU Baker 7" 'N-I' permanent bridge plug on E-line. RIH and set bridge plug at 5812' MD RKB. POOH RD E-line. Test wellbore to 3500 psi, testing bridge plug and cement plug to ensure isolation from perforations. 6. Whipstock will be set immediately above bridge plug to allow milling of 7" casing and kicking-off for sidetrack. WSI 12/12/97 Milling Fluic 3G-14 Proposed Plugback APl#: 50-103-20138 RKB = 90' Pad Level = 53~ 9-5/8" 36#, J-55 casing set @ 3115' MD 7" Baker 'Window Master - Bottom Trip Whipstock System' set on top of bridge plug. 7" Baker 'N-I' Bridge Plug @ 5812' MD. Cement plug spotted on top of production packer up to Abandoned A & C Sand Perfs 7", 26#, J-55 3-1/2" x 7" Camco 'HRP-I-SP' Retrievable Production Packer @ 6386' MD. 3-1/2" Baker 'N-2' Bridge Plug set in tubing tail @ 6402' MD. Rock screen fish stuck in tubing tail below landing nipple @ 6469' MD Top Perforation @ 6564' MD ~ TD = 7040' MD WSI 12/12/97 0 R I Al_ASK. ~OIL AND GAS CONSERVATI~ COMMIS~I,~ REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Operation Shutdown Stimulate Pull tubing Alter casing., Repair well Plugging , Perforate X Other 2. Name of Operator ARCO Alaska. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X, Exploratory Stratigraphic _ Service 4. Location of well at surface 2538' FNL, 20' FEL, Sec. 23, T12N, R8E, UM At top of productive interval 1308' FSL, 1334' FEL, Sec. 23, T12N, At effective depth 1308' FSL, 1334' FEL, Sec. 23, T12N, At total depth 1041' FSL, 1536' FEL, Sec. 23, T12N, 12. Present well condition summary Total Depth: measured 7 0 true vertical 61 R8E, UM R8E, UM R8E, UM 40' feet 62' feet Plugs (measured) None 6. Datum elevation (DF or KB) 90' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3G-14 9. Permit number/approval number 90-117 10. APl number 5o-103-201 38 . 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 6 5 6 3' true vertical 5 8 2 2' feet Junk (measured) feet None Casing Length Size Structural Conductor 1 1 5' 1 6" Surface 31 1 5' 9 - 5 / 8" Intermediate Production 7 031 ' 7" Liner Perforation depth: measured 6588'-6604', true vertical 5840'-5851 ', Tubing (size, grade, and measured depth) Cemented 216 Sx AS I 700 Sx AS III & 470 Sx Class G 415 Sx Class G & 200 Sx Class G Tail 6564'-6576' 5823'-5831' 3-1/2" 9.3#, EUE, ABMOD, @6481' Packers and SSSV (type and measured depth) SSSV: Otis FMX (1802'), Packer: Camco HRP-1-SP (6386') 13. Stimulation or cement squeeze summary Perforate 5840'-6588' Intervals treated (measured) Measured depth True vertical depth 115' 115' 3115' 3115' EEE i{JED JAN 2 8 t992 Nas~ 011 & Gas Cons. C0mmtssiOa Anchorage Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 0- -0- -0- -0- -0- -1788-/~1956- -0- -1525- -154- 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed C,(,I~ .. ~ Title Operations Engineer Form 10-404 Rev 09/12/90 Date J/2~'/~2. SUBMIT IN DUPLIOATE ..~RCO Alaska, Inc., Subsidiary of Atlantic Richfield Company · ELL i PBDT WELL SERVICE REPORT FI ELD ',~ ~,~,~.,4.~,~'DISTRICT' STATE ,~¢~'~',,'<- ~--~o~ DAY%~. OPERA/T,4pN AT REEOR'~ TIME DATE ~ -,~ ~,, -~/ [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knots I Signed DIST: ORIG- NSK KOE FILES · KOE FILES OAvts" - DS~~ ~ c~ F~S KUPARUK OPERATIONS ENGINEERING PERFORATION RECORD WELL NAME: ~C-tq .... ____EG REP: COMPLETION DE_TAILS: GUN INFO: ~/. ~$" " r)TA~ /~,.-;* 6/3 ~, PP SPF: ~' i~ PHASINGi" I,YO o . ORIENTATION:, ~0° cc GRAM WT: I,I , HOLE SIZE mmmm m m emmmm ~mm m emmm mm emmm m. SERV. CO & ENG: PERF INTERVAI~ SAND A ~ INT SAND c INT SAND INT GtJN PJK)POBED ~D GUN CCL CCL TIME RUN PERFORATIONS PERFORATIONS LENGTH TO TOP SETTING GUN NO. (md-D I L) (md-CET) ( f~! ) SHOT DEPTH COMMENTS SHOT WELL: ~> ~ - tzf' ' DATE: ~/'~¢/~1 IREADING ....... PERFORATION ORIENTING QC FORM IDIFFERENCE ICALCULATIONS(Note: Direction DiffisCCWlfAng Dlfl=+&CWif-) I I(DH-SURF) ............... I t '" ANGLE= ,,~0 ~ ~.4:.,~ , .. AVG DIFF=(LOwDIFF+HIGH 'DIFF)/2: ' - ~)/~' ........... LOW= , '~ I + J LOW= ~940':,' - ;~ I , TARGET VALUE=SURF NAV+/-AVG BIFF: ,' .... z~. ~ q 5~ ............ ,,, HIGH= ~ / g ~ HIGH= 7~ +~, , ,'" ~'5~- TARGET BIFF=DH ,NAV-TARGET VALUE: /0 5'~' ' ,,', L ..... NAV= ~"11'~ NAY= ~'o · o ANG BIFF=TARGET BIFF/28: "~, , , .. , ACTUAL ANGLE=SURF ,,ANGLE +/- ANG ,LE BIFF: ~= ~)0 e¢c.,,J AVG DIFF=(LOWDIFF+HIGH'DIFF)/2: -/~..FO .... L(31V~ '"50a'~' ~ ~l, q4t. O 1~'5"' ,.. TA. RGET VALUE=SURF NAV+I-A..VG DIFF: Z/-~'~2~ ....... HIGH= i~'Oq~ HIGH= '2 q$? --/~,.~'" , TARGETDIFF=DHNAV-TARGETVALUE: -~',OO NAV- 4- 5'¢~- NAV- ~ 4~il' ~,! ANG BIFF=TARGET BIFF/28: - O, ~ I ~ - ' ' ACTUAL ANGLE=SURF ANGLE +/' ANGLE DIFF: I q, "~ e ~: ~j ..... ~- ........ , AVG DIFF-(LOWDIFF+HIGH BIFF)/2: ' , ' ' , .... ' ' ~ IOW= TARGET VALUE=SURF NAV+/-AVG DIFF: i ii iii i i i i ii i i HIGH= HIGH= TARGET BIFF=DH NAV-TARGET VALUE: NAV= NAV= . , , ANG BIFF=TARGET BIFF/28; , ACTUAL ANGLE=SURF ANGLE +/- ANGLE BIFF; , , , ~ AVG ,DIFF,,,(L.O..WDIFF+HIGH'DIFF)/2:" ,. ' .... .., ' .... ~ LOIN= ,,, TARGET VALUE=SURF NAV ,+I-AVG BIFF: _, HIGH,, '- HIGH- , , TARGET DIF,F=DH NAV-TARGET VALUE: ....... NAV- NAV= ANG BIFF=TARGET BIFF/28: i iii i i ACTUAL. ANGLE=SURF ANGLE +1- ANGLE DIFF~ , I ANGLE- , AVG .DIFF-(LOWDIFF+HIGH BIFF)/2: ' ' ' , ' ~ ~ !TARGET VALUE=SURF NAV+I-AVG BIFF: HIGH. HIGH. TAR(~ET DIFF=D~ NAV-TARGET VALUE: .... NAV= NAV= ANG DIFF=TA, ,RGET BIFF/28: , ,, ACTUAL ANGLE=SURF ANGLE +1- ANGLE BIFF: ,, I ~= A.VG DIFF=(LOWDIFF+HIGH DIFF)f2: , ~ i ~ ' ' TA,,.RGET VALUE=SURF NAV+I-AVG BIFF: . ~HIGH= HIGH= TARGET BIFF=DH NAV-TARGET VALUE: NAV= NAV= ANG BIFF=TARGET BIFF/28: , .... ACTUAL ANGLE=SURF ANGLE +/- ANGLE BIFF: .,, ARCO Alaska, Inc. Date: September 20, 1991 Transmittal #: 8227 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. 1 R-27 OtX- O~IR 27 ~\.q~C 1 a-03 1B-03 \ ...... 3G- 14 ~,/~..~ "1, ..,,,2U 06 ~-~[.~2 U 06 ~ -~1 R 20 ~(1B-03 Receipt Drilling Cement Bond Log Cement Evaluation Log ,,~Cement Bond Log ,-Cement Evaluation Log ..-NavPac Log ~.NavPac Log ~amma Collar Log ..-Cement Evaluation LOg Cement Bond Log 9-8-91 10382-12250 9-8-91 10382-12250 9-1 1-91 6705-7558 9-1 1 -91 6705-7550 8-26-91 6400-6700 7-20-91 7810-8000 7-20-91 7810-8000 9-12-91 8678-9968 9-12-91 8678-9968 6705-7556 6705-7558 ..Cement Bond Log 13 ~'/" r- ~ ~)~ ~4,;,91 ..-Cement Evaluation LOg ~, IX [~ t,.. J~ ! ¥ ~417)91 ~//"~ Alaska'~0,~_~. Ga.s Cons Cg rmsmon ~ State of Alaa~~p,~ ' ' WELL COMPLETION OR RECOMPLETION REPORT AND LOG Y 'i Status of Well Classification of Service Well OIL r~ GAS I--1 SUSPENDED ~ ABANDONED r'-I SERVICE r-'l 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-117 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 r~ ~...T::~. :~, 50-103-20138 4 Location of well at surfaceIL"U~'~P~'T~'~-"~'~ 9 Unit or Lease Name 2538' FNL, 20' FEL, SEC 23, T12N, R8E, UM ' AT,~ l LOCATi~~' KUPARUK RIVER At Top Producing Interval 1308' FSL, 1334' FEL, SEC 23, T12N, RSE, UM At Total Depth 1041' FLS, 1536' FEL, SEC 23, T12N, RSE, UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) J 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 90'I ADL 25547 ALK 2661 1'2 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Abend. 15 Water Depth, if offshore ]16 No. of Completions 8/21/90. 8/25/90. 1/08191. NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 7040' MD, 6162' TVD 6947' MD, 6096' TVD YES ~ NO [-'] 1802' feet MD 1600' APPROX 22 Type Electric or Other Logs Run EWR, CN, SFD, DGR, CET, CBL, GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER Fr. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 216 SX AS I 9-5/8" 36~ J-55 SURF 3115' 12-1/4" 715 SX AS III, 400 SX CLASS G 7" 26# J-55 SURF 7031' 8-112" 200 SX CLASS G TAIL 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD ,,, interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 6481' 6386' 6620'-6654' W/4-1/2" CSG GUN @ 4SPF MD 5863'-5887' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ,, 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I , , Date of Test Hours Tested ~PRODUCTION FOR OIL~BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 2. CORE DATA r' '. - arief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 6563' 5822' NA KUPARUK C BOTTOM 6576' 5831' KUPARUK A TOP 6576' 5831' KUPARUK A BOTTOM 6733' 5944' 31. LIST OF ATTACHMENTS GYRO 32. I hereby certify that the foregoing is true and correct to the best of my knowledge _ , . -- ,..- _ DRILLING ENGINEER Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion repod and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Oir,-,,d Gas COmpany Well History - Initial Report- Daily instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. Field KUPARUK RIVER UNIT Auth. or W.O. no. AK5113 ICounty. parish or borough NORTH SLOPE Lease or Unit ADL: 25547 ALK:2661 Title COMPLETION IState AK Well no. 3q-14 Operator ARCO Spudded or W,O. begun JDate I~our SPUD 08/21/90 12:00 Date and depth as of 8:00 a.m. 01/07/91 (7) TD: 0 PB: 6947 SUPV:DB/LA Complete record for each day reported NORDIC I IARCO W.L 55. 252072 Prior status if a W.O. RD HLS MW: 0.0 NaCl/Br MOVE RIG F/3G-13 TO 3G-14, ACCEPT RIG 1/6/91 @ 23:30, ND MASTER VALVE & THA, SET TP, NU BOPE STACK & TEST, RU HLS & PERF F/6654'-6620 W/4.5" CSG GUNS @ 4SPF 180 DEG PHASE ALTERNATING BH CHARGES, RD HLS DAILY:S21,882 CUM:$804,754 ETD:S804,754 EFC:$1,220,000 RECEIVED ,~las'k. . a_ .Oil.& .Gas Cons, The above is correct S,gnature For form preparation and_distr~tion, ~ see Procedures Manual,.Secti~]/10, Drilling, Pages 86 and 87. Date I Title ! UnlllrlU OUl,~. AR3B-459-1-D INumber all daily well history forms consecutively as they are prepared for each well. Page rio ARCO O,I 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" shoutd be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Auth. or W.O. no. AK5113 Accounting cost center code District County or Parish State ARCO ALASKA INC. I NORTH SLOPE AK /well no. Field ILease or Unit KUPARUK RIVER UNIT I ADL:25547 ALK:2661 3q-14 I Title I COMPLETION Operator ARCO Spudded or W.O. begun SPUD A.R.Co. W.I. Date I otal number of wells (active or inactive) on this. cst center prior to plugging and bandonment of this well 5 .2520721 our I Prior status if a W.O. 12:00 I 08/21/90 Date and depth Complete record for each day reported as of 8:00 a.m. NORDIC 1 01/08/91 ( TD: 0 PB: 6947 SUPV:DB/LA 8) RIG RELEASED MW:10.7 NaC1/Br RD HLS E-LINE UNIT, FINISH LOADING TBG IN PIPE SHED, RUN 3-1/2" COMPLETION ASSEMBLY, TEST CNTL LINE TO 5000 PSI, DROPPED 2-1/2" BRASS BALL 5 JTS BEFORE TBG HNG, LAND TBG RILDS, CIRCULATE 1 TBG VOLUME, BALL NOT SEATD, INCREASE PUMP RATE, NO CHANGE, CYCLE SSSV AND CIRC, NO CHANGE,DROP 2ND BALL, CIRC DOWN, NO CHANGE, VSLL OUT SPINNER/TEMP LOGGING TOOLS AND SLICKLINE UNIT, RU HLS SLICK LINE, TEST PACKOFF TO 1000 PSI, RIH W/ 1-11/16" SPINNER/TEMP LOG, TAG UP AT SSSV, KNOCKED BALLS THROUGH SSSV, LOG TOOLS RUN FREELY IN AND OUT THRU SSSV, BALLS SEATED WHILE CIRCULATING, POH, RD HLS, RELEASE OTIS SLICKLINE UNIT, SET PACKER W/ 2500 PSI, HOLD PRESSURE TO 1000 PSI FOR 10 MIN, BOLDS, PU AND SHEAR PBR AT 68K#, BLEED OFF TUBING, RELAND HANGER, RILDS, TEST SSSV W/ 500 PSI, OPEN SSSV, BLEED PRESSURE, CLOSE SSSV, SET BPV, ND BOP, NU TREE, TEST CSG AND PKR TO 2500 PSI, SHEAR SOS AT 3300 PSI, REVERSE CIRD 12 BBL DIESL CAP INTO ANNULUS, INJECT 4 BBLS DIESEL CAP DOWN TUBING, RELEASE RIG DAILY:S49,804 CUM:$854,558 ETD:S854,558 EFC:$1,220,000 Old TD New TD Released rig Date PB Depth JK nd of rg Classifications (oil, gas, etc.) Type completion (single, dual, etc,) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effec:.e :,~'.~ corrected The above is correct Signature ~ ~ For form preparation and distribul~on, see Procedures Manual, Section Drilling, Pages 86 and 87, AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. Division of Allanh¢~a,~ ORIGINAl. GREAT LAND Client .... : Field ..... : Well ...... : Section at: Surveyor..: DIRECTIONAL DRILLING, ARCO ALASKA, INC. Kuparuk River Unit KRU 3G-14 (23-12-8) S,42.40,W MIKE NAIRN S MEAS INCLN C DEPTH ANGLE 7 100 0.17 7 200 0.16 7 300 0.36 7 400 0.18 7 500 0.22 7 600 0.22 7 700 0.27 7 800 0.19 7 900 0.14 7 1000 0.34 7 1100 0.38 7 1200 0.22 7 1300 0.33 7 1400 0.28 7 1500 0.28 7 1600 0.25 7 1700 0.58 7 1800 0.24 7 1900 0.33 7 2000 0.31 7 2100 0.19 'Survey Codes: (KRU3G14G) VERTICAL-DEPTHS BKB SUB-SEA 100.0 10.0 200.0' 110.0 300.0 210.0 400.0 310.0 500.0 410.0 600.0 510.0 700.0 610.0 800.0 710.0 900.0 810.0 1000.0 910.0 1100.0 1010.0 1200.0 1110.0 1300.0 1210.0 1400.0 1310.0 1500.0 1410.0 1600.0 1510.0 1700.0 1610.0 1800.0 1710.0 1900.0 1810.0 2000.0 1910.0 2100.0 2010.0 7/GYR0 INC. SECTION DISTNCE RECORD OF SURVEY DIRECTION BEARING -0.1 N 44.07 E -0.2 S 83.07 W -0.1 N 30.75 W 0.1 S 51.14 W 0.4 N 84.10 W Computation...: Survey Date...: RKB Elevation.: Job Number .... : API Number .... : 10/15/90 RADIUS OF CURVATURE 09/25/90 90.00 ft AK0990G247 50-103-20138 0.8 S 23.71 W 1.1 N 54.61 W 1.4 S 6.70 W 1.4 N 66.07 E 1.1 S 74.29 E 1.0 S 40.29 E 0.9 S 77.48 E 0.8 S 27.48 E 1.0 S 16.72 E 1.3 S 23.56 E RELATIVE-COORDINATES FROM-WELL-HEAD CLOSURE DL DISTNCE BEARING /100 0.1N 0.1E 0.3N 0.0W 0.5N 0.4W 0.6N 0.SW 0.5N 1.2W 0.1 N 22.04 E 0.17 0.3 N 7.54 W 0.01 0.7 N 39.47 W 0.20 1.0 N 54.65 W 0.18 1.3 N 66.85 W 0.04 0.3N 1.5W 0.2N 1.SW 0.1N 2.1W 0.1S 1.9W 0.0S 1.5W 1.5 N 77.86 W 0.00 1.8 N 83.23 W 0.05 2.1 N 87.79 W 0.08 1.9 S 88.28 W 0.05 1.5 S 88.91 W 0.20 0.4S 1.0W 0.6S 0.6W 0.9S 0.2W 1.4S 0.0W 1.9S 0.2E 1.1 S 70.33 W 0.04 0.9 S 42.52 W O.lf ) 0.9 S 12.88 W 0.11'~ 1.4 S 0.35 W 0.05 1.9 S 4.89 E 0.00 1.6 S 19.09 W 2.3 S 61.17 W 3.0 S 56.59 W 3.4 N 81.22 W 3.6 N 64.86 W 2.3S 0.2E 2.9S 0.3W 3.2S 0.9W 3.3S 1.4W 3.2S 1.9W 2.3 S 4.37 E 0.03 2.9 S 5.58 W 0.33 3.3 S 15.45 W 0.34 3.6 S 22.31 W 0.09 3.7 S 30.94 W 0.02 4.0 S 2.02W 3.4S 2.2W 4.0 S 33.38 W 0.12 KRU 3G-14 (23-12-8) S MEAS INCLN C DEPTH ANGLE 7 2200 0.45 7 2300 0.54 7 2400 0.58 7 2500 0.46 7 2600 0.38 7 2700 0.32 7 2800 0.25 7 2900 0.17 7 3000 0.08 7 3100 0.08 7 3200 0.32 7 3300 0.70 7 3400 6.75 7 3500 12.24 7 3600 15.06 7 3700 17.90 7 3800 21.37 7 3900 24.53 7 4000 27.76 7 4100 30.88 7 4200 34.02 7 4300 36.90 7 4400 39.43 7 4500 41.75 7 4600 41.97 7 4700 42.94 VERTICAL-DEPTHS BKB SUB-SEA 2200.0 2110.0 2300.0 2210.0 2400.0 2310.0 2500.0 2410.0 2600.0 2510.0 2700.0 2610.0 2800.0 2710.0 2900.0' 2810.0 3000.0 2910.0 3100.0 3010.0 3200.0 3110.0 3299.9 3209.9 3399.7 3309.7 3498.3 3408.3 3595.4 3505.4 3691.3 3601.3 3785.5 3695.5 3877.6 3787.6 3967.3 3877.3 4054.5 3964.5 4138.9 4048.9 4220.3 4130.3 4298.9 4208.9 4374.9 4284.9 4449.4 4359.4 4523.1 4433.1 RECORD OF SURVEY SECTION DIRECTION RELATIVE-COORDINATES DISTNCE BEARING FROM-WELL-HEAD 4.3 N 32.46 W 3.5 S 2.6 W 4.1 N 38.64 W 2.8 S 3.1 W 4.0 N 43.84 W 2.0 S 3.8 W 4.0 N 42.72 W 1.4 S 4.4 W 3.9 N 45.37 W 0.8 S 4.9 W 4.0 N 62.14 W 0.5 S 5.4 W 4.2 N 78.89 W 0.3 S 5.9 W 4.5 S 64.11 W 0.4 S 6.2 W 4.7 S 17.52 W 0.5 S 6.4 W 4.7 S 54.90 E 0.7 S 6.3 W 4.5 N 57.58 E 0.7 S 6.0 W 4.6 S 34.30 W 1.1 S 5.5 W 11.0 S 41.52 W 6.2 S 9.5 W 27.5 S 50.43 W 17.7 S 21.4 W 50.8 S 51.28 W 32.6 S 39.7 W 78.8 S 51.41 W 50.3 S 61.8 W 111.9 S 53.89 W 70.7 S 88.5 W 150.1 S 53.96 W 93.6 S 120.0 W 193.4 S 52.26 W 120.1 S 155.3 W 241.6 S 52.30 W 150.0 S 194.0 W 294.6 S 49.99 W 183.7 S 235.8 W 352.3 S 47.47 W 222.0 S 279.4 W 413.8 S 47.88 W 263.6 S 325.1 W 478.7 S 45.76 W 308.1 S 372.5 W 545.3 S 45.93 W 354.6 S 420.4 W 612.7 S 45.12 W 401.9 S 468.5 W Page 2 10/15/90 CLOSURE DL DISTNCE BEARING /100 4.3 S 37.04 W 0.26 4.2 S 48.44 W 0.09 4.3 S 61.63 W 0.04 4.6 S 72.63 W 0.17 5.0 S 80.20 W 0'08 ..~ / 5.4 S 84.85 W 0.06 5.9 S 86.87 W 0.07 6.2 S 86.62 W 0.08 6.4 S 85.25 W 0.09 6.3 S 84.11 W 0.00 6.0 S 83.72 W 0.24 5.6 S 78.60 W 0.38 11.4 S 56.78 W 6.05 27.7 S 50.39 W 5.50 51.3 S 50.60 W 2.82 79.7 S 50.87 W 2.84 113.3 S 51.40 W 3.49 152.2 S 52.04 W 3.1f 196.3 S 52.28 W 3.25 245.3 S 52.28 W 3.12 298.9 S 52.08 W 3.22 356.8 S 51.53 W 3.02 418.5 S 50.96 W 2.54 483.4 S 50.41 W 2.50 549.9 S 49.85 W 0.23 617.3 S 49.38 W 1.04 'Survey Codes: 7/GYRO KRU 3G-14 (23-12-8) S MEAS INCLN C DEPTH ANGLE 7 4800 44.69 7 4900 45.01 7 5000 45.72 7 5100 46.01 7 5200 46.78 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 4595.3 4505.3 681.9 4666.2 4576.2 752.4 4736.4 4646.4 823.5 4806.1 4716.1 895.2 4875.0 4785.0 967.5 7 5300 47.34 4943.2 4853.2 7 5400 46.04 5011.8 4921.8 7 5500 46.55 5080.9 4990.9 7 5600 46.86 5149.4 5059.4 7 5700 47.56 5217.4 5127.4 7 5800 48.24 5284.4 5194.4 7 5900 46.86 5351.9 5261.9 7 6000 46.39 5420.6 5330.6 7 6100 46.86 5489.3 5399.3 7 6200 43.60 5559.7 5469.7 7 6300 43.42 5632.2 5542.2 7 6400 43.84 5704.6 5614.6 7 6500 44.00 5776.6 5686.6 7 6600 44.00 5848.5 5758.5 7 6700 44.18 5920.4 5830.4 RECORD OF SURVEY 7 6800 44.60 5991.8 5901.8 7 6900 44.98 6062.8 5972.8 X 7040 44.98 6161.8 6071.8 1040.7 1113.4 1185.6 1258.3 1331.6 1405.7 1479.4 1552.0 1624.4 1695.1 1763.8 1832.5 1901.6 1970.8 2040.1 2109.7 2179.9 2278.4 DIRECTION BEARING S 40.35 W S 40.39 W S 39.89 W S 40.18 W S 39.97 W 39.85 W 40.69 W 40.10 W 39.58 W 39.12 W S 39.32 W S 39.93 W S 37.84 W S 37.24 W S 38.33 W RELATIVE-COORDINATES FROM-WELL-HEAD 452.7 S 515.5 W 506.4 S 561.2 W 560.8 S 607.1 W 615.8 S 653.2 W 671.2 S 699.8 W 727.3 S 746.8 W 782.8 S 793.8 W 837.9 S 840.7 W 893.8 S 887.3 W 950.5 S 933.9 W 1008.0 S 980.8 W 1064.8 S 1027.8 W 1121.4 S 1073.4 W 1179.1 S 1117.7 W 1235.2 S 1161.2 W S 37.38 W 1289.5 S 1203.5 W S 37.24 W 1344.4 S 1245.3 W S 37.62 W 1399.5 S 1287.5 W S 37.53 W 1454.5 S 1329.8 W S 36.82 W 1510.0 S 1371.9 W S 36.91 W 1565.9 S 1413.8 W S 36.99 W 1622.2 S 1456.2 W S 36.99 W 1701.3 S 1515.7 W Page 3 lO/15/9o CLOSURE DISTNCE BEARING DL /lOO 686.1 S 48.71 W 2.94 755.9 S 47.94 W 0.32 826.5 S 47.27 W 0.75 897.7 S 46.69 W 0.32 969.7 S 46.20 W 0.78 1042.5 S 45.76 W 0.56 1114.9 S 45.40 W 1.37 1186.9 S 45.10 W 0.60 1259.4 S 44.79 W 0.42 1332.5 S 44.49 W 0.74 1406.4 S 44.21 W 0.69 1480.0 S 43.99 W 1.42 1552.4 S 43.75 W 1.19 1624.7 S 43.47 W 0.57 1695.3 S 43.23 W 3.30 1763.9 S 43.02 W 0.48 1832.5 S 42.81 W 0.43 1901.6 S 42.61 W 0.24 1970.8 S 42.44 W 0.04 2040.1 S 42.26 W 0.39 2109.8 S 42.08 W 0.42 2179.9 S 41.91 W 0.38 2278.6 S 41.70 W 0.00 'Survey Codes: 7/GYRO X/EXTRAPOLATED KRU 3G-14 (23-12-8) Page 4 10/15/90 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA MEAS INCLN DEPTH DEPTH ANGLE 0 90 0.15 100 190 0.16 200 290 0.34 300 390 0.20 400 490 0.22 TVD MD-TVD VERT DIRECTION RELATIVE COORDINATES BKB DIFF CRRT BEARING FROM WELL HEAD __ 90 0 0 N 44.07 E 0.11 N 0.04 E 190 0 0 N 82.83 W 0.33 N 0.01 W 290 0 0 N 37.37 W 0.48 N 0.39 W 390 0 0 S 60.95 W 0.62 N 0.81 W 490 0 0 N 88.57 W 0.50 N 1.13 W 500 590 0.22 590 600 690 0.27 690 700 790 0.20 '790 800 890 0.14 890 900 990 0.32 990 0 0 S 30.93 W 0.35 N 1.46 W 0 0 N 64.77 W 0.20 N 1.79 W 0 0 S 18.56 W 0.12 N 2.14 W 0 0 S 42.15 W 0.15 S 2.25 W 0 0 N 42.28 W 0.24 N 1.88 W 1000 1090 0.38 1090 1100 1190 0.24 1190 1200 1290 0.32 1290 1300 1390 0.28 1390 1400 1490 0.28 1490 0 0 S 43.69 E 0.32 S 1.06 W 0 0 S 73.76 E 0.62 S 0.62 W 0 0 S 32.47 E 0.87 S 0.24 W 0 0 S 17.79 E 1.36 S 0.02 W 0 0 S 22.88 E 1.82 S 0.14 E 1500 1590 0.25 1590 1600 1690 0.55 1690 1700 1790 0.27 1790 1800 1890 0.32 1890 1900 1990 0.31 1990 0 0 S 14.83 W 2.27 S 0.19 E 0 0 S 56.97 W 2.80 S 0.20 W 0 0 S 57.05 W 3.20 S 0.85 W 0 0 N 85.43 W 3.33 S 1.31 W 0 0 N 66,49 W 3.19 S 1.85 W 2000 2090 0.20 2090 2100 2190 0.42 2190 2200 2290 0.53 2290 2300 2390 0.58 2390 2400 2490 0.47 2490 0 0 S 13.30 W 3.32 S 2.22 W 0 0 N 46.97 W 3.51 S 2.57 W 0 0 N 38.02 W 2.84 S 3.06 W 0 0 N 43.32 W 2.11 S 3.70 W 0 0 N 42.83 W 1.43 S 4.33 W 2500 2590 0.39 2590 0 0 N 45.11 W 0.89 S 4.85 W ,~RU 3G-14 (23-12-8) Page 5 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL lO/15/9o ~UBSEA MEAS INCLN TVD DEPTH DEPTH ANGLE BKB MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 2600 2690 0.33 2690 0 0 N 60.47 W 0.51 8 5.34 W 2700 2790 0.26 2790 0 0 N 77.22 W 0.33 S 5.81 W 2800 2890 0.18 2890 0 0 S 67.79 W 0.35 8 6.19 W 2900 2990 0.09 2990 0 0 S 22.16 W 0.51 8 6.35 W 3000 3090 0.08 3090 0 0 S 47.69 E 0.64 S 6.32 W 3100 3190 0.30 3190 0 0 S 28.47 W 0.91 S 6.25 W 3200 3290 0.66 3290 0 0 N 54.53 E 0.23 S 5.34 W 3300 3390 6.16 3390 0 0 S 40.82 W 5.39 S 8.83 W 3400 3492 11.78 3490 2 1 S 49.68 W 16.53 S 20.04 W 3500 3594 14.90 3590 4 3 S 51.23 W 31.67 8 38.53 W 3600 3699 17.86 3690 9 4 S 51.41 W 50.03 3700 3805 21.52 3790 15 6 S 53.89 W 71.72 3800 3914 24.97 3890 24 9 S 53.73 W 97.02 3900 4026 28.56 3990 36 12 S 52.27 W 127.51 4000 4142 32.19 4090 52 16 S 51.34 W 163.50 4100 4262 35.82 4190 72 21 $ 48.42 W 207.01 S 4200 4388 39.14 4290 98 26 S 47.83 W 258.65 S 4300 4520 41.79 4390 130 32 S 45.79 W 317.49 S 4400 4655 42.50 4490 165 35 S 45.49 W 380.33 S 4500 4793 44.56 4590 203 38 S 40.70 W 448.72 S 4600 4934 45.25 4690 244 41 S 40.22 W 524.66 S 4700 5077 45.94 4790 287 43 S 40.11W 603.05 S 4800 5222 46.90 4890 332 45 S 39.94 W 683.40 S 4900 5369 46.45 4990 379 47 S 40.43 W 765.58 S 5000 5513 46.59 5090 423 45 S 40.03 W 845.29 S 61.48 W 89.95 W 124.66 W 164.87 W 211.12 W 262.79 W 319.63 W 382.18 W 446.79 W 512.11 W 576.66 W 642.50 W 710.08 W 779.06 W 846.91W 5100 5660 47.28 5190 470 46 S 39.31 W 927.46 8 915.02 W ~RU 3G-14 (23-12-8) Page 6 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL lO/15/9o ~UBSEA MEAS INCLN TVD )EPTH DEPTH ANGLE BKB MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 5200 5808 48.12 5290 518 49 S 39.37 W 1012.85 5300 5956 46.60 5390 566 47 S 38.77 W 1096.15 5400 6101 46.82 5490 611 46 S 37.25 W 1179.69 5500 6242 43.52 5590 652 41 S 37.93 W 1257.85 5600 6380 43.76 5690 690 38 S 37.27 W 1333.27 5700 6519 44.00 5790 729 39 S 37.60 W 1409.73 5800 6658 44.10 5890 768 39 S 37.12 W 1486.43 5900 6797 44.59 5990 807 40 S 36.91 W 1564.51 6000 6938 44.98 6090 848 41 S 36.99 W 1643.96 984.73 W 1053.48 W 1118.22 W 1179.04 W 1236.84 W 1295.35 W 1354.14 W 1412.75 W 1472.54 W KRU 3G-14 (23-12-8) Page 7 DATA INTERPOLATED FOR 1000 FT MEASURED DE~TH INTERVAL lO/15/9o MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD DIST BEARING 1000 0.34 1000 910 2000 0.31 2000 1910 3000 0.08 3000 2910 4000 27.76 3967 3877 5000 45.72 4736 4646 1 S 74.29 E 0 S 2 W 4 N 64.86 W 3 S 2 W 5 S 17.52 W 1 S 6 W 193 S 52.26 W 120 S 155 W 823 S 39.89 W 561 S 607 W DL/ 100 2 S 88.91 W 0.2 4 S 30.94 W 0.0 6 S 85.25 W 0.1 196 S 52.28 W 3.3 826 S 47.27 W 0.8 6000 46.39 5421 5331 1552 S 37.84 W 1121 S 7000 44.98 6134 6044 2250 S 36.99 W 1679 .S 1073 W 1552 S 43.75 W 1.2 1499 W 2250 S 41.76 W 0.0 10/15/90 by GREAT LAND DIRECTIONAL DRILLING, INC. for Gyrodata Services, Inc. Client .... : ARCO ALASKA, INC. Field ..... : Kuparuk River Unit Well ...... : KRU 3G-14 (23-12-8) Section at: S,42.40,W Surveyor..: MIKE NAIRN Computation...' RADIUS OF CURVATURE Survey Date...' 09/25/90 RKB Elevation.' 90.00 ft Job Number · AK0990G247 API Number · 50-103-20138 INTERPOLATED MARKERS REPORT Surface Location' 2538 SNL 20 WEL S23 T12N R8E MARKER IDENTIFICATION KB 9-5/8" CASING TOP KUPARUK C~ BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A 7" CASING TD MEAS INCLN DEPTH ANGLE 0 0.00 3115 0.12 6563 44.00 6576 44.00 6576 44.00 6733 44.32 7026 44.98 7040 44.98 YERT-DEPTHS SECT DIRECTION REL-COORDINATES BKB SUB-S DIST BEARING FROM-WELLHEAD 0 -90 0 N 0.00 E 0 N 0 E 3115 3025 5 N 11.03 W 1 S 6 W 5822 5732 1945 S 37.56 W 1434 S 1314 W 5831 5741 1954 S 37.55 W 1441 S 1320 W 5831 5741 1954 S 37.55 W 1441 S 1320 W 5944 5854 2063 S 36.85 W 1528 S 1386 W 6152 6062 2269 S 36.99 W 1693 S 1510 W 6162 6072 2278 S 36.99 W 1701 S 1516 W <KB>O 350 700 t050 ``400 VERTICAL SECTION VIEW ARCO ALASKA, INC. KRU 3G-~4 [23-t2-8) Section at: S 42.40 ~ lVO Scale.: t inch = 700 feet Dep Scale.: ! inch = 700 feet Drawn ..... : i0/i5/90 Harker Identification MD TVD SECTN INCLN A) KB 0 0 0 0.00 B) TD 7040 6i62 227B 44.98 t750 2tO0 2450 2800 3150 3500 3B50 4200 4550 4900 5250 5600 5950 6300 350 350 700 ``050 ~400 ,,750 2~00 2450 2800 3``50 3500 Section Depart. ute , ] artT£. Harker Identification HO N/S A) KB 0 0 N 0 E §] TD 7040 t70t S 15t6 PLAN VIEW ARCO ALASKA, INC. KRU 35-i4 [23-i2-8) CLOSURE ..... : 2279 ft S 4~.70 DECLINATION.: 0.00 E SCALE ....... : ! inch = 300 feet DRA~N ....... : ~0/15/90 i50 0 i50 3OO 45O 6O0 750 9OO t050 t200 i350 1500 t650 t800 t950 i650 t500 t350 i200 t050 900 750 600 450 300 i50 0 i50 <- NEST ' EAST -> PEFiMiT# ..... ,~ AOGCC GEOLOGICAL hiATE~.iALS iNYENTORY LiST - //~' WELL NAME )~/~L.~ ,~ · COMPLET!ONDATE / ! c~ /?/ ... cheC"z'°ff or I'ist data aS' it is rcCe,,!ved.~ -I.7 !* 3/~,~/,,~/ ,, drillin9 histo.-y' I cored i.~ervais core analysis, CO. CONTACT ist received date for 407. if ," surveyl, / !weli tests dry ditch interv~is ' not required list as"'NR ' ~! core dcscriptio~.~//~ di§itai data ARCO Alaska, Inc. Date: November 2, 1990 Transmittal #: 7940 RETURN TO: ARCO Alaska, Inc. ATTN: Jenny Gamage Kuparuk Operations File Clerk ATe-1119 P.O. Box 100360 Anchorage, AK 99510~0360 Transmitted herewith are the following items. signed copy of this transmittal. · ~3~G-14 Pulse Echo Cement Evaluation(PET) 9 1 6 Pulse Echo Cement Evaluation(PET) 9 /~'~GG'17 18 .,,,3~.G - 14 17 18 Please acknowledge receipt and return one -2 -2 Pulse Echo Cement Evaluation(PET) 9-2 Pulse Echo Cement Evaluation(PET) 9-2 Acoustic Cement Bond Log 9 - 2 Acoustic Cement Bond Log 9 - 2 Acoustic Cement Bond Log 9 - 2 Acoustic Cement Bond Log 9 - 2 5-90 3308-6908 4-90 5820-9530 2-90 4668-7668 4-90 6500-9520 5-90 2992-6919 4-90 6500-9535 2-90 4668-7668 4-90 6500-9520 Acknowledged: ~~~ Receipt Date: DISTRIBUTION: Drilling NSK RECEIVED ~ 0 V o~at~,~) Alaska(+SePia) Alaska Oil & (~s Cons. Commissior~ Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ 2. Name of Operator ARCO Alaska, inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Operation Shutdown X _ Plugging _ Pu, II tubing - 5. Type of Well: Development X.~ Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 2538' FNL, 20' FEL, Sec. 23, T12N, R8E, UM At top of productive interval 1340' FSL, 1300' FEL, Sec. 23, T12N, R8E, UM At effective depth NA At total depth 1156' FSL, 1468' FEL, Sec. 23, T12N, R8E, UM (approx) Re-enter suspended well Time extension Stimulate Variance Perforate Other 6. Datum elevation (DF or KB) (approx) 12. Present well condition summary Total Depth: measured 9650' feet (approx) true vertical 6128' feet Effective depth: measured N^ feet (approx) true vertical NA feet Plugs (measured) None Junk (measured) None RKB 90' 7. Unit or Property name Kuparuk River Unit 8. Well Number 3G-14 9. Permit number 90-117 10. APl number 50-1 03-201 38 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Casing Length Size Structural Conductor 8 0' 1 6" Surface 4339' 9 5/8" Intermediate Production 961 5' 7" Liner Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None Cemented Measured depth True vertical depth (approx) 216 SXAS III 115' 115' 945 Sx AS III & 4376' 3058' 570 Sx Class G 200 Sx Class G 9650' 6128' sx c,ass E £ E IV ED ,,~,,. I~ -- Alaska 0il & Was Cons, 13. Attachments Description summary of proposal _ Detailed operation program _X___ BOP sketch 14. Estimated date for commencing operation November. 1 16. If proposal was verbally approved 15. Status of well classification as:, Oil X Gas __ Suspended _ Name of approver Date approved Service , , 17. I hereby certify that the foregoing is true and correct to the bes' of my knowledge. Signed ~',~/, //~W~¢./~ Title Area Drilling Engineer / FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test _ Location clearance__ Mechanical Integrity Test ~ Subsequent form require 10- ~-~/¢ Date IApproval No. I (:;;)/3 - '7/~ Approved by the order of the Commission Commissioner Date (~iq Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LONNIE C. SMITH Approved Copy Rietur ed ,, SUBMIT IN TRIPLICATE ARCO Oil ana Gas Company Well History- Initial Report - Daily Inltructionl: Prepare and submit tho "Initial Report" on the first Wednesday aftra 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 ARCO ALASKA INC. Field KUPARUK ' Auth. or W.O. no. AK5113 ICounty, parish or borough NORTH SLOPE Lease or Unit ADL: 25547 ALK: 2661 Title DRILLING State AK lWell no. 3G-14 Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a,m. 08/22/90 (1) TD: 2882' ( 288; SUPV:KSP 08/23/90 (2) TD: 3115' ( 23~ SUPV:JMM 08/24/90 (3) TD: 5217'( 2102 SUPV:JMM 08/25/90 (4) TD: 6559'( 134; SUPV:JMM 08/26/90 (5) TD: 7040' ( 481 SUPV: JMM Date Complete record for each day reported DOYON RIG 14 ARCO W.I. 55.2521 JPr or status if a W.O. 12:00 DRLG @2882 MW: 9.1 VIS: 54 MOVE RIG, ACCEPT RIG 8:00. NU 20" ANNULAR PREVENTER AND RISER AND FLOW LINE. PU BHA AND MWD TOOL, TEST DIVERTER, SPUD AT 12:00. DRLG TO 2882'. DAILY:S85,107 CUM:$85,107 ETD:S85,107 EFC:$1,220,000 MU BHA #2 W/ TURBINE MW: 0.0 VIS: 0 DRILL 12-1/4" HOLE FROM 2882' TO 3164'. SHORT TRIP TO 1067'. POOH, RUN 80 JTS 9-5/8" 36# J-55 CASING TO 3115'. RU DOWELL AND CEMENT WITH 248 BBLS AS III 12.1 PPG CEMENT LEAD AND 108 BBLS D707 AS III 15.8 PPG TAIL. DISPLACE WITH 240 BBL WATER, LOST RETURNS AT 90 BBL OF DISPLACEMENT. BUMP PLUG TO 2500 PSI, FLOATS HELD. CALC TOC AT 770'. CIP AT 2050 HRS. PERFORM TOP JOB WITH 150 SX AS III 15.7 PPG CEMENT. INSTALL SPEED HEAD, NU AND TEST BOPE. PU NEYRFOR TURBINE ASSY, MU RLL TOOL AND SOURCE. DAILY:S214,938 CUM:$300,045 ETD:S300,045 EFC:$1,220,000 DRILLING @ 5217' MW: 9.5 VIS: 37 MU BHA INCL NEYRFOR TURBINE. SLIP AND CUT DRLG LINE. RIH, DRILL OUT FLOAT COLLAR, TEST CASING OK TO 2000 PSI. DRILL OUT FLOAT SHOE AT 3115' AND DRILL NEW FORMATION TO 3180'. TEST FORMATION TO 12.5 EMW (497 PSI), BLED BACK TO 225 PSI . ~??i(10.9 EMW) IN 5 MIN. FORMATION WAS NOT BROKEN DOWN, SLOW i.!~I.~,AK OFF. CONTINUE DRILLING TO 5217' ~DAILY:$66,317 CUM:$366,362 ETD:S366,362 EFC:$1,220,000 . RIH W/ BIT #3 MW:10.7 VIS: 35 DRILL FROM 5217' TO 6026'. CHANGE OUT MUD PUMP #1 MUD SWAB. DRILL FROM 6026' TO 6477'. POOH TO SHOE AND PERFORM EMW TEST TO 11.2 PPG, OK. DRILL FROM 6477' TO 6559', LOST PENETRATION RATE. POOH, BIT 70% WORN.RIH WITH NEW BIT. DAILY:S93,473 CUM:$459,835 ETD:$459,835 EFC:$1,220,000 MW:10.7 VIS: 38 RIH W/ BIT #3. TURBO DRLG 6569'-7040'. CIRC AND COND HOLE, SHORT TRIP TO SHOE, CIRC AND COND HOLE. DROP SS SURVERY, SPOT DIESEL PILL, POOH LDDP, BHA. DAILY:S60,114 CUM:$519,949 ETD:S519,949 EFC:$1,220,000 The above is c~j~ct Signatur For form pre~aratlon~ dlitribution, see Procedures Man{al, ~ction 10. v Drilling, Pages 86 an~. AR3B-459-1-D INumberall dally well history forms consecutively no. as they are prepared for each well. ' IPage I ARCO OiL _,rd G'as Company Daily Well History-Final Report ~! I Accounting cost center code '";~ ICounty or Parish Jl State I NORT. SLOPE J AK I Lease or Unit Well no. I ADL: 25547 ALK: 2661 3G-14 I Title I DRILLING Instructions: Prepare and submit the "Filt!l?eport" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted~al.~.-::...~l~..~a~t operations are suspended for an indefinite or appreciable length of time. On workovere when an official test is not required upon completion, report comlgil~.t~ atld 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 KUPARUK Auth. or W.O. no. AK5113 Operator ARCO Spudded or W.O. begun A.R.Co. W.I. 55.2521 Date 08/21/90 Iotal number of wells (active or inactive) on this dst center prior to plugging and I bandonment of this well I our I Prlor status if a W,O, I 12:00 SPUD Date and depth as of 8:00 a.m. 08/27/90 (6) TD: 7040'( 0 SUPV:JMM Complete record for each day reported DOYON RIG 14 MW:10.7 VIS: 0 L/D BHA, R/U AND RUN CSG. R/U AND CMT CSG. BUMP PLUG, HELD OK. R/D CMT HD, R/D BOPE, SET SLIPS, CUT AND DRESS CSG. INJECTED 100 BBL DOWN 3G-14 ANN. PREPARE TO MOVE TO 3G-17. DAILY:S262,923 CUM:$782,872 ETD:S782,872 EFC:$1,220,000 S E P - ? 1990 Old TD Released rig Classifications (oil, gas, etc.) INew TD I PB Depth Date IKind of rig I Type completion (single, dual, etc,) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above i~c~rrect Signa~ ~ __ Date [Title see Procedures` jI, Section 10, ' AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each we . iPage no. Division of AtlsntlcRIchfleldCompa~y $. 000~01;~r£$ SHOWN &OF A.$.P. ZONF 4, N&O 87. /5 i FO~ ~8' 4F. 98~" ' I§0 ~00'$9.§$$" ~530'~ 195' 40.~ ~4.0 ~30'~ I?0' 47.0 ~530'~ tgO' 45.5 5~.0 2950' ~ 9~' 46.9 NO. ~ X 19 5, 980, t$0.~4 400, ~O ~,900. '500.00 4 90, ~/ ~,9~, 5~0.~ 498,/~4. F. IV.L. F.£,I,. 0,5. ~$$'~' ~0' 4?.8 ~. ~30'-- 45' 4Z.I g530'~ ?O' 46.9 ~30'-- 95' 46.8 ~3.0 ~'~ / ~0' 4~.6 ~.9 ~3~' ~ IlO' 46.4 R~30' 19~' 45.3 53,0 SURV£)'OI~'~ CFRTIF/ C&rF __ ANCO ,~&ASgA, INC. OW~. ~0. ' ARCO Alaska, Inc. Date: August 31, 1990 Transmittal Ct: 7874 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the OPEN HOLE following items. receipt and return one signed copy of this transmittal. 3 G- 19 Dual Gamma Ray Compensated Neutron Porosity Simultaneous Formation Density ,//3G-19 Dual Gamma Ray Electrmagnetic Wave Resistivity 3 G- 14 Dual Gamma Ray Compensated Neutron Porosity Simultaneous Formation Density 3G-14 Dual Gamma Ray Electrmagnetic Wave Resistivity Formation Exposure Time 3 G- 16 Dual Gamma Ray Compensated Neutron Porosity Simultaneous Formation Density 3G-16 Dual Gamma Ray Electrmagnetic Wave Resistivity 8-12-90 8-12-90 8-25-90 8-25-90 8-20-90 8-20-90 Please acknowledge 3798-8200 3798-8200 3160-7040 3160-7040 4370-9653 4370-9653 Receipt Acknowledged: DISTRIBUTION: Date: RE6EIVED .... 'SEP - 4 1990 Alaska Oil & Gas Cons. ~;0mmissi0; Anchorage D&M Drilling Franzen Vendor Package(Johnston) NSK ~tate of Ataska(.~Sepia~ ARCO Alaska, Inc. Date: August 31, 1990 Transmittal #: 7873 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 ~/ 3G-19 ~/3G-14 v3G-16 Transmitted herewith are the OPEN HOLE following items. receipt and return one signed copy of this transmittal. LIS Tape and Listing 8- 9- 9 0 LIS Tape and Usting 8 - 2 9 - 9 0 LIS Tape and Listing 8 - 2 9 - 9 0 Receipt Acknowledged' ~ DISTRIBUTION: Lynn Goettinger Please acknowledge soo83o 900834 Date' - ......... S .P - . ~St~te'of Alaska August 21, 1990 Telecopy~ (907)276-7542 A. Wayne. McBride Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3G- 14 ARCO' Alaska', Inc.- Pemit No. 90-117 Sur. Loc. 2538'F~L, 20'FEL, Sec. 23, T12N, RSE, UM. Btmhole Loc. l156'FSL, 1468'FEL, Sec. 23, T12N, R8E, UM. Dear Mr. McBride Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law fr.om other govermnental agencies, and does not authorize conductzng drilling operations until all other required pe~itting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. Sincerely, David W. JohnstOn Commi s s ioha~ ................... Alaska Oil and Gas Conservation Commission BY OPJ)ER OF ~ COMMISSION dlf Enclosure cc~ Department of Fish & Game, Habitat Section w/o encl. Depart~nt of Environmental Conservation w/o encl. - STATE OF ALASKA ~ ,z~[/' "./-,A OIL AND GAS CONSERVATION COMfy. ;ION PERMIT TO DRILL 20 AAC 25.005 i la. Type of Work Drill ;~ Redrill __ J lb. Type of Well Exploratory__ Stratigraphic Test _ Development Oil ..~ Re-Entry _ Deepen --I Service _ Development Gas __ Single Zone ~ Multiple Zone _ 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Irw, RKB 90'. pad 5,3' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25547 ALK 2661 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2538' FNL, 20' FEL, Sec. 23, T12N, RSE, UM KuDaruk River Unit At top of productive interval (TARGET) 8. Well number Number 1340' FSL, 1300' FEL, Sec. 23, T12N, R8E, UM 3G-14 #U630610 At total depth 9. Approximate spud date Amount 1156' FSL, 1468' FEL, Sec 23, T12N, RSE, UM 27-AUG-90 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3G-16 6974' MD 1156' @ TD feet 50' at 500' feet 2560 6162' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 3240' feet MaXimum hole anC~lle 45° Maximum surface 1850 psig At total depth (TVD) 3250 psig :18. Casing program Setting Depth size Specification Top Bottom Quantity el cement Hole Casin~ Weic~ht Grade couplinc~ Lenc~th I~D TVD IVD TVD (include sta(~e data/ 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' ±200 Cu. Ft. 12.25 9.625 36.0# J-55 BTC 3085' 35' 35' 3120' 3120 1400 Cu. Ft. AS III & HF-ERW 460 Cu. Ft. Class G 8.5 7" 26.0# J-55 BTC 6939' 35' 35' 6974' 6162~ 200Cu. Ft. ClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true verticaltrue vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural co, uc,o RECEIVED Sudace Cu. Ft. Intermediate Liner , ~ Perforation depth: measured ~{:I~a~jj.&GaS Co~o. 20. Attachments Filing fee ~ Property plat ~ BOP Sketch ~ Diverter Sketch -~L Drilling program .Z.. !Drilling fluid program X Time vs depth plot ~ Refraction analysis _ Seabed report _20 AAC 25.050 requirements ery certify that the foregoing is true and correct to the best of my knowledge Signed~j~,~'.~ ~J~,(--~lTit.lmem' . Area Drilling Encjineer Date nI~umb~r ~ss~on USeApprovaiOnly~ I ' - ~ I See cover letter for Permit C~O--//~;'Number II I da'008/21/90 I o,hor requirements Conditions of approval Samples required __Y e s ,~ N o Mud log required__ Ye s ~ N o Hydrogen sulfide measures ~ Yes /z~ N o Directional survey required ~ Yes ~ N o Required working pressure for BOPE ~2M; ~,~ 3M- ~ 5M' ~ 10... · ~ I 5M Approve Commissioner the commission Date ~ ! Form 10-401 Rev. 7-24-89 Submit in triplicate DRILLING FLUID PROGRAM (3G-14) Spud to 9-5/8" Drill out to surface casing weight UD Density 8.6-10.0 8.6-9.3 PV 1 5-35 5- 1 5 YP 15-35 5-8 Viscosity 50-100' 30-40 Initial Gel 5-15 2-4 10 Minute Gel 15-40 4 - 8 APl Filtrate 10-1 2 8- 10 pH 9- 1 0 8.5-9 % Solids 10 +/- 4- 7 Weight up to TD 11.0 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 10-12 Drilling Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes' - Drilling fluid practices will be in accordance with regulations stated in 20 AAC 25.033. - Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1850 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. - The nearest well to 3G-14 will be 3G-16. As designed, the minimum distance between the two wells would be 50' at a depth of 500'. The wells would diverge from that point. - Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. RECEIVED AUG 1.5 ]990 .A_la~ka .0~. i & Gas C0~s, * Spud mud should be adjusted to a funnel viscosity between 100-120 to drill gravel beds. ARCO ALASKA. Ino. Pad 3G. Wsll No, 14 Kupsruk FI s I d, Nor th Proposed Slops, Alaska 0 . RKB ELEVATION, 90' 1 000_ 2000 3000. 4000 _ 5000 _ 6000 ZOO0 B/ PERHAFROST TVD-I605 T/ UGNU SNDS TVD-IZZO T/ W SAK SNDS TVD=2460 B/ W SAK SNDS TVD=2920 9 5/8" CSG PT TVD-3120 KOP TVD-3240 TtlD=3240 DEP-O 3 K-lO TVD-3310 TMD=3310 DEP-I 9 21 BUILD 3 DEO PER I00 FT 3 x~ 39~s . . AVERAGE ANGLE ~.. EOC TVD-4598 THD 4750 OEP 567 45 DEG 1 9 FIIN D-4650 THD-482S DEP-620 ~ TARGET / TOP ZONE C-A TVD-5915 THD-6623 DEP-1898 % -%.: .., B/ KUP SNDS TVD-6021 THD-6ZZ4 DEP-2006 ~,~- TO (LOG PT) TVD-6162 THD-69Z4 DEP-2148 I I 1 000 2000 VERTZCAL SECT]ON 3000 HOR I ZON,~-~L PROJECTION SCALE I IN. = I000 FEET ARCO ALASKA. Pod 3(3. Well*-No, Kup~ruk FIolcl, North Propoeed Slope. Aleoke l 000 1 000 2O00 ;~000 3000 2000 , I WEST-EAST 1 000 0 1000 I I I )J.~J~_L~CE RECEIVED TD LOCATiO#, liS6' FSL. 1468' FEL SEC. 23. TI2N. RSE SURFACE LOCATION, 3538' F#L. 30' FEL SEC. 23. TI2N. RSE AUG 1.5 ,An~hnr2C~A ~ TARGET / ZONE CIA T~.6623 DEP- 1898 SOUTH WEST I ~80 TARGET LOCATION, 1340' FSL. 1300' FEL SEC. 23. TI2N. RSE S 42 1898' DEG 24 MI N W (TO TARGET) 2500 2550 26OO 265O 2700 2750 2800 200 I 150 I · ' 500 I / /' 900 I / I f 1100 ! I I I I / /' ~3oo / / / / / / / / 4100 / / 100 50 0 I ! I / / / 3900 50 100 150 200 /~ 500 '%500 500 ~' 3500 t 700 ~3~)0o ~ 900 I I I I ,oo Vool - O0 7 0 :~'~)~' [~ 1100 ~ I ~,,~_ 265 900 \ \ 11100 \ \ \ \ \ \ \ \ \ I 300 I I I I 270 275 280 200 150 100 50 0 50 100 150 200 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 3G PAD I · . . 1 Si Si . · · 10. 11. 12, 13. 14. 15. 16. 17. 18. 19. 20. Move in and rig up Doyon 14. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan, Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or RLL as needed. Run and cement 7" casing. (Isolation of the Colville sands will be performed if there is hydrocarbon presence.) Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel Shut in and secure well. Clean location and release rig. Fracture stimulate well. 21. Reperforate and add additional perfs. '-,dPARUK RIVER UNI. 20" DIVERTER SCHEMATIC 5 I HCR 4 I 5 3 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION . . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2~1/16"- 2000 PSI BALL VALVES 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20"- 2000 PSI ANNULAR PREVENTER SRE 2/6/90 ,6 , 5 4 13 5/8" 5000 !-..,I BOP STACK ACCUMULATOR CAPACITy TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACKTEST 1. FILL BOP STACKAND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTORAND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOTA FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMSAND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE 8/22/89 DOYON 14 CHECK LIST FOE NEW WELL PERMITS IT_tH APPROVE DATE (2) Loc ~:hru 8) '~ 6~ £3)'_~' ~0. (10 ~d 13) 12.. !3. (14 th~ 22) (23 Thru 28) (!9 Thru 31) rev: 01/30/89 6.011. · 14. 15. 16. I?. 18. !9. 20. 21. 22. 23. 24. 25. 26. 27. 28. ~or 29. 30. 31. 32. Company YES NO L"'~,.RK.S' 2. Is well to' be located in a defined pool ............................. ~ ..... 3. Is well loca=ed proper distance from proper~y line ...... ' ........... ~ ,., 4. Is well located proper dis:ance from o:her wells ........ ; ........... , 5. Is sufficient undediaaTed acreage available in =his pool ............ 6. Is well to be deviated and is weilbore plat included ................ ~ · 7. Is operator the only affected parry. ................................ ~__ , 8. Can permit be approved before fifTeen-day wait ...................... Is the permit fee at:ached .......................................... Does operator have a bond in force ................... .. ............. /~ is a conservation order needed ...................................... Is adminisTraTive approval needed ................................... Is :he lease number appropriate ..................................... ~-- Does the we!! have a unique name and number ......................... · IS c6nduc=or string provided ........................................ ~ Will surface casing protect all zones reasonably ~xpecued :o se~-ce as an underground source of drinking wauar ..................... Is enough cement used to circulate on conductor and surface ......... W'~!l cement tie in surface and intermediate or produc:ion strings .. Will cement cover ~ known produc:ive hor~.zons ..................... Will all casing give adequate safety in collapse, tension and burs:. Is this well to be kicked off from an e~.%sting we!!bore ............. Is old ~e!!bore abandoument procedure included on 10-403 ............ is adequate we!lbore separation proposed ...................... ...... Is a diver=er system reauired ....................................... Is the drilling fluid program schema=ia and list of equipment adequate ~ Are necessary diagr~ and descrip=ions of diver=er and BOPE a==ached. Does BOPE have sufficient pressure rating - Test to ~0 psis .. Does the choke manifold comply w/API RP-53 (Nay 8&) .................. Is the presence of H2S gas probable ............................. g... exy. loraTory and S~ra=igraphic we!lsr Are d. aTa presented on potential overpressure zones? ................. Are seismic anal.vsis data presented on shallow Sas zones ............ If an offshore loc.. are survey results of seabed conditions presented .. AddiTional reeuirements ............................................. · Addi:ional R.~rks: ' 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 APPENDIXl .. No special'effort has been made to chronologically organize this category of information. (NOTE: **** LIS READ **** MAXIMUM RECORD LENGTH - 8192 BYTES) ** REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SSDS DATE: 90/08/29 ORIGIN OF DATA: RLL REEL NAME: ARCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: RLL DATE: 90/08/29 ORIGIN OF DATA: 3G14 TAPE NAME: KUPARUK CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE (EOF # 1) ********** ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: 3G14.MWD SERVICE NAME: RLL VERSION #: v2.40 DATE: 90/08/29 MAX. RECORD LENGTH: 1024 FILE TYPE: E1 PREVIOUS FILE NAME: ** COMMENTS ** COMPANY: ARCO ALASKA INC.// WELL: 3G-14// API: 50-103-20138// DATE: 25-AUG-90 LOCATION: 2538' FNL & 70' FEL, SEC. 23, TWP. 12N, RANGE 8E, KUPARUK FIELD, NORTH SLOPE BOROUGH, ALSKA, USA// RIG: DOYON 14// CO. REP.: J. McCULLEY// RLL ENG.: BROWN & GALVIN// COMMENTS ***> NEUTRON AND DENSITY DATA ARE CALIPER CORRECTED. ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# DEPT EWR MWD ROP MWD FXE MWD NF0 MWD NFl MWD NN0 MWD NN1 MWD GRC MWD CAL MWD DRHO MWD RHOB MWD NPSC MWD LOG TYP CLS MOD NO. LVL CODE FT 0 0 0 0 1 4 0 1 68 OHMM 0 0 0 0 1 4 0 1 68 FT/H 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 API 0 0 0 0 1 4 0 1 68 INCH 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 P.U. 0 0 0 0 1 4 0 1 68 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY DESCRIPTION 4 1 66 255 LOG DIRECTION, DOWN 0 1 66 TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 1 4 0 1 68 EWR ROP FXE NFO NFl NN0 NN1 GRC CAL DRHO RHOB NPSC MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD OHMM FT/H HOUR CTS CTS CTS CTS API INCH G/C3 P.U. 68 68 68 68 68 68 68 68 68 68 68 68 ** DATA VERIFICATION DEPT NN1 3000.000 -999.250 3100.000 2341.878 3200.000 2376.000 3300.000 2600.000 3400.000 2520.000 3500.000 2488.000 3600.000 2600.000 3700.000 2592.000 3800.000 2589.794 3900.000 2616.000 4000.000 2616.000 4100.000 2648.000 4200.000 2728.000 4300.000 2568.000 4400.000 2502.813 4500.000 2595.054 4600.000 3288.000 4700.000 2552.000 4800.000 2552.000 4900.000 2507.877 (every 100 FT) ** EWR GRC ROP CAL FXE DRHO -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 8.294 61.079 -999.250 8.590 -999.250 -.780 3.445 93. 101 425.195 8.750 1.525 -.003 3.984 85.838 220.295 8.630 .682 -.062 3.115 102.489 105.167 8.570 .825 -.035 3.237 85.734 162.636 8.480 .793 -.058 2.281 90.754 282.467 8.530 .647 -.026 2.684 92.319 191.455 8.390 .631 -.116 2.675 100.991 155.499 8.510 1.546 -. 080 2.837 115.789 262.354 8.600 .688 -.054 2.399 85.0OO 183.647 8.630 .767 -.052 3.301 90.754 216.211 8.830 .624 .003 3.010 93.013 128.697 8.550 .717 -.037 3.643 147.932 233.020 8.920 .514 -.003 1.915 110.910 199.316 8.450 .972 -.058 2.043 104.836 292.067 8.720 .514 .000 5.599 153.584 146.977 8.730 .650 -.009 2.857 125. 178 132.878 8.890 .655 .004 3.963 113.442 338.619 8.480 .669 -.033 3.674 103.272 140.625 8.650 .715 -.002 NF0 RHOB -999.250 -999.250 404.891 2.936 567.000 2.394 599.000 2.302 511.000 2.562 527.000 2.384 519.000 2.318 527.000 2.575 576.953 2.571 599.000 2.253 551.000 2.467 647.000 2.506 631.000 2.263 631.000 2.786 572.531 2.678 567.000 2.703 871.000 2.876 607.000 2.805 583.000 2.513 523.710 2.628 NFl NPSC -999.250 -949.287 441.772 55.700 519.000 46.683 567.000 40.573 519.000 45.537 503.000 46.835 559.000 42.274 567.000 43.365 542.748 41.834 615.000 40.049 655.000 39.471 607.000 35.416 639.000 35.201 639.000 37.652 594.062 43.371 551.000 42.361 807.000 21.564 599.000 39.507 543.000 43.813 562.877 44.697 NN0 -999.2'50 2343.618 2392.000 2568.000 2568.000 2488.000 2648.000 2576.000 2631.496 2584.000 2584.000 2792.000 2856.000 2616.000 2518.813 2529.892 3368.000 2600.000 2536.000 2526.663 5goo. Qoo 2.918 286.659 .510 583.000 607.000 2600.000 108.748 8.440 -.106 2.623 41.297 2584.000 5100.000 3.928 291.932 .438 626.225 618.477 2743.748 93.101 8.540 -.014 2.585 37.712 2641.297 5200.000 3.622 365.625 2648.000 97.013 8.530 .714 615.000 599.000 -.014 2.472 38.879 2680.000 5300.000 3.651 253.008 .730 588.791 635.552 2785.104 97.795 8.520 -.031 2.849 36.698 2757.522 5400.000 3.851 231.436 2744.000 104.054 8.910 .525 607.000 607.000 .002 2.595 35.653 2680.000 5500.000 4.619 325.675 2824.000 87.624 8.730 .445 655.000 671.000 .001 2.586 32.532 2824.000 5600.000 5.526 214.824 2712.000 104.836 8.770 .517 631.000 623.000 .000 2.587 34.745 2808.000 5700.000 5.103 306.575 2729.467 101.707 8.720 .537 649.627 601.627 .000 2.563 36.145 2691.360 5800.000 4.070 202.832 2612.507 99.360 8.720 .817 601.084 562.361 .000 2.764 41.305 2533.446 5900.000 3.286 218.796 2522.916 129.872 8.780 .798 623.000 607.000 .005 2.535 38.320 2733.792 6000.000 3.789 200.098 2760.000 113.442 8.490 .962 631.000 575.000 -.044 2.504 39.286 2616.000 6100.000 3.847 243.867 2488.000 140.043 8.660 .813 583.000 599.000 -.033 2.585 44.924 2424.000 6200.000 3.345 219.210 2504.000 199.502 8.540 .897 735.000 719.000 -.035 2.417 39.881 2552.000 6300.000 2.934 204.199 2399.272 138.383 8.590 .814 576.456 623.728 -.017 2.437 46.141 2389.088 6400.000 2.157 197.153 2381.300 109.531 8.630 5.465 532.811 530.773 -.004 2.427 48.719 2375.926 6500.000 1.919 44.775 2225.892 113.594 8.900 9.853 481.212 482.955 .013 2.292 56.661 2170.500 6600.000 18.050 166.433 2872.000 63.145 8.710 .860 642.247 621.416 .000 2.272 31.921 2974.493 6700.000 2680.000 6.209 126.199 85.617 ~ ~ 8.900 1.946 607 081 557.255 .012 2.427 38.10~ 2625.503 6800.000 3.416 29.060 2411.552 97.513 8.780 2.463 541.891 534.877 .000 2.450 46.426 2428.292 6900.000 2.987 21.054 2.168 555.099 579.155 2519.565 103.144 8.830 .007 2.487 42.030 2533.873 7000.000 -999.250 26.314 -999.250 -999.250 8.340 -999.250 -999.250 -999.250 .000 .490 -949.287 -999.250 7100.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -949.287 -999.250 ** 432 DATA RECORDS ** FROM 3000.00 TO 7100.00 FT ** FILE TRAILER** FILE NAME: 3G14. MWD SERVICE NAME: RLL VERSION #: v2.40 DATE: 90/08/29 MAX. RECORD LENGTH: FILE TYPE: E1 NEXT FILE NAME: 1024 ********** END OF FILE (EOF # 2) ********** ** TAPE TRAILER** SERVICE NAME: RLL DATE: 90/08/29 ORIGIN OF DATA: 3G14 TAPE NAME: KUPARUK CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** REEL TRAILER ** SERVICE NAME: SSDS DATE: 90/08/29 ORIGIN OF DATA: RLL REEL NAME: ARCO CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT