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185-291
Image 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 (done) RESCAN [] Color items: Grayscale items: [] Poor Quality Originals: [] Other: ?~'/L/' DIGITAL DATA [] Diskettes, No. [] Other, No/Type TOTAL PAGES: ~? NOTES: ORGANIZED BY: ~ BREN VINCENT SHERYL MARIA LOWELL Project Proofing OVERSIZED (Scannable) [3 Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds Other By: Date: PROOFED BY: I~EVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: ~si PAGES: ~? (at the time of scanning) SCANNED BY: BEVERLY BREN VINCEN~MARIA LOWELL RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /SI General Notes or Comments about this file: PAG ES: Quality Checked (done) Rev1 NOTScanned.v4od PLUGGING = LOC_%TION C__g_~_~CE R~,PORT Stats of Alaska .~ev!ew ~--e well .-'-'~- an~-¢-~-~C on ptug~i=g, well head suauus, ~ !oca=imn ~!e~ca - p~de loc. c~. code .... 'pos: or place: ' c~c!usio~: Code · o STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil [--] Gas D Suspended [] Abandoned r~ Service F"] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-291 / 399-139 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-029-21499 4. Location ofwell at surface 9. Unit or Lease Name 52' FSL, 158' FEL, Sec. 19, T12N, R9E, UM !~~ 't f Kuparuk River Unit At Top Producing Interval~ 10. Well Number 1302' FNL, 1496' FEL, Sec. 19, T12N, RgE, UM i 3F-13 At Total Depth '! 1'1. Field and Pool 945' FNL, 1618' FEL, Sec. 19, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 31' feetI ADL 25632 ALK 2565 Kuparuk River Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions I December 12, 1985 December 18, 1985 August 13, 1999 (P&A'd) I N/A feetMSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 8108' MD/6410'TVD 7346' MD/5802'TVD YES D No ['~I 1795' feetMD 1500' (approx) 22. Type Electric or Other Logs Run 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO-FI'OM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 110' 24" 331 sx AS II 9.625" 36# J-55 Surface 3652' 12-1/4" lOOO sx PF 'E', 400 sx PF 'C' 7" 26# J-55 Surface 8050' 8-1/2" 305 sx Class 'G'r 175 sx PF 'C' cement plug @ 7346'r cement retainer @ 7370'~ brid,~e plu,~ @ 7603'-7605 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) N/A N/A N/A * Plugged & Abandoned all perforation intervals. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED see attachments KELI:IVhl Date First Production Method of Operation (Flowing, gas lift, etc.) - v N/A Plugged & AbandonedAlaska 0il & Gas Cons. C0mmi :Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL I N/A Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (tort) ~ress. 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. * This 10-407 is submitted as directed per the 10-403 form approved (Approval #399-139) Form 10-4.07 Rev. 7-1-80 CONTINU ED ON REVERSE SIDE Submit in duplicate 29. GEOLOGIC MARKERS NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A MEAS. DEPTH TRUE VERT. DEPTH 7474' 7581' 7706' 7868' 5900' 5983' 6081' 6212' 30. FO RMATION TESTS Include interval tested, pressure data, all fluids recovered and gravily. GOR, and time of each phase. N/A ,31. LIST OF ATTACHMENTS Summary of Operations 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Mark Chambers 265-1319 Signed.//~ ~ -3~_ Title Drilling Team Leader Date - Graham C. Alvord INSTRUCTIONS Prepared by Sharon AIIsup-Drake General: This form is designed for submitting a complete and correct well completion report and Icg 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 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 cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Oth er-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. KUPARUK RIVER UNIT ,~ WELL SERVICE REPORT ,~ K1(3F-13(W4-6)) WELL JOB SCOPE JOB NUMI~ER " 3F-13 DRILLING SUPPORT-EXP SIDETRACK 0809991629.4 DATE DAILY WORK UNIT NUMBER 08/09/99 BRIDGE PLUG SETTING 2145 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 YESI YES SWS-STEPH ENSON FERG USON FIELD AFC# CC# Signed ESTIMATE AK0041 230DS36FL InitialTbgPress FinalTbgPress Initial lnner Ann Final lnner Ann ]lnitialOuterAnn I Final Outer Ann 500 PSI 125 PSI 50 PSI 50 PSII 1300 PSI 300 PSI DALLY SUMMARY BRIDGE PLUG SET @ 7603'-7605' (ABOVE AVA NIPPLE @ 7640', COULD NOT PASS THRU WITH PLUG). WILL PLAN TO PULL DUMMY IN MANDREL @ 7436' AND TEST PRE-SQUEEZE INJECTIVITY. WILL PLAN TO SHOOT TBG PUNCH FOR CIRCULATION IF REQUIRED.[Cement-Poly Squeeze] TIME LOG ENTRY 10:45 DEPART FOR DS 3F-13 11:10 ARRIVE ON LOCATION - HOLD SAFETY MEETING - START RIG UP 11:30 CALL FOR RADIO SILENCE 11:50 PRESSURE TEST TO 3000# 12:00 RI H 13:15 LOG TIE IN PASS 13:40 GOT STUCK IN AVA - OPEN WELL TO GET OUT 13:45 RELOG TIP 13:50 LOG INTO SETTING POSITION AND SET BP @ 7604' 13:55 LOG OFF BP 14:00 POOH 14:45 START RIG DOWN - OPEN WING BACK UP - PRESSURE DROPPED TO FLOWLINE PRESSURE AND SAW NO TEMPERATURE INCREASE - BP IS HOLDING 15:15 RELEASE RADIO SILENCE 15:30 COMPLETE RIG DOWN - LEAVE LOCATION ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '~' K1(3F-13(W4-6)) WELL JOB SCOPE JOB NUMI~ER " 3F-13 DRILLING SUPPORT-CAPITAL 0809991629.4 DATE DAILY WORK UNIT NUMBER 08/13/99 SET CMT RETAINER AND SQZ UNIT #3 DAY OPERATION COMPLETE J SUCCESSFUL KEY PERSON SUPERVISOR 3 YESJ YES DS-Starck FERG USON FIELD AFC# CC# Signed ESTIMATE AK0041 230DS36FL Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann , Initial Outer Ann , Final Outer Ann 570 PSI 420 PSI 1275 PSI 1275 PSII 1175 PSI 175 PSI DAILY SUMMARY RU DS COIL UNIT#3. WASH TBG TO 7450' WITH DIESEL TAKING RETURNS TO OPEN TOP. POOH. PU 3 1/2' EZSV CMT RETAINER RIH AND SET RETAINER @ 7370' CTM CORRECTED TO ELM. PUMP 54 BBLS SLURRY BENEATH RETAINER AND DRESS OFF CEMENT TOP ABOVE RETAINER TO 7350'[Cement-Poly Squeeze] TIME LOG ENTRY 07:30 RU DOWELL UNIT #3. PT LINES 09:30 RIH WITH NOZZLE CIRC 1/2 BPM DIESEL TAKING RETURNS TO TIGER TANK 10:00 INCREASE RATE TO 3/4 BPM 1630 COIL PSI, WELLHEAD 90 PSI 10:40 WT CHECK @ 5000' IS 10800# 11:05 WASH TBG TO 7450' CTM. TOTAL FLUID PUMPED 73 BBLS. WHP=90 PSI, COIL 1750 PSI. RETURNS TO TANK=150 BBLS CRUDE & DIESEL. NO SIGNIFICANT SOLIDS IN RETURNS. 11:45 POOH @ 1900' CIRC 3/4 BPM @ 1500 PSI COIL, 115 PSI WHP. 240 BBLS TO TANKS WITH 104 BBLS DIESEL PUMPED. 12:05 OUT OF HOLE WITH COIL. TOTAL DIESEL PUMPED 117 BBLS. WHP=140 PSI. CALL FOR VAC TRUCK TO SUCK DOWN OPEN TOP TANK. 12:30 RADIUS BROUGHT OUT WRONG TOOLS FOR 1 1/2" COIL. CALL FOR CORRECT ADAPTERS. 13:30 RADIUS AARRIVES WITH TOOLS. RU CMT RETAINER 14:15 RIH WITH 3 1/2" EZSV CMT RETAINER. WHP=540 PSI 15:45 WT CHECK @ 7400' =13800 15:55 TAG UP ON BP AT 7593' CORRECT TO EL AT 7604' 16:00 CORRECT TO ELM AND PU TO 7370' TO SET CMT. RETAINER. 16:15 DROP BALL FOR SETTING TOOL. PUMPING BALL AT 1BPM 2500 PSI COIL AND 500 PSI WHP. TAKING RETURNS TO TIGER. 16:35 CUT RATE TO 1/4 BPM TO SEAT BALL. COIL 1050 PSI; WHP=415 PSI. GOOD INDICATION THAT BALL SEATED AND SHEARED. 17:00 PU TO 7359' DROP DOWN AND TAG RETAINER @ 7370'. POOH TIME 17:50 18:15 19:30 19:40 20:20 20:40 20:45 20:55 21:50 22:15 22:25 23:00 23:45 LOG ENTRY OUT OF HOLE WITH SETTING TOOL START IN HOLE WITH STINGER FOR RETAINER. HOLDING 500 PSI POSITIVE PRESSURE ON WH WITH CHOKE WHILE RIH. STING INTO RETAINER (7337' CTM CORRECTED TO 7370' ELM) TEST BACKSIDE OF RETAINER TO 1200 PSI 900 PSI ON COIL). RETAINER TEST OK. DISPLACE VOLUME BELOW RETAINER TO FLUSH ANY GAS INTO PERFS. DISPLACE 30 BBLS DOWN COIL USING SLICKWATER. 1.2 BPM @ 3475 PSI COIL, 140 PSI WHP, 4 BBLS SLICKWATER PUMPED BENEATH RETAINER FOR FLUSH. COMPLETE 30 BBL DISPLACEMENT BENEATH RETAINER. MAX RATE 1.8 BPM AT 3575 CT PRESS. PT CEMENTERS TO 4000 PSI. LEAD 2 BBLS FRESH WATER AND FOLLOW WITH SLURRY 15.8 PPG CLASS 'G' PUMPING SLURRY AT 1 BPM AND 3693 PSI WITH 6.5 BBLS AWAY. WHP=112 PSI TOTAL SLURRY PUMPED 54.2 BBLS. START DISPLACEMENT WITH FRESHWATER. PUMPING 0.9 BPM AT 3800 PSI. WHP-139 PSI DISPLACE SLURRY WITH 23.5 BBLS FRESHWATER(COIL VOL=24 BBLS) STING OUT OF RETAINER AND PU TO 7230' WHILE OVER DISPLACING COIL WITH FRESHWATER. DROP DOWN AND DRESS OFF CEMENT CAP TO 20' ABOVE RETAINER (7350' TOC) POOH WITH STINGER PUMPING SLICKWATER 1.5 BPM AT 120 FPM(80%) SWITCH TO DIESEL TO LAY IN FREEZE PROTECT CAP FROM 2500' TO SURFACE(22 BBLS DIESEL REQUIRED) OUT OF HOLE WITH STINGER. RDMO ARCO Alaska, Inc. KUPARUK RIVER UNIT ~ WELL SERVICE REPORT '~, K1(3F-13(W4-6)) WELL JOB SCOPE JOB NUMI~ER " 3F-13 DRILLING SUPPORT-CAPITAL 0809991629.4 DATE DAILY WORK UNIT NUMBER 08/14/99 TAG CEMENT PLUG, P/T TBG 70101 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 4 YES YES HES-OBER FITZPATRICK FIELD AFC# CC# Signed ESTIMATE AK0041 230DS36FL Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 175 PSI 0 PSI 325 PSI 325 PSII 200 PSII 200 PSI DALLY SUMMARY ITAGGED CEMENT PLUG @ 7346' RKB, REC. SAMPLE OF HEAVY SCALE. BLED CSG TO 0 PSI, OK. TESTED TBG 2500 PSI, OK. BLED TBG TO 0 PSI, OK. PULLED DV @ 7300' RKB, GLM LEFT OPEN. [Tag, PT Tbg-Csg, GLV] TIME LOG ENTRY 11:15 MIFFGSM- SLIPS, TRIPS & FALLS. MUSTER AREA. COMMUNICATION. CONGESTED PAD. 11:30 RU- HES & LRS. 1.875" TS: RS,QC,5',KJ,5',KJ,LSS,QC. BLEED 7" CSG TO 0 PSI. PFF LINES & EQUIP 2500 PSI. 12:20 RIH W/3' X 2.25" SMP BLR; TAG @ 7321' SLM (7346' RKB= 25' CF 07/14/99) UNABLE TO MAKE HOLE, TOOLS STICKING- POOH, BLR 1/4 CUP SCALE. 13:20 14:30 RIH W/2.72" CENT- 2- STEM- 2.735" GAUGE RING; TBG CLEAR TO 7321' SLM (7346' RKB) POOH. PRESSURE TEST TBG TO 2500 PSI, 7" CSG= 25 PSI, MONITOR 30 MINUTES, TBG= 2450 PSI, 7" CSG= 25 PSI- GOOD. 15:15 BLEED TBG TO 0 PSI, 7" CSG= 0 PSI, MONITOR 15 MINUTES, TBG = 0 PSI, CSG= O PSI- GOOD. 15:30 17:00 RIH W/3" OM-1 & 2.0" SM; LATCH @ 7286' SLM (7300' RKB) POOH W/DV ON RM. RDMO TO 30-02, TURN WELL OVER TO DSO. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 28, 1999 Mr. Robert Christenson Comm/ssioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3F-13 (Permit No. 85-291 / 399-~39) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the recent abandonment of I<RU 3F-13. This well was sidetracked and re-drilled to an alternate bottom hole location and renamed 3F-13A. If there are any questions, please call 265-6120. Sincerely, Graham C. Alvord Drilling Engineering Supervisor AA[ Drilling GCA/skad RECEIVED ,,'T g i ,999 Alaska 0it & Gas Cons. C0mmissi0~, Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request Abandon _X Suspend _ Operational shutdown" ..... Re-enter su.~l~ended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Other _ Change approved program _ Pull tubing _ Variance _ Perforate _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 31' feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk River Unit 4. Location of well at surface 8. Well number 52' FSL, 158' FEL, Sec. 19, T12N, RDE, UM 3F-13 At top of productive interval 9. Permit number/approval number 1302' FNL, 1496' FEL, Sec. 19, T12N, RDE, UM 85-291 At effective depth 10. APl number 50-029-21499 At total depth 11. Field / Pool 945' FNL, 1618' FEL, Sec. 19, T12N, RDE, UM Kuparuk River Field/Kuparuk Oil Poe 12. Present well condition summit Total depth: measured 8108 feet Plugs (measured) true vertical 6410 feet Effective depth: measured 7962 feet Junk (measured) true vertical 6289 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 110' 16" 331 sx AS I~ 110' 110' Surface 3615' 9.625" 100o sx PF 'E', 400 sx PF 'C' 3652' 3065' Production 8013' 7" 305 sx Class 'G', 175 sx PF 'O' 8050' 6363' Liner ORIGINAL measured 7479'-7579', 7592'-7599', 7721'-7748', 7763'-7814' RECEIVED Perforation depth: true vertical 5904'-5982', 5993'-5998', 6094'-6116', 6127'-6168' ,,~ k,u 02 1999 iTubing (size, grade, and measured depth 3.5", 9.3#, J-55 @ 7663', 2.875", 6.5#, J-55 @7666' ~)I~I~EI, 0il & Gas Cons. Commission Anchorage Packers & SSSV (type & measured depth) Otis 'HB' pkr @ 7365', Otis WD pkr @ 7654', Camco TRDP-1A-ENC SSSV @ 1795' 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: August 11, 1999 16. If proposal was verbally approved Oil ~__X Gas__ Suspended __ Name of approver Date approved Service __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mark Chambers 265-1319 Signed ' ~'~..~i¢--~~ Title: Drilling Team Leader Date Randy"Thomas Prepared b~ Sharon Allsup-Drake FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representativ.~..may witness I Approval noj~./~_.. Plug integrity ~ BOP Test ~ Location clearance -- Mechanical Integrity Test __ Subsequent form required 10- /'~'O "~ ..SGN Approved..b.y order of the Commission ORIGINAL_.I__ED'BY ...... _,.,C, dommissJoner Date Form 10-403 Rev 06/15/88 · Hobert N. Chri~[en~un SUBMIT IN TRIPLICATE 3F-13 Proposed P&A 9-5/8" 36# J-55 casing set @ 3652' MD 7" Baker 'Window Master Whipstock' top_@ 6632' MD. Bridge Plug Depth tied in with CET 1/7/86 7" Baker Bridge Plug set @ 6653' MD. Abandoned C-Sand Perfs 7479'-7579' 7592'-7599' Cement retainer set in first full joint below packer @ +/-7390' MD with cement squeezed below, down through AVA into C sand perfs ~;~.~ Bridge plug set in 10' pup joint below AVA @ +/-7647' MD to isolate A sand perforations. Abandoned A-Sand Perfs 7721'-7748' 7783'-7814' 7',26#,J-55 casing@8050'MD Last Tag at 7828' MD on 7/14/99 PBTD = 7962' MD TD = 8108' MD BDN / MAC 7/28/99 KRU 3F-13 SUNDRY OBJECTIVE P & A WELL FOR SIDETRACK OPERATIONS (reference attached plugbaCk schematic) CURRENT WELLBORE STATUS: 3F-13 was drilled and completed in December 1985 as a 3-1/2" selective single completion producing from the Kuparuk C and A sands. The C sand has watered out and hydraulically limits A sand production. An infill injector is planned for 2000 in this fault block and along with existing producer 3F-19 will recover the remaining ^ sand reserves. The sidetrack of 3F-13 is into an isolated fault block to the west, targeting A sand reserves with injection support provided by 3F-16A. The 3F-13 C sand is currently shut in and the gas lift mandrels contain dummy valves (except for an OV in the top station at 2479' MD RKB). The tubing tail with stuck ^merada gauges in the 'D' nipple was cut on 8/30/97 at 7666' MD RKB. There is also documented 7" by 9 5/8" communication when the well is on gaslift and dried pipe dope on the 7" BTC connection is suspected. The 7" casing pack off pressure tested successfully on 7/17/99. The P&A to prepare the well for sidetracking is a two step procedure. First setting a bridge plug in the 3-1/2" tubing above the bottom production packer to isolate the A sand perforations and then setting a cement retainer as noted on the plugback schematic and down-squeezing cement through the AVA and into the open C sand perfs. P&A WORK (Pre-Rig): RU slickline unit. RIH and pull 1/4" OV at 2479' MD RKB and run dummy valve. Pressure test 7" casing to 3500 psi for 30 min (chad test). RIH and pull BPI from AVA at 7640' MD RKB. RU E-line unit or use SL downhole power unit. RIH and set bridge plug in 3-1/2" tubing at +/-7647' MD RKB (middle of 10' pup joint below AVA and above Otis 'WD' packer) to isolate A sand perforations. 3. RU pump truck. Perform C sand injectivity test for upcoming CTU squeeze, by bullheading +/- 15 bbls of diesel down tubing into perforations. Record pressure and pump rate. , RU CTU. RIH and establish injection rate into perforations. Record breakdown pressure and rate. Note final injection rate and pressure. Tag bridge plug set in step #2 to tie-in CTU depth with RKB depth and flag coil. RIH with cement retainer on CTU and set retainer at +/- 7390' MD RKB (in first full joint of 3-1/2" tubing below Baker 'HB' packer). Squeeze 37 bbls of 15.8 ppg Class G cement below retainer (10 bbl for the 3-1/2" and 7" volume between the packers + 27 bbis into perfs). If needed, use a spotting valve placed immediately above the retainer to displace the cement down coil to desired distance above top of retainer. Close valve and pump cement squeeze below retainer into perfs. Unsting from retainer and circulate any excess cement from well bore. Leave well shut-in with initial tubing pressure on wellhead. RDMO CTU. Bleed annulus pressure to 0 psi. Pressure test tubing above cement retainer to 2500 psi for 30 min (chart test). Slowly bleed tubing pressure to 0 psi and monitor pressure for build-up. 7. RU slickline unit. RIH and pull 1-1/2" DV from bottom GLM at 7300' MD RKB, leaving an open pocket. 8. RU E-line unit. RIH and cut tubing at +/-7330' MD RKB (middle of first full joint of 3-1/2" tubing above Baker 'HB' packer). 9. Remove well house and scaffolding. BDN 7/28/99 ,~r[' BY' 8- 2-53 ; 3:44FM ' AKCO AL~bKA~ DUI ZIO IO~Z,'~- /-/ /- ARCO Alaska, Inc. ,~ GKA 3F-13 i . ii 3F-13 , · .... APl: 50829~149g00 WAlt Typo: PROD ^n~l~ ~ T8:138 d~ S~SVT~~ Cm~ ddg Completion: 1~2o/85 J Angle ~ ~: 34 deG ~ 6108 TRDP-1A-ENC - (L~k~ Out) AnnularFluld: Leal Wlo: 2~5/go .~ Re.eh T~ ~h. ~temnce Log: Roi L~ Oa~: L~ U~: 7126/gg Guiqs~i~D-,~ONDUCT~R .,, ' -' ,. ~sing $~pg - SURFACE Slzg [ Top i gofom j WD ~ Wt....[Grad,'-[ 9.626 I O ,, J 3~ 'l ~ 36,00 J 66 ] ~ C~l~g SWing. PROD~iON ..... ... [.0~ ~ ,, 0 I 6050 6363 ' ~5 " Tubing 8~ng- TUBING' (t~.9' TBG TAIL C~ OFF) -- 3.500 O I 76e3 6~8 9,30 0-55 ' EUE ~ MOD Inlowal WD Zeno Status Fget ~PF Dato TyH C~ment 7479-7579 50~.6082 ,3,C-e,~4,qg '1~ 12 1/30~U IPeRF 420aeg,~aei'~;5'~llbegGun 7b92-756~ 5~Z-5~6 _i ~ITO 7 12 1~0~6 IPE~F 120~.ph~;S"~JIIC~ 7721 - ~748 ~- 6116 A-3 27, 8 ~1166 A~RF 60 ~. ~sing; 2 77~- ~814' 6128- 8169 A-2 ','~ 51 4 11~6 IPE~F ~ deg. ~a~; 4" ~ II C~ G~' G~ LI~ Mandm~Na~% ~ ' , 8tn MD ~ Man Man v~' VT~a'" VOD La'~h Po~ ThO M~ T~e Run :omment i 24~g ~sr Mer~ ~PD / DMy' '1.0 BK' ~.~0 o 7~8~9 3 47~R ' 381~ M~a T~PD D~ 1.0 , BK ~.~0 0 0116~1 4 ~81 4060 ~eda ~PO DMY 1.0 BK ~.~ 0 S ~SS 43~ ~ ~P~ DaY ~,0 BK ~:0Oa 6 ~33 4648 ~ ~PD DMY 1~ ~ ~.~o o 7 ~z~o 4937 M~a TMPD DMY 1.0 aK 0,000 0 ~5~0 · 8 ~ 65~Q 5~1 MeHa TMPD DMY 1,0 aK 0.0~ 0~ g 69~ 55~ M~a ~D OMY 1.0 BK ~,000 01 ~0 7~ .7.7 OIb 'Le~ DMY 1,~ aM 0,~ ' OJ .produc~on Mandml~alv~ . ~ Type ~un men/ 1~1 ~l {8721 Mede ! ~PD .1 DMY '3.0 lek 10.oDeI "oI ~/~' I~os~ :~ther~plug~ equip., ~,) - JE~LRY ' .. ' . .... .,, ~p~ : ~D T~a Des'c~p~on ID t798 q~2 8~v C~b~-IA-ENC'"' ~cked O~ 10/4/95) 2.6~2 7351 56~ PRR ~ker 2,995 ~65 58i~ PKR ~ket'HB~ ' zg40 7640 -60~ NIP AVA ~L ~NG NIPPLe, left ~en 712~g 2,760 7~4 6~1 PKR ~a ~' 3.000 ~h"' FmH ('tY:9' Tea ~L} STmN~ C~ Oq ~nOa7), ,, Depth D~cdpdon ~oLLOW~Na Comment 7~o c~ PLu~ w/~ ~eW FISH (JUN~D) , 7~0 NIP G~ 'D' ~ple (JUN~D) NO GO 7852 .JUNK in Y~ . ' LeE avar from pr~ia% Fb~l~ Opera~ne; . , uii & ~as Cons. c~ .... ,, ~--~ . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed' Operation Shutdown __ Pull tubing X Alter casing Stimulate __ Plugging Perforate Repair well X Pull tubing Other 2. Name of Operator ARCO AIs, sk¢,, In6. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 52' FSL, 158' FEL, Sec. 19, T12N, R9E, UM At top of productive interval 1302' FSL, 1496' FEL, Sec. 19, T12N, R9E, UM At effective depth 1207' FNL, 1590' FEL, Sec. 19, T12N, R9E, UM At total depth 945' FNL, 1618' FEL, Sec. 19, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 81 0 8' feet 6 41 0' feet Plugs (measured) 6. Datum elevation (DF or KB) 93' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3F-13 9. Permit number/approval number 85-291/90-063 10. APl number 50-029-21499 11. Field/Pool Kuparuk River Oil Pool feet Effective depth: measured 7 9 6 2' true vertical 6289' feet Junk (measured) feet Casing Length Structural 8 0' Surface 3 61 5' Intermediate Production 8 01 3' Liner Perforation depth: measured 7479'-7579' true vertical 5904'-5982' Tubing (size, grade, and measured depth) Size Cemented Measured depth 16" 331 sxCSII 115'md 9-5/8" 1000 sx PF "E" & 3652'md 400 sx Class PF "C" 7" 350 sx Class G & 8050'md 175sx PF"C" , 7592'-7599', 7721 '-7748', 7763'-781 4' , 5993'-5998', 6093'-6115', 61 27'-61 68' 3-1/2", 9.3#, J-55 tbg W/ tail @ 7662' Packers and SSSV (type and measured depth) Baker "HB" Pkr @ 7365', Otis WD Pkr @ 7638', Camco "TRDP-1A" SSSV @~17.98': True vertical depth 11 5'tvd 3065'tvd 6363'tvd 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsec~uent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 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 ~,~, --~- ~-'~ Form 10-404 Rev 05/17/89 Title Area Drilling Engineer Date ~/~~ SUBMIT ~N DUPLICATE ARCO t..,nd Gas Company Well History - Initial Report- Daily Instructions: Prepare and submit the "Initial Re~ert" on the first Wednesday after a well is spudded or workover operations are starled. Daily work prior to Spudding should be summarized on the form giving inclusive dates only. District I County. parish or borough ARCO ALASKA INC. J NORTH SLOPE Field ILease or Unit KUPARUK RIVER UNIT I ADL: 25632 Auth. or W.O. no. JTitle AK4648 I WORKOVER State KRU 3F-13 no. Operator ARCO Spudded or W.O. begun IOate /Hour W.O. I 2/17/90 2{.:00 Date and depth as of 8:00 a.m. 02/18/90 ( TD: 0 PB: 7962 SUPV:GB 02/19/90 ( TD: 0 PB: 7962 SUPV:GB 02/20/90 ( TD: 0 PB: 7962 SUPV:GB 02/21/90 ( TD: 0 PB: 7962 SUPV:DB 2) 4) Complete record for each day reported NORDIC ~1 ARCO W.I. 55.8000 JPrior slatus f a W.O. The above is correct S, g n at u re~.,~.,~__~, sFeO~ '1~, ~r~c ~drue PJsratMla°r~ ed i~l ~nb ult '0,0n, Drilling. Pages 86 and 87. PUMP SALT PILL 7"@ 8050' MW:ll.3 NACL/NABR CONT. MOVING RIG FROM/PBU, ACCEPT RIG 2100 HRS, 2/17/90, RU LINES, LOAD PITS WITH BRINE, RU BJ TITAN, TEST LINES TO 2500 PSI, PUMP 12 BBLS VISC BRINE FOLLOWED BY 40 BBL BRIDGESAL PILL, DISPLACE WITH 67.5 BBL 11.3 BRINE, PRESSURE BUMPED FROM 400 TO 1500 PSI. DAILY:S150,696 CUM:$150,696 ETD:S150,696 EFC:$330,000 NU BOPE 7"@ 8050' MW:ll.3 NACL/NABR FIN SPOTTING KILL PILL, RD BJ, LOAD ANNULUS WITH BRINE, RU HLS, RIH W/ 1.25" PERF GUN, SHOOT GUN AT 7250', TUBING PRESSURE DID NOT CHANGE, (NO HOLE IN TBG) RD HLS, CONT FILLING ANNULUS WITH BRINE, SET BPV, ND TREE, NU BOPE. DAILY:S121,519 CUM:$272,215 ETD:S0 EFC:$602,215 PULL AVA SLEEVE 7"@ 8050' MW:ll.3 NACL/NABR PT BOPE, PU TUBING, CIRC GAS FROM WELL. PULL TUBING AND REMOVE STUCK SSSV FROM 1ST JOINT OF TUBING. STAB BACK ONTO SLICK STICK, ATTEMPT TO PULL AVA SLEEVE, UNSUCCESSFUL. SLEEVE IS STUCK, DROP CUTTER BAR Il, NO CUT, DROP CUTTER BAR #2, NO CUT, DROP TIMED CUTTER, CUT LINE. RECOVERED TIMED CUTTER, MADE 3 RUNS TO RECOVER CUTTER BARS Jl AND #2 AND 8' OF WIRE. ATTEMPT TO FISH ORIGINAL . RETRIEVAL TOOLS WITH SLICKLINE, SHEARED OFF, NO RECOVERY. RU BRAIDED LINE. -DA~Z-LY:$32,465 CGM:$304,680 ETD:SO EFC:$634,680 '~H- -_ WITH TBG 7"@ 8050' MW:ll.3 NACL/NABR RIH WITH BRAIDED LINE TO FISH WT BARS, JARS, AND AVA SLEEVE. 1ST COULD NOT LATCH, 2ND RUN LATCHED FISH AND BROKE DOGS ON RETR TOOL. RAN BLIND BOX, COULD NOT LATCH, RAN RETR TOOL AND TAGGED AT 7572' (18' HIGH TO FIRST RUNS). COULD NOT LATCH. RAN 2.7" IMP BLOCK TO 7580', NO IMP, RAN 2" DRIVE DOWN BAILER TO 7565' (LOST 15'). BAILER FULL OF MUD, SCALE AND SAND. RU ATLAS WIRELINE, RIH WITH 2-5/8' CHEM CUTTER. CUT TUBING AT 7451' (25' ABOVE TOP BLAST RING JOINT). RD ATLAS. PU AND UNSTING FROM SLICKSTICK, CIRCULATE TO EVEN OUT BRINE COLUMNS, LOST 11 BBL WHILE CIRC. POH WITH TUBING, CHANGE OUT COLLARS TO 8RD AB MODIFIED. 3 BBL LOSS WHILE PULLING TBG. TUBING CONDITION IS GOOD, DRIFT OK. PULLED TO SSSV AT 0600HRS. DAILY:S46,027 CUM:$350,707 ~TD:$0 EFC:$680,707 AR3B-459-1-D INumber all daily well history forms consecutively as they ere prepared for each well. Page no. ARCO 0,...nd 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 describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlarim" sheets until final completion. Report official or representative test on "Final" form. 1) Submil "Interim" sheets when filled out but not less frequently than every 30 days. or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District lCounty or Parish Slate ARCO ALASKA INC. I NORTH SLOPE AK Field Lease or Unit KU?ARUK RIVER UNIT ADL: 25632 KRU 3F-13 Complete record for each day while drilling or workover in progress NORDIC #1 Date and depth as of 8:00 a.m. 02/22/90 (5) TD: 0 PB: 7962 SUPV:DB 02/23/90 ( 6) TD: 0 PB: 7962 SUPV:DB 02/24/90 (7) TD: 0 PB: 7962 SUPV:DB 02/25/90 (8) TD: 0 PB: 7962 SUPV:DB RIH WITH DP AND OVERSHOT 7"@ 8050' MW:ll.3 NACL/NABR CONT POH WITH TUBING. CHANGE OUT COLLARS TO 8RD AB MOD. RECOVERED 237 JTS, 6 JTS LAID DOWN; 2 BAD THREADS, 4 CRIMPED. OTHERWISE PIPE IN GOOD CONDITION. SLIGHTLY THICKER SCALE NEAR BOTTOM BUT DRIFTED 2.850" OK. FLUID LOSS 4 BBLS. LOAD DRILL PIPE IN PIPE SHED; RACK, TALLY, AND STEAM TREADS. PU TRI-STATE FISHING ASSEMBLY INCL CUT LIP GUIDE, DAILY:S37,814 CUM:$388,521 ETD:S0 EFC:$718,521 PREP TO RUN RTTS 7"@ 8050' MW:ll.3 NACL/NABR RIH WITH FTA, ENGAGE SBR SLICK STICK AT 7354' NORDIC RKB. PACKER PULLED FREE AT 210 Kt (100K OVER). POH 3 STANDS TO CLEAR "C" SAND, HAVE 4K EXTRA WEIGHT. CIRC BU, NO GAS. POH SLOW. REC U. PKR AND ALL OF TAILPIPE ABOVE LOWER PKR. NO SIGN OF ATTEMPTED CUT ON OUTSIDE OF TBG. CAN SEE SIGNS OF ATTEMPTED CUT INSIDE JT BELOW GLM. MUD AND SCALE FILL IN TAILPIPE UP TO STEEL BLAST JOINT 30' ABOVE AVA SLEEVE. RECOVERED SLICKLINE TOOLS STILL ATTACHED TO AVA SLEEVE. REMOVE BLAST RINGS FROM TUBING. PREP TO RUN RTTS TO PRESSURE TEST CASING. FLUID LOSS APPX 5 BBLS/HR. DAILY:S28,147 CUM:$416,668 ETD:SO EFC:$746,668 POOH LD DRILL PIPE 7"@ 8050' MW:ll.3 NACL/NABR RIH WITH HALLIBURTON CHAMP PACKER. SET PACKER AT 7310' AND TEST 7" CASING TO 2500 PSI FOR 30 MIN, NO LOSS, GOOD TEST. Pooh WITH PACKER. MU 18' JT OF 1-1/4" HYDRIL TBG AND OTIS DUMMY LOCATER SEAL ASSY. RIH WITH 1-1/4" STINGER AND DUMMY SEALS. TAG OTIS PERM PKR AT 7637'. RUN STINGER THRU TAILPIPE AND LOCATE DUMMY SEALS INTO PKR AT 7637'. CONT CIRCULATING WITH DUMMY SEALS JUST ABOVE PKR. CIRC BU. POOH LD 3-1/2 DP. DAILY:S146,977 CUM:$563,645 ETD:SO EFC:$893,645 PREP TO LOCATE INTO PKR 7"@ 8050' MW:ll.3 NACL/NABR SERVICE RIG. CONT POH AND LD DP. RIH WITH 3-1/2" COMPLETION INCL OTIS SEAL ASSY, AVA NIPPLE, STEEL BLAST JT, 4 BTC BLAST JOINTS WITH 110' OF CARBIDE RINGS, GLM, BAKER HB PKR AND PBR, GLM WITH CV, 3-1/2" 8RD AB MOD TBG WITH 9 1" GLMS WITH DUMMIES, AND SSSV. PERM PKR. DAILY:S28,147 CUM:$591,792 PREP TO LOCATE INTO OTIS 'WD' ETD:SO EFC:$921,792 JWell no. The above is correct AR3B-459-2-B I Number all daily well history forms consecutively as they are prepared for each well. IPage no. ARC(. iii and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Repert" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. /Accounting cost center code District County or Parish I State ARCO ALASKA INC. NORTH SLOPE Field I Lease or Unit I Well no. I I KUPARUK RIVER UNIT JTitle~%~])L: 25632 KRU 3F-13 Auth. or W.O. no. AK4648 I WORKOVER Operator I A.R.Co. W.I. I ARCO IDate55,8000 I Spudded or W.O. begun W.O. I 2/17/90 Complete record for each day reported Date and depth as of 8:00 a.m. 02/26/90 ( TD: 0 PB: 7962 SUPV:DB NORDIC fl j'l'otal number of wells (active or inactive) on this [cost center prior to plugging and I labandonment of this well I I Hour I Prior status if a W.O. 21100 RIG RELEASED @ 2200 HRS 7"@ 8050' MW: 0.0 DIESEL PREP TO STAB SEALS INTO OTIS PERM PKR. BREAK CIRC @ 2 BPM AND 150 PSI. STAB IN SEALS, VERIFY LOCATION BY LOST RETURNS. SPACE OUT 1' WITH 2-15' PUPS 1 FULL JT BELOW HGR. MU HANGER, TEST CONTROL LINE TO 5000 PSI, DRAIN STACK, LAND TBG, RILDS. RU OTIS SLICKLINE, PULL ISOLATION SLEEVE FROM AVA NIPPLE AND SET SLEEVE WITH PLUG. POH, RD OTIS. PRESSURE TBG TO 2500 PSI TO SET PKR, HOLD FOR 10 MIN. PRESSURE ANNULUS TO 1000 PSI FOR 10 MIN. PU AND SHEAR PBR @ 90K (24K OVER PULL). RELAND TBG, PRESSURE TEST SSSV OK. SET BPV, ND BOPS, NU TREE, TEST TREE TO 5000 PSI. TEST ANNULUS TO 2000 PSI, OK. REVERSE CIRC DIESEL TO DISPLACE BRINE. BLED ANNULUS, CV HOLDING OK. SET BPV, RD, RELEASE RIG AT 2200 HRS 2/25/90. MOVE RIG TO 3K-8. DAILY:S114,942 CUM:$706,734 ETD:S0 EFC:$1,036,734 Old TO Released rig Classifications (oil, gas, etc.) New TD PB Depth Date K nd of r g 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 is correct For form preparatio~'~nd O'~'strib~'""~'~ti~n, see Procedures M~'~us~, Section 10, Drilling, Pages 86 AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. jPage no. Dlvldofl of AIImltlcRlcMletdCompa~y /'~'SKA OIL AND GAS CONSERVATI~ CON,,.,SSION REPOHT OF SUNDRY WELL OPERATIONS 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 5. Type of Well: Development , X. Exploratory _ Stratigraphic _ Service 4. Location of well at surface 52' FSL, 158' FEL, Sec. 19, T12N, R9E, UM At top of productive interval 1302' FNL, 1496' FEL, Sec. 19, T12N, R9E, UM At effective depth 1027' FNL, 1590' FEL, Sec.19, T12N, R9E, UM At total depth 945' FNL, 1618' FEL, Sec. 19, T12N, R9E, UM 12. Present well condition summary Total Depth: Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate X Other _ 6. Datum elevation (DF or KB) feet 93' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3F-13 measured true vertical 81 08' feet Plugs (measured) 641 0' feet Effective depth: measured true vertical 7962' feet Junk (measured) 6289' feet Casing Length Structural Conductor 110' Surface 3 61 5' Intermediate Production 8 01 3' Liner Perforation depth: measured 9. Permit number~ 10. APl number 50-029-21499 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 7478'-7578', true vertical 5904'-5982', Tubing (size, grade, and measured depth 3 1/2", 9.3#, 7678' MD Size Cemented Measured depth True vertical depth 1 6" 331 Sx AS II 110' 110' 9 5/8" 1000 Sx PF "E" 3652' 3065' 400 Sx PF "C" 7" 305 Sx Class "G" 8 0 5 0' 6 3 6 3' 175 Sx PF "C" Packers and SSSV (type and measured depth) Camco TRDP SSSV @ 1795' MD, Otis RRH Pkr @ 7381' MD, Otis WD Pkr @ 7638' MD '~ ~'~/00 13. Stimulation or cement squeeze summary Perforated the A Sand Intervals treated (measured) 7721 '-7748' Treatment description including volumes used and final pressure 14. Reoresentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 28 21 18 1100 150 30 48 5 1100 150 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Water Injector _ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~]ned Title SR. OPERATIONS ENGINEER Date Form 10-404 Rev 05/17/89 SUBMIT IN DUPLICATE '~ARCO Alaska, In.~ {) Subsidiary of Atlantic Richfield Comi WELL - 3F~13 NTRA ~TO .EM^.KS JJ',3 IpaoT , I F,ELB- D~S~?CT ~TAT/E/ ~_ /'~, AZ. (,~, IOPERATION AT REPORT TIME WELL SERVICE REPORT IDAYS I, $~,c fiDO "772t ' I~oo - ~o ~v~~ry CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK (o~/~ Weat~ . T~p. Chill F.~ l Visibili~ Wind Vel. -- R~ 'F - 'F/ mil. I knot. AI~"gA OIL AND GAS CONSERVATION COMi JION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program_ Operation Shutdown _ Re-enter suspended well _ ~ Plugging _ Time extension _ Stimulate _ Pull tubing ~ Variance _ Perforate _ Other 2. Name of Operator 5. Type of Well: Development Exploratory Stratigraphic Service ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 52' FSL, 158' FEL, Sec. 19, T12N, R9E, UM At top of productive interval 1302' FNL, 1496' FEL, Sec. 19, T12N, R9E, UM At effective depth 1027' FNL, 1590' FEL, Sec.19, T12N, R9E, UM At total depth 945' FNL, 1618' FEL, Sec. 19, T12N, R9E, UM 81 0 8' feet 6 41 0' feet Present well condition summary Total Depth: measured true vertical 12. Effective depth: measured true vertical 6. Datum elevation (DF or KB) 93' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3F-13 9. Permit number 85-291 10. APl number 50-029-21 499 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Plugs (measured) None 7962' feet Junk (measured) None 6 2 8 9' feet Casing Length Size Structural Conductor 1 1 0' 1 6" Surface 361 5' 9 5/8" Intermediate Production 8 01 3' 7" Liner Perforation depth: Cemented Measured depth 331 Sx AS II 1 10' 1000 Sx PF "E" & 3652' 400 Sx Class PF "C" 305 Sx Class G & 8 05 0' 175 Sx PF "C" measured 7479'-7579', 7592'-7599', true vertical 5904'-5982', 5993'-5998', 7721'-7748', 7763'-7814' 6093'-6115', 6127'-61 68' Tubing (size, grade, and measured depth 3-1/2", 9.3#, J-55 tbg w/ tail @ 7662' Packers and SSSV (type and measured depth) Otis RRH pkr @ 7381', Otis WD Pkr @ 7638', Camco WRDP SSSV nipple @ 1795' 13. Attachments Description summary of proposal X Detailed operation program _ Proposed workover will remove and replace stuck SSSV. True vertical depth 110' 3065' 6363' 14. Estimated date for commencing operation March 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Service Suspended 7. I here_by certify that the foregoing is true and correct to the best of my knowledge. Si,ned "~~ ~ ~,--'%~ Title // 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 JApproval No.~i~} .~. I~ I _ Approved by the order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LONNIE c- , .,;~-i~ . Approved Copy Retur.ned Commissioner Date SUBMIT IN TRIPLICATE KUPARUK RIVER UNIT 3F-13 Workover Procedure SUMMARY: Kuparuk Well 3F-13 will be worked over to remove a wireline retrievable SSSV. The valve became stuck 15' below the surface during a routine removal procedure for wireline work on the well. A new tubing retrievable SSSV will be installed in the well during the workover. PROCEDURE: 1. Move in and rig up Nordic #1. 2. Pump kill pill and displace tubing and annulus with brine. 3. Nipple down tree and nipple up BOPE. Test same. 4. Pull out of hole with tubing. Remove SSSV. , Run in hole with completion string and new tubing retrievable SSSV. Locate into retrievable packer. 6. Pressure test annulus to 2500 psi. 7. Nipple down BOPE and install tree. 8. Displace annulus and tubing with diesel. 9. Secure well and release rig. 5000 PSI BOP STACK 6 5 4 3 I. i I ,, 1. 9 5/8" CASING HEAD 11" -3000 PSI FLANGE 2. 11" - 3000 PSI X 7 1/6" - 5000 PSI TUBING HEAD 3. 7 1/6" - 5000 PSI X 11" - 5000 PSI CROSS-OVER SPOOL 4. 11" -5000 PSI BLIND RAMS 5. 11" -5000 PSI PIPE RAMS 6. 11" -5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1 · CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH BRINE. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. 2. 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. 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 PREVENTER AND CLOSE PIPE RAMS.. 6. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 7. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 8. OPEN PIPE RAMS. BACKOFF RUNNING JOINT AND PUll OUT OF HOLE. 9. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 1 0. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF BRINE AND ALL VALVES ARE SET IN THE DRILLING POSITION. 1 1 . TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 1 3. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. 14. SIGN AND SEND TO DRIllING SUPERVISOR. 1 5. PERFORM COMP~ BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. NORDIC SRE 9/89 KUPARUK WELL 3F-13 APl #: 5(X)292149900 SPUD DATE: 12/1~ ADL LEASE: 25632 PERMIT #: COMPLETION DATE: 02/01/86 WORKOVER DATE: 85-291 ORIGINAL RKB:' SURFACE LOCATION: 5ZFSL,158'FEL, SEC19,T12N,RgE TOP OF KUPARUK: l:302'FNL,1496'FEL, SEClg,T12N,RgE TD LOCATION: 945'FNL,1618'FEL, SEC19,T12N,R9E All depl~ am MD-I:II<B ~ lop of equirm'te~t unlem~ oll'terwi~e held 93 TUBING SPOOL: 35 PAD ELEVATION: CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 1~" 62.~ Halo 110 3.$" 9.31 J-55 EUE 7662 LINER DETAILS SIZE WEIGHT GRADE TOP BTM TUBING JEWELRY ITEM TYPE ID DEPTH SSsv CAMCO TRDP-1A-SSA 2.812' 1795 SBR OTIS SBR 2.812' 7353 PKR OTIS RRH 7381 AVA AVA 'BPL' NIPPLE 7624 PKR OTIS WD 7638 NOC.-~ CAMCO 'D' NIPPLE 2.25' 7653 SHROUT CAMCO 7661 WELLTYPE: 56 GAS' UFT and FLOW INFORMATION VALVE STN DEPTH MANDREL SIZE 1 247~ M F.J:ILA 3341:10 1.0" 2 40~ MERLATMFR) 1.0" 3 4704 MERLA TMI:K) 1.0' 4 507~ MERLA TMPO 1.0' 5 5454 MERLA TMPO 1.0" 6 5826 MERLA TMPO 1.0' 7 6202 MERLA TMPO 1.0" 8 6571 MERLA TMPO 1.0' 9 6~4S MERLA TMPO 1.0' 10 7314 OTIS I. BX 1.5' 11 742:3 MERLA TMPD 1.0' PERFORATION DATA INTERVAL ZONE FT SPF PHASE 7479-7579 100 12 120 7592-7599 7 4 7763-7814 51 4 PORT SIZE COMMENTS SOS 5' CSG GUN SOS 4' CSG GUN SOS 4' CSG GUN MISC. DATA DESCRIPTION KICK OFF POINT: MAX HOLE ANGLE: HOLE ANGLE THRU KUP: LAST TAG DATE: RATHOLE: FISH/OB,5'TRUGTION: dee DEPTH 7962 6196 ii REVISION DATE: 03/05/86 REASON: ARCO Alaska, Inc. Date: February 23, 1989 Transmittal #: 7432 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. 3F-15 3N-18 3F-01 3F-02 3F-09 3F-06 3F-10 3F-11 3F-15 3F-14 3N-10 3N-06 3N-09 31-01 3N-11 3N-14 3F-08 3N-01 3N-14 3F-15 3F--15 3F-13 3F-15 1B-05 1E-25 3B-11 3A-03 3H-01 2Z-19 31-12 1 E-08 3M-18 Kupaurk Fluid Level Re Kupaurk Fluid Level Re Kupaurk Fluid Level Re Kupaurk Fluid Level Re Kupaurk Fluid Level Re Kupaurk Fluid Level Re Kupaurk Fluid Level Re Kupaurk Fluid Level Re Kupaurk Fluid Level Re Kupaurk Fluid Level Re Kupaurk Fluid Level Re Kupaurk Fluid Level Re Kupaurk Fluid Level Re Kupaurk Fluid Level Re Kupaurk Fluid Level Re Kupaurk Fluid Level Re Kupaurk Fluid Level Re Kupaurk Fluid Level Re Kupaurk Fluid Level Re Kupaurk Fluid Level Re Kuparuk Well )ort 3ort 3ort 3ort 3oft 3ort 3ort 3orr 3orr 3ort 3ort 3ort 3ort 3ort 3ort 3ort 3ort 3ort 3ort 3orr Pressure Report Kuparuk Well Pressure Report Bottom-Hole Pressure Survey Kuapruk Well Pressure Report Kuparuk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report 12-03-87 12-18-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 5-18-87 5-22-87 5-21-87 4-24-87 4-15-87 4-13-87 4-14-87 4-20-87 12-04-87 2-02-89 8-27-87 8-27-87 8-25-87 2-2O-89 2-19-89 2-20-89 2-21-89 2-21-89 2-2O-89 2-2O-89 2-19-89 2-15-89 Casing Casing Tubing Tubing Tubing Tubing .Tubing Tubing Tubing Tubing Casing Casing Casing Casing Cas, Casing Casing Casing Casing Tubing Sand 'C' Sand 'C' BHP Amerada Casin Casing Casing Casing Tubing Tubi. Casin~ Casin~ 3 H- 01 Kupaurk Fluid Level Report 2-15-89 Casing 3 El- 1 3 Kupaurk Fluid Level Report 2-17-89 Casing I E-29 Kupaurk Fluid Level Report 2-15-89 Casing 1C-05 Kupaurk Fluid Level Report 2-18-89 Casing/Tubing 3 M - 1 '7 Kupaurk Fluid Level Report 2-16-89 Casing 2Z-20 Kupaurk Fluid Level Report 2-18-89 Tubing 30-1 0 Kupaurk Fluid Level Report 2-16-89 Casing 31-1 2 Kupaurk Fluid Level Report 2-20-89 Tubing 3 H- 1 0 BHP Report 2-13-89 BHP Receipt Acknowledged' - .......................... Date' - ........... DISTRIBUTION: D&M _ State of Alaska SAPC .. Unocal Mobil Chevron ARCO Alaska, Inc. Date: February 17, 1989 Transmittal #: 7429 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 F- 1 I Sub-Surface Pressure Survey 1 0 - 0 6 - 8 8 3 H - 1 2 Kuparuk Well Pressure Report 8 - 2 9 ~ 8 8 3 O- 0 7 Kuparuk Well Pressure Report I 2 - 2 0 - 8 8 3 F- 1 0 Kuparuk Well Pressure Report 8 - 2 9 - 8 7 3 F- 0 6 Kuparuk Well Pressure Report 8 - 2 9 - 8 7 3 F- 0 2 Kuparuk Well Pressure Report 8 - 2 9 - 8 9 3 F- 1 6 Kuparuk Well Pressure Report 8 - 1 7 - 8 7 3 F- 1 6 Kuparuk Well Pressure Report 8 - 1 7 - 8 7 3 F- 1 I Kuparuk Well Pressure Report 8 - 2 9 - 8 7 3 F- 0 4 Kuparuk Well Pressure Report 6 - 2 6 - 8 7 3 F- 0 5 KUparuk Well Pressure Report 1 2- 1 2 - 8 8 3 F- 1 3 Kuparuk Well Pressure Report 1 2- 3 1 - 8 8 3 N- 1 0 Kuparuk Well Pressure Report 6 - 1 1 - 8 7 3 N- 1 0 Kuparuk Well Pressure Report 6 - 1 1 - 8 7 3 N - 0 4 Kuparuk Well Pressure Report 9 - 0 1 - 8 7 3 N - 0 9 Kuapruk Fluid Level Report 5 - 0 4 - 8 7 3 O- 1 4 Kuparuk Fluid Level Report 2 - 1 3 - 8 9 3 O- 1 4 Kuparuk Fluid Level Report 2 - 1 0 - 8 9 3 M - 1 8 Kuparuk Fluid Level Report 2 - 1 0 - 8 9 3 F- 1 6 Kuparuk Fluid Level Report 6 - 0 5 - 8 7 3 F- 1 3 Kuparuk Fluid Level Report 6 - 0 9 - 8 7 3 F- 1 3 Kuparuk Fluid Level Report 6 - 1 8 - 8 7 3 F- 1 3 Kuparuk Fluid Level Report 6 - 1 6 - 8 7 3 F- 1 3 Kuparuk Fluid Level Report 6 - 21 - 8 7 3 F- 0 8 Kuparuk Fluid Level Report 5 - 0 8 - 8 7 3 F- 1 6 Kuparuk Fluid Level Report 8 - 1 8 - 8 7 3 F - 1 6 Kuparuk Fluid Level Report 8 - 2 4 - 8 7 3 F- 1 3 Kuparuk Fluid Level Report 6 - 0 5 - 8 7 3 F- 1 6 Kuparuk Fluid Level Report 6 - 2 / 3 - 8 7 3 F- 1 6 Kuparuk Fluid Level Report 8 - 5 - 8 7 3 F- 1 6 Kuparuk Fluid Level Report 6 - 5 - 8 7 3 F- 1 4 Kuparuk Fluid Level Report 9 - 8 - 8 7 #7-889 Amerada Sand 'A' Amerada Amerada Amerada Sand 'A' Sand 'A' Amerada Sand 'A' ' Both Sands Both Sands Sand 'A' Casing Casing Casing Casing Tubing Casing Casing ~ OJ~~orls, CorrliTljs,sjoi] Casing A~ch0rage Tubing Casing Casing 3F-14 3F-06 3F-14 3F-08 3F-14 3F-09 3F-05 3F-09 3F-06 3F-05 3N-10 3N-10 3N-11 3N-10 3N-05 3N-04 3N-13 3N-11 3N-18 3N-17 3N-07 3N-15 3N-05 3N-09 3N-04 3N-14 3N-08 3N-06 3N-02 3N~10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-07 3N~01 3N-04 3N-04 3N-09 3N-10 Receipt Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Ku :)aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku :~aruk Fluid Ku 3aruk Fluid Ku :)aruk Fluid Ku'3aruk Fluid Acknowledged: Level Level Level Level Level Level Level Leyel Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Report Report Report Report Report Report Report Report Re ~ort Re ~ort Re ~ort Re ~ort Re~ort Re ~ort Re ~ort Re ~ort Re ~ort Re~ort Re ~ort Re ~ort Re aort Re'~ort Re aort Re ~ort Re )ort Report Report Report Report Report Report Report Report Report Report Report 'Report Report Report Report Report Report 9-1 I-87 12-06-86 9-11-87 10-11-87 9-16-87 4-11-88 4-08-88 4-01 -88 3-26-88 1 -30-88 10-12-87 10-15-87 10-28-87 10-28-87 10-28-87 10-28-87 3-19-87 9-12-87 9-10-98 9-10-87 9-10-87 9-12-87 9-08-87 9-01 -87 9-01 -87 9-06-87 9-06-87 9-06-87 9-06-87 6-01 -87 5-31 -87 6-03-87 6-06-87 .6-08-87 6-09-87 6-25 -87 4-17-87 4-18-87 6-17-87 6-20-87 5-07-87 8-24-87 ........................... Date' Casing Tubing Casing Tubing Casing Cas,ng Casing Casing Casing Casing Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Casing Alaska Oil & Gas Cons. ....... ¢r~c~Orage DISTRIBUTION: D&M State of Alaska - Mobil Chevron Unocal SAPC ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510=0360 Telephone 907 276 1215 January 10, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. Well Action Anticipated Start Date 3F-1 3 Perforate January, 1989 2 W- 0 1 Chemical Sqz. January, 1989 If you have any questions, please call me at 265-6840. Sincerely, G. B. Smallwood Senior Operations Engineer GBS :kjr Attachments CC: J. Gruber ATO 1478 M. L. Hagood ATO 1120 S. P. Twiggs ATO 1130 KOE1.4-9 .. '~"~ ~ncnu!age ' ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AU-~ OIL AND GAS CONSERVATION COMM,,..,iON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well_ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate X Other 2. Name of Operator ARCO Alaska, In~. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 52' FSL, 158' FEL, Sec. 19, T12N, R9E, UM At top of productive interval 1302' FNL, 1496' FEL, Sec. 19, T12N, R9E, UM At effective depth 1027' FNL, 1590' FEL, Sec.19, T12N, R9E, UM At total depth 945' FNL, 1618' FEL, Sec. 19, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 81 08' feet Plugs (measured) 641 O' feet 6. Datum elevation (DF or KB) 93' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3F-13 9. Permit number 85-291 10. APl number 5o-029-21499 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 7962' feet Junk (measured) 6 2 8 9' feet Casing Length Structural Conductor 110' Surface 3 61 5' Intermediate Production 8 01 3' Liner Perforation depth: measured 7478'-7578', true vertical 5904'-5982', Tubing (size, grade, and measured depth 3 1/2", 9.3#, 7678' MD Packers and SSSV (type and measured depth) Size Cemented 1 6" 331 Sx AS II 9 5/8" 1000 Sx PF "E" 400 Sx PF "C" 7" 305 Sx Class "G" 175 Sx PF "C" 7592'-7599', 7763'-7814' 5993'-5998', 6127'-6168' Measured depth True vertical depth 110' 110' 3652' 3O65' 8050' 6363' Camco TRDP SSSV @ 1795' MD, Otis RRH Pkr @ 7381' MD, Otis WD Pkr @ 7638' MD 13. Attachments Description summary of proposal X_~ Adding perforations to a new interval. Detailed operation program BOP sketch 14. Estimated date for commencing operation January 15, 1089 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas ~ Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test _ Subsequent form require ORIGINAL SIGNED BY Approved by the order of the Comm~J'~IE O. SMITH Form 10-403 Rev 06/15/88 Approved Copy Returned Commissioner IAppr~;~,al No. SUBMIT IN TRIPLICATE Kuparuk Well 3F-11 Application for Sundry Approval January 5, 1989 , The estimated BHP is 2860 psig at -6200' SS based on data taken 11/22/88. 2. No workover fluids will be required for perforating. . There will be a lubricator with a 5000 psig rated BOP used during the perforating work (see the attached diagram). Oil & Gas Cons. 3 1. SOO0 PS1 7" W~LLHF. AD CONNECTOR FLANGE 2. 5000 PS1 WIRELIN£ RAMS (VARIABLE SIZE) 3. .5000 PSI 4 1/6" LUBRICATOR 4. 5000 PS1 4 1/6" FLOW TUBE PACK-OFF bi ] REL ] NE BOP E(~U ] PHENT Through Tubing Perforating Procedure Kuparuk Well 3F-13 o . , . , , , . , 10. Shut in well. MIRU perforating unit and pressure test equipment to 2500 psig. RIH with gun assembly and tie in depths using the following Schlumberger logs: DIL/SFL dated 12/19/85 CET dated 1/7/86 Open well at choke for a 300 psig underbalanced condition and retie in depths. Once well is retied in, perforate the following interval' SAND DEPTH ~MD RKB~ SHOT DENSITY A3 7721' - 7748' 4SPF (inclusive) ~MENTS Use magnetic centralizers to offset charges approx. 45° from center. After charges are detonated, check for increases in well head pressure and shut well in to prevent flowing debris up hole. POOH with gun assembly. Pick up new gun assembly and repeat steps 3 through 5 to achieve a total shot density of 8 SPF. **** NOTE .... On the second perforating run, the magnetic centralizers MUST be set up with the charges offset 45° to the OPPOSITE side of center as set up for the first gun run to achieve two separate rows of 4 SPF perforations for an effective 8 SPF, 90° "V" phasing. POOH with second gun assembly. RDMO perforating unit. Open well to CPF and obtain a 12 hour well test after well has stabilized for 24 hours. ARCO Alaska, Inc. Date: January 6, 1989 Transmittal #: 7396 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 K - 0 6 Kuparuk Fluid Level Report I - 0 3 - 8 8 Casing 3 F- 1 3 Kuparuk Well Pressue Report I 2 - 3 1 - 8 8 Receipt Acknowledged: DISTRIBUTION: State of Alaska D&M .' '~" AIa~.~i:&,, ~chorageGas Co'n-s'.'CS~Fs'siort Unocal SAPC Chevron Mobil ARCO Alaska, Inc.,. Date: October 14, 1988 Transmittal #: 7316 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 H - 1 2 Sub-Surface Pressure Survey 9 - 2 2 - 8 8 PBU 3 H - 1 2 Sub-Surface Pressure Survey 9 - 2 2 - 8 8 PBU 3 H - 1 7 Sub-Surface Pressure Survey 9 - 2 2 - 8 8 PBU 3 H - 2 2 Bottom-Hole Pressure Survey 8 - 0 7- 8 8 PBU 2 C- 1 1 Kuparuk Fluid Level Report 1 0 - 0 6 - 8 8 Casing 3 H - 1 4 Kuparuk Fluid Level Report 1 0- 0 7- 8 8 Tubing 3 F- 1 3 Kuparuk Fluid Level Report 1 0 - 0 7 - 8 8 Casing 3 C - 1 6 Kuparuk Fluid Level Report 1 0 - 0 7 - 8 8 Casing 3 K - 0 6 Kuparuk Fluid Level Report 1 0 - 1 1 - 8 8 Casing Receipt Acknowledged: DISTRIBUTION' D&M ~TState~of Alaska: Chevron Unocal Mobil. SAPC · ARCO Alaska, Inc. Date' September 7, 1988 Transmittal #: 7285 3 . 3 3 '3 3 ,_,,3 1 3 1 1 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. F-13 Ku K-18 Ku B-13 Ku Q-15 Ku N-08A Ku H-1 4 Ku E-1 2 Ku K-14 Ku 1-03 Ku Y-06 Ku Y-07 Ku 3aruk Fluid Level Report 8- 2 7- 8 8 3aruk Fluid Level Report 8 - 2 7 - 8 8 3aruk Fluid Level Report 8 - 2 6 - 8 8 3aruk Fluid Level Report 8 - 2 7- 8 8 3aruk Fluid Level Report 8 - 2 6- 8 8 3aruk Fluid Level Report 8 - 2 6 - 8 8 3aruk Fluid Level Report 8 - 2 6 - 8 8 :)aruk Fluid Level Report 8 - 2 6 - 8 8 3aruk Fluid Level Report 8 - 2 6 - 8 8 )aruk Well Pressure Report 8 - 2 6 - 8 8 )aruk Well Pressure Report 8 - 2 6 - 8 8 Casing Tubing Casing Casing Casing Casing Casing Casing Casing Both Sands Sand 'A' Receipt Acknowledged' DISTRIBUTION' D&M State of Alaska Chevron Unocal Mobil SAPC ARCO Alaska, Inc~... Post Offic~ x 100360 Anchorage, ,.,iaska 99510-0360 Telephone 907 276 1215 Date: February.26, 1987 Transmittal # 5926 ---RETURN TO: ARCO Alaska, Inc. Attn: 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. 3Q-8 CBL 2-16-87 6195-9264 2H-6 CET 1-17-86 7400-8873 2H-5 CET 1-16-86 6525-7959 3F-13 CET 1-7-86 6160-7920 3F-12 CET 1-23-86 6946-7250 2H-8 CET 1-1-86 8000-8650 2H-7 CET 1-1-86 6800-7938 3F-14 CET 1-7-86 4700-6760 3K-5 CET 7-16-86 6988-7990 3K-3 CET 7-14-86 7595-8800 3K-4 CET 7-14-86 7793-8787 3F-12 CET 1-7-86 6050-7416 _ NSK Drilling State (+ sepia) BPAE Chevron SAPC Mobil Unocal Vault (film) ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfieldCompany STATE OF ALASKA ~ "'- ALASKA oiL AND GAS CONSERVATION CO,vYMISSION W LL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well 1. Status of Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator, 7. Permit Number ARCO Alaska, ~nc, 85-291 3. Address 8. APl Number P, 0, Box 100360, Anchorage, AK 99510 50- 029-21499 4. Location of well at surface 9. Unit or Lease Name 52' FSL, 158' FEL, Sec.19, T12N, R9E, UM Kuparuk River Unit 10. Well Number At Top Producing Interval 1302' FNL, 1496' FEL, Sec.19, T12N, R9E, UM 3F-13 11. Field and Pool At Total Depth 945' FNL, 1618' FEL, Sec.19, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.} 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 93' RKB ADL 25632 ALK 2565 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore I 16. No. of Completions 1 2/1 2/85 I 2/18/85 1 2/20/85* N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8108'MD,6410'TVD 7962 'MD ,6289 'TVD YES~ NO [] 1811 feet MDI 1500' (Approx) 22. Type Electric or Other Logs Run D IL/GR/SP/SFL, FDC/CNL, Cal, CET/GR/CCL, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16:: bZ.~CF H-4~U 5urt 110' 24" 331 SX AS II 9-5/8" 36.0# J-55 Surf 3652' 12-1/4" 1000 sx PF "E" & 400 sx PF "C" Performed top job w/65 ,~x PF "C" 7" 26.0# J-55 Surf _ 8050' 8-1/2" 305 sx Class G & 175 sx PF "C" 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) 7762' - 7813' w/4 spf 3-1/2" 7678' 7397' & 7654' 7591' - 7598' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7478' - 7578' w/12 spf DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27.N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cofr) Press. 24-HOUR RATF 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE '"~ ' Form 10-407 * NOTE: Tubing was run & well peforated 2/1/86. WCl/055 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate GEOLOGIC MAR'~:~S "'FORMATION TESTS NAME include interval tested; press0:~e data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7474' 5900' N/A Base Kuparuk C 7581' 5983' Top Kuparuk A 7706' 6081 ' Base Kuparuk A 7868' 6212' 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~ ~~/~ TitleAss°ciate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 AtlanticRichfieldCompany Daily Well History-Final Report Instl~Jction$: Prepare and submit the "Final Report" on the first Wednesday after allowaole has been assigned or well is Plugged, Abandoned, or Sold. "Final Ropol't" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test dala in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District Alaska Field Kuparuk River Auth. or W.O. no. AFE AK0511 Nordic 1 Operator ARCO Alaska, Inc. Spudded or W.O. begun Comp let e 1/31/86 Oate and depth as of 8:00 a.m. 2/01/86 thru 2/02/86 ICounty or Parish Lease or Unit Title Accounting cost center code State North Slope Borough Alaska J Well no. ADL 25632 3F-13 Completion API 50-029-21499 A.R.Co. W.I. 56.24% Date 1/30/86 Complete record for each day reported Iotal number of wells (active or inactive) on this i est center prior to plugging and bandonment of this well our IPrior status if a W.O. 0900 hrs. I 7" @ 8050' 7962' PBTD, Rn'g 3½" CA 9.9 ppg NaC1/NaBr Accept ri~ @ 0900 hrs, 1/30/86. ND tree, NU & tst BOPE. RU WL, perf w/4" gun, 4 SPF, 90° phasing f/7762'-7813' & 7591'-7598', w/5" gun, 12 SPF, 120° phasing f/7478'-7578'. Rn 6-i/8" gage ring/JB, would not pass 5100'. Rn 5.937" gage ring/JB, POH. RU WL, set WD pkr @ 7638' WLM. RU & rn 3½" CA. 7"'@ 8050' 7922' W~M PBTD, RR 6.8 ppg Diesel Rn 239 jts, 3½", 9.3#, J-55 EUE 8RD IPC tbg w/ WD Pkr @ 7654', "D" Nipple @ 7669', RRH pkr @ 7397', TT @ 7678', SSSV @ 1811'. Set RRH pkr, tst tbg, shear SBR. Att to tst pkr by press'g ann to 2500 psi; ann leaking. POOH w/3½" tbg. RIH, retrv pkr. RU & re-rn 3½" compl, set RRH pkr, tst tbg, tst pkr w/2500 psi, tst SSSV. ND BOPE, NU & tst tree. Displ well to diesel. Tst orifice vlv. RR @ 2015 hrs, 2/1/86. Old TD I New TO PB Depth 7 9 2 2 ' W'LM PB'~ZD I Released rig ~ Date Kind of rig 2015 hrs. I 2/1/86 Rotary Classifications (oil, gas. etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test lime Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature For form preparation and c~stribution, see Procedures Manual, Section 10, Drilling, Pages 86 an(t 87. Drilling Superintendent $UB-~URFACE DIRECTIONAL ~URVEY ~UIDANCE ~]ONTINUOUS ~OOL Company ARCO ALASKA INCORPORATED Well Name _ WELL 3F-13 (52'FSL, 158' FEL, S19, T12N, R9E) Field/Location ,, ~owAR~, NORT~ ,SLOPE, ALASKA Job Reference No. 71175 SARBER Date 24-JAN-1986 Computed By: OGDEN GCT DIRECTI]N.~L SURVEY 'USTJMER LISTIN:S ~RC] ~L~SK6~ 3~-13 ~U)~RJK NORTw SLOP=,~L~$K& METH]]S ~= C]~PJT~TIOq T]DL LgS~TI]N: T6NSENTIAL- !NTERO2,~TI]N: LINEAR ~ERTIC6L SECTI2N: ~ORIE. gIST. SURVEY D~T$: O7-J~N-'~5 ~V:q~SEJ D:VI~TI]N PR3J:CTSD gNTJ a T~RG=T ~ZZMJTH 6'I~UTq 15 COM, PUTATI ]~ ARCO ~L~SKA, INC. 3=-13 N]RTH SLOPE,AL~SK~ DARE: 24-J~N-85 INTEROOL~TED VALJES FOR 5VEN 100 FEEt COJRS5 VERTICAL OOJLEG 2EV!4TION AZIMUTH lEG ~IN 0:~ MIN ~ET OE~/iO~ ME~SURE] VERTIC4L VERTICAL 2EPT~ OEPTt DEPTH 0 0 N 0 O ~ 0.00 O.OO 0 5 $ 6~ ~ W 0.05 3.36 0 ~5 $ ~O ZT N 0.05 3.07 0 ZO N 55 15 W 0.25 9.29 0 29 N 57 3~ ~ 0.~2 0.12 0 25 N 56 35 W 1.43 3.11 0 16 N 65 12 W 1.87 O.l~ 0 37 N 72 3~ W 2,!1 1,52 2 56 N 25 15 W 5,00 1,28 5 0 N 17 49 ~ 11,48 9 12 15 17 2O ,?.3 26 31 34 23 N 11 5 W 2~,31 3,37 ~5 N 9 21 W 43,24 3,2~ 25 N 15 lO W 57,71 ;!,97 1~ N 21 3~ W 95.80 Z.~l 4 N 25 57 W 127,15 3,64 27 ~ 28 40 ~ 163,32 3,42 26 N 25 17 W 20~,67 3,61 12 N 1~ 1 W 250,19 18 N I1 13 W 299.42 34 N 9 5~ ~ 353.77 3.0~ 0.00 0.00 -9~.00 100.00 100.00 7.00 ZO0.O0 200.00 107.00 300.00 300.00 207.00 ¢DO.O0 400,00 307.00 500,00 ~99,~9 ~05,99 $~0o00 599.99 505,99 ?00.00 699.99 605.99 ~00,00 7'99.93 705.93 gO0.O0 899,71 805,71 lO30,~O 998,~5 905,85 1100,00 1097,~2 100~,02 1200.00 1193,94 1100,94 1300.00 1289.~9 1195.89 l~O0.O0 13B4.71 1291.T1 1500.00 1477.56 138~.56 1500.00 1568.07 1475.07 l?O0.~ 1656.87 1563.8? 1~00.00 1743.86 1650.86 1900,00 1827,$2 1734,62 37 39 42 43 44 45 46 47 48 48 47 47 46 45 45 45 0 N 13 48 W 412.10 3.43 22 N 17 51 W 473.89 3.24 50 N 29 58 W 535.87 2.42 59 N 21 4~ W 605.07 9.67 ~0 q 21 3~ W 57~.1~ 1.0~ ~3 N 20 55 ~ 7~3,43 1.35 39 N 20 2~ W .~1~.12 3.71 54 N 1~ 4~ W ~85.00 1,69 ~5 N 19 15 W 959,43 0.67 8 N la 5¢ W 1033,50 0,4~ 13 N 18 25 W 1107,97 15 N 18 1 W 1132.43 8 N 17 50 W 1255.90 0.20 ~8 N 17 29 W 1331,22 4 N 17 21 W 1404,~5 1,00 12 N 17 13 W 1477,51 3,98 27 N 17 12 W 1549,10 0.57 Z1 N 17 1~ W 1520.08 0.65 ~9 N 17 38 ~ 1591.52 3.35 ~ N 17 52 W 1763,30 0,27 zooo.oo zoo.oo z oo.oo Z~O0oO0 2209.57 Z11M.S7 oo.oo oo.oo 3100.00 Z$]85- ?~ 2595.74 3Z~0.~0 Z?~.38 2662.38 3300.00 Z$ZZ.ZO Z?Zg. ZO 3~00.00 2889.?~ 3500.00 2958.~5 2865.¢5 3600.00 30~8.Z0 2935.~0 3?00.00 3098.59 3005.5~ 3800.00 3168.50 3075.50 3900.00 3238.35 3145.05 S~TE 3: SdR~EY: 07-J~q-S6 ,"AE A SU R =3 RECTANSULAq C3"~OI',~T'E'.~ qDqlZ. qS~Td/SOOTH Ef, ST/W:ST DIST. ~ [-i E: T F:~T F: :T 0.30 q 0.00 E 0.00 0.06 S O.~l W 0.42 0,46 "Q 1..~4 W 1.52 O,:~O ,q 2,1~ W 0.32 1,22 N 2,66 W Z. )3 1,33 ~4 3,!~ ~ 3.40 3.~6 '4 4,~1 W 6,25 3,93 q 7,26 W 1~.30 22,37 N 10,43 W 4i,15 ~ 13,45 W 55,13 N IB,5'~ W 67.72 91.77 N 27,6! W 120,79 '~ 40,~2 W 127,38 153,50 N 57,6) W 164,38 191,00 ".~ 77,93 W 206,25 233.45 'q 95.28 W 252.14 281.21 N 107.23 W 335.S2 N 116.43 ~ 354.67 392 · ~+31. 513, 575. 70~, 770, 53.2, 903, 111~. 1190. 1261. 1331. l~O1. 1~37. 1505. 1574, ~ZZqUT'H "lin 2~ N 128,2B W ~12,63 55 q 145,25 N '~7~,'~4 06 N 167.15 W .53).60 92 N 192. I~. 'N 6~7~ .1g 51 '~ 217.57 'd 675.60 'q 1~, a7 ' ~9 q 242,94 d 745.!i 'q 1~ 1 ) 97 q 267.95 '~,1 516.25 70 N 292.85 W 3:3~.36 15 M 317.37 W ;52.00 )9 N 365-60 W 1110.37 :33 N 388.90 W 1185.44 77 N 411.85 W 1Z59.93 55 N 434,46 W 133~.35 97 ~ 456.53 N 1~+03.03 &O N 478.10 W 1~80.71 BZN 499.35 W 1~52.33 57 N 520.36 W 87 ~ 541.~3 30 N 563.7~ W 1765.67 =T 3=-13 KJ:~ARJK N3RTH SLOPE,ALaSKa, C3MPUT~TI3N D~TE: Z4-J~N-SS D¢.T~ 3= SJ'RYEY: 07-JAN-85 5NGiqEER: S. Z 93,03 =T INTErPOLaTED VALUES FOR EVEN 100 FEET TRUE SJB-SEA 4EASURED VERTICAL VERTIOAL 3EPTH DEPTH OEP~H 4000.00 3307.14 321~.14 4100.00 3375.79 3282,79 4200.00 3444.~8 3351.48 4300.00 3515.16 3422.16 4~OO.O0 3557.~7 3495.87 4500.00 3651.~9 3568.89 ¢500.00 3735.88 3642.88 4700.00 3809.90 3715.90 4~00.00 3383.51 3790.61 4~00.00 3956.88 3863.38 5000.00 4029.97 3935.97 5100.00 %103.12 ~010.12 5200.00 4176.~3 ~083.43 5300.00 4249.~ 4155.88 5~00.00 ~323.~8 4230.48 5~30.03 4397.44 $30~.44 5500.00 ~71.B1 4373.81 5?00.00 ~548.59 ~453.69 5800.00 4622.02 ~529.02 5900.00 ~597.~3 ~603.83 6000.00 4774.~3 ~6~1.43 6100.00 ~851.00 4758.00 6200.00 ~928.38 ~835.08 6300.00 5005.56 ~91Z.56 6~00.00 5082.91 ~989.91 6500.00 5159.79 5065.79 6630.00 5235,~T 5142.87 6700,00 5311,72 5218.72 5~00,00 5387.34 5294.34 6900.00 5~62~56 5369.56 ..,.,-,;, ~... ~,. ~ . . '~'"~ ~h~ ",L~' '. 7000.00 ' ~ '~ 54~.86 7100.00 ,i~'~ 5520.51 7200.00 56B9~$0 5596.60 7300.03 5766.18 557].1~ 7~00.03 58,3.02 5750.02 7500.00 5920.12 5827.12 T600.O0 5997.?7 590~.7? 7700.00 5073.,0 59~3.40 7800.005156.265063.26 7900.03 $237.88 51~.8~ CDJRSE VERTICAL DOSLEG RECTANS DEVIATION AZIMUTH SECTION SEVERITY NORTH/S 3EG ~IN DES MIN FEET DEG/lO0 FSET 46 31 N 17 52 W 1835.50 46 ~,0 N 17 59 ~ 1908.13 3.1~ 46 11 N 18 1:2 W 1980.70 43 52 N 19 F+3.W 2051.25 1.27 ~2 ~4 N 19 25 W 2119,67 1.63 42 10 N lB 53 W Z185.74 0.20 42 16 N 18 48 W 2253.87 0.41 42 ZO N 18 %2 W 2320.97 O.ZO 42 ~4 N 18 42 W 2388.42 O.~ 42 57 N 18 45 W Z~55,33 0.23 43 3 N 18 53 W Z524.43 0.18 42 55 N 18 53 W Z592.46 3.18 42 ~T N 18 52 W 2660.33 42 ~0 N 1~ 5~ J !728,03 0.17 42 29 N lB 5B W 2795.58 3.3~ 42 $ N 18 47 W Z~62.'74 0.35 41 ;6 N 18 40 W ~929.45 0.41 41 16 N 18 41 W 2995.61 0.39 40 57 N 18 45 W 3061.23 40 19 N 18 4] W ~1Z6.31 39 59 N 18 53 N 3190.45 39 50 N 19 0 N 3254.53 3.52 39 1~ N 19 ~ W 3318.18 0.31 3'9 14 N 19 4 N 33'31.25 0.43 40 12 N 19 2 W 3508.28 0.72 40 33 N 19 17 W 3573.01 3.37 40 ~5 N 19 29 W 3537,97 0,2~ 41 3 N 19 29 W 3703,22 ~,35 41 12 N 19 30 W 3768,92 41 4 N I9 30 W 3834,51 0,39 40 39 N 19 40 W 3~99,72 ~,37 40 1I N 19 42 N 3954,39 0,55 39 55 N 19 32 W %028,4B J,16 39 %0 N 19 2~ W %092,30 0,27 39 23 N 19 7 N ~155,$2 0,65 33 39 N 19 5 W ~21~.57 3.79 37 33 N 18 58 W ~280,30 1.33 36 19 N 13 &~ W %3~D.35 1,83 34 22 N 18 43 W ~398.01 3.00 ULA~ CG]ROIq~TES H]RIZ. OUTH E~ST/NEST DIST. F~':ET 1743,39 N 585,01 W 1~3~,'95 1~12,28 '4 50~,37 W 1)11,57 1331,36 N 630,'~3 W 1984,34 1948,23 2012,82 ,i 577,20 W 2123,59 2075,3'7 N 699,15 N 2190,92 2140.34 N 720.38 W 225:3.23 2203.71 q 742.50 W 23.25,&3 2267.73 N 764.15 W 2393.01 2332.17 'q 735.01 W 2361.J6 2396,7 2525,5 2353.~ 2717.5 2780.9 Z~3.5 2967.? 302,~. 5 3089,3 3149,5 ~209,3 3289,2 ]329,7 3391.3 3~5Z.~ 351~,i 3575.2 3533.3 3 '599 · 9 3761.0 3~21.5 3~81,9 3942.0 4301.5 4053.9 4116.) ~171.5 808,01 W 2529,31 330,13 W 2597,:~9 352,11 W 2565,51 874,05 W 2733,3.5 396.03 W 2~0!.37 917,77 W 286~,37 939,22 W 2935,22 950.45 W 3001.50 981.5~+ W 3067.26 1002.54 W 3132.43 1023,33 W 31~5,77 104~,20 W 3251,03 1065,J1 w 332~,. 79 1035,5.~ W 33:~.~.01 1106.'33 ~ 3351.3~ 1127,15 W 35!5.3~ 11~8.42 W 3~{2.23 1170.10 W 3545.3,~ 1191.9~ W 3710.31 1213.93 W 3775.70 1235.92 W 3~42.4~ 1257.82 W 3907,39 ~2~9,~4 N 3372,77 1301.33 W 4337.05 1322.6~ W 4101.~6 1343.73 W 4164.75 136~,26 W 4227,75 1384.49 W 4239.5~ 1403. }3 N 4349.72 1~22.34 W 4~}7.a~ DEPARTURE ~ZlqJTq N 19 39 .~ q 1~ 39 ~ '~ 13 39 w N 15 39 ~' AqCD &L~S~A, INC. 3F-13 NDRTH SLDPE,~L&,SK~ C2MPUT&TIDN D&~E: '?4-J&N-85 INTErPOLaTED VAL3ES FDR EVEN 100 ~ET O: TRUE SJB-S=A ME&SUREO VERTICAL VERTI'~L ]EPTH DEPTH DEO~H CDURSE VERTI:S~L DOGLEG 2EVI&TI2~ ,~ZIMUTq S=CTION SEVERITY WIN DEG MI~ FEET g~/lO3 34 Z2 N 18 ~0 W %~5~.34 O.O0 34 ?Z N 18 ~ W %51~.6~ 3.03 34 Z2 N 13 40 '~ ~515.1g 0.00 80OO.OO $320.~2 5227.42 81OO.OO $402.97 5309.97 8108,O~ 6409.57 5315.57 3&T~ .)~- SJRVEY: O7-J~-j5 KELLY ~d S'~IqG 3 RE'TAN,StJLAR C3OROI~AT~S qDR!l. ND?TH/S']~JTq E&STIWEST DIST. ¢':: 5 T F E E T ~- E = T &Z25.15 N 1440.41 W 4463,93 ~Z7'~.63 q 145S.47 W ~Z~2.~'$ q 1459.92 W ~ZI'qdTH =1' CgMPUT&TIDN D&TE: 24-J~N-~5 73 0''~ FT ~NTS~POL~TED VALJES FOR EYE~ 1003 :SET 3= TRUE SJB-SE~ MEASURED VERTICAL VERTID~L DEPTH DEPTq DEPTH 0.00 0.00 -93.00 lOOO.O0 998.85 905.85 2000.00 1908.74 1815.74 3000.00 2622.12 2529.12 4000.00 3307.14 321~.14 5D~0.~9 4029.~7 3935.97 6000.00 ~7T~.~3 ~$81.43 ?O00.O0 5537,96 5444.86 8000,00 5320.~Z 52Z7,42 8108.00 5409.57 6315.57 ME~SJ~ CDJRSE VErTICaL 905LEG DEVI&TIDN AZIMUTH SECTIgN SEVERITY DEG ~IN DE& MI~ ;EET D':G/IO] 0 0 N 0 0 E 0.00 0.00 9 ~3 N 11 5 ~ 24.31 3.37 37 0 N 13 48 W 412.10 3.43 48 13 N 18 25 W 1107.97 0.4~ 46 31 N 17 52 W i~35,50 0.43 43 3 N 18 53 W Z524,43 39 59 N 1~ 53 W 3190.46 0.38 41 4 N 19 30 W 3334.51 0.3~ 34. 22 N 18 40 W %454.34 0.00 34 22 ~ 13 40 ~ ~515.19 0.00 22. 392. 1348. 1743. 2395. 3328. 353:3. ~225. E9 3IJL,~R CSOR S31JTq r O0 N O. 37 N 19. 24 q 12:9. ?9 q 365. O~9 N 585. 78 q 803. 55 N 1023. 33 N 1235, 15 '4 14~+'3. 90 N 1459. /WEST OIST. ¥ F~ET 09 E 3. 40 W 24. Z:~ W '~12. 50 w 1110. O1 W 1B33. 31 W 252g. 33 W 3190, 92 W 3B42. 4! W 4N53. 92 W 3EP~RTUR~ ~ZZ~UTq '}='~ ':'% 4~C0 4L~S(4, I~C. 3:-13 KJPARUK NgRTH SLOPE,ALaSKA C~MPUT'~TI3N D~T~: 24-J~N-B5 INTERPOL&TED VALUES FOR EVEN 100 FE:T O; TRUE SUB-SEA ME~SURE9 VERTICAL VERTICAL DEPTH DEPT4 DEOTH 0,00 0,00 -93,00 93,00 '93,00 9,00 193,33 193,00 lOD,O0 293.00 293.00 200.00 393,00 393,00 303,00 4~3.0! ¢93.00 400.00 593.01 593,00 500,00 593.01 593.00 600.00 793.06 793.00 703.00 ~93.27 893.00 ~OO.O0 ~94.07 993.00 900.00 1095.89 1093.00 lO00.O0 1199.02 1193.00 llOO.O0 1303.25 1293.00 1209.00 1408.84 1393.90 1300.00 1516.92 1493.00 1400.00 1527.92 1593.00 1500.00 1741.14 1693.00 1500,00 1~58.17 1793.00 1700.00 1980.40 1893.00 1800.00 2107.35 1993.00 1900.00 2240.32 2093.00 2003.00 2377,15 2193.00 2100.00 2515.52 2293.00 2203.00 2659.37 2393.00 2300.00 2906.50 2693.00 2956.28 2593,00 2500.00 3105,40 2693.00 2603.00 3256.38 2793,00 2700.00 3434,72 2893.00 2800.00 3592.05 , : ,-' '00 3000.00 3935.18 3193.00 3100.00 3979.46 3293.00 3200.00 4125.07 3393.00 3300.00 4269.13 3493.00 3409.00 4406.97 3593.00 3500.00 45¢2.01 3693.00 3603.00 4577.14 3793.00 3700.00 4912.79 3893.00 3803.00 S IJ 5 -.S .E & CDJR.SE VERTICAL DOGLEG DEVIATION AZIMUTH SECTION SEVERitY NA~TH/ ]EG ~IN DES MI~ FEET DEG~IO0 0 0 N 0 0 E 0.00 0.00 0 6 S 63 20 W 0.06 O.&~ 0 15 S 79 10 N 0.05 O.lO 0 18 N 57 30 W 0.22 0.30 0 Z9 N 57 27 ~ 0.78 3.13 0 26 N 56 34 W 1.39 3.12 0 16 N 54 40 W 1.85 0.17 0 31 ,N 77 5 W 2.08 1.22 2 51 N 25 57 W ~+,65 1,39 4 ~+6 N 18 17 W 10.94 3.75 11 N 11 29 W 23.35 3.5'9 27 N 9 15 W 42.38 3.32 Z4 N 15 5 W 67.45 2.9~ 2.2 N 21 43 W 95.75 2.40 !2 N 25 18 W 130.16 3.55 2 N 28 40 W 170.03 3.43 0 N 24 19 W' 217.01 ~.03 13 N 14 43 W 269,84 ~.71 24 N 9 33 W 330.41 3.32 31 N 12 59 W 400.43 3.49 9 12 15 17 20 24 27 29 33 36 33 N 18 5 W 478.59 3.33 Z9 N 21 35 W 555.79 1.32 18 N 21 44 W 658.55 0.6'~ 54 N £0 ~':) ,4 755.03 18 N 20 5 W .~55.59 !.57 $8 N 19 15 ,~ 95~.30 0.56 10 N 15 39 ~ 1075.41 0.49 14 N !{ ~ ~ 11~7.20 0.!5 3 N 17 40 W 1298.35 2.64 1 N 17 21 W 1409.32 1.05 %6 N 17 15 W 1513.21 18 N 17 lB W 1514.43 0.61 54 N 17 45 W 1716.75 0.33 25 N 17 52 W 1{20.61 0.01 ~D N 18 2 W 1926.34 3.15 32 N 19 17 W 2029.83 58 N 19 21 W 212~.37 1.55 15 ~ 18 59 W 2214.91 ].21 17 N 18 43 R Z305.61 0.19 %7 N 13 ~l W ~397.07 ~TE 3= SURVEY: 37-J~'~-'7'5 qELLY !~US~.I~G ELi'.-'VarZA'.~: )3.30 39 42 43 44 46 47 4,8 43 48 47 45 45 46 44 42 42 42 42 g!JL&R C33RgIq&Tt.~.:S q]qIZ. SSUTH EAST/NEST gIST. 3.30 N 0,00 E 0.00 9.35 N 0.07 W 0.09 0,05 S 9.33 W 0.33 0.32 N 0.79 W 0.79 3,43 ~ 1.39 W !.'~6 0,~7 N 2.09 W 2.27 1.20 N 2,53 W 2.~]9 1,31 N 3,12 W 3,39 3,53 N ~.75 W 5.93 ~.~2 N 7.09 W 11.79 21.~ 40.30 64.36 '92.56 123.55 159.55 202.31 252.32 311.55 3~0.~5 ~56. 53.3. 524. 715. 510. 912. 1318. 112~. 1Z30. 1335. 1~35. 1532. 1529, 1728, 1~29. 1927. 2017. 2103. 21{9. 2275. 10.21 W 23.74 13.33 W 42.~4 15.47 W 57.~5 27.97 W 95.7) 41. 79 N 130.~2 51.~3 W 170.)2 ~3.31 W 21:'.:3,79 100,75 W 271.70 112.53 W 331.57 125.55 W 12 N 146.75 N ~79,14 Z7 ~1 177.05 W 566.54 9'9 N 211.74 W 55'3. 59 39 ,',J 2.~+7.0) W 756.~5 9~ N 282,74 W '~5.~.3a 76 ~ 318,93 W 96~. 59 ]7 N 355.22 W 1373.25 37 '~ 390.37 'J 1190.21 76 ~ 424,6~ W 130!.~7 28 N 457.53 W 1$11.%9 52 N 488.69 W 1516,~2 Z7 N 518.68 W 1517.63 ~3 N 549.51 W 1720.07 99 q 581.43 W 1824.05 62 >4 614.01 W 1929.~0 95 N 646.75 W 2~33.57 27 N 678.76 W 212~.~0 39 N 708.2~ W 2219.15 13 ~ 737.55 W 2310.04 34 M 766.94 W 2~01.~9 9EP&RT aZi~JT GE3 MI ~J R ~ FT HRCO HLASK4, INC. 3F-13 KJPHRU.~ NORTH SLOPE,ALaSKA CO~PUT&T'I3N D&TE: 24- J ~N -35 ZNTERPOL&TEO V~LUES FOR EVEN 100 ::'iT 3F TRUE SJB-SEH MEASURE] VERTICAL VERTIC&L DEPTH DEPTq DEOTH 4~49.39 3993.00 3900.00 5086,17 4093,00 ~003.00 5222,59 4193,00 4100,00 5358,51 4293,00 %200,00 5494,01 43'93,00 4300,00 5528.42 4493.00 4400.00 5761.52 4593.00 %500.00 5893.5% 4693.00 %603.00 6024.27 4793.00 4700.00 6154,50 4893,~0 480],00 6283.,80 4993.00 4900.00 5413.06 5093.00 5000.00 6543.59 5193.00 5100.00 6575,28 5293.00 520~.00 6B07.50 5393.00 5300.00 6~0,~2 5493.00 5~OO,OO 7072.96 5593.00 5500.00 7204.46 5693.00 5503.00 7334.95 5793.00 5700.00 7464.$5 5893.00 5800.00 CDJRSE VERTICAL 3OSLEG 3EV'I&TION aZIMJTq SECTION SEVERITY 3EG ~IN DEG MIN FEET DES/lO0 43 2 N 18 48 W 2489,94 0,18 42 5.5 N 18 53 W 25:33,06 3,17 42 ~5 N 18 52 W Z675.65 0.25 42 35 N 18 54 W 2767,64 0,12 42 8 N 1~ 47 W Z85~.73 3.35 41 38 N 18 40 W 294B.35 0.77 41 4 N 18 42 J 3035.02 0.21 40 ~2 N 18 ~9 W 3122.19 0.83 40 3 N 18 5~ W 3205.04 0,19 39 31 N 19 % ~ 3289.44 0.55 39 13 N 19 5 W, 3371.04 0.37 39 27 N 18 59 W 3452.74 0.51 40 25 N 19 7 W 3535.44 0.43 40 %2 N 19 28 N 3521.~$ 0.37 &l 5 N 19 29 W 3709,13 2,37 41 9 N 19 31 W 3795,42 0,2~ 40 44 N 19 35 W 35~2,15 0,51 40 9 N 19 42 W 3957,26 0.52 39 50 N 19 29 W ~050.83 0,33 39 31 N 19 15 W ~133.51 38 ~2 N 19 5 N ~21~,~6 0,73 37 18 N 18 55 W ~292.99 !.08 35 22 N 18 32 W ~355.92 Z.41 34 22 N 13 ~3 W ~35.6~ 34 22 q 18 40 W %503.~8 9.00 34 12 N 1~ 4~ W %515.1'9 7593.89 5993.00 5903.00 7720.91 5093.00 5000.00 7845.37 5193.00 5100,00 7956.7~ 5293,00 5200,30 8387.93 5393.00 5303.00 8108,00 5409,57 5315,57 DaTE ] ~: SJ~',"¢ =Y: 07-J~'..~- '~5 K=LLY 3US'il;',J]~_~-LL:Va~';',3,'~', · 5 95,00 SUS-S=a 2354, 2~52. 2540, 2527, 2 71 ..~. 27'9~3. 2932, 2 ~63. 3943. 31~. 3199. 3277, 3355. 3518, 3501. 35~3, 3763. 3]42. 3929, 3)97. %J71. 41~2. ~+ 2,37 . ~272. ~232. O~PTH 333 TH T 17 N ¢ ,] '4 7,3 N ',54 33 '~ 37 ~1 '~ 10 :.1 27 N ~2 N 33 N 72 N 7O N :99 '~ 3 ~ N 17 ',1 ~ 0 "4 C33RDI'N~T:S :"t3~iZ. ']=O~qTJRE EaST/W=ST DIST. aZIqUT~ 7'96.5 .~27.0 857.0 886.9 945 . 2 973.4 1001.2 102'3.3 1055 . 5 10~2,3 1109.0 1135.3 llSg,T 1193.5 1222,3 1251.9 1280,7 130~,~ 1335,3 1363,0 13~8.5 14lg.~ 1434.& 1456.2 145~.9 2%94.75 2580.95 2773,05 2{6~.35 2~54,!,6 ~04'~ 30 312{,B5 3212. B9 3377, ? !~ 35~3.56 3.52 ~ · 3715.74 3't03.29 3B90.23 3~75,65 a35:~.a7 ~142,3B '= T ARCO /~LASKA, INC. 3F-13 KUPARUK N3RTH SL~E~L~SK~ M~RKER TOP KUPARUK C BASE KUPAR~K C TOP KU~&RUK & SASE KUP~RUK 6 CO~PUT~TI3~ D~TE: Z4-,J&N-85 INTERPOLATED VALJES F:DR CHOSEN H3RIZ]NS qE4SUREO DEPTH TVD BELOW KB FROM KB 7~7G.00 5900.06 7581.00 598Z.~5 7706.00 5081.15 7868.00 5211.51 T~62.00 5289.05 BLOB.00 5409.57 K:LLY ~USqI.qG ELEV~TI31'.;' E~IG£NEER: G. S~R~R 52' :St, SJB-SE~ 5~07.35 5~5'9.96 593~.15 $11~.51 5196.~6 $316.57 1 5 8 ' SJRF~CE ,3C2TIJN ~T R~CT~N~SUL~R '~']RD'IN~TES NOqTH/S]UTH ~&ST/R~S'T 133.3.Z~ ~ 1353.3~ W 1385.57 W 1¢15.5} ~ 1~33.54 W 145',~.?Z '4 =T ~RCO ~L4SKA, 3~-13 KJ~RJK N3RTH SLOP~,~L~S~ COMPUTATID~ DATE: Z4-J~N-$5 D'~TE DF SLJRV~Y: OT-J~q.'~5 ' MARKER TOP KUD~RUK 3 B4SE KUPARUK C TOP KUP'~RUK 4 BASE KJDARUK 4 PBTD TD ~**~*~*~ STRATISRAPSIC ~E~SD"RED DEPTH BELOW KB 747a.00 7581.00 7706.00 7868.00 7962.00 8108.00 S U ;4M.4 R Y FROM 3 R I; I N '= TVD KB 5900.06 5982.95 5081 .!5 5211.51 6289.0.5 54, 0 9.57 52 ' FSL, SJB-SEZX 5~07.36 51 '~ .5 · 35 5215.57 1 58 ' FEL, REC S ,J R S.'LC T RTH D53 154 20A, 252 FAC~ _.3C~lYlOq !~, TlZN, RDE, U~ /SDUTq E~ST/WEST PIN4L WELL LOC4TIDN ~T TO: TRJE ~EASURED VERTICAL V~RTI3~L DEPTH DEPTH DEPTH SlOB.OD 5a09.57 5315.57 HDRIZ3NT~L. ]ED~RTURE DISTANCE &ZI~!UTH FEET DES MIN ~5Z~.~9 ~ 18 ~9 SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY WELL ARCO ALASKA 3F-l~' I NC FIELD KUPARUK COUNTRY USA RUN ONE DATE LOOOEO REFERENCE 0000"71 ] 7S WELL 3F- 13 (52' FSL, 158' FEL, S]/'~',,T12N, RgE) HORIZONTAL PROJECTION 40130 10OO -lO00 SOUTH -zooo -4000 NEST SCt:IL£ = 1/1000 IN/FT ......... II :~[ ~J J ~ I i ! J i i ,-:~ ...................... ~ ............ = : - ~-~. ~..?.~.-~., i~ ~ ~ ~ - ~ ~ ;ii~ I ~ ~ -~ {~ ~:i ~-~' ~i ?--+.4--4-H.~ itl. i ~j!ii ~i ~i~r~H-4---~--.-H.~ i i ~ ~ ~~-+~--~~/~+F~H-.-bH-.b~-FF-F-H--+--~-.-~H ...... F~H...,-.-H..++. ! j J ~ i i ~ ~.~-i &~! ! ! ! ~ J ! ! ! ~ ~ ~ ! ! -.~-~-.~~..--~...~-~,-~--.~--~.--,~4-.~--.-+..,..+--? Fi!! i I ~ ; :iii ; i [ ~ . : : : : i ~ H I ; ! ~ : ! i ~ i I i ; i [ : : ~ I t : : ~ ~ : : : : i ~ : : ~ ~ : ~ ~ ~ i~ ~ : ~ ,ill ~-~?~.%?"m'~'?"?'-Yt~ i ~ii iii ii i ~"~'TTTT-~"'~"~T'~-'T"'-Y'Y'T'-T"--~-T-"T'~'T'"YT"Y'T ....... t"' J ~ -'~-H-~'4'"~'"+'+~-H'-~'~H '1 -.~.~+, ~4~-- -~-~-~--~;~-~.....~..~-.~ ..... ~:~¢~~ ~ ~ i-¢b~i?.4-¢-~4-.¢-~ ...... ~-..;...bb-;...~...~.H..~-~...~-~ ...... ~-~...;-:...~.+ ~.-.;.. -.4-~-.;-.-M-¢.&-~.~-~} .... bF-bb-.-..M..44.., b}-~4-4~.-~ ~..4 ...... b+4.-.b .-.H-4-~ ...... H-++--b+-~.--H ..... ~-¢.-H.- 4-..*-;-i ...... H-..; ...... .--* ......... _~&~&.L.C _LZ.L.L.....LLZ.L_.-;...L.~4- .... ~ ~ ~ ~zl~ ~ ~ t~.~ ~_;~L~;_~_.4 z~, ;~ :.~. ~.~; ..... I...;..L:...; ..... ;_L;_.;..~..~..L;...: ...... L.,...:...~.I...;.: -~Y~Y--YWY'Y'"F"?~'~'YT'F"F"~ ....... ~-F"Y'Y' ~ ~ ~ ~ ~ ~ ~ ~ : ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ , ~ ~ ~ : ~ ~ : ~ - ~ : ~ : ' : : ~ : - 1 -~W",~"r'r'T"F' -9000 -2000 - 1000 0 1000 2000 :~000 4000 WELL 3F-13 (52'FSL. 158' FEL. S19,~'~12N, R9E) ~-'", YERTICAL PROJECTION M_no0 :3000 4000 5000 0 ~ i i ~ [ :. ~ ~ ~ ~ d .: .: ~ :: ~ ~ ~ ! i i ~ i i i ! ! ~ ! ~_ ~ ~ ~.:.;-Ht-HHb. ~...mt-: ?"-..*-±-t-t-'--T-T'~'f-J-T'?-':-: ~ .: =. : :' :. : -: ~ ~ t .1. [ : .: i ~ i ] _.: :- : : -: .3..-~.~--:.--i--~...i--i--,..4-~-.-.r.?-t---'r--?~---'~-r-~''~ :, i ~ ~ i ~: ~-." i i ii i ~-'?_ ~ ] '.L~ ~] ! ! i ~--' ! ~- ~-~---?~"'~f~i~'":~J ..l~: ~'"~-: '~'T'Y"I"Y''7''Y''-'l+-'l : ~ ~ I ~ ~ ~ : : :. ~--~--~ . .-",-~-?'W?~.+ ~. i ?~--:: :~ ] ] ?~L, ~ ] : : : : : : : : : : · ' -.i-..i--4--4-]---,b-~--~-.~..-~'.?'-'t"'?'?- ..'-T-f=-?.. :~-' : : : ! : : :~ :---: :---:-~r-:-: : 4- -~'-~-';-4-4-4-4-;--~--H~--P-~-: P+-+"~"?'"'t-:-'F'F'Y'?-t'''t-'?'''~-?''Y'YT : : : : : : : :.L.:...L.: -.~ ~ ~ : ~ : : = ~r--:-= ?'m'C"F"'I~ ..+-'f ~ T ~~/:::: .... 4-~ ~-.L.Z~-__.~__~.~__~..+..l.~...~--~.~'.l r'"'--'?'"?'"? ..... "'"?"?'? ..... ?'"?'"T'":' ": ? ? f ~ ~ :" : :: ] : : : : :-.~-41~..-.-;-;--~---;*-.1-¥-+-~--'?-.'??~'.. *,.-T"Y'~---.."--t-.. 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FT't"'i"['] I :i i i:: :i:i ,. :L::: ..... ...... :---:---:...:...j-.-:--.:-..:.--: ...... ....... {::: Ii.i:i ..LLLLi..i..LL-i .... L-i--.~--.{---.l-bb'.--P:---'..~{: b~:. FHb-H--f+-+..---f'f--?-t-'"-f"r-:"?"r't--':.:7:t: :1 :::::::::::::::::::::::::::::::::::::::::::::::::::::::: ..... -T'.-'T-:-F .~i: ?--K :. :_:_i :..Li..i...~ ...... ~ ....... :...~.~.~-=~...~-~--~-...~.-~-¥+."-~.~+-P.~-~...~:...?..:.~..:...F...~...:...r..~...~..r..?: t : : : : : ~ :...L :...: ..... -..~ ........ :..: ....... · -'r~? ..... ~'T-T ....... T ? i : : i: : .:'.. :..L.b.~_~_L_L_L.L.;_~_,...;.._p4_~-~.-;...:--H~..+...-:...,,-*.---: ...... f--+-+.-,..-..-?:--.:--, ....... t"-:"-?'": ..... : . ? : ~ ] : : : : ~ ~ ~-L~.4.J .... i...L.;-~.L..~-..~...~..-~ ........ :---~---~--~.--Ht-+-+--.--+--~-+--t---~---~'r-'r"j":-.?'r-'T'--,"T-'r":":: .... : : : : I : : : : , ~ i i : : : : : : , J : , .~ ............ ~ .................... :---~ ~ ? ~ .... I .... t- ............. ~ ................................................................ :---. ........ .4-;.=-~---j-~4-: ....... H--+-H---~--':-"--+'-~ .... :y'f--:"~'--r'~'"?~--':-'Fr'i:K::"::.T.:::::::[::::::::::.'....LL~.-.L-~.-:--.~-..:.-.~-.!--.L!---b-b-H-:..~..-~ ....... ~---:-':-"~ .......... :" :'":'"~"'? ....... : ' _.~...~_~_~.+..-.z4._-: .......... H-.'.~--+--j-H?-t--~ ..... :'"~'-"'"~"'~-'?'"'~":"? .... T'":' =~-. 'T L T- :': : I i :.: Z..i :. ~ ..~-..~ ...... L.:...~...:.J...=--:-..?..-H~--.?.~ ........ + .......... ~"~ .................. ! ..... : ~ : : ~ : : ~ .... L._L_L-L._~..-L-:-..~----> : .' : '--: -H"~'~- '--r-?~'-""-,-'?-'~-"?'-'t-- - -'-~--'T' - · ; : · : : ~ : : : i : = / ' , , ~ ~ ' : ' ' '"-".:-':'-:":'":7-':-:'-' ~ ~!: ~:i~ : :11~lqoo~:: :~ : :~,-: ~/ ~ ..- ..... 6OOO 344. PROJECTION ON VERTICAL PLANE 344. - 1B4. SCi:II_ED 1N YERTICRL OEPTHS HORIZ $CRLE = 1/1000 [N/FT for ~imely eomp~innce ~h our regulnL~ong. , · , · · .. Required Well'llieto£y Samples /Iud Log Ch£~'De~e£iptton Registered Survey Plat Inclination gurvey Dtrectional.~urvey Drill Stem tesl~. Reporta Production ~est Reports Log Run Digitized Data _ ARCO Alaska, Inc..~/'~'' Post Office. x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 13, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Well Completion Reports Dear Mr. Chatterton- Enclosed are Well Completion Reports and gyroscopic surveys for the following wells' 3F-14 3F-13 I have not yet received the Well Histories (completion details). When I do, I will forward copies to you. If you have any questions, please call me at 263-4944. Sincerely, / · Gruber Associate Engineer JG/tw GRU13/L119 Enclosures E B 2 1 19BG .Anchorage ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA '~-" ALASKA rjtL AND GAS CONSERVATION CO,~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-291 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21499 4. Location of well at surface 9. Unit or Lease Name 52' FSL, 158' FEL, Sec.19, T12N, R9E, UN -'[0CATIONS= Kuparuk River Unit At Top Producing Interval ~ VEP, JF/I,~D 10. Well Number 1302' FNL, 1496' FEL, Sec.19, T12N, R9E, UN Surf. ~,,~ 3F-13 At Total Depth B.H. ~ 11. Field and Pool -~ · 945' FNL~ 1618' FEL, Sec.19~ T12N~ R9E~ UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 93' RKB ADL 25632 ALK 2565 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 1~. Water Depth, if offshore J 16. No. of Completions 1 2/1 2/85 1 2/18/85 1 2/20/85* N/A feet MSLJ 1 17. Total Depth (MD+TVD) 18. PIug Back Depth (M~D) 19. DirectionaISurvey J 20. Depth where SSSV set I 21. Thickness of Permafrost 8108'HD~6410'TVD 7962'MD~6289'TVD YES ~X NO ~J 1811 feet MDI 1500' (Approx~ 22. Type Electric or Other Logs Run D II /~R/~P/&FI FD~/CNI Ca 1 ~FT/R~/~I RCT 23. ' ' - ' ' ' ' CA~NG, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 1~- ~ ~ N-&fl c,,~ ~ ~h- Cc~d'dc~" ~cpc~ ~ct )", .......... Porformed top 7" 26,0~ -J-55 R.,rf 8050' 8-1/2" 305 sx C!ass 6 & !75 s~. PF "C" 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) 7762' - 7813' w/4 spf ~_~/~,,¢ .,- ~,,~,~ ~o~,,¢¢, ~"-~=,.,,~¢~ 7591' - 7598' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7478' - 7578' w/12 spf DEPTH INTERVAL(MD) AMOUNT& KINDOF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OILRATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE ~ E B 2 1 19BG ~as~ 0il & 6as Cons. ~0mmmS,0n'' ~chorage Form 10-407 * NOTE: Tubing was run & welEo~ig~L~do~/F]~F~RSE SiS~MP3/WC72 Submit in duplicate Rev. 7-1-80 29. ', 30. ._ 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 7474' 5900' ! N/A Base Kuparuk C 7581' 5983' Top Kuparuk A 7706' 6081'I Base Kuparuk A -7868' 6212' · 31. LIS-I- OF ATTACHMENTS Well History.. Gyroscopic Survey f~ · .R? I hnrnhv n~rtifv th2t thn fnrnnninn it trim 2nd nnrrpnt in thR hp~t nf mv knowIpdo~ 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 n°t 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 ADDENDUM WELL: 12/27/85 1/09/86 3F-13 Arctic Pak well w/175 bbls PF "C" followed by 57 bbls Arctic Pak. ' Rn CET/GR/CCL f/7920'-6160'. Rn GCT gyro f/7900'-40'. RErFI\IED MAR 1 7 198,6 Alaska Oil & Gas Cons. Commission A~chor3rje Drilling ~Uperintendent ARCO Oil and.Gas Company ~) Well History - Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded'or workovsr operations are started. Daily work prior to SpUdding should be summarized on the form giving inclusive dates only. District Alaska Fietd Kuparuk River Auth. or W.O. no. AFEAK-511 Doyen 9 ICounty. parish or borough North Slope Borough Lease or Unit ADL 25632 Title DrilI Istete Alaska JWell no. 3F-13 AP1 50-029-21499 Operator ARCO Alaska, Inc. Spudded or W.O, begun- Spudded JDate 12/12/85 IH°ur Date and depth aa of 8:00 a.m,. - 12/13/85- 12/14/85 thru 12/16/85 12/17/85 12/18/85 Complete record for each day reported ARCO W.I. Prior status if a W.O. 56.24% 0945 hrs. 16" @ 110' 2747', (2637'), Drlg Wt. 9.6, PV 15, YP 25, PH 9.0, WL 13.2, Sol 9' Accept ri~ @ 0700 hfs, 12/12/85. NU diverter sy$, Spud well @ 0945 hfs, 12/12/85. Drl to 717', Navi-Drl & surv 12¼" hole to 2747'. 717', Assumed vertical 794', 2.0°, N30-1/4W, 794 TVD, 1.58 VS, 1N,. 1W 1169', 14.5°, N10-3/4W, 1164 TVD, 55 VS, 54N, 12W 1540', 24.7°, N28-3/4W, 1514 TVD, 174 VS, 165N, 57W 1793', 30.7°, N10-3/4W, 1738 TVD, 291VS, 275N, 97W 9-5/8" @ 3652' 6951', (4204'), Navi-Drl Wt. 9.3+, PV 8, YP 4, PH 8.5, WL 7.6, Sol 6 Drl to 3670', short t~ip, circ well cln, TOH. RU & rn 92 ]ts, 9-5/8", 36#, J-55 BTC csg w/FS @ 3652', FC @ 3570'. Cmt w/1000 sx PF "E", followed by 400 sx PF "C". Displ using rig pmps, bump plug. CIP @ 0420 hrs,, 12/14/85. ND diverter sys. Perform 65 sx PF "C" top job. TIH, tst csg to 2000 psi. DO cmt & flt equip + new hole to 3680'. Conduct formation tst to 12.8 ppg EMW. Navi-Drl & surv 8½" hole to 6951'. 2585', 45.4°, N17-3/4W, 2343 TVD, 797 VS, 760N, 245W 3088', 48.2°, N16-3/4W, 2684 TVD, 1167 VS, IlliN, 359W 3620', 45.4°, N14-3/4W, 3046 TVD, 1556 VS; 1486N, 468W 4320', 43.4°, N18-3/4W, 3535 TVD, 2056 VS, 1965N, 612W 4763', 42.5°, N16-3/4W, 3862 TVD, 2355 VS, 2250N, 702W 5389', 42.6°, N17-3/4W, 4322 TVD, 2779 VS, 2655N, 830W 6012', 40.0~, N16-3/4W, 4791TVD, 3190 VS, 3046N, 953W 6643', 40.6°, N17-3/4W, 5276 TVD, 3593 VS, 3431N, 1075W 9-5/8" @ 3652' 7732', (781'), Drlg Wt. 9.8, PV 15, YP 10, PH 8.5, WL 5.8, Sol 11 Navi-Drl & surv 8½" hole to 7539', rotary drl to 7732'. 6955', 41.1°, N17-3/4W, 5276 TVD, 3593 VS, 3431N, 1075W 7432', 49.6°, N17-3/4°, 5757 TVD, 3999 VS, 3819N, 1199W 7449', 39.50, N17-3/4°, 5879 TVD, 4101VS, 3916N, 1230W 9-5/8" @ 3652' 8078', (346'), Drlg Wt. 9.9, PV 16, YP 12, PH 9.5, WL 5.6, Sol 11 Drl to 7806', short trip to 5891', C&C, TOH. unable to log all of "A" sand, POH, RD Schl. 8078'. ;t; ',17 C E IV E D FEB 2 1 1986 Alaska Oi~ & Gas {;o~b. ~ummission Anchorage RU Schl, RIH, RIH, drl to The above is correct Signature _ For form prsparetion l~d distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. 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 I County or Parish Alaska I North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25632 Auth. or W.O. no. ~Title AFE AK0511 I Drill Accounting State cost center code Alaska no. 3F-13 Doyon 9 API 50-029-21499 Operator I A.R.Co. W.I. ARco Alaska, Inc. I 56.24% Spudded or W.O. begun [ Date Spudded [ 12/12/85 Complete record for each day reported Date and depth as of 8:00 a.m. 12/19/85 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. · 0945 hrs. 12/20/85 12/21/85 9-5/8" @ 3652' 8108', (30'), Logging Wt. 9.9, PV 13, YP 9, PH 9.5, WL 5.2, Sol 11 Drl to 8108', 10 std short trip, circ, POH. RU Schl, rn DIL/SFL/SP/GR f/8093'-3650', cont w/GR to 1700. Rn FDC/CNL f/8067'-7440'. Rn CAL f/TD to 3652' . 8062', 32.0°, N15.75W, 6385.5 TVD, 4475.7 VS, 4275.6N, 1335.2W 9-5/8" @ 3652' 8108', (0'), Prep to cmt Wt. 9.9, PV 10, YP 8, PH 9.5, WL 5.6, Sol 11 RD Schl. Make cond'g trip. RU & rn 186 its + mkr jr, 7", 26#, J-55 BTC csg w/FC @ 7962', FS @ 8050'. Circ& recip pipe prior to cmt'g. 7" @ 8050' 8108' TD, 7962' PBTD, RR 9.9 ppg NaC1 Cmt 7" w/305 sx C1 "G" w/.6% FDP-C344 & .25% HR-7. CIP @ 0911 hfs, 12/20/85. Chg rams to 5". ND BOPE. Instl pack-off & 000 rs, E IV I New TO OIdTO I 8108' Tm Released rigJ Date 1300 hrs. 12/2'0/85 Classifications (oil, gas, etc.) . Type completi?_.,~nn (single, dual, etc.) 0il Sing le Producing method FEB 2 1 1986 AII~sK~ Oil & Gas rjul~, uommission J PB Depth Anchorage 7962 ' PBTD I Kind of rig [ota~f Flowing Official resemoir name(s) Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature J Date ITitle For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Alaska, Inc. Post Oftice Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 14, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are the December monthly reports for the following wells- 1A-7 2H-6 3A-13 3F-12 3J-11 4-29 L2-29 1A-13 2H-7 3A-14 3F-13 3J-12 16-15 L3-5 1A-14 2H-8 3A-15 3F-14 4-23 16-19 L3-19 1H-4 2H-9 3A-16 3F-15 4-24 16-20 LS-I~ 1H-8 2X-8 3F-11 3J-10 4-27 L2-21 If you have any questions, please call me at 263-4944. Sincerely, .. Gruber Associate Engineer JG/tw GRU13/L05 Enclosures RECEIVED JAN i 1986 Nuka 011 & Gas Cons. ~'nmiss/0n Am~ra~ STATE OF ALASKA -. ALASKAC ANDGAS CONSERVATION COt ,.IlSSION -M NTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilli.'~g (N~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-291 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21499 4. Location of Well atsurface 52' FSL, 158' FEL, Sec.19, T12N, R9E, UN 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 93' RKB ADL 25632 ALK 2565 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 3F-13 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of. December , 19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0945 hrs, 12/12/85. Drld 12-1/4" hole to 3670'. Ran, cmtd, & tstd 9-5/8" csg. Prld 8-1/2" hole to 8108'TD (12/18/85). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 7962'. Secured well & RR ~ 1300 hrs, 12/20/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set (~ 110'. Conductor report not yet received. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 3652'. Cmtd w/lO00 sx PF "E" & 400 sx PF "C". Top job performed w/65 sx PF "C". 7" 26.0#/ft J-55, BTC csg w/shoe @ 8050' Cmtd w/305 sx Class G & 175 sx PF "C" 14. Coring resume and brief description None 15. Logs run and depth where run DIL/GR/SP/SFL f/8099' - 7440'; OR to 1700' FDC/CNL f/8099' - 7440', 4750' - 4550' Cal f/8099' - 3652' RECEIVED JAN 1 4 1986 1 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED (~.-¢ ~ /~~ TITLE Associate Engineer DATE /'7'4~ NOTE--Report c~ this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~404 TEMP/MR04 Submit in duplicate ARCO Alaska, Inc. Post Office °. Anchor~ ge, Alas,.., 99510 Telephone 907 277 5637 P~TL~RN TO: Date: 01-07-86 Transmittal No: 5504 · ~JlCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. BOX 100360 '~mchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of. this transmittal. Open Hole LIS Tapes ,Plus Listingsr-One copy of each Schl · 12-2s-8s Run #1 3A-16 12-26-85 Run ~,1 1890 0-9142 ~3F-13 12-19-85 Run 91 1688.5-8112.0-'"~-D.ZF..F.~ -,~'-~J:'~/'7-/~--2~//_-P,. 3F-14 12-24-85 Run #1 1700 0-6966 0-~.'~z~.~'3.~-....~--gPF~/g-/~Z~d -~~ Alaska Oil & Ga-~ Cons. Oommiss!on Anch3ra[!e Receipt Ac.'~owiedged: -'B. Currier BP~ Chevron D &M Date: DISTRIBUTION Drilling W. Pasher Geolog~L.Johnston ~on Mobil NSK Drill Clerk Phillips Oil J. 7~ thmell Union K. Tulin/Vault November 29, 1985 1-~. jeffrey B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3F-13 ARCO Alaska, Inc. Permit No. 85-291 Sur. Loc. 52'FSL, 158'FEL, Sec. 19, T12N, R9E, UM. Btmhole Loc. 1094'F!-tL, 1271'FEL, Sec. 19, T12N, R9E, UM. Dear M~. Kewin: Enclosed is the approved application for permit to drill the above reference well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other govern- mental 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 pre- vention equiPment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. %~ere 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. Vey. y~ tru~t~~lrs ,~ ~ C. V.'Chattert6n Chairman Alaska Oil and Ga~ Conservation Co~ission BY ORDER OF THE C~MISSION be Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of gnviro~entai Conservation w/o encl. i~. Doug L. Lowery ARCO Alaska, Inc. Post Office B,~ .00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 18, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 3F-13 Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill Kuparuk 3F-13, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plot Diagram and description of the surface hole diverter system o Diagram and description of the BOP equipment We estimate spudding this well on December 9, 1985. If you have any questions, please call me at 263-4970. Sinc ely, Regional Drilling Engineer JBK/LWK/tw PD/L192 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany la. Type of work. · '. STATE OF ALASKA '~-" ALASKA ,..,L AND GAS CONSERVATION CL,,,,MISSION PERMIT TO DRILL 20 AAC 25.005 DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~ DEVELOPMENT GAS I--I SERVICE [] STRA~.!G RAPH SINGLE ZONE~ MULTIPLE ZONE 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 9. Unit or lease name 52' FSL, 158' FEL, Sec.19, T12N, R9E, UM At top of proposed producing interval 1420' FNL, 1183' FEL, Sec.19, T12N, RgE, UM At total depth 1094' FNL, 1271' FEL, Sec.19, T12N, RgE, UM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 93', PAD 56' ADL 25632 ALK 2565 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Kuparuk River Unit 10. Well number 3F-13 11. Field and pool Kuparuk River Fi eld Kuparuk River 0il Pool Amount $500,000 13. Distance and direction from nearest town 30 mi. NW of Deadhorse miles 16. Proposed depth (MD & TVD) 7836' MD, 6282' TVD feet 14. Distance to nearest property or lease line 52' @ surface feet 17. Number of acres in lease 2560 15. Distance to nearest drilling or completed 3F-12well 25' ~ surface feet 18. Approximate spud date 12/09/85 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 700 feet. MAXIMUM HOLE ANGLE 41 o l (see 20 AAC 25.035 (c) (2) 2750 .psig@ 80°F Surface 3157 _psig@ 6132 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program i SIZE SETTING DEPTH QUANTITY OF CEMENT Hole F24" Casing 16" 2-1/4" 9-5/8" !8-1/2" 7" 22. Describe proposed CASING AND LINER Weight I Grade I CouplingI 2.5# / H-40 / Weld I program: Length MD TOP TVD 80' 35' I 35' 3511' 35' I 35' I 7802' I 34 I I 34' I I MD BOTTOM TVD 115'l 115' 3546'1 3063' 7836'I 6282' I (include stage data) + 200 cf 940 sx PF "E" & 400 sx PF "C" 300 sx Class "G" neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7836' MD (6282' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOP stack will be installed on the 9-5/8" surface casing. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2750 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3500 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 3F-13 will be 25' away from 3F-12 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) 23. I hereby cer.~+y that the foregoJngjs true and correct to the best of my knowledge T h e s P a c e,/J~o~ ~r~-~l;~m i'ss i o n u~ Samples required []YES [~t4M O Permit number 85-.29 APPROVED B~~_~ '~ Form 10401 --(LWK Regional Drilling Engine,er DATE CONDITIONS OF APPROVAL Mud log required ! Directional Survey required ] APl numbeE OYES I~o j' ,~,YES E]NO J 5002'9-21499_ Approval date SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE November 29, 1985 by order of the Commission Submit in triplicate PERMIT TO DRILL 3F-13 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 175 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. - i , -I,/EST--+EAS-T .__-__-_'2000-_:_ _ .-- _ .... 1094-'---FN L, { 2~ 1 :--FEL-: ........ - . -- ' -4. .... -~ ? ~ . ; .... : .......~ .......... . ........... .~ _ _ .... ~_--._T.D"?48~ .... :.-'..__': .... _ ........... 4 .... -~'.--:-= ..... ~ ..... ' : ! ~_:UEP.a. O4.Z.__.-__i ................. :~ .................. ': ....... . --~ ..... -~ ................................ ! .................. ? ........ ,. __ · : ~ ' : ' -UOC'^T '- .... .... ~.___. _ , ~ ! : ~ ~,{E'ST'-q 0~2- -- ~AROE~- TON,---' · -.-.' -- ! . : ; ,~ ................... 1'320'--FNL-; -- l'210"-~FEL ......... ' .... i -- ~ ~ - . __ : .. SEC. .~..'__-I 9,:"T12N,':' · . ~ ; ............. :0 ........ ~ ......... ! .................................................... ............ ~ ........ _~ ..................· ........~ ....... : ............................. , ....................... . .... .............. · --"! ........ : --- T _~_ __ ' ...... ~ ................. _ ......................... ............. !=, -2o.oo_:_: - -;_- ...... .... . . . , .............. ~1~ ................ ................... ~{:)._ - __ _:_ ........ - ...... - i . ........ ; ................. · ............... . .............. ._ _. ................... :-~_. .... : ................................................ , ........... ..... · """! ................. ; ..................... ! .......................... .......................... ........ -: ........... . ........ ' , ----~r .... 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' I : ' . . -4-..~- ': :-! , · 4 - - .;- ...... -4 .......... .:-- --'~- ..... i : i ~. ! .~; ........ ---e-:--~- : - : i ' - ' I ' ' ' ; ........ : ......... ; ,~:~:.'t , --~? ::!,', !-.,. - . , KUPARUK RTVER UN:IT 20" -DIVERTER SCHEMATIC ii1! DESCRIPTION I. 16' C~TOR. 2. TAhI(O STARTER HEAD. 3. TANKO SAVER SUB. 4. TANKO LOWER OUICK-C~CT ASSY. 5. TAr, a(O UPPER QUI CK-C~CT ASSY. 6. 20' 2000 PSI DRILLING SPOOL W/i O' OUTLETS. 7. I0" HCR BALL VALVES W/lO' v/ DIVERTER LINES, VALVES OPEN AUTOMATICALLY UPON CLOSURE OF A~AR PREVENTER. 8. 20" 2000 PSI AhIN~ULAR PREVENTER. 7 MAI NTENANCE & OPERAT I ON 2 I. UPON INITIAL INSTALLATIO~ CLOSE PREVENTER AND VERIFY THAT VALVES HAVE OPENED PROPERLY. 2. CLOSE Aht~JLAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE Ah~JLAR PREVENTER IN THE EVENT THAT AN IhFLUX OF tNELLBORE FLUIDS OR GAS IS DETECTED. IF NECESSARY, MAh~JALLY OVERRIDE AND CLOSE APPROPR I ATE VALVE TO ACHIEVE DOV~NWlND DIVERSION. ?*i:'~/2 ;' '~'~::' DO NOT SHUT IN W~LL A~aska Oit & ~a,~ Co~-~, C~.,,,~,?~'.:~'~or, U~R ANY CIRCU~TA~ES. An cJ~ora~$ 7 6 1:5-5/8" 5000 PSI RSRRA BCP STACX /-~. 1. I~' - '7. 13,--5/8" B(::P STACX TEST 1. F"/:LL ~ 5-rAo<: AhD (3-10<E 't,W~FI:I..D W3"TM OI~¢X TMA~ ALL LOCX ~ ~ IN ~I~EAD FULLY R~'FRA~. S~AT TEST PLU~ IN V~ LIDE VALV~ AD~ TO B~P STACX. ALL -P~:~SSLRE t~ 'TO ~.~ FSI A~D ~ FOR lO ~N. IN-, ~ ~ TO ~ PSI AhD i-iI::LD FOR 10 I~N. _~ mrr'~ ~ TO 0 PSI, L.ThE: VALVES. CLOSE TO:~ PIPE: RN~ AI~ I..I¢:R VALVES '1:~ lC, ILL ~ ~ 6.';l--r, ST. TO ~ PSI AN~ ~ PSI AS IN STEP 4, ~ A 2S0 PSI LDa' ~ ~ PSI HIGN. 'rEST AS t~DT a FU_L ~._OSIN~ POSITIVE SF_.AL C~. FU~I~ 1F.~l ~ TMA1 DO h~D1 FLK.LY a. ~ TOm PIPE RA~ AND CLOSE BOT'FO~ PIPE R~. TE~'T BOTTO~ PIP~ RA~ TO 250 PSI A~D ~000 PSI. -¢L.DSE BL,I:~ RN~ AN:) ~ TO 2.50 PSI At~D FSI. FLUID. S&"l* ALL VALVES 3.N I::R~LL3.1~ TEST'.S'rAhI::PIPE VALVES, k'm~Y, ~ ~Y CI:13e, So DRILL .PIPE SAFLr~ VALVE, AJ~ II~;ZI:E tBCP TO 250 PSI F~ $lg~L AI~ ~ TO I:IRILLIN8 SLI::'ERVISCR. W~EKL¥ ~ Ft..td~Z~Y CPEIIATE BO~ DALLY REv. ARCO Alaska, Inc../~"~' Post Office E,... 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 21, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Bui~lt Location Plat - 3F Pad Well s 1-16 Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, - ~ Gruber Associate En§ineer JG/tw GRUll/L22 Enclosure If RECEIVED OCT 2 Alaska OiJ & Gas Cons. Commission knchorag9 ARCO Alaska, inc. is a Subsidiary o! AtlanticRichfieldCompany ~--'~' AS BU "CQNDUCTOR$ I-I IN SECTION 1- Y=5, Yd5,734.98 LAT=70°22 ' 20.0858,, X= 508,662.35 LONG=149°55 ' 46. 549'' 89 FNL, 162 FWL, 52 O.G., 56.1 PAD- 2- Y=5,985,745.10 LAT=70°22' 20. 1856'' X= 508,638.99 LONG=149°55'47.233'' 78 FNL, 139 FWL, 52 O.G., 56.3 PAD 3- Y=5,985,754.79 LAT=70o22 ' 20. 2812" X= 508,616.29 LONG=149°55' 47.896'' 69 FNL, 116 FWL, 52 O.G. 56.3 PAD 4- Y=5,985,764.77 LAT=70°22 ' 20.3796'' X= 508,593.66 LONG=149°55' 48. 558" .59 FNL, 93 FWL, 52 O.G. 56.2 PAD 5- Y=5,985,774.87 .LAT=70°22'20.4792'' X= 508,570.43 LONG=149°55'49.237 ~ 49 FNL, 70 FWL, 52 O'.G. 56.2 PAD 6- Y=5,985,784.84 LAT=70°22 ' 20. 5776'' X= 508,547.58 LONG= 149055, 49. 906" ' NOTES 39 FNL, 48 FWL, 52 O.G. 56.1 PAD I.COORDINATES ARE A.S.R, ZONE4. 7- Y=5,985,794.93 LAT=70°22'20.6771'' 2. SECTION LINE DISTANCES ARE TRUE. X= 508,524.44 LONG.149°55'50.582'' 28 FNL, 24 FWL, 52 O.G.,55.9 PAD 3. HORIZONTAL AND VERTICAL POSITIONS ARE BASED 8- Y=5,985,804.81 LAT=70°22'20.7744'' ON MONUMENTS SF-MIDDLE & 3F-EAST PER L.H.D&ASSOC. X= 508,501.41 LONG=149°55'51.256'' 4. O.G. ELEVATIONS INTERPOLATED FROM S/C DWG. NO. 18 FNL, 1 FWL, 52 0.G.,55.9 PAD CED-RIXX-30$O RE~V~L'~_~.,. - AS BUILT CONDUCTORS 9-16 IN 8ECTI~)N 19 * F A/. , 9- Y= ,985,8 ,.85 L^ =70o22,21.0708;; ~- .-"'"-.~"~- X= 508,432.81 LONG=149°S5' 53.26~'' ~_! .~ : , .'' °-~?~"I~'"" -.=-/~'"?~%,- '~.. 12 FSL, 67 FFL, 51.20.G., 56.1 PAD ' ~: '4r~TH'*~ 'i'~ ' 10- Y=5 985 844 70 LAT=70°22'21 1678" .... ' : ~1~'o &f;~'"//w~. ~ · ~. ~ , , · · '; :' ~ ~eee~®®®®®ee~ee~oe ..... ~ X-' 508 410 73 LONG=149°55' 53 908" i:.::/-:;:::_ /_ 21-FSL, 89 FEL, 51.20.G., 56.2 PAD - T.~'r~_. 4~SO-S .' .,__ X= 508,387.41 LONG=149°55'54.590'' : ~'~.","4. '.. ..' _-. - ~-~l~,7'"",.-" ..~,"..'- 32 FSL, 112 FEL, 51.2 O.G., 56.3 PAD _ . q~;,.7~S~t3~_~,,~ 12- Y=5,985,865.19 LAT=70°22'21.3699'' ' '~ ~;~'~ X= 508,364.05 LONG=149°55' 55.273" . I HEREBY'CERTIFY THAT I AM PROI~RLY RE(~I·TERED 42 FSL,136 FEL,51.1 0.G.56.2 PAD AND.LICENSED TO PRACTIC· LAND $URVEYIM4~'IN 13- Y=5,985,874.97 LAT=70°22'21.4663'' THE .$TATE OF ALASKA, THAT TI"Ill I)~I~T R~IM~NT$ X= 508,341.36 LONG=149°55' 55 . 937" A SURVEY I~I~DE UW3.~R MY DIRECT ~III~R¥1~ION AND~ 52 FSL, 158 FEL, 51 . 1 O.G. , 56.3 PAD . THAT CONDUCTOR8 I ~ · AI~.CORI~CT Al OF 14- Y=5,985,885.08 LAT=70°22'21.5660'' SEPTeMbER 19,19~ ANO.CONI3~ICTO~I~'$ 'I~I~U 15 ARE CORR~CTA8 OF~PT~M~ER~,I~. X=. 508,318.27 LONG=149°55'56.612'' 62 FSL, 181 FEL, 51.1 0.G.,56.3 PAD 19 _T. H_I,S__. 3S.3B - 15. Y=5,985,894.96 LAT=70°22 ' 21. 6635'' ~~~ 2 X= 508,295.72 LONG=149°55' 57.271'' 72 FSL, 204 FEL, 51 O.G. 56.1 PAD D.S3F' ~ 29~)~28 7~ ~, .~, ~ ~...~~ 2 5 ~ 16-Y=5,985,904.95 LAT=70°22'21. 7619'' 30 '2 X= 508,272.74 LONG=149°55' 57. 943'' ~. - ~(~ ~-~ ;~ S' _:__:.~82 FSL~ 227 FEL~ 51 O.G. 56 PAD 6 ( as < CONDUCTOR AS-BUILT - ~1 i LOCATIONI _ CONDUCTORS I THRU ~ LOCATED IN PROTRACTED SEC. 29, T. 12N.,R.9 E., U. MER. ]liSlE D.t-: October !1.1985 ,..,:' N.T.S. CONDUCTORS 9 THRU 16 LOCATED IN PROTRACTED SEC. 19, T. 12N.,R.gE.,U. MER. ,,-,.,~..,~,,.,,,,m= Drifted by: Sydney2 Dwi. Ne. N~K85-26 I CHECK LIST FOR t~E~,7 \,', ::.,_: ! ....... , ............. ITEM APPR0\:E (1) Fee / (2) .,'?- '?f (2' thru 8) '(8) ' ' (3) Admin ~6__ ///' ) ! 'g~ 9. (9 thru 12) 10. (10 and 12. (13 thru 21) (22 thru 26) 13. ,14. 15. 16. 17. 18. 19. 20. 21. YES NO 1. Is the permit fee attached .......................................... ~-x_.__ 2. Is well to be located in a defined pool ........................... ~ 3. Is well located proper distance from property line ....... 1.~.. 4. Is well located proper distance from other wells ............. ~ · 7. Is operator the only affected party ........................ , 8. Can permit be approved before ten-day wait .......................... ~ 22. 23. 24. 25. 26. 27. Does operator have a bond in force .................................. ex, Is a conservation order needed ...................................... ,, Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~. Is conductor string provided ................................ ......... 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 surface casing protect fresh water zones ............... ........ Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment,procedure included,on 10-403 ............ Is adequate wellbore separatiOn proposed ............................ Is a diverter system required .................... ' . ......... Are necessary· diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to ~CD~ psig .. Does the choke manifold comply w/AP1RP-53 (Feb.78). ............. ' .... Is th f H2S g p b bi ' e presence o as ro a e ......................... .. ..... Additional requirements ............................................. REMARKS Additional Remarks: Geology: Ens$~neerin~: HWK ,.1~ LCS ~7'~'' ~ -- WVA -- MTM..~. HJH ~ rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ~.,.~: ~,, ~ ~,..>.~?..~ !-:o,',..../~o ~: ,,~L~ ~ 0 /~ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically - :. - .. organize this category of information. ~----SCHLUMBERGER----~ LIS T~P[] VERIFICATION LISTING bVP 010.H02 VER.[FIC~TIfiN L].$Ti,NG PAGE; 1 SERVICE N,~MF, :~;DIT DATE :85/12/29 ORIGIN : REEL NA~E :135~96 CONTINUATION PREVIOUS REEb : ** TAPE HEADER SERVICE NAME DATE :85/12129 ORIGIN :FS1A TAPE NA~,~E CDNTI~UATION ~ PREVIOUS TAPE COMMENTS :~IBRAR¥ TAPE ** FILE HEADER ** FILE NA~E :EDIT ,001 SERVICE NAME VERS! N DATE MAXI~{j~ 5EN~TM FiL~ TYPE PREVIOUS FIhE ** INFORMATION RECORDS ** CONTENTS CN : ARCO AbABKA INC, FN [ KUPARUK RANG: gE TO'WN~ 12N SECT: 19 COUN~ NORTH SLOPE STAT: AbASKA CTRY: MNEM CONTENTS PRES1 F: UNIT TYPE CATE SIZE CODE 0o0 000 061 O65 000 000 006 065 000 000 008 0~5 000 000 002 o~5 O0 ooo°°° §~00 00~ 0650~5 000 000 012 065 000 000 006 065 000 000 004 065 UNIT TYPE CATE SIZE CODE ooo o0o ooi 065 LVP 010,H02 YER!KICA'i'IO~J LISTING PAGE 2 * SCHLUMBERGER * ALASKA COMPUTING CENTER COMPANY : ARCO ALASKA WELL = 3F'13 FIELD : KUPARUK COLJN~Y : ~ORTH SLOPE OOROOGH STATE = ~bASKA JOB NUMBER AT ACC: 71113 RUN #1, DATE LOGGED: 19-DEC-85 bDP: L, B, CUDNEY CASING : 9 625" ~ ]650' - BIT SIZE m 8,5" TO 8108' TYPE F[,UID = b~ND DEN$ITYT m 9 8 bB/G RM m 3,640 ~ 74 0 OF v~scos~ ¥ = 4{§0 s R~F = ~.14o PM = 9, RMC H' = 3,460 @ 64 0 DF FLUID bOSS : 5,8 C~ RM AT B ~ : 2,076 ~ ~§, DF ~ATRiX S,6.~)OSTON LYF OlO.d02 VER. iFI(iAT!OI,} 5IS'i'If'~ PAGE 3 HOLE COaRMCTIOM = CALIPER ***** THIS DATA HAS NOT BE~N DEPTH SHIFTED - OVERLAYS FIEbO PRINTS ******************************************************************************* ****************************** , SCHLU~SERG£R LOGS INCLUO~iD WITH THIS MAGNETIC TAPE~ , , , , , * OUAL INDUCTION SPHERICALLY FOCUSED 50G (DIb) * * DATA AVAILABLE: 8089' TO ~6~7' * FO~MATION DENSI'.~¥ COMPENSATED bOG (FUN} * * CO~PENSATED ~EUTRON LOG CFDN) * DATA AYAIbAOL~: 8089' TO 3647' * * DATA AVAILABLE: 3800' TO 1690' * ** DATA FORMAT RECORD hVP 010,[402 VER!FICATIO~'4 LISTING PAGE 4 ENTRY BbOCKS TYPE 2 8 9 16 0 SIZE 1 4 1 DATUM SPECIFICATION BbOC MNEM SEPVlCE SERVICE tin ID ORDER ~ SFLU DIL CALl FDN RHOB FDN DRHD FDN NRAT FDN RNRA FDN NPHI FDN NCNL FON FCN[, FD~ ~R Cr~b KS IT APl AP1 bOG ~YPE FT O0 000 DHM¥ O0 220 OH~ 00 120 MV O0 0~0 GAPI 00 3 0 GAPI 00 310 IN O0 2~0 G/C3 00 350 G/C3 O0 356 O0 4~0 O0 000 PO 00 890 CPS O0 330 CPS 00 330 G~PI O0 310 REPR CODE 66 65 66 66 CbASS MOD NO, O0 0 0 O1 0 0 46 0 0 44 0 0 01 0 0 O1 0 0 O1 0 0 01 0 0 02 0 0 01 0 0 O1 0 0 O0 0 0 O0 0 0 31 0 0 3O 0 0 O1 0 0 SI ENTRY 0 I 60 ,lin 1 0 zg SPL REPR CODE 4 1 68 4 1 68 4 1 68 4 I 68 4 1 68 4 {. 68 4 ! 68 4 1 68 4 1 b8 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 I 68 0000000~ CTAh) 00000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 0000000000000~ 000o000000000 O00OO000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 DATA ** DEPT 5P RHOB NPHT 8112,~00~ SFDU -49. 25 GR 2,4436 DRHO 47,6074 NCNL OEP,,, RHOB NPHI 8100,0000 SFbU -3:~,.!I045 GR 47,4436 ORHO .6074 NC:Nb DEPT SP RHOB NPHI ooo. oooo · 4,_4,23 8 '3 420:,,42.475 ] 44 NC N DEPT RHOB NPHI 7900 O000 8FLU 2 8 .. [)RHO 42 089@ NCNL DSZPT SP RHOB ~§ 0000 SFLO 78 , ,7759 GR 2,3362 DRHF) 121,'589 0,2285 NRAT 1978,6875 FCNL 2,8167 ILO 12~,'5898 GE ,2285 NRAT I978,6875 FCNL 566 NRAT 200 , 875 FCNL ], 8752 100,7773 OR ,08';9 NRAT 1748,6875 FCNL 0059 NRAT 54'52 ,2385 12,5898 .,7405 484,89'06 60~ '3752 .3125 2,4436 I03,7773 ,4944 421,8906 IbM CAbI RNRA GR IbM CAb I RMRA GR RNRA CALl R MR A GR RNRA ,50 0 4,07 9 -999,2500 2,5374 8,4785 4,0789 3,2932 -999,2500 2,4885 I,.504 9,6426 8,8535 3,3225 LVP OlO.H02 VERIFICaTiON ~,ISTING PAGE 5 NPHI 31.29B8 NCNL DEPT 7?00 0000 SFbU RHOB 2,4709 DRH~ N_PHI 40,527{ DEPT 7600.0000 SFLU SP -16,7139 GR RHOB 2,3733 DRHD NPHI 30,0781 NCNb DEPT ';500 0000 SFLU SP -22:4795 GR RHOB 2,4885 DRHO NPHI 40,5762 NCNb OgPT 7400,0000 SFLU SP -53,73B3 GR RHOB 2,2952 DRHO NPHI 44,4336 NCNb DEPT 7300 .0000 SFLU SP ,8945 GR RMDB 2,]870 DRHO NPH! 45,1660 NCNL DEPT 7200,0000 SFLU ". 15,7324 GR NPHI ,.999,2500 NCN{~ $P ,, 14, 355 GR RHt3B .-999, i}500 DRHO NPHI 999,2500 NCNb DEPT 7000,0000 SFGU SP -27,932' GR RHOB -999,250~ DRHO NPHI "~:99.:250'0 NCNb P 29,5576 ' RHOB 999.~,2500 DRHO NPHI -999,2500 NCN~ DEPT 68.0~,0000 SFbU SP 3 ,3945 RHOB -999,2500 DRHD NPHI -999,2500 NCNb DEPT 6700,0000 SFbU SP '38,8633 (;R 2745.5OO0 ~,7639 ~05,~77] 0.0718 1785.~875 6.8796 75 0:0029 3027,5000 ~,7930 .0 ,2773 ,0044 2109,5000 1.8096 12~,6523 ,0132 1668,6875 2,~334 117, 898 '0.~I03 1776, 75 4,9343 -999~ -999,2~00 5,~859 279, 906 -999,~500 -999,2500 4,3406 '2'500 '99:9,,:2500 4,1~70: I16, 23 -999,2500 -999,2500 -99 ,2500 "999'2500 5,852~ 98.652 FCN[, NRAT FCN5 Gl{ NRAT FCNb NRAT FCNL GR NRAT FCNb ILD G~ NEAT FCNb IbD NR~T FCN{., R NEAT FCNb 'R G N RAT FCNb I [, o GR NRAT FCNG ILO GR NEAT FCNG R 825.8125 GR 2,5959 ~bM 105,2773 ALI 3,4'885 RNRA 500.6406 GR 8,0254 Ib~ 75,5898 Clb! 2,8088 RNRA 960,3125 GR 47.8555 99 RNRA 567" 3 25 GR 1,5469 Ib~ 123 01.4 RNRA 396,8906 OR , 9581 1bM ,5898 CALI 113,194~03 RNRA 416, 6 OR ] 8772 ILM I 5 CAE1 -999 R -999 ~500 GR 27~,5803 IbM ,3 906 A b I -999,2500 RNRA "999,2500 GR 3.5940 16 ,8125 CALI -99~ A ,2500 RNR · ,999,25 O0 GR 2,9788 ILM 125,4648 CAbI -999,2500 RNRA -999,2500 G~ 948,539.83 ibm ,652 CAbI -999,2500 2,7j07 10,~348 3,5667 '999,2500 8,2832 9,2598 3,1506 -999,2500 47'!180 I: '999, O0 1,6221 10,1191 4,2039 '999,2500 ,0 764 ,8457 -999, 3,~280 , 500 999,~500 -999!:2500 -999 -999 0 -,999 O0 "'999 .2500 4,555 10,158~ LVP O]O,H02 VERIF'tCATIOi~ [_,ISTI~G PAGE 6 -999.2500 - 999,2500 DEPT 6600 , SP '30.2920 RHOB -999.2500 NPHI -999,2500 DEPT 6500 0000 SP -28,6357 RHOB -999,25(30 NPHI -999,2500 DEPT 6400 0000 OB -999.2500 NPH',I -999,2500 DEPT 6200,0000 SP . '9.9121 RHOB 999,2500 NPHI -999.2500 RHOB NPHi DEPT NPHI sp RHOB {~PHl DEPT SP NPHI DEPT SP Rt]OB oooo 91 '70 2500 ~i000,0()00 -17,9639 999,2500 999,2500 -999:2500 -999. 2500 ~800 0o00 -1 1767 -999 2500 -999 2500 5!00,0000 30,1982 99 . 2500 5600.0©00 DRHO SFbU GR DRHO NCNb SFLU SFbU DRHO N~Nb SFLU GR DRHO NCNb $Fbt] DRHO NCNL SFbU GR DRHO NCN5 SFLU DRHO NCNb I)RHO NCNL DRHO NCN5 SFLU DRHO NCNb SFL{} -999.2500 NRAT -999.2500 FCNL 6 340~ Ibt> 88.65~3 GR '9~9.2500 NRA'r -999.2500 FCIV[., 4.~359 lb[) 116 398 GR -999:2500 NRAT '999,2500 FCNb 3 1858 117!8398 GR -999 2500 NRAf -999 25.00 FCNL 3,8479 ILD 102,4648 GR 999,2500 NRAT ~999,2500 FCNL 3 79~2 117,~9375 GR '999.2500 NRAT '999.~500 FCNL 2 9084 lbo 137 3~25 GR '999 2500 NRAT 134, 3 5 '999.2500 NRAT '999,2500 FCtqb 2,8242 - 99,2500 NRA'T -999.2500 FCNL 2.1272 IUD .173,8125 GR 999,2500 NRAT -999,2500 FCNL 2,5784 ILO 148,9375 GR '999,25:00 NRAT '999'25(.)0 FCN[, 1.5~55 -999.2500 RNRA -999.2500 4 5710 88,6523 CAbI -999.2500 RNRA '999,2500 GR 4.~81 116, 98 CALl "999,2500 RNRA '999,2500 GR' 3,2229 117,8398 CALl -999,2500 RNRA -999.2500 GR 3,7249 IbM 102,4648 CALl -999.~500 RNRA -999. 500 GR .. .2500 RNRA '999,2500 GR I3~, CAb! -999.~50'0 RNRA -999. 500 GR 3,0393 ~4,9.375 CAbI ' 9,2500 RNRA '999,2500 GR 45 , ALI ,2500 GR 1.9962 IbM .173,'8125 CAbI 999~2500 RNRA -999,2~00 GR 2.2678 IbM 9375 (IAI./ 148, -999,~500 RNRA -999. 500 GR 1.6700 ~999,2500 999,2500 5,1062 8,4941 -999,2500 -999,2500 4,0906 10,7207 -999,2500 -999,2500 1 5332 -999,2500 -999,2500 3,8166 11,4551 ~999,2500 -999,2500 3,5549 . 10,49~1 ,999,25 0 '999.2500 ~,1662 9395 -999, '999, 3,945' 025~ 999,'2500 99 , O0 . ,. '999,2500 :999,2500 999,2500 1,8321 , , bVP 010,H02 VERiF1CATII3:'~ )'~IS".('t.~t.: PAGE 7 R }tL]B q99: 25(30 t.) ~{ ~ ['] 999 NPHI ~999,2500 NCNb 2999 DEPT 5500,0000 SFLU 8633 SP '33, . RHOB -999,2500 DF, HO NPHI .,999 ~, 2500 DEPT 5400,0000 SFLU SP -25,6201 RH[]B -999,2500 DRHO NPHI -999,2500 NCNb DEPT 5300,0000 SP -26,5889 GR RHOB -999,2500 DRHO NPHI -999,2500 NCNb D~PT 5200 0000 SFI. U SP -38,8945 GR RHOB -999,2500 DRHO NPHI -999,2500 NCNb DEPT 5~00,0000 SFLU SP 28,9482 GR R~OB -999.2500 DRHO NPHI -999.2500 NCNb, DEPT 5000,0~00 SFLU SP -34,~508 RHOB -999, 500 DRHO NPHI -999,2500 NCNb EPT P RHOB NPH~ '29, GR ~999,2~00 -999,2500 NCNb 4800,0000 SFbU '3:8,4883 -99~'2500 DRHO ,999,2500 NCNb 0000 SFLU 4700'4570 GR 2,2117 [)RHO 42,0 0 NCNb 4600,0000 ~4~,2070 GR ..,~049 DRHO 45.3613 NCNb DEPT SP RHBB NPHI DEPT SP RHOB NPHI RHOB NPH! 1875 i25~')0 2500 1 112i -999 -9q9 2. 105. -999. -999. 2. 103. -999. -999, 2, 12i, "99 , '999, 2 ~14' '999, '999, '999 "999 3 94' '999, -999, 3, 109, '999, '999, 2151, 2 122 0 1971 9532 9023 2500 2500 4553 4648 2500 2500 4514 4023 2500 2500 4534 9648 2500 2500 2500 2500 8967 4023 2500 2500 2327 902.3 2500 250O 4963 9)23 2500 2500 9827 1523 0005 5000 9612 6875 G R I~RAT lbo GR NRAI FCNb lbD GR NRAT FCNL GR NRAT FCNb IbD GR NRAT FCNb GR NRAT FCNL GR NRAT ILO NRAT FCNh ,NRAT FCNb GR NRAT FCNL GR NR,~T FCNL 150 1875 CAbI -999!2500 RNRA -999 2500 GR 1,9747 IbM 112.9023 CAbI ~999,2500 R~RA 999,2500 GR 2.7249 IbM 105,4648 CAbI '999.2500 RNRA '999,2500 GE 2 4397 103' ,4023 C~LI '999,2500 RNRA -999,2500 GR 2,650'6 IbM 121,964B CAbI -999,2500 RNRA -999,2500 GR 11~,70756 IbM , 273 CALl -999,22500 RNRA '999. 500 GR 3 15O6 - 2500 -999 250O IbM CAbI RN'RA GR 3655 IbM 999, RNR -g991 aR 10~,5803 IbM ,90.21 -999;2500 RNRA ;1523 CAb! ~,5~98 RNRA 535,8~25 GR ~526 3, 7~ 12~,7 13 CAbI ,6956 RMRA 491,1406 GR 9 3848 2999: soo 999,2500 2,0198 '999. 500 '999, 500 2,4807 9,5254 -999,2500 -999,2500 ,4495 ,4238 -999,2500 -999,2500 2,5667 9,6348 '999,,2500 -999,.2500 2,~819 9,494~ -999,250 -999.2500 ,0959 -999, . -999,2500 ,3596 ,6973 -:999,2500 -999,2500 3,5452 9,5688 '999,2500 -999:,2:500 2,8870: 9,5098 .99~:~0125 ,2500 3,1663 -999,2500 LVP 010,H02 VERIFICATION L, ISTI~\iG PAGE 8 DEFT 4500 0000 SP -57i3~20 RHOB 2 3264 NPHI 38 1348 SFbU GR DRHO $ F b U GR DRHO NCNb SFbU DRHO NCNb RHOB -999.2 O0 NPHI -999,250[) OEPT 4300 0000 SP -40:4258 RHOB -999,2500 NPHI -999,2500 DEFT 4200. OO00 BP -50,7070 NPH! 999. 500 SFbU GR DRHO NCNb DRHO NCNb GR DRMO NCNb D~PT 4100.0000 SP '35.2695 RHOB -999,2500 NPHI .999,2500 DEFT 4000,.0000 SP -52,0508 RHOB =999,2500 NPHI -99'9,2500 D~PT 3900,9000 SFbU SP -38,8633 GR RHOB -999,2500 DRHU NPHI -999.2500 NCNb DF, PT 3800. 0000 SFLU 8P -66,7~227 GR RHOB -999, 500 DRHO NPMI -999,2500 NCNb DEPT SP RHOB NPHI 3700,000 SFbU -83,972~ GR -999,2500 DRHD -999.2500 NCNb 3600.0000 SFbli -9 ,.2500 ""~ -9. 250(i) DRHO -992500 NCNb 3500 0000 SFbo -999 2500 GR -999 ~50(+ DRHO -999 2500 NCNL P R H 0 B ~P H I 3,3284 1.13.7148 0,0024 1994,6875 3.7034 117,1523 -999.2500 -999.2500 3.5764 104.1523 -999.2500 -999,2500 2,7151 103.1523 :999.2500 999,2500 98 398 -999 500 108,~148 '999. 500 '999.2500 101. '999.2500 '999. 2500 3 98 -999 -999 2~ 92. -999, -999. -999. -999. -999. -999. -999. -99~. -99 -999. ~023 2500 2500 2500 25O0 25OO 5oo 2500 2500 .2500 250O 500 5 O0 GR FCNL ILO GR NRAT FCNL IbD GR NR&T FCNL ILO GR NRAT FCNL IbP GR NRAT FCNL NRAT FCNL GR NRAT FCNL I bD GR ('{RAT FC.Nb GR NRAT FCNL I bD GR NRAT FCNL G~ NRAT FCN b 3.b135 113.7!48 CALl 3.4084 RNRA 536.3125 GR 3.9065 IbM 117.~523 C.AbI -999. 500 RNRA -999,2500 GR 3 7444 AbM 104' .1523 CAbl -~99,2500 RNRA - 99,2500 GR ' 9.2500 RNRA -999,2500 GR 4,~$35 98.]~98 CAbI '999,2500 RNRA '999.2500 GR 3 0979 IbM 999,2500 GR , bi -999,2500 RNRA -999.2500 GR '10 ~ CADI -999, 500 RNRA -999.2500 GR '999. 50 '999,2500 '999,~5'00 '999, 500 RNRA -999.2500 GR -999.2500 IbM -999.2500 CALI -999,2500 RNRA -999.2500 GR 3,5081 10,9004 3,7190 -999.2500 3.8049 11,{051 -999, 500 -999,2500 3.6174 10,3926 -999,~500 -999, 500 2,8713 -999~2500 ~,2468 10.7754 99,2500 2.9397 10,45~1 -999,'25 0 -999.2500 1 , 16 .,999.2500 -999 ' 2500 ,.99 "999, ~00 3,0940 10 ,~ 13 999~ 400 113 0898 -999,2500 -999,2500 -999,2500 48.8242 -999,~900 '999, 500 '999,2500 62',5742 bYP 010oH02 VFRIFiCATION LISTING ,,AG.E 9 DEPT 3400.0000 SFbiJ 8P -999,2500 GR RHUB -999.2b00 DR!4[] NPHI =999,2500 NCNb DEPT 3300 0000 SFbU SP -999:2500 GR EH08 -999,2500 ORHO NPHI -999,2500 NCNU D~PT ~200,0000 5FLU SP 999,2500 GR RHOB -999.2500 DRNO NPHI -999,2500 NCNb DEPT 3~00,0000 SFbU SP -999,2500 GR RH00 -999.2500 NPHI -999,2500 NCNb DEPT 3000,~000 SFLU P -999, 500 GR HOB =999,2500 DRHO NPHI -999,~500 NCNG DEPT 290~,0000 SF'LU SP -99 ,2500 GR ENOB -999,2500 DRHO NPHI -999.2500 NCNb os:p , asoo 000o sr;u RHOB -999,2500 DRHf3 NPHI -999,2500 gCNL 5P -999, 500 ~ RH~B -9'99'~§0 DRHO NPHI '999, 0 NCNb DEPT 2600,.0000 8F[.U OB -999,2'50 DRH[3 NPHI '999,2500 NCNb ~ ~000 SFLU EPT 2500 P -999 500 GR RHOB -999 .~500 NPHI -999 2500 NCNb ~ 000o SFLU DEPT 400: 2500 GR SP 99 Ri:lOg 99 .2500 DRHO -999.2500 lbD :999 2500 GR 9~9:2500 I~RAT -999,2500 f'CNL -999 2500 -9'99:2500 GR -999,2500 bRAT -999.2500 FCNL -999.2500 -999,2500 GR -999.2500 NEAT -999,2500 FCNI~ - 99,2500 ILD -~99.2500 GR -999.2500 NRAT -999.2500 FCNL -999,2500 It, D -999 '~500 GR '999: 500 NEAT -999.2500 FCNL · ,999,2500 ILD -999,~.500 OR -999,.~.500 N~AT -999, ,500 F NL :9~,2500 IbD · 2500 NRAT 99,'2500 FCN[4 -999,999,2500 ,2500 .,999,2500 NEAT -999,2500 FCNL '999,2500 I'LD -999, '999,~500 FCNL '999.'2500 -999 ~2500 -999;2500 NEAT -9~9.~500 FCNL 2999,2500 ILD 999..~50o GR -999,~500 NRAT -999 2500 -999!2500 CAbI -999 2500 RNRA -999 2500 GR -999,2500 IbM -999,2500 CALl -999,2500 RNRA -999,2500 GR -999,2500 IbM =999,2500 CAbi -999.2500 RNRA '999,2500 GR -999,2500 IbM '999,2500 CAb.I '999,2500 RNRA -999,~500 G~ -999,2500 IbM ~500 CALl '999, 500 RNRA -999. -999,2500 GR -999.2500 IbM -999.2500 CAbI '999,2500 RN'RA -999,2500 GR -999 2500 I[,~ .999: 25oo CAbl '999,2500 RNRA '999,:2500 GR -999,.2500 '999,2500 RNRA -999,2500 GR -999,2500 IbM ,99_9.,2500 CAb! -999,2500 RNRA '999,2500 GR :999,2500 IbM 999,2500 CALl -999,2500 RNRA "999,2500 GR =99'9,2500 IbM ~999,2500 CAbI -999'2500 RNRA -999,2500 -999,2500 -999.2500 58,7930 -999, 500 -999,~500 -999,2500 49;4492 -999,2500 -999,2500 '999,2500 52,6367 -999,2500 .,999~2500 -999,~500 53,1992 -999,2500 -999.2500 -999.2,500 38,4180 '999,25 44. *' 92 -999 i50000 48 305 '999 ~500 -999 500 -.999 ,,.999..2500 99, 41,04~0 "999, 33, I00-999. · O0 '999, -999, O0 LVP 010,!.[02 VERIFICATIOt'.i LISTING PAGE 10 NPHI -999,2500 NCNb -999 D~PT 2300,0000 Sf'bU -999 ,P -999,2500 GR -999 RMOB -999 2500 DRMO -999 NPHI -999:2500 NCNb -999 2500 2500 2500 500 5O0 O~PT 2200 0000 SFLU '999 SP '999' 999,2500 GR -999 - ,2500 DRHO -999: RMOB NPHI -999,2500 NCNb '999, DEPT 2100,0000 SFLU -999 SP -999,2500 GR -999'· RHOB -999,2500 D~ftO -999, NPHI -999,2500 NCNb -999, DEPT 2000,0000 ,FLU -'999, SP -999,2500 GR -999, RHOM -999,2500 DRHD -999, NPHI -999,2500 NCNb -999, OEP? 1900,~00 SFLO 99~. SP -999, O0 GR ~99 , RMOB -999,2500 DRHO -999, NPHI -999,2500 NCNb -999, DEPT 1800,0000 SF[.U -999 SP -999,25U0 GR -99 9 RiqOB -999,2500 DRHO -999 ~PHI -999,2500 NCNb -999 PT 1700,0000 SFLU -999 ~ -999,2500 GR -999 RMOB -9~9,2500 DRHO -999 ~PHI -9.9,2500 NCNb -999 DEPT 1688,~000 SFLU -999 ~P -999,~5:00 OR HOB '999,2500 DRMO -909 NPMI -999,2500 NCNb -9~9 .2500 500 500 2500 2500 2500 2500 2500 250O 2500 2500 2500 2500 2500 2500 25O0 2500 2500 2500 2500 2500 2500 2500 2500 ,2500 ,2500 ,2500 ,2500 FCN t., GR NRAT ILD GR NRAT FCN[, GR NRAT FCNb GR NRAT FCNL ! hD GR NRAT FCNI. ILO GR FCNL GR NRAT FCNL ILD GR NRAT FCNb FILE NAME ~EDIT ,001 VERSION # : OA'.tE MAX MUM hE~GTH I 1024 FIb TYPE : NEXT FIbE NAME : EOF -999,2500 GR -999 2500 IbM '999' ,2500 CA~I -999,2500 RNRA -999,2500 GR -9gg 2500 Ib~ '999i2500 CA~I '999 2500 RNRA '999,2500 GR -999.2500 IbM -999.2500 CAbI -999,2500 RNRA -999,2500 GR '999,2500 IbM '999,2500 C.ALI -999,2500 RNRA -999,2500 GR -999,~500 Ib~ '999, 500 CA[,I -999,~500 RNRA -999, 500 GR -999 2500 IbM '999, 500 RNRA '999,2500 GR -99g,25:00 "GM ~ALI -999,2500 '999,2500 RNRA '999,2500 OR ,.222,250o -999, R -999,2500 GR 34,8242 -999 2500 -99912500 -999 25~0 47,38 7 -999,2500 -999,~500 -999,2500 47,3867 -999,2500 -999,2500 -999,2500 51,1367 .,999,2500 -999,2500 41'1055 -ggg,~500 -999. 500 -999,2500 55,1367 .,999,2500 "'g99~.2500 -9 ,2500 31,1611 ,,g99,2500 -99g,2500 -.999,2500 31,1455 -ggg,2500 '999,2500 -999,2500 28,6299 5VP 0!0,H02 VI~.~R.IY[C~TIO!,J L!STING PAGE ** TAPE S~R¥ICE DATE J@5/12/29 O~IGIN ~FSI~ TAPE CONTINU~TIOM ~ :0~ ~EXT T~PE NAME CO~EN'TS :bIBRARY ** REEL TRAILER SERVICE NAME :EDIT DATE :85/12/29 ORIGIN : REEL, ~!AME :135890 CONTINUATION # 101 NEXT RE~b NA~E : CON~ENTS II~IBRARY EOF EOF
