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Home My WebLink About183-078WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďǇĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. 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The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϭϴϯϬϳϴϬͲ^Ğƚ͗ϯϲϭϳϬJRBy Abby Bell at 1:43 pm, Dec 21, 2021 1D-0350029204080000 KRU WLIPROFFINAL FIELD29-Aug-211F-0750029208300000 KRU WLGLSFINAL FIELD13-Oct-212W-0950029212350000 KRU WLSCMTFINAL FIELD18-Nov-212W-0950029212350000 KRU WLSCMTFINAL FIELD22-Sep-212U-1350029212610000 KRU WLPPROFFINAL FIELD16-Oct-213N-0650029215380000 KRU WLPPROFFINAL FIELD31-Oct-211Y-1750029223680000 KRU WLPPROFFINAL FIELD25-Jul-211Q-20A50029225890100 KRU WLSBHPSFINAL FIELD29-Jul-213S-24A50103204560100 KRU WLUSITFINAL FIELD25-Nov-212N-318A50103203430100 KRU WLSCMTFINAL FIELD12-Nov-211D-0350029204080000 KRU WLIPROFFINAL FIELD27-Mar-211D-0550029204170000 KRU WLSCMTFINAL FIELD8-Oct-211D-0250029204290000 KRU WLIPROFFINAL FIELD2-Apr-211A-0550029206270000 KRU WLLDLFINAL FIELD1-May-211B-1050029206560000 KRU WLWHIPSTOCKFINAL FIELD25-Sep-211F-0350029208530000 KRU WLPERFFINAL FIELD19-Oct-211Y-0650029209580000 KRU WLPPROFFINAL FIELD1-Nov-212D-0850029211580000 KRU WLGLSFINAL FIELD18-Jul-212D-0450029211760000 KRU WLBISNFINAL FIELD20-Nov-212D-0450029211760000 KRU WLSCMTFINAL FIELD10-Oct-212X-1550029211990000 KRU WLPPROFFINAL FIELD17-Oct-211Q-0950029212090000 KRU WLIPROFFINAL FIELD17-Nov-212E-1450029212140000 KRU WLSHBPFINAL FIELD30-Oct-212W-0950029212350000 KRU WLBISNFINAL FIELD19-Nov-211Q-0250029212480000 KRU WLIPROFFINAL FIELD29-Apr-212W-1450029212530000 KRU WLIPROFFINAL FIELD1-May-211Q-1550029213080000 KRU WLIPROFFINAL FIELD28-Apr-211R-0850029213330000 KRU WLIPROFFINAL FIELD3-May-211R-1350029213850000 KRU WLIPROFFINAL FIELD27-Jun-213F-0250029214470000 KRU WLWHIPSTOCKFINAL FIELD14-Nov-213F-1450029215000000 KRU WLLDLFINAL FIELD30-May-213M-0550029217060000 KRU WLCHEM CUTFINAL FIELD28-Oct-213M-0550029217060000 KRU WLSTRINGSHOTFINAL FIELD27-Oct-21 PLUGGIN(. & LOCATION CLEA_A_~CF_ REPORT State of Alaska .ALASKA 0IL & GAS CONSERVATION COHMISSION · · . =: '%~ :kO, Note casing size, wt, depth, =At vol, & procedure. Review the well file, and-c_~-~e~t on plugging, well head status, and location c!earanc~ - orovid~ loc, clear, code. , ~arker ~os~ or ~la~e:' ' ~~ . Code "-"~ STATE OF ALASKA -'" ALASK~ OIL AND GAS CONSERVATION CL, MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well [] Oil [] Gas [] Suspended [] Abandoned ~1 Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 83-78 3. Address 8. APl Number P. O. Box 100360, Anchorage, Alaska 99510 50-029-20958 4. Classification of Service Well 12. 17. 22. Location of well at surface .__ 571' FNL, 1911' FWL, Sec. 1, T11 N, R9E, UM At top of productive interval 1277' FSL, 1044' FEL, Sec. 1, T11 N, R9E, UM At total depth 1036' FSL, 962' FEL, Sec. 1, T11 N, R9E, UM Elevation in feet (indicate KB, DF, etc.) i6. Lease Designation and Serial No. 96' RKB, Pad 67' I ADL 25646 ALK 2577 9. Unit or Lease Name Kuparuk River Unit 10.-0'7--Well Number 1 Y-06 11. Field and Pool Kuparuk River Date Spudded i13. Date T.D. Reached'-~ 14. Date Comp., Susp., or Aband.~15. Water depth, if offshore 116. No. of Completions 5/15/83 5/22/83 ~ 8/15/97 I N/A MSLI One Total Depth (MD+TVE)! 18. Plug Back Depth (MD+TVD)I19. Directional Surveyl20. Depth where SSSV set~21. Thickness of Permafrosl 8120 6436 FT] 6138 4774 Fq I-lYes [~No j 1779' MD/ 1380' (Approx.) Type Electric or Other Logs Run 23. CASING S~ZE VVT. PER FT. GRADE 16" 62.5# H-40 Surf. 9.~' i 40.0# J-55 Surf. ....... -?" ...... ii 26.0# J-55 Surf. 24. Perforations open to Production (MD+TVD of Top and bottom CASING, LINER AND CEMENTING RECORD SETTING DEPTH t HOLE i TOP BO'FrOM !_ _S_!_z_E I _C___E_MEN_T!NG RECORD 116' i 24"~J280sxASII 2458' I 12.25" 11000 sx AS III & 368 sx AS I 8064' ~~X-CiaS$ G- & i50--~X AS I ~, P&A ~ ~ ~ I bridge plug @ 6138' I inflatable retainer @ 7411' 25. TUBING RECORD AMOUNT PULLED and interval, size and number) MD None, all perfs down-squeezed during abandonment TVD MD TVD SIZE DEPTH SET (MD) PACKER SET (MD) 26. AC~D FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 15 bbls Class G cement down-squeezed into perfs 27. PRODUCTION TEST Date First Production iMeth°d of Operation (Flowing, gas lift, etc.) N/A__ ..... Date of Test Hours Tested PRODUCTION FOR iO~L-BBL GAS-MCF WATER-BBL TEST PER~OD ' ~ Flow TubingiCasing Pressure ~,ALCULATED ' 1OIL'BBL GAS-MCF WATER-BBL Press. i 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity~ fractures, apparent dips and presence of oil, ga chips. I'Oi[ iG~A-~)~Y:API (CORR) N/A Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markr"--" 30. '--" Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. N/A 31. List of Attachments Summary of Daily Drilling Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ..... S_ig_n ed__'J~"L- ~_ ~,~,,,,._ __~--- ....................................... · Title O~,tZ~L- ~;,~Et~.,~(,,- Date ~E~PT' 'Z. (~, ~Cl3r Prepared By Name/Number: Sharon AIIsup-Drake/263-4612 ....... INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage 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, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Date: 9/9/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iY-06A WELL ID: AK8885 TYPE: AFC:--AK8885 AFC EST/UL:$ STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD: START COMP: RIG:NORDIC WI: 908M/ 1135M API NUMBER: BLOCK: FINAL:08/26/97 0% SECURITY:0 50-029-20958-01 08/03/97 (D1) TD: 0'( 0} SUPV:RLM DAILY:$ 08/04/97 (D2) TD: 0'( SUPV:RLM 0) DAILY:$ 08/05/97 (D3} TD: 0'( 0} SUPV:DLW DAILY:$ 08/06/97 (D4) TD: 0' ( 0) SUPV: DLW DAILY: $ 08/07/97 (D5) TD: 0'( 0) SUPV:DLW DAILY:$ 08/08/97 (D6) TD: 0'( 0) SUPV:DLW DAILY:$ 08/09/97 (D7) TD: 0'( 0) SUPV:DLW DAILY:$ 08/10/97 (D8) TD: 0'( 0} SUPV:DLW DAILY:$ 08/11/97 (D9) TD: 0'( 0) SUPV:DLW DAILY:$ 08/12/97 (D10) TD: 0' ( 0} SUPV:DLW DAILY:$ MW: 0.0 VISC: 0 PV/YP: RIG MAINTENANCE Secure pad. Pull rig off lB pad. 27,149 CUM:$ 27,149 ETD:$ 0/ 0 APIWL: 0.0 0 EFC:$ 935,149 MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: RIG MAINTENANCE Move rig 4 miles from lB pad to 1Y pad. Prep rig to lay down derrick. 7,148 CUM:$ 34,297 ETD:$ 0 EFC:$ MW: 0 0 riSC: 0 PV/YP: 0/ 0 RIG MAINTENANCE Rig maintenance. 7,148 CUM:$ 41,445 ETD:$ 0.0 942,297 APIWL: 0.0 0 EFC:$ 949,445 MW: 0 0 VISC: 0 PV/YP: RIG MAINTENANCE Rig maintenance 7,149 CUM'$ 48,594 ETD'$ 0/ 0 APIWL: 0.0 0 EFC:$ 956,594 MW: 0 0 VISC: 0 PV/YP: RIG MAINTENANCE Rig maintenance 7,149 CUM:$ 55,743 ETD'$ 0/ 0 APIWL: 0.0 0 EFC:$ 963,743 MW: 0 0 VISC: 0 PV/YP: RIG MAINTENANCE Rig maintenance 7,149 CUM:$ 62,892 ETD'$ 0/ 0 APIWL: 0.0 0 EFC:$ 970,892 MW: 0 0 VISC: 0 PV/YP: RIG MAINTENANCE Rig maintenance 7,149 CUM:$ 70,041 ETD:$ 0/ 0 APIWL: 0.0 0 EFC:$ 978,041 MW: 0 0 VISC: 0 PV/YP: RIG MAINTENANCE Rig maintenance 7,148 CUM:$ 77,189 ETD:$ o/ o 0 EFC:$ APIWL: 0.0 985,189 MW: RIG MAINTENANCE Rig maintenance 7,149 CUM:$ MW: RIG MAINTENANCE Rig maintenance 7,148 CUM:$ 0 0 VISC: 0 PV/YP: 0/ 0 0 . 0 VISC: : S F.P 2 19907 91,486 ETD:$ EFC:$ ~l~l~j_t & .Gas _l~o~]s, APIWL: 0.0 992,338 APIWL: 0.0 999,486 Date: 9/9/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 08/13/97 (Dll) TD: 0'( 0) SUPV:DLW DAILY:$ 08/14/97 (D12) TD: 7335' (7335) SUPV:DLW DAILY:$ 08/15/97 (D13) TD: 7020' ( 0) SUPV:DLW DAILY:$ 08/16/97 (D14) TD: 6150' ( 0) SUPV:DLW DAILY:$ 08/17/97 (D15) TD: 6150' ( 0) SUPV: DLW DAILY: $ 08/18/97 (D16) TD: 6167' ( 17) SUPV: DLW DAILY:$ 08/19/97 (D17) TD: 6750' (583) SUPV:RLM DAILY: $ 08/20/97 (D18) TD: 7627' (877) S UP V: RLM MW: RIG MAINTENANCE Rig maintenance. 7,148 CUM:$ 0.0 VISC: 0 PV/YP: 98,634 ETD:$ 0/ 0 APIWL: 0.0 0 EFC:$ 1,006,634 MW: 9.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 NU BOPE Finish with the rig maintenance. Accept rig for operation @ 1100 hrs. 8/14/97. Pump water and mud down tubing. Well dead. 25,465 CUM:$ 124,099 ETD:$ 0 EFC:$ 1,032,099 MW: 9.6 rISC: 46 PV/YP: 11/15 APIWL: 10.2 L/D TBG N/D tree and N/U BOPE, function test. Test BOPE 300/3500 psi. Pull tubing to rig floor. Pump cement to P&A the well. Continue to pull and lay down tubing. 54,813 CUM:$ 178,912 ETD:$ 0 EFC:$ 1,086,912 MW: 9.5 VISC: 68 PV/YP: 16/29 APIWL: 8.0 MILL WEDGED WORKING TO FREE Continue to pull 3.5" tubing. RIH with whipstock. 47,343 CUM:$ 226,255 ETD:$ 0 EFC:$ 1,134,255 MW: 9.5 rISC: 60 PV/YP: 15/31 APIWL: 7.2 M/U DRILLING BHA & RIH Continue RIH w/whipstock assembly on 3.5" DP. Set whipstock w/bottom @ 6150' and top @ 6130' Shear off whipstock wedged mill @ whipstock face was unable to rotate. Work and torque milling assembly to free up. Came free after 6 hrs. Start cutting window from 6130' to 6149' Was unable to shut off pump #2 continued to run while controls turned off. Continue cutting window from 6149' to 6160'. Perform FIT, EMW of 11.7 ppg. 44,100 CUM:$ 270,355 ETD:$ 0 EFC:$ 1,178,355 MW: 9.7 VISC: 50 PV/YP: 12/15 APIWL: 6.8 DIRECTIONAL DRLG 6.125" @ 6270 Slide thru window @ 6130' to 6143' MWD malfunction tool face jumping around all over. Unable to correct problem. Recalibrate MWD and rerun BHA #2. Broke air lines to hydromatic. Continue RIH w/BHA #2 to 6129'. Slide thru window from 6130' to 6143' without pump. Start pump. Drill 6.125" hole from 6162' to 6167' 110,620 CUM:$ 380,975 ETD:$ 0 EFC:$ 1,288,975 MW: 9.7 VISC: 47 PV/YP: 13/17 APIWL: 5.2 DIRECTIONAL DRLG 6.125" @ 6924 Directional drill and survey with MWD from 6167' to 6367' Having problems making hole rotating or sliding. Circulate bottoms up while adding drill-n-slide. Still not able to make hole. Directional drill and survey with MWD from 6367' to 6750' 57,851 CUM:$ 438,826 ETD:$ 0 EFC:$ 1,346,826 MW: 11.2 VISC: 47 PV/YP: 21/21 APIWL: 4.0 CIRCULATE BOTTOMS UP Directional drill and survey with MWD from 6750' to 7627' Perform OH LOT to 12.1 ppg. Date: 9/9/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 DAILY:$ 08/21/97 (D19) TD: 7914' (287) SUPV:RLM DAILY:$ 08/22/97 (D20) TD: 8422' ( 508} SUPV:RLM DAILY:$ 08/23/97 (D21) TD: 8494' ( 72) SUPV:RLM DAILY:$ 08/24/97 (D22) TD: 8494' ( 0) SUPV:RLM DAILY:$ 08/25/97 (D23) TD: 8494' ( 0) SUPV:RLM DAILY:$ 08/26/97 (D24) TD: 8494' ( 0} SUPV:RLM DAILY:$ 60,121 CUM:$ 498,947 ETD:$ 0 EFC:$ 1,406,947 MW: 11.2 VISC: 50 PV/YP: 24/21 APIWL: 3.8 WELL SHUT IN ON KICK Directional drill and survey with MWD from 7627' to 7669'. Losing mud. Reduced pump rate from 160 spm to 100 spm, no improvement in losses. Performed OH LOT to 12.6 ppg. Increased mud weight to 11.2 ppg. Directional drill and survey with MWD from 7669' to 7914' 59,795 CUM:$ 558,742 ETD:$ 0 EFC:$ 1,466,742 MW: 11.8 VISC: 50 PV/YP: 26/21 APIWL: 3.8 CONDITION MUD TO TRIP OUT Directional drill and survey with MWD from 7914' to 8173' Well flowing, shut in well. Increase mud weight from 11.2 to 11.5 ppg. Circulate kick out through choke. CBU. Bottoms up gas and oil cut to 10.7 ppg. Directional drill and survey with MWD from 8173' to 8295'. Increased mud weight to 11.8 ppg while drilling. Directional drill and survey with MWD from 8295' to 8422' 58,732 CUM:$ 617,474 ETD:~ 0 EFC:$ 1,525,474 MW: 12.9 VISC: 49 PV/YP: 30/18 APIWL: 3.6 TRIP IN ON SHORT TRIP Directional drill and survey with MWD from 8422' to 8494' Circulate bottoms up. Monitor well, flowing. Weight up from 11.8 to 12.8. Monitor well, dead. Short trip to window at 6130' extremely tight from 7843' to 7688'. Had to work, pump and ream to get through this area. Had intermittent severe packing off problems. 59,975 CUM:$ 677,449 ETD:$ 0 EFC:$ 1,585,449 MW: 12.9 VISC: 49 PV/YP: 33/20 APIWL: 3.8 RIH W/3.5" LINER Continue POOH. Work, pump and ream out from 7790' to 7843'. RIH slow to minimize surge pressures, hole free, no fill. Circulate bottoms up, mud cut to 12.2 ppg. Drop tandem single shot survey. Retrieve survey. Run 3.5" liner and make up liner hanger and packer. 37,069 CUM:$ 714,518 ETD:$ 0 EFC:$ 1,622,518 MW: 12.3 rISC: 50 PV/YP: 30/18 APIWL: 4.0 LAY DOWN DP Run 3.5" liner to window at 6130' Circulate bottoms up mud cut 12.9 to 12.6 weight up to 12.8 ppg. Lost all returns, well taking 2-3 bbls/minute. Run liner to bottom at 8484' Cement liner with shoe at 8492' Circulate long way to remove oil and gas cut mud from well. 122,203 CUM:$ 836,721 ETD:$ 0 EFC:$ 1,744,721 MW: 8.4 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 PREP TO NIPPLE DOWN BOPE Lay down drill pipe. Run in with drill collars and remaining drill pipe. Run in hole with completion to liner top at 5915' Test casing, liner and liner lap to 2500 psi with 12.3 mud for 30 minutes. 102,241 CUM:$ 938,962 ETD:$ 0 EFC:$ 1,846,962 Date: 9/9/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 08/27/97 (D25) TD: 8494' ( 0) SUPV:RLM DAILY:$ MW: 8.4 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Test 3.5" tubing and 7" x 3.5" annulus with diesel. OK. ND BOPE. NU tree.'Test packoff to 5000 psi, test tree to 250/5000 psi. Release rig at 1430 hrs. 8/27/97. 21,183 CUM:$ 960,145 ETD:$ 0 EFC:$ 1,868,145 End of WellSummary for Well:AK8885 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 26, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1Y-06 (Permit No. 83-78) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the recent abandonment of KRU 1Y-06. This well was sidetracked and re-drilled to an alternate bottom hole location and renamed 1Y-06A. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad ORIGINAL RECEIVE,'D SEP 29 1997' Gas ~.0ns, 60m_lCs_~lo' STATE OF ALASKA ALASKA OIL AND.rGAS CONSF_,RVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend Operation Shutdown Re-enter suspended well Alter casing _ Repair well _ Plugging ~ Time extension _ Stimulate m Plugback for Change approved program _ Pull tubing _ Variance _ Perforate _ Other X Reddll 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development ARCO Alaska. Inc. Exploratory 96' RKB. Pad 67' feet 3. Address - Stratigraphic _ 7. Unit or Property name .P.O. Box 100360, Anchorage, AK 99510 Service _ Kuparuk River Unit 4. Location of well at surface 8. Well number 571' FNL, 1911' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 9. Permit number 1277' FSL, 1044' FEL, Sec. 1, T11N, R9E, UM At effective depth 10. APl number 1098' FSL, 982' FEL, Sec. 1, T11N, R9E, UM 50-029-2095{I At total depth 11. Field/Pool 1036' FSL, 962' FEL, Sec. 1, T11N, R9E, UM Kuparuk River 12. Present well condition summary Total Depth: measured 8120 feet Plugs (measured) None (approx) true vertical 6436 feet Effective depth: measured 7982 feet Junk (measured) Top of fill @ 7817' (approx) true vertical 631 4 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' 1 6 ' 280 sx AS II 1 10' 1 1 0' Surface 2427' 9.625' 1000 sx AS III 2458' 2199' Intermediate & 368 sx AS I Production 8034' 7' 900 sx Class G & 8064' 6387' Liner 150 sx AS I J~'~ ~ ~ ~ ~ # Perforation depth: measured J~ [~ ~ ~ ~ V' 7565'-7659', 7796'-7800', 7809'-7834', 7859'-7863' true verticalJ U L. 0 1997 5942'-6027', 6149'-6153', 6161'-6183', 6205'-6208' Tubing (size, grade, and measured depth) .~].aS~ ~jJ & Gas Cons, 4', 11#, J-55 @ 4007', 3.5', 9.3#, J-55 @ 7359' '- Packers and SSSV (type and measured depth) 4' Camco TRDP-4A SSSV @ 1798', Camco 7x 3.5' HRP-1-SP retr. packer @ 7349' & Baker 7' FB-1 perm. pkr @ 7741' 13. Attachments Description summary of proposal , Detailed operation program ~ BOP sketch Contact William Isaacson at 263-4622 with an)/cluestions. 14. Estimated date for commencing operation 15. Status of well classification as: Julv 16. 1~7 Oil Gas Suspended ~ 16. If proposal was verbally approved of appr.~ver / Date approved Service , & Name 17. I hereby ce~'~y~//ith.~the/foregoing is true and correct to the best of my knowledge. Ft."(/~ Title Drill-Site Development Supv Date ~'7-'~...-? '7 Signed FOR COMMISSION USE ONLY Conditions of approval: ~ commission so re.i;~.resentative may witness IApprova~ Plug integrity BOP Test ~__ Location clearance ~ Mechanical Integrity Test_ Subsequent form require ,.Jrtg nal Signea By iApproved by the order of the Commission Oavid W. JohnstonCommissioner Date '~'"/1 " rm 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Approved C® Returned KRU 1Y-06 SUNDRY OBJECTIVE to P & A WELL FOR SIDETRACK OPERATIONS (reference attached plugback schematic) PRE-RIG WORK: 1. RU slickline unit. RIH and isolate C Sand behind pipe by setting an isolation sleeve in AVA nipple (which is incorporated into merla patch across C Sand mandrel at 7428' MD RKB). . 3~ Establish injection rate into A Sand perfs for upcoming cement downsqueeze. RU CTU. RIH with inflatable cement retainer on CTU. Set inflatable in 3-1/2" tubing immediately below top production packer. Mix cement. Circulate the cement down coil to immediately above circulating valve on top of retainer. Close circulation valve and down- squeeze cement below retainer into A Sand peris. Use sufficient volume to fill 3-1/2" tubing down through tubing tail and 7" casing from top of fill to tubing tail, plus excess to squeeze away into peris if possible. Unsting from retainer and circulate well clean on top of inflatable retainer. RDMO CTU. RU sliclfline unit. RIH and pull dummy valve from bottom GLM at 7284' MD RKB, leaving an open pocket. WORKOVER RIG WOmb; 1. MIRU Nordic Rig 2. Lay hard-line to tree. 2. Verify well is dead. Load pits w/water. Circulate well to water. 3. Pressure test wellbore to 2500 psi testing cement squeeze and retainer, to ensure isolation from perforations. Set BPV. 4. ND tree. NU and test BOPE. . Screw in landing joint. Pull tubing hanger to rig floor. Spot a 150' cement plug on top of top production packer. Pull above cement plug top and reverse circulate tubing clean. POOH laying down all 4" tubing and standing back 3-1/2" tubing. 6. RU E-line unit. Run gauge ring through bridge plug setting depth. RIH and set permanent bridge plug at 6138' MD-RKB. 7. Whipstock will be set immediately above bridge plug to allow milling of 7" casing and kicking-off for sidetrack. WSI 7/8/97 Milling Fluid Fresh water 1Y-06 Proposed P ugback APl #: 50-029-20958 RKB = 96' Pad Level = 67' 9-5/8" 40#, J-55 set @ 2458' MD 7" Baker 'Window Master - Bottom Trip Whipstock System' set on top of bridge plug. 7" Baker 'N-I' Bridge Plug @ 6138' MD. 50' Balanced Cement Plug with top at +/-7185' MD. Abandoned C Sand Perfs Isolated Behind Tubing 3-1/2" x 7" Camco 'HRP-1-SP' Retrievable production packer w/PBR @ 7335' MD. 3-1/2" x 7" Camco 'HRP-I-SP' Retrievable production packer w/OEJ @ 7359' MD. Inflatable cement retainer set in tubing at +/-7405' MD with cement squeezed below retainer to fill 3-1/2" tubing and 7' casing down to top of fill at +/-7953' MD. Top perforation @7565' MD Bottom perforation @ 7659' MD Abandoned A Sand Perfs 7", 26#, J-55 3-1/2" x 7" Baker 'FB-I' Permanent packer @ 7741' MD. Tubing tail at +/-7772' MD. Top pedoration @ 7796' MD Bottom pedoration @ 7863' MD of fill tagged at +/-7953' MD. PBTD =7982' MD TD = 8120' MD WSI 7/8/97 . STATE OF ALASKA ALASKA OIL AND GAS CONSE~AT~ COMMIS~ REPORT OF SUNDRY WELL OPERATIONS Perforate __ "~"~'~w~h~,,._,.. Other X 6. Datum elevation (DF or KB) -:~' RKB 96 feet 7, Unit or Property name Kuparuk River Unit 1. Operations Performed: Operation Shutdown __ Stimulate Pull tubing Alter casing Repair well 2. Name of Operator 5. Type of Well: Development _ ARCO Alaska. Inc. Exploratory _ 3. Address Stratigraphic _ P. O. Box 100360, Anchorage, AK 99510 Service X Plugging __ 4. Location of well at surface 571' FNL, 1911' FWL, Sec 1, T11N, R9E, UM At top of productive interval 1277' FSL, 1044' FEL, Sec 1, T11N, R9E, UM At effective depth 1098' FSL, 982' FEL, Sec 1, T11N, R9E, UM At total depth 1036' FSL~ 962' FEL~ Sec 1~T11N~ R9E~ UM 12. Present well condition summary Total Depth: measured 81 2 0 true vertical 6436 feet feet 8. Well number 1Y-06 9. Permit number/approval number 83-78 10. APl number s o-029-20958 11. Field/Pool Kuparuk River Oil Field/Pool Plugs (measured) None Effective depth: measured 7982 true vertical 6314 feet feet Junk (measured) None Casing Length Size Structural Conductor I 1 0' 1 6" Surface 2427' 9-5/8" Intermediate Production 8 03 4' 7" Liner Perforation depth: measured 7565'-7959', true vertical 5942'-6027', Tubing (size, grade, and measured depth) Cemented Measured depth True vertical depth 280 SX AS II 1 1 0' 1 10' 1000 SX AS III & 2458' 21 99' 368 SX AS I 900 SX Class G & 8 0 6 4' 6 3 8 7' 150 SX AS I 7796'-7800', 7809'-7834', 6149'-6153', 6161'-6183', 7859'-7863' 6205'-6208' SSSV: Camco TRDP-4A @ 1794' RECEIVED DEC 1 7 199 Alaska Oil & Gas Cons. Commission 4", 11#, J-55 @ 4004', 3.5", 9.2#, J-55 @ 4004'-7759' Packers and SSSV (type and measured depth) PKR: Baker FB-1 @ 7737' & Camco HRP-1-SP @ 7345' & 7377'; 13, Stimulation or cement squeeze summary Converted well from Oil Producer to MWAG Injector on 12/5/93. Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A 14. Re0resentative Daily Average Production or In!ection Data Anchorage OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 658 2212 7016 1100 220 Subseciuent to operation 0 0 1000 1720 1510 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil _ Gas Suspended Service MWAG Ini 17. I here~}( certify that the foregoing is true and correct to the best of my knowledge. Si9ned . Title Senior Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE RECEIVED DEC 1 ? 199~ A!~ska Oil & G~s Oons. CommJssjor, Anchorage/ , F T P F T r v,~ P P id P ~-.:; i P ._~c' i" n '-'M, OM 0 . w.F, 0 0 OH ?' -" .!.76 16°, oo "-'l 0 0,,'1 Or4 ~ = 0 OM OM. 0 i 76 172 '~ ~ ' 65 176 171 130 '74 0 OM OM 0 176 210 I I0 97 is;= 13!3 119 4'7 176 179 !40 91 0 "~-' = 478 142 v5 176 16B 93 5 0 600 0 0 0 Q 0 9~0 400 ' 0 i400 40 0 5,20 0 65 tOrO 660 40 l~nO~-. ~°70 0 0 0 20 1360 720 55 2660R 190 80 t 450 860 0 1400 0 80 !lOO ltOOR 0 /.nn aO0 T l'-l,J OP i- '~P'TER VOl_ RA"FE i:;L., ..-.a D T h..iO Pi:'36 F tfl'-~(]. FDP "'~,"" '~ "-. 0 600M 769 ~,';. ~"~ 6 ,.,, ~. 5 0 O .500 .7'. 0 ¢.-~ 50 () ":. '.) · 3 "' 5 3 0 51. 7 ',500 '!. 0 0 500 ,=-' 'i- 0 0 ...500 2. ~"..' 0 658 462 ;:....':. 5 0 451 433 O. 0 0 500 ._-~. 0 7~4 -/90 ',5. 3 0 0 (} O. (') 0 2 0 O. ,";, 0 1 O0 500 2. C.: 0 0 0 C,. 0 0 fO 5 0 0 '.:-:!. ,'.::';' C ~v 'r i'] '' ;,l -72 'l'i',! .:__ ................ '~ '. } 00 t'-'> '-: ;":.3 (} 0 . .~ i ;5 ':.7., :i. ,", ('5(]: -:. C; 0 C: ) Q '-" C'.' ,. _,,~- .:. !._' () ~'!-00 0 ';'.) 00 0 ';.' 00 0 . ,.7?..0 .,.'-='..'3 ",' ;} (',' 0 · .."!00 36 · .,' q3'.'_'~ .... (} (?, OTALS' o7~-9 74.54. IN,JECTION WELL STATUS yj '7 "- E O T CHOKE 7" 10" I.._ N A OR TN,J '.:]SO CS'g- l_ E T % PS! FTT PSI PSI ! ~ PW .I00 21z-.o .... 146 1050 "" B- MI om :2895 I02 ,,-n 3 B PW I00 21:26 148 1220 300 4 B F'W 100 ~164 147 Ii00 200 ~ 25 175! 143 !800- OW !I'qdECTiON VOLUMES 0 3464 0 0 0 4!53 0 4631 I hI,J VOL MMSCF 5137- 0.000 0 8.193 4870* 0.000 5781'~ O. 000 0 IO00M 5781~ 0.000 7 B MI 8 B PW 9 B PW 10 ~ PW !1 B PW 2 B PW 3 B PW q A PW :. B i 0 -I 5 .I ,,", 145 ! 7''~r'~ 0 ! O0 3459 102 0 0 i00 2166 146 600 500 100 2! 30 !48 750 575 100 ~1~¢o i49 !00 2147 147 2650R 400 ~5~ i 768 146 ,.* '*20~--, ~ 700 5 1736 147 1-400~ 700 .... '~ :47 -' 5"'~0 760 5 1555 t t O(}Olfl __ 0~.* O. 0 0 13. 307 ,39[38 2704 O. 000 3005 3952~ O. 000 ..~0 ,i O. "72 q. 6 = o 000 ].900' 32!93 O. 000 1 ~'' c.'- '~ ~ o · ~ ..... .......... · ;_-, c-~ O. 4 ;3'77 3948 O. 000 !. 6 ;:_! 9 26 i 0 * 0. r'j () C) c,L.: :f.,O 4 '4-:--/.(_'~O. G,.')Q. . ARco Alaska, Inc. Post Office ~100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 13, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in;tr.,.i, pJiCate'are multiple Applications for Sundry Approval on the following Kuparuk wells. W~II 95--~,~, 1Y-0 4 _ ~,~?e, 1Y-06 ~.~..u~?_ 1Y-16 Action Change Program Change Program Change Program Anticipated Start Date 9/93 9/93 9/93 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments RECEIVED 8EP ! ? ]993 Anch0ra~e ARCO Alaska, Inc. is a Subsidiary ot AtlanticRichfieldCompany AR3B-6003-C · ~ - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS,51ON ~'"/~) APPLICATION FOR SUNDRY APPROVALS 1 Type of Request: Abandon __ SuSpend__ Operation Shutdown __ Re-enter suspended well -- I Alter casing_ Repair well_ Plugging_ Time extension_ Stimulate__ /~/&; I Change approved program ~ Pull tubing __ Variance m Perforate __ Other __ "~/~,~ 2. Name of Operator 6. Datum elevation (DF or KB) ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well' Development _ Exploratory _ RKB 96 Stratigraphic _ 7. Unit or Property name Service ~ Kuparuk River Unit 8. Well number 1Y-06 g. Permit number 83-78 10. APl number 50-029-20958 11. Field/Pool Kuparuk River Oil Field/Pool 4. Location of well at surface 571' FNL, 1911' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 1277' FSL, 1044' FEL, Sec. 1, T11N, R9E, UM At effective depth 1098' FSL, 982' FEL, Sec. 1, T11N, R9E, UM At total depth 1036' FSL~ 962' FEL, Sec. l~T11N, R9E, UM 12. Present well condition summary Total Depth: measured 81 2 0 true vertical 6 4 3 6 feet Plugs (measured) None feet feet Effective depth: measured 7 9 8 2 true vertical 6 31 4 feet Junk (measured) None feet Casing Length Size Structural Conductor 1 1 0' 1 6" Surface 24 2 7' 9 - 5 / 8" Intermediate Production 8034' 7" Liner Perforation depth: measured 7565'-7659', true vertical 5942'-6027', Tubing (size, grade, and measured depth) Cemented 28O SX AS II 1000 SX AS III & 368 SX AS I 900 SX Class G & 150 SX AS I Measured depth True vertical depth 110' 110' 2458' 2199' 8064' 7796'-7800', 7809'-7834', 7859'-7863' 6149'-6153', 6161'-6183', 6205'-6208' 4", 11#, J-55 @ 4004', 3 1/2", 9.2#, J-55 @ 4004'-7759' Packers and SSSV (type and measured depth) 6387' RECEIVED SEP ! ? ].°.,93 _ Anchorage PKR' Camco HRP-I-SP @ 7345' & 7377', Baker FB-1 @ 7737'; SSSV: Camco TRDP-4A @ 1794' 13. Attachments Description summary of proposal Connvert oil producer to MWAG injector. 14. Estimated date for commencing operation September 1993 16. If proposal was verbally approved Name of approver X Detailed operation program _ BOP sketch Date approved 15. Status of well classification as: Oil __ Gas __ Suspended Service MWAG In!ector 17. I hereby~Jertify that_the foregoing is true and correct to the best of my knowledge. Si~ned , Title Senior Engineeer FOR COMMISSION USE ONLY Date ~*"~'-~' "~ Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test _ Location clearance __ Mechanical Integrity Test ~,. Subsequent form require 10- ~*/ JApprov_al No. Approved by order of the Commission Form 10-403 Rev 06/15/88 Origins-!c~u,°'"'~'-"d,~ By David W. Johnston Commiesioner -' E)ate--~'7)'/~ 2//7 ,,~ SUBMIT IN TRIPLICATE Attachment 1 Conversion to Water Injection Kuparuk Well 1Y-06 ARCO Alaska requests approval to convert Well 1Y-06 from an oil producer to an MWAG injector. This well will be operated as a Class II UIC well in compliance with Area Injection Order No. 2. Water alternating with miscible gas will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 5942' and 6208' TVD. This interval correlates with the strata found in ARCO's West Sak River State Well No. 1 between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. ECE VED SEP 1 7 1993 Alaska 0il 8, gas Go, Is. b..:~:.., .- An~horag~"~ STATE Of ALASKA ALASKA OIL AND GAS ~SERVATION ~MISSION 0 REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown__ Pull tubing X Alter casing Stimulate __ Plugging Perforate _ Repair well Other ~ 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 571' FNL, 1911' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 1277' FSL, 1044' FEL, Sec. 1, T11N, R9E, UM At effective depth 1098' FSL, 982' FEL, Sec. 1, T11N, R9E, UM At total depth 1036' FSL, 962' FEL, Sec. 1, T11N, RgE, UM 12. Present well condition summary Total Depth: measured true vertical 8120' 6436' feet feet ~{~' RKB. PAD 67' 7. Unit or Property name Kuparuk River Unit 8. Well number 1Y-06 feet 9. Permit number/approval number 83-78///261 10. APl number 50-029-20958 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) None Effective depth: measured 7982' true vertical 631 4' feet feet Junk (measured) Top of fill @ 7817' tagged 4/29/89. Casing Length Structural 8 O' Conductor Surface 2427' Intermediate Production 8 0 3 4' Liner Perforation depth: measured 7565'-7659', true vertical 5942'-6027', Size 16" Cemented 280 Sx AS II Measured depth True vertical depth 11 0'md 1 1 0'tvd 9-5/8" 1000 sx AS III 2458' md 2199' tvd 368 sx AS I 7" 900 sx Class G 8064' md 6387' tvd 150 sx AS I 7796'-7800', 6149'-6153', 7809'-7834', 6161'-6183', 7859'-7863' 6205'-6208' Tubing (size, grade, and measured depth) 4" 11#J-55 @ 4007, 3-1/2" 9.3# J-55 @ 7359' Packers and SSSV (type and measured depth) Baker 'FB-I' Pkr @ 7746', Camco 'HRP-1SP' @ 7335', Camco 'TRDP-4A' SSSV ~ 1797' 13. Stimulation or cement squeeze summary RECEIV D OCT 2,5 1991 ~,laska 0ii & Gas Cons. C0t~ Anchorage..~ Intervals treated (measured) Treatment description including volumes used and final pressure 14. Reoresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X. 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. S,gni Title Area Drilling Engineer F°rm 10-404 Rev 05/17/89 Date SUBMIT IN DUPLICATE ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: 1Y-06 BOROUGH: NORTH SLOPE UNIT: KUPARUK RIVER UNIT FIELD: KUPARUK RIVER FIELD LEASE: ADL 25646 ALK 2577 API: 50-029-20958 PERMIT 83-78 APPROVAL: Conservation Order #261 ACCEPT: 08/24/91 17:30 RELEASE: 08/27/91 16:30 OPERATION: WORKOVER RIG: NORDIC 1 AFE: AK6179 WI: 55.347699 08/25/91 ( 1) TD: 0 PB: 7982 SUPV:GB/CD 08/26/91 (2) TD: 0 PB: 7982 SUPV:GB/CD 08/27/91 ( 3) TD: 0 PB: 7982 SUPV:GB/CD DISPLACE WELL TO 11.3 PPG THXL MW:ll.3 THXL MOVE RIG FROM 3K-12 TO 1Y-06,ACCEPT RIG @ 1730 HRS 24-AUG-91 LEVEL RIG, PULL VR PLUG F/ANNULAR VALVE,RU KILL LINE TO FLOW TANK, PULL BPV, DISPLACE WELL TO SEA WATER, SITP=750 PSI SICP=750 PSI,TAKE ON THIXSAL BRINE,DISPLACE WELL TO 11.3 PPG THIXSAL DAILY:S40,274 CUM:$40,274 ETD:S40,274 EFC:$230,000 POH/LD 3 1/2" BTC TUBING MW:ll.0 THXL CONT DISPLACE WELL W/ll.3 PPG THIXSAL, 11.3 PPG IN/10.8 PPG OUT, SHUT DN AND MONITOR WELL, BUILD VOLUME IN PITS,FLUID LOSS +/- 40 BBL/HR, SET BPV, ND TREE,NU BOPE,PULL BPV, INSTALL TEST PLUG, TEST BOPE TO 3000 PSI,PULL TBG HGR TO FLOOR, CIRC AND BUILD VOLUME,REDUCE THIXSAL WT F/ll.3 TO 11.0 PPG,MONITOR WELL, OK, PUMP SLUG, LD TBG HGR, POH W/COMPLETION STANDING BACK 4" TUBING, RABBIT AND STRAP SAME,LD 3 1/2" BTC TUBING AND JEWELRY,FLUID LOSS +/- 5 BBL/HR DAILY:S51,067 CUM:$91,341 ETD:S91,341 EFC:$230,000 LAND TUBING MW:ll.0 THXL SERVICE RIG, CONT POH W/COMPLETION, LD 106 JTS 3 1/2" BTC MOD TBG,CLEAR RIG FLOOR, LOAD PIPE SHED W/3 1/2" EUE MOD TBG DRIFT STRAP TALLY SAME,INSTALL SEAL RINGS, SLIP AND CUT DRLG LINE,PU CAMCO PKR ASSY,RIH W/4" X 3 1/2" SINGLE SEL. COMP,MU CAMCO 4" SSSV, TEST CONTROL LINE TO 5000 PSI,CONT RIH,TAG PACKER, VERIFY POSITION W/700 PSI,SPACE OUT,MU FMC GEN 4 TBG HGR, TEST CONTROL LINE TO 5000 PSI,LAND HANGER DAILY:S116,154 CUM:$207,495 ETD:S207,495 EFC:$230,000 SIGNATURE: RECEIVED ARCO Alaska, Inc. Date: May 12, 1989 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. 30-18 . .'~3A-03 ~'3A-08 ~"30-11 ~"'30-13 ~"30-17 B-14 D-08 "~'3A-0S ~3 2 O-1 2 -14 '~1 R-02 '~3F-1 6 ~ 3F-16 '~'1 R-02 ~1Y-06 '~' 2T-07 ""~ 1 E-25 Sub-Surface Pressure Survey Kuparuk Fluid Level Report Kuparuk Fluid Kuparuk Fluid Level Re Kuparuk Fluid Level Re Kuparuk Fluid Level Re Kuparuk Fluid Level Re Kuparuk Fluid Level Re Kuparuk Fluid Level Re Kuparuk Fluid Level Re Kuparuk Fluid Level Re Kuparuk Fluid Level Re Kuparuk Fluid Level Re Kuparuk Fluid Level Re Kuparuk Fluid Level Re Kuparuk Fluid Level Re Kuparuk Fluid Level Re Kuparuk Fluid Level Re Kuparuk Fluid Level Re Kuparuk Fluid Level Re, Kuparuk Well Level Report Presure Report 8 Transmittal #: 7470 Please acknowledge receipt and return 2-15-89 4-23-89 4-23-89 3ort 4 - 2 2 - 8 9 3ort 4 - 2 2 - 8 9 3ort 4 - 2 2 - 8 9 3ort 4 - 2 4 - 8 9 3ort 4 - 2 4 - 8 g 3ort 4 - 2 4 - 8 9 3ort 4 - 2 4 - 8 9 3ort 4 - 2 9 - 8 9 3ort 4 - 2 9 - 8 9 3ort 4 - 2 9 - 8 9 3ort 4 - 3 0 - 8 9 3ort 4 - 2 9 - 8 9 3ort 5-03-89 3ort 5 - 0 4 - 8 9 3ort 5 - 0 3 - 8 9 3ort 5 - 0 8 - 8 9 3ort 5 - 0 7- 8 9 11-07-8 #64613 Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Tubing Casing Casing Casing Amerada Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION: D&M ~ SAPC Chevron Mobil Unocal ARCO Alaska, Inc. Date: December 30, 1988 Transmittal #: 7392 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 Z- 1 4 Kuparuk Fluid Level Report I 2- 2 7- 8 8 1 Y- 0 6 Kuparuk Fluid Level Report I 2- 2 6 - 8 8 2A-05 Kuparuk Fluid Level Report I 2-26-88 2 X- 1 4 Kuparuk Fluid Level Report I 2- 2 5 - 8 8 2 Z- 1 3 Kupaurk Fluid Level Report 1 2- 2 6 - 8 8 2 C- 0 9 Kuparuk Fluid Level Report I 2- 2 2- 8 8 2 W - 01 Kuparuk Fluid Level Report 1 2- 2 2- 8 8 3 K - 0 6 Kuparuk Fluid Level Report 1 2 - 21 - 8 8 3 B - 1 3 Kuparuk Fluid Level Report 1 2- 2 1 - 8 8 Tubing Casing Tubing Tubing Tubing Casing Casing Casing Casing Receipt Acknowledged: DISTRIBUTION: D&M State of Alaska Unocal Chevron Mobil SAPC · - STATE Of ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OILN'~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-78 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20958 4. Location of well at surface 9. Unit or Lease Name 571' FNL,1911' FWL, Sec.1, T11N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1277' FSL, 1044' FEL, Sec. 1, T11N, R9E, UM 1Y-6 At Total Depth 11. Field and Pool 1036' FSL, 962' FEL, Sec.1, TllN, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 96' RKB .J ADL 25646 ALK 2577 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 05/15/83 05/22/8:3 06/11/8:3'I 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 8120'MD/64:36'TVD 7982'MD/6:314'TVD YES'X~] NO [] 1779' feet MD] 1:350' (approx) 22. Type Electric or Other Logs Run GR/SP/DIL/SFL/FDC/CNL/Cal , CBL/GR/CCL/VDL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 7:3' 24" 280 sx AS I I 9-5/8" 40.0# J-55 Surf 2458' 12-1/4" 1000 sx AS Iii & 368 sx AS I 7" 26.0# J-55 Surf 8064' 8-1/2" 900 sx Class G & 150 s:~ AS I · 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) 4"/3~" 7759' ?'~RR' & 777R' Perforated w/12 spf 7565 '-7659'MD/5942'-6027 'TVD 26. ACI D, FRACTUR E, cEMENT SQUEEZE, ETC. 7796'-7800'MD/61#9'-6153'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7809 ' -7834 'MD/6161 ' -618:3 'TVD Stimul ati on data 7859 ' -7863 'MD/6205 ' -6208 'TVD when comol eted. -, 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER~BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ ..... Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~F · 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or ware r. Submit core chips. None DEC 1 9 1988 Alaska 0ii & ~-~s Con:. Commission * NOTE: Drilled RR 5/24/83. Perforated we]l& ran tubing 6/11/8:3. Workover performed 9//~r.a§e - Form 10-407 Submit in duplicate /7, -/ Rev. 7-1 ~80 CONTINUED ON REVERSE SIDE OEo~.OGic MARKERS:; :' ~ ';. ',-"."~,',' '.' i'..! i i'_i.~i,! :i ,-"~ . NAME Include interval tested, pressure data, all fluids recovere~l and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 756z~' 59z~2' N/A Base Upper Sand . . 7653' 6022' · Top Lower Sand 7786' 6141' Base Lower Sand .,7921' 6261' : . .. ,~ . . 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge : . _ Signed ~ ~ ~7 Title ~Fea 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- lng and the location of the cementing tool. ; Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas I njecti0n!"S~hut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. Date: December 15, 1988 Transmittal #: 7375 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 4 Kuparuk Fluid Level Report '1 2- 1 0- 8 8 ~ 3 H - 1 5 Kuparuk Fluid Level Report I 2- 0 9 - 8 8 · 3 H- 1 7 Kuparuk Fluid Level Report I 2- 0 9 - 8 8 · 3 M - 1 9 Kuparuk Fluid Level Report I 2- 0 9 - 8 8 · 3 H - 0 6 Kuparuk Fluid Level Report 1 2- 0 8 - 8 8 · 3 H - 0 9 Kuparuk Fluid Level Report 1 2- 1 3 - 8 8 · 3 H - 21 Kuparuk Fluid Level Report I 2- 1 3 - 8 8 · 3 K - 0 6 Kupaurk Fluid Level Report I 2- 1 2 - 8 8 · 3 H- 21 Kuparuk Fluid Level Report I 2-1 2- 8 8 · 1 Y- 0 6 Kuparuk Fluid Level Report I 2-1 2 - 8 8 ' 30-07 BHP Report I 1-27-88 Casing Tubing Casing Casing Tubing Casing Casing Casing Casing Casing Receipt Acknowledged: Alaska Oil & 62,s Cc~=. Commission A~.~c~orage Date: ............ DISTRIBUTION: State of Alaska D&M Unocal SAPC Chevron Mobil .,, "-"- STATE OF ALASKA AL~_.~ OIL AND GAS CONSERVATION COMMIb... ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Perforate __ Pull tubing ~ Alter casing __ Repair well ~ Pull tubir~g -X-- 2. Name of Operator ARCO Alaska, inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well: Development --X-- Exploratory __ Stratigraphic __ Service __ 4. Location of well at surface 571' FNL, 1911' FWL, Sec.1, T11N, RgE, UN At top of productive interval 1277' FSL, 1044' FEL, Sec.l, T11N, R9E, UH At effective depth 1098' FSL, 982' FEL, 5ec.1, T11N, R9E, UN Attl°(~16d'ePFtsbL, 962' FEL, Sec.1, T11N, R9E, UN 12. Present well condition summary Total depth: measured true vertical 8120 ' MD None feet Plugs (measured) 6436 'TVD feet Effective depth: measured true vertical 7982 'MD feet Junk(measured) None 6314 'TVD feet Casing Length Structural Conductor 73 ' Surface 2427 ' Intermediate Production 8034 ' Liner Perforation depth: measured Size Cemented Measured depth WORKOVER Other -X- true vertical 6. Datum elevation (DF or KB) RKB 96 ' 7. Unit or Property name Kuparuk River Unit 18~ _W6ell number 16" 280 sx AS II 73'MD 9-5/8" 1000 sx AS III & 2458 'MD 368 sx AS I 7" 900 sx Class G & 8064 'MD 150 sx AS I 7565'-7659'MD, 7796'-7800'MD, 7809'-7834', 7859'-7863' 9. Permit number/approval number 83-78/8-602 10. APl number 50-- 029-20958 11. Field/Pool KuparukRiver Oil Pool 5942'-6027'TVD, 6149'-6153'TVD, 6161'-6183'TVD, 6205'-6208'TVD Tubing (size. grade, and measured depth) 4"/3-1/2", J-55, tbg w/tail @ 7759' Packers and SSSV (type and measured depth) Camco 'HRP' pkr ~ 7368', Baker 'FB-I' pkr ~ 7728', & AVA SSSV @ 1779' 13. Stimulation or oement squeeze summary N/A Intervals treated (measured) True vertical depth Treatment description including volumes used and final pressure 14. N/A 73'TVD 2199'TVD Prior to well operation Subsequent to operation 6387 'TVD 15. Attachments Copies of Logs and Surveys run..._ Daily Report of Well Operations ._~ Representative Dali)/Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 16. Status of well classification as: Oil X Gas__ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /'~g(.,~/rJ,~ ~' ~//' Title Area Drilling Engineer Form 10-404 Rev 06/15/88 (Pani) 5W03/039 ~0TE: Workover Well History Service Tubing Pressure feet Date/~//t SUBMIT IN DUPLICATE ARCO Oil and Gas Company Well History - Initial Report - Dally Insbuctionl: Prepare and submit the "initial RN~ort" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO Alaska, Inc. Field KUPARUK Auth. or W.O. ,8t2(2891 ICounty, pa~ID{i~M'o~LOP E Lease or I.~L .' 25646 Title WORKOVER API: 50-029-20958 IState AK 1Y-06 Well no, Operator A~CO Spudded or W.C~.~T JDate 09/06/88 IHour Date and depth as of 8:00 a.m. 09/07/88 ( Complete reco~aT~l~ d~]~ reported CIRC 10.2 PPG BRINE 1430 HRS IARCO~.. 0000 Prior stalus if s W.O, Y~: 10.2 NACL/NABR TD: 8120 PB: 7982 SUPV:DS 09/08/88 ( TD= 8120 PB: 7982 SUPV:MD/L 09/09/88 ( TD: 8120 PB: 7982 SUPV:MD/L 09/10/88 ( TD: 8120 PB: 7982 SUPV:MD/L 09/11/88 ( TD: 8120 PB: 7982 SUPV:MD/L 09/12/88 ( TD: 8120 PB: 7982 SUPV:MD/L 09/13/88 ( TD: 8120 PB: 7982 SUPV:MD/L 2) 5) MOVE RIG TO 1Y-06, ACCEPT RIG @ 1430 HRS, RU HARDLINE, RU SLICKLINE, PULL DV FROM GLM @ 7386, LOAD TGB W/FRESH WTR, RECORD PRESSURE, CIRC FRESH WTR INTO ANNULUS, RECORD SITP=650 PSI, PUMP 10.2 PPG BRINE DOWN TBG, SITP-0, CIRC 10.2 PPG BRINE INTO ANNULUS DAILY=S116,733 CUM:$116,733 ETD:S116,733 EFC=$780,000 CIRC WITH 10.3 PPB BRINE MW:10.3 NACL/NABR CONT. CIRC. TO KILL WELL, LOST RETURNS, SPOT 20 BBL HOWCO TEMPBLOK PILL ACROSS PERFS, MONITOR WELL, CIRC 10.1 PPG BRINE, 65% RETURNS, CIRC. 9.9 PPG BRINE, SITP-60 PSI, CIRC. 10.0 PPG BRINE, SITP=50 PSI, CIRC 10.1 PPG BRINE, SITP-20, CIRC. 10.3 PPG BRINE DAILY:S91,154 CUM:$207,887 ETD:S207,887 EFC=$780,000 POH WITH 3-1/2" TBG MW:10.3 NACL/NABR CONT. CIRC. WITH 10.3 PPG BRINE, PUMP TEMPBLOK PILL, ND TREE, NU BOPE, ROTATE AND PULL TBG FREE, CIRC. 10.3 PPG BRINE (23 BBL LOST}, PUMP TEMPBLOK PILL, POH WITH 3-1/2" TBG DAILY:S82,525 CUM:$290,412 ETD:S290,412 EFC:$780,000 CIRC. OUT GAS MW:10.3 NACL/NABR POH WITH 3-1/2" TUBING, LD EXCESS TUBING, PU 3-1/2 DRILL PIPE, RIH WITH PKR RELEASING TOOL, UNSEAT PKR, CIRC. OUT GAS DAILY=S29,100 CUM=$319,512 ETD:S319,512 EFC=$780,000 BULLHEADING 10.3 PPG BRIN MW:10.3 NACL/NABR CONT. CIRC. OUT GAS, POH WITH DP AND PKR, RIH AND SET RBP AT 7400', POH 2 STANDS, SET STORM PKR AT 25', ND BOPE AND 3000 PSI TBG HEAD, NU 5000 PSI TBG HEAD AND BOPE, RETRIEVE STORM PKR, RIH 'AND RELEASE RBP, POH, MU BIT AND SCRAPER ASSEMBLY, BULLHEAD 10.3 PPG BRINE DAILY=S38,505 CUM:$358,017 ETD:S358,017 EFC:$780,000 RIH W/ PKR ON WIRELINE MW:10.3 NACL/NABR CONT. BULLHEADING 10.3 PPG BRINE, RIH WITH 6-1/8" BIT AND SCRAE'ER ON DP, CIRC. HOLE CLEAN, POH AND LD DP, RU E-LINE AND RUN GR/JB, RIH WIHT 7" BAKER FB-1 PKR ON E-LINE DAILY=S54,075 CUM:$412,092 ETD:S412,092 EFC=$780,000 NU FMC 4" XMAS TREE MW:10.3 NACL/NABR CONT. RIH WITH PERM. PKR ON E-LINE, SET PKR AT 7737' (WLM), MU AND RIH WITH COMPLETION ASSEMBLY, STAB INTO PERM. PKR, TEST, SPACE OUT AND SET RETRIEVABLE PKR, SHEAR OUT OF CAMCO OEJ, TEST ANNULUS TO 2500 PSI, TEST SSSV, SHEAR OUT PUMP OUT SUB, ND BOPE STACK, NU TREE. NOTE: AVA SSSV @ 1779', CAMCO 'HRP' PKR @ 7368', BAKER ;FB-i' PKR @ 7728', & TT @ 7759'. The above Is/0o~rect For form preparation/afll~ distribution, see Procedures Ma~'u~.~J,,'Section 10, Drillino. Paaes 86 an-"d-87. DAILY:S289, 952 CUM: $702,044 ETD: $702,044 EFC:$780,000 Date / Title ARCO Oil and Gas Company Daily Well History-Final Report Inslructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ARCO Alaska, Inc. Field KUPARUK Auth. or W.O. n~l%K2891 Operator ARCO Spudded or W.OA(~i~j~[~,l, I county or %fSt~. SLOPE Lease or U~bL: 25646 Title WORKOVER API: 50-029-20958 Accounting cost center code state AK 1Y-06 IWell no. Date and depth as of 8:00 a.m. 09/14/88 ( TD: 8120 PB: 7982 SUPV:MD/L IA-R.Co-W~6,0000 Date 09/06/88 Complete recO[~of~e~l~,,h ?y reported 8) Iotal number of wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well I our 1430 HRS IPrlor status if a W.O, RIG RELEASED MW: 6.8 DIESEL NU XMAS TREE, PULL BPV, DISPLACE ANNULUS TO DIESEL, TEST TREE TO 5000 PSI, CONTINUE DISPLACING WITH DIESEL, TEST ORIFICE VALVE, SECURE WELL, RELEASE RIG @ 1430 HRS, 9/13/88. DAILY:S30,239 CUM:$732,283 ETD:$732,283 EFC:$780,000 Old TD I New TO ] PB Depth Released rig Date I Kind of rig Classifications (oil, gas, etc.) Producing method Potential test data Type completion (single, dual, etc.) Official reservoir name(s) 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 Drilling, Pages 86 and 87. IDate / ITitle . ARCO Alaska, In~ Post Office~:i00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: September 15, 1987 Transmittal ~:6054 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. 3C-16 Kuparuk River Unit 'A' Sand 100598H' 8-26 thru30-87 2Z-1 Kuparuk River Unit 'A' Sand 100557H 8-31 thru9-2-87 3Q-2 Kuparuk River Unit PBU 100559H 8-25 thruS-29-87 3M-12 Kuparuk Well Pressure Report(Otis) Static A Sand 9-3-87 3M-13 Kuparuk Well Pressure Report(Otis) Static A Sand 8-28-87 3M-14 Kuparuk Well Pressure Report(Otis) Static A Sand 9-1-87 1Y-14 Kuparuk Well. Pressure Report(Camco) C Sand 8-23-87. 1Y-6 Kuparuk Well Pressure Report(Otis) 8-21-87 1Y-5 Kuparuk Well Pressure Report(Otis) Static C Sand 8-23-87 1Y-16 Kuparuk Well Pressure Report (Otis) 8-21-87 IY-I1 Kuparuk Well Pressure Report (Otis) Static 8-21-87 1Y-9 Kuparuk Well Pressure Report (Otis) 8-21-87 1Y-3 Kuparuk Well Pressure Report (Otis) Static C Sand 8-22-87 2X-14 Kuparuk Well Pressure Report (Otis) Static C Sand 7-18-87 2Z-1 Kuparuk Well Pressure Report (Otis) Static C Sand 7-2-87 2X-lO Kuparuk Well Pressure Report (Otis) C Sand 7-19-87 Receipt ~cknowledged: DISTRIBUTION: ate: / /~aska _Gas. Cons: Commission 0il & /' ..... Anchorage D&M ..... ?' State of- Alaska BPAE Chevron Mobil SAPC ARCO Alaska, Inc. Is a Subsidiary of AllanlicRichlieldCompany Unocal ARCO Alaska, Inc. Date: September 7, 1988 Transmittal #: 7285 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 3 Kuparuk Fluid Level Re 3K-1 8 Kuparuk Fluid Level Re 3 B-1 3 Kuparuk Fluid Level Re, '3Q-15 Kuparuk Fluid Level Re' '3N-08A Kuparuk Fluid Level Re ,~ 3 EH. 1 4 Kuparuk Fluid Level Re: I -12 Kuparuk Fluid Level Re' 3 K- 1 4 Kuparuk Fluid Level Re '31-0 3 Kuparuk Fluid Level Re 1 Y- 0 6 Kuparuk Well Pressure 1 Y- 0 7 Kuparuk Well Pressure 3ort 8 - 2 7 - 8 8 Casing 3ort 8 - 2 7 - 8 8 Tubing 3ort 8 - 2 6 - 8 8 Casing 3ort 8 - 2 7 - 8 8 Casing 3ort 8 - 2 6 - 8 8 Casing 3ort 8 - 2 6 - 8 8 Casing 3ort 8 - 2 6 - 8 8 Casing 3ort 8 - 2 6 - 8 8 Casing 3orr 8 - 2 6 - 8 8 Casing Report 8 - 2 6 - 8 8 Both Sands Report 8 - 2 6 - 8 8 Sand 'A' Receipt Acknowledged: DISTRIBUTION: D&M State of Alaska Chevron Unocal Mobil SAPC STATE OF ALASKA ~'-' ALASr,,-, OIL AND GAS CONSERVATION COMN,,,SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing,._ ~ Other ~ CANCELLATION 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, inc. RKB 96' Feet 3. Address 6. Unit or Property name P.O. Box 100360, Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 571' FNL, 1911' FWL, Sec.1, TllN, R9E, UN At top of productive interval 1277' FSL, 1044' FEL, Sec.1, T11N, RgE, UN At effective depth 1098' FSL, 982' FEL, Sec.1, T11N, RgE, UM At total depth 1036' FSL, 962' FEL, Sec.1, TllN, RgE, UN 7. Well number 1Y-6 8. Approval number 7-197 9. APl number 50-- 029-20958 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical feet Plugs (measured) feet Effective depth: measured true vertical feet Junk (measured) feet Casing Length Size Cemented Measured depth ~ue Vertical depth The work described in our Application for Sundry Approvals, dated 3-25-87, has not been done. Therefore, please cancel our request (#7-197). 1Y-6 is currently scheduled for a workover later'this month. A new Application for Sundry Approvals will be submitted at that time. Perforation depth: measured true vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments None Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ :.¢/~,=~.-.~ ~'~ ~'~,~ Form 10-404 Rev. 12-1-85 (,/ Title Associ ate Engineer (JG) SW03/028 Date in Duplicatel~~' Submit STATE OF ALASKA ALASF~ OIL AND GAS CONSERVATION COMM,oSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing ~ Time extension ~ Change approved program ~ Plugging ~ Stimulate ~ Pull tubing .~Amend order ~ Perforate ~ Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 96' 3. Address 6. Unit or P~roperty name P. O. Box 100360, Anchorage, AK 99510-0360 Kuparuk r~iver Unit 4. Location of well at surface 571' FNL, 1911' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 1277' FSL, 1044' FEL, Sec. 1, T11N, RPE, UM At effective depth 1098, FSL, 982' FEL, Sec. 1, TllN, RPE, UM At total depth 1036' FSL, 962' FEL, Sec. 1, T11N, R9E UM 11. Present well condition summary Total depth: measured true vertical 81 20 ' MD feet 6436 ' TVD feet Effective depth: measured 7982 ' MD feet true vertical 631 4 ' TVD feet 7. Well number 1Y-6 8. Permit number 83 -78 9. APl number 50-- 029-20958 10. Pool Kul~aruk River Oil Pool Casing Length Size Conductor 73 ' 1 6" Surface 2427 ' 9-5/8" Producti on 8034 ' 7" Plugs (measured) None Junk (measured) None Cemented Measured depth 280 sx AS I I 73 ' MD 1000 sx AS I I I 2458'MD & 368 sx AS I 900 sx Class G 8064'MD & 150 sx AS I Perforation depth: measured 7565'-7659', 7796'-7800', 7809'-7834', 7859'-7863' true vertical 5942'-6027', 6149'-6153,, 61 61 '-6183', 6205'-6208' Tubing (size, grade and measured depth) 3-1/2", J-55, tubing w/tail ~ 7485' Packers and SSSV (type and measured depth) CAMCO HRP-I-SP @ 7454', CAMCO TRDP-14E SSSV @ 1880' 12.Attachments RECEIVED AUG - 9 19 8 Alaska Dii & Gas Cons. C0m~ssli3n Description summary of proposal ~ Detailed operations program [] BOP sketch 13. Estimated date for commencing operation August 25~ 1988 True Vertical depth 73 ' TVD 2199'TVD 6387'TVD 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ ~'bCL~-~ j Title A ssoc ia te E ngi neet ~/ Commission Use Only Conditions of approval ORIGINAL SIGNED BY LONNIE C. SMITH Approved by Form 10-403 Rev 12-1-85 Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved Cop:~ ,~ ~F~r/n~' Commissioner IApproval No. Date ~-~ -,~ byorderof u~b~l\~ '¢. the commission Date, S it in triplicate feet Kuparuk Well Conversion to 4" Seleclive Single Preliminary Procedure . 2. 3. 4. 5. 6. . 8. 9. 10. 11. 12. 13. 14. 15. 16. Rig up w/reline unit. Obtain BHp. Move in and rig up Workover rig. Kill Well. Nipple down tree. Nipple up and test BOPE. Shear out of SBR. POOH and lay down tubing. Pick up 3-1/2" drill pipe and retrieve Packer. POOH. RIH and set retrievable bridge plug. Install 5000 ps/Wellhead and test casing. Retrieve bridge plug. Make casing scraper run and filter brine. Clean out fill if required. Run GR/jB to PBTD. RIH and set permanent packer between "A" and "C" Sands Run 4" single selective COmpletion assembly. ND BOPE. NU tree and test. Displace Well to diesel by reverse circulation. Test annulus and tubing to 2500 ps/. Secure well and release rig. Move in and rig up fracture stimulation equipment. Pump gelled diesel fracture stimulation through A Sand perforations. Rig down equipment and return well to production. Completion Fluid = NaCl Brine Expected BHP =:~o psi Anticipated start date-"_- August 25, 1988 RECEIVED AUG - 9 1'3: 8 Alaska Dil & t~as Cons. Commissibr~ ANNULAR PREVENTER PIPE RAMS 4 BLIND RAMS S TUBING HEAD 5 1. 16" CONDUCTOR SWAGED TO 9-5/8" 2. 11"-;3000 PSI STARTING HEAD ;3. 11 "-3000 PSI X 7-1 / 16"-5000 PSI TUBING HEAD 4. 7-1 / 16" - 5000 PSI PIPE RAMS :5. 7-1 / 16" - 5000 PSI BLIND RAMS 6. 7-1 / 16" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1, CHECK AND FILL ACCUMULATOP RESERVOIP TO P~OPEP LEVEL WITH HYDRAULIC FLUID, -'-',- .... ASSURE THAT ACCUMULATOP PRESSURE IS 3000 PSI WITH t500 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 ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 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 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. 7, INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PS! TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3[000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI, 9. OPEN PIPE RAMS. BACKOFF RUNNING dOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES, BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG, MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION, 11. TESTSTANDPlPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14, PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY JO JULY 28, 1986 (NORDIC RI(3 9-5/8") STATE OF ALASKA ~'-~ ALASh,,~ OIL AND GAS CONSERVATION COM~,..SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown ~ Re-enter suspended well ~ Alter casing ~ Time extension ~- Change approved program ~ Plugging ~ Stimulate .~. Pull tubing ~,,Amend order ~ Perforate - Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 96' feet 3. Address ..6 Unit or Property name P. O. Box 100360, Anchorage, AK 99510-0360 K~paruk River Unit 4. Location of well at surface 571' FNL, 1911' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 1277' FSL, 1044' FEL, Sec. 1, TllN, R9E, UM At effective depth 1098' FSL, 982' FEL, Sec. 1, TllN, R9E, UM At total depth 1036' FSL, 962' FEL, Sec. 1, TllN, R9E UM 7. Well number 1Y-6 8. Permit number 83 -78 ~J. APl number 50-- 029-20958 10. Pool Kul~aruk River Oil Pool 11. Present well condition summary Total depth: measured true vertical 81 20 ' MD feet 6436' TVD feet Plugs (measured) None Effective depth: measured 7982 ' M D feet true vertical 631 4 ' TVD feet Junk (measured) None Casing Length Size Conductor 73 ' I 6" Surface 2427 ' 9-5/8" Production 8034 ' 7" Cemented Measured depth 280 sx AS I I 73'MD 1000 sx AS I I I 2458'MD 368 sx AS I 900 sx Class G 8064'MD RECE Vj::'D Perforation depth: measured 7565'-7659', 7796'-7800', 7809'-7834', 7859'-7863' true vertical 5942'-6027', 6149'-6153', 61 61 '-6183', 6205'-6208' Tubing (size, grade and measured depth) True Vertical depth 73 ' TVD 2199'TVD 6387'TVD 3-1/2", J-55, tubing w/tail ~ 7485' Packers and SSSV (type and measured depth) CAMCO HRP-I-SP (~ 7454', CAMCO TRDP-14E SSSV @ 1880' 12.Att ach merits Description summary of proposal .~, Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation August 25~ 1988 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Associate Engineer [bAS/UUZ/) commission Use Only Date Conditions of approval Notify commission~o representative may witness I Approval No. ~ Plug integrity .~ BOP Test ~ Location clearanceI ORIGINAL SIGNED BY LONNIE C. SMITH Approved by Approved Copy Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate Kuparuk Well 1Y-6 Conversion to 4" Selective Single Preliminary Procedure , . . 10. 11. 12. 13. 14. 15. 16. Rig up wireline unit. Obtain BHP. Move in and rig up workover rig. Kill well. Nipple down tree. Nipple up and test BOPE. Shear out of SBR. POOH and lay down tubing. Pick up 3-1/2" drill pipe and retrieve packer. POOH. RIH and set retrievable bridge plug. Install 5000 psi wellhead and test casing. Retrieve bridge plug. Make casing scraper run and filter brine. Clean out fill if required. Run GR/JB to PBTD. RIH and set permanent packer between "A" and "C" Sands Run 4" single selective completion assembly. ND BOPE. NU tree and test. Displace well to diesel by reverse circulation. Test annulus and tubing to 2500 psi. Secure well and release rig. Move in and rig up fracture stimulation equipment. Pump gelled diesel fracture stimulation through A Sand perforations. Rig down equipment and return well to production. Completion Fluid = NaCI Brine Expected BHP =~oo .psi Anticipated start date = AugUst 25, 1988 ANNULAR PREVENTER PIPE RAHS 4 BLIND RAHS 5 TUBING HEAD 1. 16" CONDUCTOR SWAGED TO g-5/8" 2. 11"-3000 PSI STARTING HEAD 3, 11"-3000 PSi X 7-1/16"-5000 PSI TUBING HEAD 4. 7-1/16" - 5000 PSi PIPE RAHS $. 7-1/16" - 5000 PSI BLIND RAHS 6. 7--1/16" - 5000 PSI ANNULAR 11. 12. 13. ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOP PESERVOIR TO P~OPEP LEVEL WiTH HYDRAULIC FLUID. 2 Z~SSLiRE THAT ACCUMULATOP 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 ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DC'..dN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER A~D CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO '25'i' PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 180C: ~SI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSi AND HOLD FOR 10 MINUTES, 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PS! TO TEST VALVES, TESTREMAININ6 UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN PlPE RAMS. BACKOFF RUNNING JOINT AND PULL OUT OF HOLE CLOSE BLIND RAMS AND TEST TO 3000PSIFOR 10MINUTES, BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION, TEST STANDPIPE VALVES TO 3000 PSI. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SfGN AND SEND TO DRILLING SUPERVISOR, 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. RECEIVED JG JULY 28, 1986 (NORDIC RIG 9-5/8"/ STATE OF ALASKA ~-' ALASt,.. OIL AND GAS CONSERVATION COMM..,SION APPLICATION FOR SUNDRY APPROVALS Re-enter suspended well ~ Alter casing C . ~/~/ 1. Type of Request: Abandon [] Suspend ...-i Operation Shutdown [] Time extension D Change approved program ~ Plugging ~ Stimulate © Pull tubing~,,Amend order C PerforateX Other / - 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska~ Inc. 3. Address P. 0. 4. Location 571 ' At top of Box 100360 Anchorage, AK 99510-0360 of well at surface FNL, 1911' FWL, Sec. 1, T11N, R9E, UM productive interval 1277' FSL, 1044' FEL, Sec. 1, T11N, R9E, UM At effective depth 1098' FSL, 982' FEL, Sec. 1, T11N, R9E, UM At total depth 1036' FSL, 962' FEL;, Sec. 1~ TllN~ R9E~ UM 11. Present well condition summary Total depth: measured 81 20 ' M D feet true vertical 6436 ' TVD feet RKD D6' 6. UnitorProperty name Kuparuk River Unit 7. Well number 1Y-6 8. Permit number 83-78 9. APl number 50_029-20958 feet 10. Pool Kupargk River Oil p9o1 Plugs (measured) None Effective depth: measured 7982 'ND feet true vertical feet -6314'TVD Casing Length Size Junk (measured) None Cemented Measured depth True Vertical depth Conductor 73' 16" 280 sx AS II Surface 2458' 9-5/8" 1000 sx AS Iii & 368 sx AS I Production 8064' 7" 900 sx Class G & 73'MD 73'TVD 2458'MD 2199'TVD 8064'MD 6387'TVD Perforation depth: measured 7565 ' -7659 ' , 7796 ' -7800 ' , 7809 ' -7834 ' , 7859 ' -7863 ' true vertical 5942'-6027', 6149'-6153', 6161'-6183', 6-205'-6208' Tubing (size, grade and measured depth) 3-1/2", J-55, BTC @ 7485' Packers and SSSV (type and measured depth) CAMCO HRP-1-SP ~ 7b. Rb.'_ CAMPn TDnD-'I~' ~¢w ~ 18~n, 12.Attachments Description summary of proposal [] Detailed operations prooram~ BOP skotch~ 13. Estimated date for commencing operation April 13, 1987 14. If proposal was verbally approved Name of approver ,~u oo,_...~.:::~,. ,'For~: DepoSed or_, 15. I hereby certify that the foregoing is true and correct to the best of my knowledge · . . SI ned ~ T~tle Associate Engineer (~ ' Commission Use Only (JLQ) 5A2/30 approval Notify commission so representative may witness I Approval Conditions of No. [] Plug integrity [] BOP Test [] Location clearanceI Date Approved by r~¥ '~"~i~ ~ ~"~ Form 10-403 Rev 12-1-85 Approved Reiur~d Commissioner by order of the commission Dater,~c:~ Submit in triplicate Kuparuk Well 1Y-6 Conversion to Selective Single Preliminary Procedure 1. RU wireline. Obtain BHP. 2. Move in and rig up workover rig. Kill well. 3. Nipple down tree. Nipple up and test BOPE. 4. Shear out of SBR. POOH and stand tubing in derrick. Install A/B modified couplings. 5. Pick up 3½" drill pipe and retrieve the packer. POOH. 6. RU wireline. Run CET. 7. Perform cement squeeze as necessary. (Use BP and retainer). 8. RIH and set retrievable bridge plug. Install 5000 psi wellhead and test casing. Retrieve bridge plug. 9. RIH with bit. Drill out retainer & cement to BP. 10. POH. PU RTTS. RIH & test squeeze perfs. POH. 11. RIH with bit. Drill out BP. 12. Make casing scraper run and filter brine. 13. Rerun CET. Reperforate 'C' sand as necessary. 14. Run GR/JB to PBTD. RIH and set permanent packer between "A" and "C" Sands. 15. Run 3½" single selective completion assembly. 16. ND BOPE. NU tree and test. 17. Displace well to diesel by reverse circulation. 18. Test annulus and tubing to 2500 psi. 19. Secure well and release rig. Anticipated Bottom Hole Pressure: 2900 psi Workover Fluid: NaC1/NaBr Brine YPAD/1Y-6d /ih .. p ANNULAR PREVENTER § PIPE RAMS 4 BLIND RAMS 5 TUBIN6 HEAl) , ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS ~15 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. .i~;~ ~-' ? ~: ~ ~',~ ! '~ !~ ~, ',,,' i i ':",- \ ~' ~': BOP STACK TEST --.,-,~.;i~,-50i~ &. ~' ..... ~ ....... ' .......... FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. A~oii:~r:~b;i CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 1800 PSi AND HOLD FOR 10 MINUTES, BLEED TO ZERO PSI, OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. INCREASE PRESSURE TO :3000 PSi AND HOLD FOR 10 MINUTES. 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. OPEN PIPE RAMS. BACKOFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO :3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. TEST STANDPIPE VALVES TO .3000 PSI. TEST KELLY COCKS AND INSIDE BOP TO :3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. , o , . , . . 10. 1. 16" CONDUCTOR SWAGED TO 9-5/8" 2. 11"-:3000 PSI STARTING HEAD 11. :3. 11"-$000 PSI X 7-1/16"-$000 PSI 12. TUBING HEAD 1.3. 4. 7-1/16" - 5000 PSI PIPE RAMS 5. 7-1/16" - 5000 PSI BLIND RAMS 14. 6. 7-1/16" - 5000 PSI ANNULAR JG JULY 28, 1986 ATTACHMENT II KUPARUK RIVER UNIT Production Logs FEBRUARY 19, 1986 Drill Site Well No. Lo9 Date 1A-4 7/6/83 1A-5 10/29/83 1A-7 2/8/82 5/7/82 1A-9 1/25/82 3/23/83 1A-11 1/19/83 3/21/83 1A-12 3/8/82 1A-14 4/1/82 1A-15 6/5/82 1A-16A 5/11/82 6/8/82 lA Drill Site Well No. Lo9 Date lB 1B-1 12/26/81 1B-2 6/25/81 1B-3 11/16-18/81 3/12/82 1B-6 11/18/81 9/10/82 1B-7 !1/23/81 1B-8 12/28/81 8/4/82 1B-9 6/24/82 8/3/84 Drill Site Well No. Lo9 Date 1C 1C-1 5/9/81 1C-2 5/8/81 1C-3 7/13/81 1C-4 11/8/81 3/9/81 1C-5 2/26/81 1C-6 :'11/30/81 lC-7 5/19/81 1C-8 ' 5/21/81 Drill Site Well No. 1D Lo9 Date 1D-1 · 1/80 5/23/83 1D-3 8/5/80 1D-4 7/30/80 8/13/80 1D-5 6/11/81 1D-6 6/9/81 1D-7 6/8/81 ~_.~lD-8 (WS-8) 5/i0/78 Oil & Gas Co:,~ ........ Attachment Page 2 Drill Site 1H Well No. Log Date 1H-3 8/16/82 1H-4 8/13/82 1H-6 6/21/82 1H-7 7/20/82 1H-8 7/22/82 Drill Site Well No. Log Date lQ ilQ ~-~~12/1785! Drill Site 1E Well No. 1E-lA 1E-2 1E-3 1E-4 1E-5 1E-6 1E-7 1E-8 1E-12 1E-15 1E-16 1E-17 1E-20 1E-24 1E-25 1E-26 1E-27 1E-28 1E-29 1E-30 Loq Date 8/19/81 8/17/81 1/17/84 10/18/81 11/7/81 8/4/80 9/2/81 11/5/81 10/27/81 10/21/81 11/12/82 10/28/81 8/28/81 11/1/81 11/28/84 8/26/82 8/29/82 9/1/82 5/7/83 2/17/83 1/17/83 1/13/83 10/31/82 10/27/82 6/13/83 10/18/82 7/18/83 10/16/82 Drill Site 16 Well No. Log Date 16-1 16-2 16-3 16-4 16-5 16-7 16-8 Drill Site Well No. 9/7/82 9/25/82 9/28/82 12/8/84 10/13/82 11/12/82 1F 1F-1 1F-2 1F-3 1F-4 1F-5 1F-6 3/12/83 Ar~orage 1F-7 Lo9 Date 2/19/83 2/3/83 1/31/83 5/29/83 10/25/82 10/28/82 11/19/82 5/7/83 Attachment · Page 3 Dril 1 Si te 1Y Well No. Log Date 1Y-1 6/6/83 10/21/83 1Y-2 6/10/83 3/4/84 ~I-~ 6/18/83 1¥-4 7/2/83 1Y-5 6/29/83 1Y-6 6/27/83 1Y-8 6/22/83 1Y-9 6/20/83 11~-~'1~ 5/10/83 1Y-12 1Y-13 1Y-14 1Y-15 1Y-16 .1/21/83 7/28/8~ 5/25/83 5/27/83 5/13/83 5/18/83 5/29/83 5/30/83 10/23/83 Drill Site Well No. Log Date 2C 2C-4 2/19/85 2128185 2C-7 10/15/84 Drill Site 2Z' Well No. Lo9 Date 12Z~ 7/10183 2Z-2 ': 6/24/83 7/19/83 2Z-3 8/5/83 2Z-4 7/12/83 2Z-6 7/27/83 2Z-7 7/28/83 2Z-8 8/3/83 VLF:pg:O052 Anchora,~ Page Dr~ll Sfte 1Y Well No. ~- 1Y-1 ~1Y-2 -~' 1Y-3 '1Y-4 'X~llY-5 ¥-6 ."'17-8 ?'~1Y-9 ~1Y-11 1Y-12 '~ 1Y-13 '~1Y-14 "1Y-15 '~ 1¥-16 Log Date 6/ .x~0/21/83/ 6/10/83'~'~-. %3/4/84/ ~ 6/18/83 % 7/2/83 ~6/29/83 ~6/27/83 ~(~. ~6/22/83 ~/20/83 ~ ~5/~o/83~ ~11/21/8~ ~5/25/83 ~5/27/83 ~/13/83~ ~5/18/83/ ' ~/29/83 ~'5/30/83' - ~10/23/83 ~ Drill Site Well No. Log Date 2Z "2Z-1 -~2Z-2 ""zz-3 "'~2Z-4 ~2Z-6 "~2Z-8 7/10/83 6/24/83~,. 7/19/83/ 815/83 7/12/83 7/27/83 7/28/83 8/3/83 Drill Site 2C Well No. Log Date -- 2C-4 "'2/19/85 _ ~- 2/28/85/~ '~' 2C-7 N~10/15/84 .! VLF:pg'O029 RECEIVED FEB 2 1 1986; Alaska' 011 & Ga~ Corm. ~ Anchorage KUPARUK ~ I NEER ! NC; TRANS~iTTAL # ,.._D~,/ TO: William VanAlen ~4: D.W. Bose/Shelby J. Matthews Transmitted herewith are the followincj' PLEASE NOllE-(~L - B F - F! I_M, T - TAPE, PC_ PHOT~PY /~ I PT ACJ<k~¥LIEDSED: PLEASE REI1JI~N RECE ! PT TO: ~ ALASI<A, INC. A~' ~E~Y J ~A~IB~ - A~s~-~3as C,,n~. Commission P. O. ~X 100360 Anchorag~ ~~~E, ~. 99510 Transmitted herewith are the followir~j' PLEASE hDTE' Bi - BLUELINE, S - SEPIA, F - FILM, T - TAPE, PT PLEASE P, ETU~'4 REC. E! FI- TO: /v,'TCO ALASKA, I h,~. ATTN. SFIFJ.P_:,Y J. /¢A-Fg-IB.;~ - ATOl 111 5-B P. O. BOX 100360 ANCI-~..,/',CE, Al(. 99510 KUP~ ENGINEERING William VanAlen FT~I: D.W. Bose/Shelby J. ~atShews-. ... WELL I~/E: ~.~_~ ~ Transmitted herewith are the following' .~ PLEASE ~: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE, AR(Z) ALASKA, INC. ATTN' SHELBY J. NATI'H~N5 - ATO/1115-B P. O. BOX 100360 ANCHORAGE, AK. 99510 KUP, A,q~ ENGINE~I~ TO:. YVi I I i am VanAI en ~: D. W. Bose/Shelby. J. t~t_thews-: Transmitted herewith are the followin9- PC- C:o-q:::,t ¢_.__--g o,",, '¢¢___c__,0 rc't ~-q~ I~. A~- ~E~Y J. ~~B~S - A~/1115LB:'''¢' P. O. ~X 100360 ~E, ~. 99510 ARC~' Alaska, Inc. P r'.~.t Office Anchorage. Al~skn 99510 Telephone 907 276 1215 July 14, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Dri°ve Anchorage, AK 99501 SUBJECT' Well Completion Reports Dear Mr. Chatterton' Enclosed are completion reports and gyroscopic surveys for the fol lowing wells- 1Y-5 1Y-6 If you have any questions, please'call JoAnn Gruber. at 263-4944. Sincerely, P. A. VanDusen District Drilling Engineer PAV/GRU3L79'sm Enclosures Alaska Oil & Gas Cons~ ,.,-.. Anchorage ~um~a~ssion ~',' ("O Alaska. Inc. is ~ Subs~dinr;,' of AtlanticRichfiefdCompany .---- STATE OF ALASKA ALASI~ ~ ,' AND GAS CONSERVATION ' I ,ISSION WELL COMPLET v I OR RECOMPLETIOh .EPORT AND LOG 1. Status of Well Classification of Service Well oILX~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-78 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20958 4. Location of well at surface 9. Unit or Lease Name 571' FNL, 1911' FWL, Sec. 1, TllN, RgE, UM Kuparuk River Unit At Top Producing Interval LOCA:TiON'~ 10. Well Number 1277' FSL, 1044' FEL, Sec. 1 , TllN, RgE, UN VERIFIED 1Y-6 AtTotal Depth i Surf. ~ ll. Fieldand Pool 1036' FSL, 962' FEL, Sec. 1, TllN, RgE, UM B.H. ~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i l Pool 96' RKBIADL 25646 ALK 2577 12. Date Spudded 13. DateT.D. Reached 14. Date Comp., Susp. orAband. I15. Water DePth, ifoffshore '16. No. of Completions 05/15/83 05/22/83 06/11/85I IN/A feet MS L 1 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8120'MD,6436'TVD 7982'MD,6314'TVD YES~I~] NO []I 1880 feet MD 1350' (Approx) 22. Type Electric or Other Logs Run GR/SP/D I L/SFL/FDC/CNL/Cal , CBL/GR/CCL/VDL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOT_..T,J~j~ HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5// H-40 Surf~_~'~J 24" 280 sx AS II 9-5/8" 40.0// J-55 Surf 24-58' 12-1/4" 1000 sx AS Ill & 368 sx A,~ I 7" 26.0# J-55 Surf 8064' 8-1/2" 900 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7565 ' -7659 ' 3-1/2" 7484 ' 7454 ' 7796' -7800' w/12 spf 7809'-7834' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7859'-7863' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A :~7. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-EEL GAS-MCF WATER-EEL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ I ., Flow Tubing Casing Pressure !CALCULATED OIL-BEL GAS-MCF WATER-EEL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Alu.;.v,,¢'" ,,:: 0il. & Gas C~ ...... tis L;0n~mis,.~i0ri Anch0rag,~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand GEOLOGIC'MARKERS MEAS. DEPTH 7564' 7653' 7786' 7921' -, '-,' ~'.'. .... ~ ". ..... :'; FORMA'E-IONT_ESTS- , TRUE VERT. DEPTH 5942' 6022' 6141' 6261' Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. NIA 31. LIST OF ATTACHMENTS Drilling Histor¥¢ Completion Summary, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Area Dri ] ling Engr. 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 1Y-6 COMPLETION SUMMARY ND adapter flange & master valve. RU Dresser-Atlas WL unit w/mast. Ran CBL/GR/CCL/VDL f/8001'-2400'. Ran gyro f/7950'-surface. RD Dresser-Atlas. NU adapter flange & master valve. Secured well. Accepted rig @ 0001 hours, 06/09/83. ND adapter flange and master valve. NU BOPE & tstd - ok. Perforated the following intervals w/12/spf: 7565'- 7659' 7796'- 7800' 7809'- 7834' 7859'- 7863' Ran 3-1/2" completion assy w/tail @ 7484', pkr .@ 7454', & SSSV @ 1880'. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well to diesel. Dropped ball & set pkr. Closed SSSV. Set BPV. Secured well & released rig @ 1030 hrs, 06/11/83. GRU3:CS9 07/11/83 1Y-6 DRILLING HISTORY NU 20" Hydril & diverter & tstd same. Spudded well @ 1800 hrs, 05/15/83. Drld 12-1/4" hole to 2488'. Ran 63 jts 9-5/8" 40#/ft, J-55 HF-ERW, BTC csg w/shoe @ 2458'. Cmtd 9-5/8" csg w/lO00 sx Arctic Set III & 250 sx Arctic Set I. ND 20" Hydril & diverter. Perform top job on 9-5/8" x 16" annulus. Pumped 118 sx Arctic Set I. Bumped plug w/1500 psi - held ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 11.9 ppg EMW - ok. Cont. drlg 8-1/2" hole to 8112'. Circ & cond hole. Ran GR/SP/DIL/SFL/FDC/CNL/Cal f/8088'-2458'. Ream 40' to btm. Drld f/8106' to 8120' TD as of 05/22/83. Circ. & cond hole. Ran 207 jts 7" 26#/ft J-55 HF-ERW, BTC csg w/shoe @ 8064'. Cmtd 7" csg w/900 sx Class "G" cmt. Bumped plug w/2000 psi. Floats held - ok. Cut off 7" csg, install 7" emergency slips, set BOP. Instld & tstd FMC head. Displ top 360' of well w/diesel. NU top of tree. Secured well & released rig 0100 hrs, 05/24/83. HILL/DH22 06/13/83 Anchorag~ PRODUCTION (INJECTION) TEST SUMMARY .. TEST DATA ARCO REP: ~ ,~,~'~ ,"' o TEST TYPE: .?_,~ ;-~? WELL TYPE: Old _X New PERFORATIONS: ~-=-TG.~ ', '7'7~/~.-'7¢~0 · /~ Pzoduce~ lnjector PERF TYPE: .,5..~ LO~CIU~ TOOLS RU~: .. _ ! PRE-lEST (If well AV~ PROD (IN2) RATE ~BOPD AVO GOR -~,'A~ WOR WHP _~~SI °APl '' G GO DATE START ),~" 6o lEST SUMMARY is currently f~win~ ACTUAL TEST DATA AYe PROD (.IN3) RATE~ AYG COR A¥~/~rDR ' WHP PSI/'/'API~''''' ~ ~ 60 WHP DATE END · . . . · . . · . - / HP ~ ~ FT HP ~ SS . PROD (IN3) TIME //qOTAL SHUT IN TIME MAOOR WELL EVENT HISTORY FT HR HR EVENT CUMULATIVE PRODUCTION (INOECTION): TOTAL PRODUCTION (INOECTION) I1ME: TIME SINCE LAST HA3OR SHUT IN: BBLS DAYS DAYS KUPARUK RIVER UNIT SEQUENCE OF EVENTS WELL: / ~ "-- k~ OPERATION= ARCO REP: ,R ~"1., ,"'¢, ,~. % EVENT · - DATE: .. . PSi SOHIO ALASKA PETROLEUM CO. PAD. S (42-$4- 12-12) S-4 Controlled Drilling Consultants LES HENDERSON' 349-3114 CONT ED-D ILUNGS C-O iS' - . . . .7608 Highlander Drive--'. . Anchorage, .Alaska 99502' '(907) 349-3114 .-. · . _. · August 5. i i983 Mr. Brian Rose Sohio Alaska Petroleum Company Pouch 6-612 Anchorage, AK 99502 RE: Magnetic Single Shot Survey. .Job No. S-4 (42-34-12=t2) Well 0783-021 Prudhoe Bay;Field ' North Slope, Alaska Date of SUrvey: 7-21-83 to 7-30-83 . . Dear Mr. Rose: - _ . Please find enclosed the "Original" and:six (6) copies of our Magnetic Single Shot Survey on the above Well. The method used in calculating this survey was Radius o!f Curvature. The depth of the survey was 4500. to 8900. Thank you for giving us this opportunity to be of service. '_ YOurs very truly, Controlled Drilling Consultants, Inc. / C.W. Harrington Directional. Supervisor SOHIO ALASKA PETROLEUM , t'!AGHET!C SiNL~LE SHOT RADIUS OF CURVATURE HETHO~ OF COHPUT~T]:O~4 SUR',/EY RAN BY C, W, HARRINGTON COMPUTED FOR L,C,L. BY OCEANTECH4~i"i LiNC'SE'? ,JOB ~'~"" ,~.u . c o..*- 02 i i.,j E L L DE;- 4 t<B ELEV 7'4. O0 FT, SURVEY [>RTE 21 ,,"07,."8~ PROPOSED ~JlR S69-86(,.t RECORD OF SURVEY :RUE MEAS, [)RIFT VERTICAL ~ [>EPTH ANGLE DEPTH SUB DR I FT SEA [:' l REt:: DEG. TOTAL COORDINATES C L 0 S U P. E S DISTANCE RNGL. E D H o o 0 .co -?4,00 i~ ,OOE ,O0 S ,00 W .00 S 90 0 0 W .... 4500 FT, ....... .... 6 ........... 4:5-0o,00 4426,0 4572 2 t4 457i,98 449'Z,98 $64 OO~.~ 4664 5 14 4~ 78 4589 70 5,' . OOi.O 4788 '7 29 4787,00 47i3,00 ...... ~%.~_..0 .............. :__._~A~ ......... 9..~_9:o_, ?= 4774, '.3":~ 495i i3,i4 4947,~i 487B.3 .... ~ 4, S .... 5231 9.f il 52~4 89 5i40.89 "'" ............. ~.., , ~,¢~ 80(8 ,¢ ,.. ~ ,~ , , ~ ~ ¢. 4 0 iii ............................................................................ 5870 22 ~2 5905', 58 57~i 58 '"': ''~ .......... ' '~ "" - , $ 6 0 iii .... _~_]_.Z..~_._~,:~_~ 4 .......... ~:Y..e~..,_.O 1 6 0.! 4 5 i 6~2~ 22 1I ~3,87 .6159,87 S68 6552 22 ¢' ";, '~-: ~ - . ~. 5 ..... ~,., ,=,, 49 6 ,:, 62, ,49 S .............................................................. 6802 24 4 6666,19 6592, ~i3 24 4 71'"~ ( o8, O,,, o 74 '7~ '~'' ' .... ~ ¢:.,s ,. o ~. ~, 57 7489, :5 '7 8i60 o,', ii ,' , , ,00 W !,26 ~,,86 W 19,76 W 28,00 W 4.5 65 2r~ W 88 94 116 67 W 227 94 436 76 W 489 7i W 564 86 W 746 3'J W 856 84 W 4. 57,88 S '1J80.,16 W ,00 S 90 0 0 w i.4i S 63 !5'7.~ 59 i.¢ 7.4.0 S ¢88 2 59 W 2i ,i2 S 69 i9 ~0,26 'J 67 ,42 27 W 50.i2 S ~S4 57' J OO,~O $ 62 28 5 256.92 S "'~ '" 375,35 $ ~2 32 52 W 49I 91 8 ...... ' '"' 551.26 S 62 .~:'~'~;~ 57 W 826 24 S 64 3= ,.;, 40 940,62 S 65 2~8 6 W J006.50 S 66 i4 124.iI S 67 22 44 W t265,88 S G8 47 48 DOG LEG SEVERITY DEC,.¢IOOFT .000 oOOO o.,tii i :..3 327 2 3 06? 547 07~4. t99 .2~8 . i65 .. 247 SECT [?, i S TAN{ , O0 I 40 2i iO $0 20 4'9 80 72 99 ~30 257 370 544 86 935 ~6 002.4 :Z 64,57' SOHIO (dELL "i" Y' ,SZNGLE SNOT JOB ,NO 0783-2 TRUE NEAS, DRIFT VERTZCAL --SEPTH ~Nt~LE hEP TH D H 885~ ~9 29 8556,27 8900 19 29 8802,47 '~GT i:-'0~"' 'HO"L'E ' CEO s .............................................................................. RECOR~: OF .... " SUB DR i ~r TM~ SEA D l REC DE(]. TOTAL COORDINATES I443 ,66 t~ FEET AT S '~ : 't 24 I [,J CLOSURES DISTANCE ANGLE D H 40i.47 S 70 ii i507,36 523,22 S COMPUTER- ~:.,, AtJ.G 8~ KB ELEV 7'4, O0 DOG,' LEt] SEVERITY DEG.','" 1 0 OFT ,OOO SECTION I F.;TANCE ,) 0 i il 5 07', 523 '"'~" SOHIO i. dELL $-4 zSIfqGLE SH, OT SURVEY ,JOB f40 0783-.----'~1 _.NERSURE~L_DER_TH A~D OTHER DATA FOR EYERY EVEN lO0 FEET OF SUB SEA DEPTH, TRUE . ..... -..~e~ED VERTICAL SUB ND-TYD VERTiCaL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINAT:S 174 174. ~7~ 274. 474 474. '. ~_74 .... $?4. 674 674, 774 774, 874 874, ............................ ..................... s'?4. I 0;'4 i 074. .................. ,ti.Z_4 i ;:274 i ~74 1 ~74, i474 1474. i 674 i 774 i ~7'4. i 874 ~ 874., t 974 i 974, 2074 2074, 2..tZ. 2.!. 7 4, 2274 2274. 2974 2374, 2474 247,4, 2~74 2574 ,~774 2774 2874 28~4 2974 2'974, Z4074 3 i 7'4 3 i ?4 , .~ , ~. 32'74, 3474 3474 , 240 -74 lO0 200 300 400 500 600 ?00 800 900 1000 i~80 i3OO i40O ~500 1600 i700 iSOO ~900 2000 2~00 2200 23'00 2408 2500 2600 2780 280~ 2900 3000 3t00 ~200 0 COMPUTER- KB Ei_EV 03 AUG 83 74. O0 FT. oOHIO [dELL E-, ..... ~ A!i'.~GLE SHOT SURVEY dOB NO 07'-"3..:, ':~! MEAgURED DEPTH RND OTHER DATA FOR EVERY EVEN lO0 FEET OF SUB SEA DEPTH, COMPUTER- i.::B ELEV 07 AUG 83 74, O0 FT, TRUE HEASURED VEi'~T iCAL ou!B MD-TVr~ VEP, T ~C:AL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES ~674 3674, ~774 3774, 3874 3874 3974 3974 4074 4074 4174 4~74 4274 4274 4374 4374 ................... ~;?-~ .................... 4474 4574 4574 4674 4674 4775 4774 48'76 4874 ................... 4.9 ;7.4, ........................... 517 4, ~.29~ ............. 5274, ..................... .......................... S 3 7 4 ,. 5474. 5619 5574, ..................................... 5.~ig~ 5674, 5836 5774, 5944 587'4, ...................... ~..~52 ............. 5974, 6268 ~'74, ~.~.~.~ 6274, ~4 6374 6593 6474, 670I 6574, ......... ................... ~.ed.] .................................. 66?4, 3508 Ct 3600 O 3700 0 3800 0 3900 0 4000 0 4i00 0 4200 0 4300 0 4400 0 4500 0 4608 O 4700 0 4800 2 4900 ,4 500~ 8 51 O0 1 ..S 52¢0 20 5308 28 5500 44 5600 5?00 61 5808 70' 5900 78 6000 86 6100 ~4 6200 I 02 6300 I t O 6400 ~ 18 6500 I2'7 660O tS.6 6800 155 6900 i65 ,00 ,00 ,OO ,00 ,00 ,00 ,00 ,00 ,00 6,88 1~,63 24,47 38,12 54,04 71,62 89,93 i08,91 I28,45 t47.87 J67.03 186,00 204,85 242,17 260,37 277,95 294,81 3t0.84 325,9:3 354,22 ~67,69 S S S S S S S S S $ S S S' S' S S S $ S O0 ,00 ,00 O0 00 O0 O0 O0 i 34 7 78 18 2'I Bi 50 96 74 103.'11 1.37.25 172.8~ 209,47 246 284.30 321 . 40 794,98 43'1 467 584, 541 W W W W W W W W W W W W W W W W W W W W W W W W W W W W W 579.1,4, 618,54 659,88 702,4i 745 .. :3 788,84 SOHIO BELL $-4 SINGLE o'J' ~,~,UT SURVEY JOB NO 0783-2 NEASURED DEPTH AND OTHER DATR FOR iOO FEET OF SUB SEA DEPTH, D.E_ET_H TRUE VERTICAL SUB HD-TVD DEPTH SEA DIFFEREHCE VERTICAL CORRECTION TOTAL COORDINATES .... 7;~'~ ...... 7074, ; 7~59 7174, 7468 7274, 7577 7374, ............................................... 7686 7474, 7794 7574, 7903 7674. 80il 7774, 8i19 7874, 8227 7.974, ~,,5 8074 8443 855~ 8274, 8657 8374, ..................................................................................... 8'764 8474° 7000 I75 71 00 i 84 7200 i 94 7366 '302 7400 Si 7508 7600 2~8 7780 7800 245 7900 eoeo 26' 81 O0 268 8208 275 8300 282 . 8400 289 . 8500 ~9~ 8528 297 9 8 9 8 8 8 8 7 '? 7 7 2 380.70 S 393.19 S 40.4.51 S 4i4.80 S 424,38 S 433.26 S 44't .42. $ 448,85 ,9 455.55 S 461.54 S 466,83 $ 471 ,42 $ 475.32 S 478.8t S 482.03 S 485, Oi S 485.8,3 S ~'" 94 874,77 9t6.95 958,70 OOO. :36 104t.95 083 .'~2 124.32 ~64.96 'i205,21 245,02 284.36 ~97,98 443,66 COMPUTER- KB ELEV 03 AUG 83 74,00 F'T, SOHIO t~IELL S .... ~- INTERPOLATED VALUES FOP, E"¢EN TRUE ' t'iE ~49U-R~ ~ vER T i CAL DEPTH DEPTH 2000 3000 4000 5000 6000 7000 8000 8900 'i 000, 2000, 3000, 4000. 4995, 68,47, ?764, 8602, .S I i',:G L E iO00 FEEl' SUB :.3 E A 926, 2926, 3926. 4921 , 6773, 71:890, 8528, · .S H 0 T 'S U P, ~,' E Y dOB NO C'F HEASURED DEPTH, T 0 ]"i:~L COORD i NATES .00 :~ .00 S ,O0 S .00 S .00 S 27',i",~ S i 95,76 S 35 O, ~ 7 S 448, i I S ,00 W Oil W O0 W oo 55 50 W 377 29 W 733 7t N 1120 ~0 I.~l i 443,66 W , COMPUTER- KB EL. EV J ...'. AUG 7~, O0 FT, · . ,,.._~_L ...... ~ ........ ~. : .... "'t ..... ~ ................. ~ ....... { ; ...... ~' -' } SOHIO ALASKA PETROLEUM ...... ji _ ,. ~ _~ - ........................... .............. ~_-- _ ~ : ........ ...... , ~ TVD = 8602' ~ TMD 8900' .... [ ..... .... ~ ~ ....... ~ .................... : ................. .__: 1 .............. : ................... ~ ....................................... ................... :--T: ....... ': .... . ; ...................... L~_~_ L_. ' ............................ ~ i : : [ CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS CORE ANALYSIS REPORT FOR ARCO ALASKA, INC, SOHIO PBU ~S-4 PRUDHOE BAY NORTH SLOPE, ALASKA These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS PAGE lA ~'~RCO ALASKA, INC. SOHIO PBU tS-4 F'RUDHOE BAY i'~0RTH SLOPE, ALASKA DATE ; il-AUG-83 FORMATION ; KUPARUK DRLG. FLUID; LOCATION ; CORE ANALYSIS RESULTS DEAN-STARK ANALYSIS FILE NO ; BP-3-862 ANALYSTS ; TLS,ROB LABORATORY; ANCHORAGE SAMPLE DEPTH NUMBER FEET PERMEABILITY (MD) POR MAXIMUM 90 DEG VERTICAL % Analwsis ~erformed on sidewall cores GRAIN FLUID SATS. DEN, OIL WTR I 3684.0 2 3690.0 39.8 3 3722.0 36.6 4 4611.0 34.2 5. 4652.0 32.3 6 4686.0 417. 7 4773.0 310. 33.7 8 4826.0 263. 31.4 9 4830.0 196, 34.0 10 4865,0 32,7 11 6866,0 26,0 12 6867,0 63, 23.6 13 6869.0 37. 28.4 14 6870.0 18. 28.1 15 6871.0 34, 28,6 16 6872,0 31, 28,1 17 6873,0 32, 21,2 18 6874,0 26, 27,2 19 6875,0 20 6876,0 37, 29,3 21 6877°0 34. 29.6 22 6879.0 16. 24.9 23 6882.0 34. 25.1 24 6885.0 fmiled-oil ~vavitw onl~ AP1 14 2,&9 28,3 52.7 ss;m-car,si sltw,f~mo APl 12 2.62 30.0 69.0 ss;f-o~,sl $1t~,f~a¢ AP1 15.5 2.63 37.4 47.2 ss;vf-m~,f~ao AP1 14.5 2.63 23,4 58,4 same;sl%~,f~m¢ AP1 16,5 '2.63 36.9 ~0.0 ss;f-m~ 2.64 33.3 55.2 ss;vf-ma~ AP1 14 2.61 37.2 43.8 same API 16 2.62 28.6 44.0 same APl 16 2.62 28,0 55,4 same;f~ao APl 14.5 2.62 11,9 69.0 ss;vf-ma~,sc ~lauc,$1t~ AP1 16.=~ 2.72 13.7 ~3.9 ss;vf-f~,~lmuo API 27~ 2.83 11.8 77.2 same API 24 2.95 10.4 77.5 same API 26 2.90 14.6 69.2 same API 25 2.65 16.2 72.9 same API 21 2.91 &.7 84.3 same AP1 30.5 failed-oil ~pavi%w onl~ AP1 27 2.86 8.9 74.9 ss;vf-m~.almuo APl 30 2.90 14.0 73.6 same API 30.5 2.62 10.0 74.5 ss;vf-f~p,slt~,si oai¢ AP1 22 2,69 14.2 70.4 same failed-oil a~avit~ onl~ AP1 30 These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. .~]RCO ALASKA, INC, ~30HIO PBU ~S-4 CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS DATE FORMATION , ° Il-AUG-B3 ~ KUF'ARUK CORE ANALYSIS RESULTS DEAN-STARK ANALYSIS PAGE FILE NO ANALYSTS 2A BP-3-862 TLS, RBB !SAMPLE DEPTH PERMEABILITY (MD) POR GRAIN FLUID SATS, ?.lUMBER FEET MAXIMUM ?0 DEG VERTICAL % DEN, OIL WTR 25 6886.0 9,76 28,2 2,62 11,0 62.5 26 6887,0 28,0 2,63 5,7 84,4 27 6888o0 25,1 2,66 4,6 86,0 28 68~0,0 27, 27,1 2,63 ~o6 82,2 26,~ 2,63 3,1 83,3 29 6891,0 1Bo 30 68?3°0 31 6894o0 28°3 2,64 10,1 78°7 32 6898o0 33 6951,0 6~0 30,1 2,64 8,3 77,4 34 6753,0 DESCRIPTION ss;vf-f~r,sh inbd same;fr~c $~me; frac seme failed-oil ~avi't~ or',l~ ss;vf-f~e,sh inbd, fT'ac f~iled-oil ~vi~ onl~ ss;vf-fa~,sh inbd failed-oil apavi't~ onl~ API 2~~ API 2 ,a API 26 API 23,5 API 28 API 30 API 32 API 26,5 API 27 API 19 These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS CORE ANALYSIS REPORT FOR ARCO ALASKA, INC~ SOHIO PBU .~S-4 F'RUDHOE BA'Y NORTH SLOPE~ ALASKA These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. ARCO ALASKA, INC. SOHIO PBU ~S-4 PRUDHOE BAY NORTH SLOPE, ALASKA CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS PAGE I DATE ; 04-AUG-83 FILE NO : BP-3-862 FORMATION ; KUF'ARUK ANALYSTS : 'rLS~RDB DRLG. FLUID: WBM LABORATORY: ANCHORAGE LOCATION : CORE ANALYSIS RESULTS BOYLES LAW - HELIUM POROSITY SAMPLE DEPTH PERMEABILITY (MD) F'OR C;RAIN FLUID SATS, NUMBER FEET MAXIMUM 90 DEC; VERTICAL % DEN. OIL WTR DESCRIPTION i 6889,3 5.49 20.4 2.65 .~.°x ~ 46.1 ms~vf-f~e,vfn sh inols 2 6890.3 11. 21.0 2.64 23.7 46.3 smme 3 &891.g 14. 21,1 2.64 23,4 45.8 smme 4 ~8~2.5 28, 21.~ 2,&4 28,5 40,8 smme '~ 9 2.6~ 27.8 ~8.4 mmme 6 6894.5 26, 2g.1 7 6895,4 0.42 15.7 2,67 29,7 51,0 mm;vf~;.,v'Fr, mh inols 8 6896,6 1,21 16,8 2.64 29,5 50,6 mmme 9 6897,~ 9,36 21,1 '~ ' . ~.64 LtO,1 40,5 ss;vf-f~e~vfn sh inols 10 6898,5 0.8~ 15.1 2~62 26,1 58,1 smme 11 6899.4 1.07 16,7 ~,6g 29,5 41.8 mmme 1 '~ ~ 6900,6 7~2~ 20,g 2,&4 27.7 40,4 mmme 13 6~01.7 1~44 17.8 14 6902, ..; 1~44 17,7 2,66 19,9 48,0 mmme 15 &90~,5 0.02 7,6 16 6904.5 0.62 19,0 2,87 1'~ 17 6905 ~ 6 0. ~;~ 20,5 18 6906,9 18,8 19 6907,4 0~02 7.4 20 6908,7 0,65 14,8 2.69 g2,0 48,0 ms ~ v¢.-'¢~', sh inbd 22 69].0,8 3,96 14,5 2~ ~ 11.4 0 · 8~ 15,0 ") ,;.~8 20,5 60.~ smme 24 6~12,7 5~4~ 14,0 2.~4 ~g,2 5;~. ~. mmme . ..:,68 3~.2 50,~ smme 27 69].5.5 46. 15.2 2.72 24.8 62.0 mmme~Pue inol,frmo 28 6916,6 g,~8 14,L~ .~,70 4.:., 1 48~5 mmme;PuY' Imm AP1 26 AP I 26 AP1 AP1 26 AP1 APl 25 AP1 APl AF'I I?.1 These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. ~RCO ALASKA, INC. SOHIO F'BU ~S-4 CORE LABORATORIES. INC. Petroleum Reservoir Engineering DALLAS, TEXAS PAGE 2 DATE : 04-AUG-83 FILE NO : BP-3-862 FORMATION ; KUF'ARUK ANALYSTS ; TI.S,RDB CORE ANALYSIS RESULTS BOYLES LAW - HELIUM POROSITY ~AMPLE DEPTH PERMEABILITY (MD) POR GRAIN FLUID SATS. NUMBER FEET MAXIMUM 90 DEG VERTICAL % DEN. OIL WTR DESCRIPTION 29 6917,8 1.30 15.1 2.65 26.7 61.4 mmme ~0 6918.9 2.76 18.7 2.64 31,4 51.9 smme AP1 31 6919,3 0.35 13.5 2.67 28.5 59.6 mmme 32 6920.2 0.18 13.1 2.66 26.3 6~.1 mmme 33 6921.8 166. 16.5 2.67 12.1 80.8 34 6922.9 0.02 15.6 2.81 10,2 82.9 smme;vsh~,mid ~5 692~,4 0.05 17.9 2.9~ 1~.1 74.2 36 6924.5 8.78 16.2 2.68 28.5 44.9 mm;vf-'f~e,sh inbd AP1 37 6925,8 6,53 14,6 2,68 22,8 68~5 mmme ~9 6927,4 0.50 15.4 2,6~ 15.0 75.2 mmme 40 6928,5 4.29 16.1 2,69 21,4 72.0 smme AP1 21 41 6929,6 26~ 14,8 2,65 2~,1 70~6 smme;f'~mo 42 69~0.8 0.05 14,1 ~.04 8.5 8~.5 $1tmt;ml sd~,mid 4~ 8¢31.8 ~8 1~7 2,~8 8~2 87~1 ss;vf.-m~:',hvs~ sh inbd 44 G~32~ L~G7 14~0 2,88 1~4 75.0 ms;vf~,hvu sh inbd 45 ~,7 18~1 2,G8 25,~ 5~.5 mmme ~sum~ fluid mnml~sis~ AP1 21. 46 ~4~7 5,08 1~.0 ~,7~ 19~5 47.7 ms;v'¢-f~ sh inbd 47 69~5,8 ~. 10 15,5 2,68 22,~. 68,2 mmme 50 69~8.4 0,74 12.9 2.65 19.~ 74.4 mmme AP1 ~1 69~9.6 1~. 1~,6 2,68 27~1 61.4 52 6940,4 7.00 12.9 2.62 5.6 87.9 mmme 5~ 6941.6 5.70 19.0 2,65 14.0 80.1 smme 54 6942~7 5.98 15~7 2~63 2~.7 61~2 smme 55 6943~5 40. 18.7 2.64 20.4 51.6 mmme AP1 16 56 6944~6 13, 17,2 2.68 26.1 6~.8 mmme 57 6945~5 142, 23.0 2,64 27.9 ~3,~ mm;vf-m~e~fn sh lmmm AP1 58 6946~3 1.37 14.9 2,64 34.~ 50.6 mm; vf--f~e, sh inbd These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS PAGE 3 ~RCO ALASKA, INC0 DATE ; 04-AUG-83 FILE NO : BF'-3-862 SOHIO PBU ~S-4 FORMATION ; KUPARUK ANALYSTS ; TLS,RDB CORE ANALYSIS RESULTS BOYLES LAW - HELIUM POROSITY SAMPLE DEPTH PERMEABILITY (Mrl) POR GRAIN FLUID BATS. NUMBER FEET MAXIMUM 90 DEC VERTICAL % DEN. OIL WTR 59 6947.4 160. 25.4 2.6:3 :33.8 21.7 ss;vf-f~r 60 6948 · 2 96. 2:3 · 3 2 · 6:3 25 · 1 :37 · :3 same .~o 7 2.64 35.8 48.1 same;fn sh lams 61 &948.8 143. 62 6949.9 108. 24.~ 2.64 24.0 46,~ mmme 6~ 6950.4 58. 21.4 2.63 29.9 54.4 smme~sh inbd 64 6951.4 3.69 13.7 2.59 32,0 51.8 ss;vf-f~,sh inbd 66 6953.5 16. 18.8 2,64 50.6 25.3 s~me;fn sh inols ~,58 40.8 44~7 ms;vf~r~sh inbd 68 6955,7 7~00 17.~ 2.62 32.5 58.7 ms~vf-'r~e,sh inbd 69 6~56.5 15.4 2,62 40.5 40,5 same; 70 6957.5 0.78 15.4 2,60 :38.1 4~.6 71 6958.8 0.41 1S.9 2.60 ~0.2 56.4 mm~vf~e,sh inbd ~.64 32,8 44.5 same 74 6961,6 0.18 13,5 2.59 24,0 6~,5 mm;vf~r,mh inbd 75 6962,6 7,69 1~.1 2,63 41.4 34.8 ss;vf-f~r,sh inbd 77 6964.8 <0.01 0.8 g,26 28.0 62.0 mid '~ 72 0 ss ~ vf~r ~ mh inbd 78 696~7 5~00 14.4 ~.. 61 20,6 79 6966,6 14.5 2.62 24,7 63~ smme~'~mo 80 6967.5 1.00 13.4 ,~,, 60 2]..~ 72.,, same 81 6968.5 12. ].5,5 2,63 26.7 57.6 ss;vf ....r~e~sh inbd 83 6970.4 0,60 13.7 ,,,63 35.8 30.9 $$~vf~r~sh inbd 84 &~71,5 O,&l 13,7 ~&O :35,~ 41~5 85 6~72.5 4.53 16.1 2.64 28.7 45.9 ss ;vf-.'¢~r ~ mh ir, bd 86 6e73.:3 4,27 15.1 '~ ~.78 .~e.7 55,6 same; 87 6974.6 3 ~ ~4 14. ~ "~ ~..61 40.6 ~4.~ ms~vf~r,sh inbd 88 6975.5 4.56 13.9 2,61 29.9 5:3,8 smme OESCRIPTION AP1 27 APl{ AP1 26 AP1 21o~ API API 31 i', APl APl 21 API 24o! These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted); bu! Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS PAGE 4 ~RCO ALASKA, INC. [mATE : 04-AUG-83 FILE NO ; BP-3-862 ~OHIO F'BU ~S-4 FORMATION ~ KUPARUK ANALYSTS ; TLS~RDB CORE ANALYSIS RESULTS BOYLES LAW - HELIUM POROSITY SAMPLE DEPTH PERMEABILITY (MD) POR GRAIN FLUID SATS0 NUMBER FEET MAXIMUM 90 DEG VERTICAL % DEN , OIL WTR DESCRIPTION 89 697605 1,83 1J.O 2.61 37.3 J3.6 smme 90 6977.4 3.17 15.5 2,62 20.5 71.2 smme AP1 ,{ ,~ 91 6978,6 5.~6 14.5 2.62 24.1 51.g smme 9J 6980,5 7,60 16,1 2,62 g4,3 46,6 smme 94 6981,6 2~76 15,9 2.61 12,9 77,2 smme 95 6982,6 1,07 11.~ 2,55 28,6 ..~o,9 smme;vshu AP1 17.~ 96 698~,5 9,14 16,0 2,61 24,3 61,5 smme 98 6985.5 1g. 1J~6 2.60 "~ ~1.7 58.8 ms;vf~e,mh inbd,'er~o 100 &~87.& 7.31 1~.0 2.~2 35.0 53.2 m~me AF'I 18~ 101 6988,6 15. 14.5 2.60 J0,~ 52.6 smme~femo 102 ~8~.~ 7.40 15.8 2.~2 2~.5 ~4.8 mmme 107 6~0. ~ 1.48 14.2 .~.. ~0 28.5 5~ · 0 mmme 104 6991.7 83. 1~.7 2.61 28.9 53,9 smme;frmo 105 6~2.4 1,87 1~.5 2.61 L~4.7 52,~ ~mme APl 22 107 &9~4.g 94. 19.8 "~ . ~ 108 6B~5.& 4.7~ 13.4 '~ ~.~.60 ~1.5 4~+6 sm;vf~sh inbd 10~ ~.~ 1.40 14~1 2~62 ~6~5 ~3~1 smme API ~0 112 ~,7 0~41 l~.& ~,'~ ~2 12,1 80,1 mm~vf--f~,mh inbd 113 7000,6 15.5 2.64 46.7 31.8 smme~frmo 114 7001,7 0,56 1~,9 2,&2 28,4 &3,0 same 115 700,.~ 0,~2 14,~ 2,~2 21 8 ~8,1 smme AP1 15 116 700~,4 0,14 12,7 2,60 21.,~ 6~,7 sm; vf,~r, sh inbd 117 7004~4 0,87 J.g,g 2,&5 4.7 8~,.~. ~mme These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. 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'"'"" ' <)0 t5 E:O 0 00 :~: 40'? 4 '::~ '.3 .... -,,:::, :?,:. .... :: ::t"~:"~ F:U/::~ :.~: :::::::: :::.; :~?:.:' :o ~ .: :::::::::::::::::::::::::: ::::::::::::::::::::::::::: ::::~'~;~':: ::::F~: ~?:.?:. ::?:::~::::.:: ::.; :>:;~:~:.h~{:::~: ~:::.:.~:~:::':' :::: ::~;::::. :::: ::::. ~:~:: :: ::~:~t:~ ~::':::~ ~:: t ~ ': ~:',~:~:~ ?: ;::: :: :::~::: ?~:: :::~ ?;: ~ a~::::~': ;~;~;~ :.': ::: ~:: ~ ::::~: ::.~ :~::: :. ~: ~: ~ ~:~::::a? :!:~;~:{:: :.~t:: ~? :::~::: :. :: :::: ': ~:::: :. :::: ~ ~:~: ::: .: :::: 0 74 ~, ::?, 9,::, ,, 00 6 :~ 0 (). 0 0 "2 ":"- ,, ' ...... . · ", a,.:,~. 6,'7 E; 24 0 0 41 a ~ :., / ~'--: :29 1:3. :22 'E', 1 :;::0 6, 4 ::', ,::, ,, :?,7 .................... ~ ............. ~'".' "~- ]=~7-=:T ........ =7: :: ::~s~::'~:: .) /. 2 ) Df4'I'/.:t CfqI_F':I._IL¢-h-I' i' Gl:,i (.hi'ID I N]-F:'RF'F)L(:CI" I ON 'BY F;;/4D I LI'.:3 OF CUR'v'ATURE " .. ARCO Alaska, Inc. Our Boss Gyroscopic Survey Job No. AK-BO-30050 Well: ~lY-6 (SEC01 TllN R09E) Kuparuk Field North Slope, Alaska Survey Date: June 4, 1983 Operator: Samec Scale: 1" = 1000' C -! o~)o. oo TF~UE NOFITH Surface Location (0571SNL 1911EWL) 100~. O0 ~2000. O0 ~3000. O0 --4000. O0 20Ob. O0 HORIZONTRL PROJECTION . ARCO Alaska, Inc. ~ Our Boss Gyroscopic Survey Job No. AK-BO-30050 Well: ~lY-6 (SEC01TllN R09E) KuparukField North Slope, Alaska Survey Date: June 4, 1983 Operator: Samec Scale: 1" = 1500' 0.00 500. O0 3000. O0 4500. OD 6000. O0 4391.45' @ S330 14'E 8120 7500, O0 I ~51~o. oo ~obo. oo VEBTIC~4L 4~o. oo PROJECTION August 26, 1983 Mr.GaryPlis~ya Sohio Alaska Petroleum Company Pouch 6-612 Anchorage, Alaska 99502 Re: Our Boss. Gyroscopic Survey Job'No:LAK-BO-30088 Well: S-4 (S~C 35 T12N R12E) Prudhoe'Bay--Field North Slope, Alaska Survey Date:~August 13, 1983 Operator~ McGuire/Sellers Mr. Plisga: Please find enclosed the "Original" and sixteen (16) copies of our . Boss Gyroscopic Multishot Directional Survey' on the'above well. Thank you for giving us this opportunity to be of service. o. Sincerely,. .- NL SPE~R~-.SU?, ~C. Kirk Afflerbach District Supervisor Enclosures SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE AUGUST 15, 1983 SOHIO ALASKA PETROLEUM-.COMPAN¥ S-4 (SEC35 T12N R12E) PRUDHOE BAY ALASKA .................. , VERTICAL SECTION CALCULATED ALONG CLOSURE TRUE SUB-SEA MEASURED. VERTICAL VERTICAL DEPTH ............. DEPTH ............... DEPTH COURSE ..... course INCLINATION .... DIRECTION DEG__~IN DEGREES PAGE i DATE-OF-SURVEY--AUGUST BOSS GYROSCOPIC SURVEY dOB NUMBER AK-BO-30088- KELL¥~BUSHING--ELE~r-=---74~OO--FT~-- OPERATOR-MCOUIRE/SELLERS DOG-LEO TOTAL SEVERITY RECTANGULAR COORDINATES. DEG/~O0. NORTH/~OU~H. EAST-Y-WEST ..... VERTICAL i SF_C~ION 3O0 .............. 400 50O 600 700 800 9O0 ........... 1000 1100 1200 1300 1400 1500 .......... 1600 1700 1800 ....... 1900 2000 0 O, 100 ........ 100. 200 200, 299, ........... 399, 499. 599. 699. 799. 899. 999. 1099. 1199. 1299. 1399. 1499. 1599. 1699, 1799. 1899. 1999. 2100 2099. ............. 2200 ............ 2199. 2300 2299. O0 O0 O0 99 99 99 99 98 98 97 96 95 93 92 91 91 90 90 90 89 89 89 89 89 -74,00 0 0. N O, 0 E ....... 26..0Q ................. 0 ...... 30 ...... N ..... 3.,89-W 126,00 0 18 ..... N 8.80 W 225.99 0 11 ..... N,33.10 W ............ 325,-9~ 0--~20.. N-24.,-39-W 425.99 0 30 N 50.89 W 525.99 0 31 N 22. 0 W O. O0 O. O0 O. O0 O. O0 . 0..51 0,. 44-N O...03-W -0..-_1-1 0.21 , . 1.15 N 0.10 W -0.25 , 0.15 1.55 N 0.24 W -0.24. 0~-1.5-- 1...97-.N 0 ~45-W -0~/6 0.26 2.52 N 0.92 W 0.12 0.26 3.23 N 1.44 W 0.40 625,98 .0 ..... 31 ........ N.-..12,89-. 725.98 0 30 N 16.89 825.97; 0 45 N 4.50 92.5.96 ..................... 0 ...... 52 ..... N-- 8., 89 W ................. 0,09 ................... 4,.11. N .................. 1,72. W 0140 ........... W 0.04 4.98 N 1.95 W 0.36 E 0.33 6,06 N 2.03 W 0.11 E .................. O. 15 ............................. 7.47, N 1.86- W ................ O. 48 ............... 1025.95 0 58 N 24.60 E 0.27 9,01N 1.38 W -1.40 1125,93 I O...N 28,60 E 0',08 10,55 N 0.61W -2.60 1225,92 0 ....... 48 ..... =.--N.....43,.1.9...E ......................... 0,.-30 ................... 11,84 N ..... 0,29.E ......................... 1325,91 0 34 N56.69.E 0.28 12.63 N 1.20 E -4.95 1425.91 0 31 ,,N 66.50 E 0,11 13.09 N 2.05 E -5.90 1525,90 .................. 0 .... 37 .......N--46, O.--E ................... 0,22 ..................... 13,-65--N 1625.90 0 29 ,N 47,89 E 0.13 14.31 N 3.57 E -7.72 1725.89 0 25 ' N 17.30 E 0,25 14.96 N 4.00 E -8,32 -.1825,89 ................. 0 ..... 25 .... :-..~:-N-43,.30-E ................... 0,19 .......................... t5.,-5~-N ........................ 4,.36.-E ........ 8.,-8~--~ 1925.85 0 18 .... N39.60 E · 0.13 16.06 N 4.79 E ..... 9.:I~I 2025,85 0 19 .... S 61.69 E 0.39 ...... 16.13 N 5.20 E 9.82 .............. 2125,.-8~ 0.---1.2 ....... ~--6~,50-E 0r.12 --.1..srgg-N 5-~2--E -1.0~16. 2225.8~ 0 20 S 47.19 E 0.17 15.67 N 6.01 E -10.45 2400 2399.88 2325.8E 0 6 S 62.30 E 0.24 15.43 N 6,31 E -10.67 .......... 2500 .......... 2499.88 ............... 2425,8E ............... 0 ....3 ............ N-.b4-,60-E .................. 0,09 ............15,40.-.N ........................ 6,44.-E -10,.79 .......... 2600 2599.88 2525.88 0 17 S31.19 E 0.29 15.21N 6.62 E -10.90 2700 2699.88 2625.88 0 21 N 74.60 W 0.60 15.08 N 6.45 E -10.70 ...... 2800 .............. 2799,87 ............ 2725,.8% ................. 0--55 ........... N-.62,-80.-.W 0.58 ................. 15.53..-N ............... 5,43E ........................... 9,-.8~- ............ 2900 289~,86 2825,86 1 12 N 7~,3~ W 0,34 16,20 N 3,69 E -8,41 SOHIO--ALASKA--PETROLEUM.COMPANY S-4 ¢SEC35 T12N R12E) PRUDHOE BAY ALASKA SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE ~AUGUST 15,.~1983 VERTICAL SECTION CALCULATED ALONG CLOSURE PAGE 2 --DATE--OF-SURVEY-AUGUST--I~2~--i~8~. BOSS GYROSCOPIC SURVEY.- dOB NUMBER AK-BO-30088 ...... KELLY--BUSHtNG-ELEV. = 74 nn FT · · ~-v i OPERATOR-MCGUIRE/SELLERS TRUE SUB-SEA COURSE. COURSE DOG-LEG TOTAL MEASURED VERTICAL VERTICAL INCLINATION .... DIRECTION -.SEVERITY...RECTANGULAR COORDINATES DEPTH ............. DEPTH ............DERTH--.DEG M-I-N . DEGRE~ DE~-I..OO---NORTHZSOUTH EAST~W~ST VERTICAL SECTION~ 3000 2999.83 3050 3049,82 3150 3149.81 3200 3199,81 ......... 3300 ......... 3299,80 3400 3399,79 .35~9,7~ 3699,75 3799,73 - 3899,70 399?,67 4099,65 4199,64. 4299,63 4399,62 4499,61.. 4549,58 4599,50 4649,36 4699,09 4748,68' ...... 4798, 4847, 4896, 3500 ......... 3600 3700 3800 ......... 3900 40OO 4100 ..... 4200 4300 4400 ..... 4500 4550 4600 4650 4700 4750 ...... 4800 4850 4900 ........ 4950 5000 5100 ........... 5150 5200 2925.83 1 15 i N 62.80 W 0.23 17.00 N 1.71 E 2975,82 ................. 1 ........ 5,-----N..58..6~-W .............. 0.3~ ................. 1-7..50-.-.N ................. 0.82-F 3075,81 0 40 N S2,80 W 0.41 18,27 N 0,52 W 3125,81 0 38 ........ N. 63,~9 W 0,09 18,52 N 1,04 W 32,.25.80 .-0 .... 52 N--75~lO_W 0.-28,-- 18..-97-,N 2,-;28-W 3325,79 0 .52 · S 67,39 W, 0,57' ~,..i. ii . 18,87N 3,73 W -$,7~ --~$~03 -5.01 -4,60 -3,55, -2,13 0,-31 3925,67 1 19 S 35,39 W 0,13 4025, 65 1 0 .S 48,39 W 0,42 . 18.11',N 4.97 W -0.72 1S..97.-N ........................... 5,-91 .... W ......................... 15,52.N 7,01 W ....... 2,00 13.9~ N 0,36 W .... 3,76 .1.2.---1,1.-N ..9~-.69-W-- ' 10.11 N 11.04 W 7.48 ., 8,58 N 12,37 W 9,20 4125.64 ....... 0 ..... -4~ ........... 8-50.-,50-W ............ 0.-t7~ ............ : ............ 7.54. N ................. 1~.58--W ......................... 1.O.&7--(' 4225,63 0 41 .... S.76.19 W 0,37 ,. 6,94 N 14,72 W, 11,94 4325,62 0 41 .... S 58,60 W 0,21 ..... 6,48 N 15,82 W 13,13 4425.61 ..................... 1 .......... l'8-----.S-59...60-W ................ 0..61 ..................... 5.~O,N ................... 17.-3-1 .... W ...................... 14.82 ..................... 4475.58 2 19 S 68,69 W 2,11 4,94 N 18.74 W 1~,38 4525,50 3 46 S 71.80 W 2.92 4,06 N 21,2~ W 1~.04 4575.3~ .................... 4 ..... 54 ................ ,:-S..:.75,.80.W ..................... -...2..36 3.02 N 24.88 W .......... 22.82 4625.09 ~ 48 S..,79.89 W 3.87 1.98 N 29.87 W 27.89 4674,68 7 45 S 73,30 W 2,54 , 0.49 N 3~.02 W 17 ........... 4724,.1.7 ................. 8 4.1 ....... S-.-6%,-80-W 2,-.45 .................... 1.,91-S ................. 42,76--W 4t~-;34 .......... 47 4773,4' 10 22 S 62,89 W 3,73 5,39 S 50,27 W 49.55 51~ 4822,5 12 S 59,89 W 3,63 10,07 S 58,81W 59~I1 4945.28 4871.28 ................. 1:3 ........ 18 ............ :--8-58'-39W .................. 2.49 ............... 15.7,1---$ ............... ~8.'24--W .............69.80 ........ 4993,82 4919,82 14 2,7 S58,39 W '2,32 '22,00 S 78,4~ W 81,44 5089,95 5015,95 17 27 S 59,39 W 3,01 36,18 S 102,01 W 108,17 5137.44 ....... 5063..44 ...... 19 ........ 0 ....... S-60,-50-W 3.18 .............. 44,01-'.S ....... 115.55-.-W t-2~45~ 5184,49 5110,49 20 29 S 61.19 W 3,00 52,23 S 130.31W 139,99 SOHIO ALASKA-PETROLEUM~--COMPANY S-4 (SEC35 T12N R12E) ~ PRUDHOE BAY .. ALASKA ........................................... SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA .... COMPUTATION DATE.-- ........ AUGUsT 15,1983 VERTICAL SECTION CALCULATED ALONG CLOSURE TRUE SUB-SEA COURSE PAGE 3 DATE--OF-SURVEY-AUGUST 1~ !98~3 BOSS GYROSCOPICSURVEY ..... dOB NUMBER AK-BO-30088 ............ --KELLY--BUSH-ING-EL~V. ~ 74.00 FT. OPERATOR-MCOUIRE/SELLERS ..... COURSE . DOG-LEG ..- TOTAL MEASURED VERTICAL DEPTH .... DEPTH VERTICAL..INCLINATION ..... DIRECTION SEVERITY.. RECTANGULAR .... COORDINATES .............. VERTICAL DEPTH DEG--MIN DE~REE~EP.~-iO0 NO~TH/-~O~kT~ EA~EST 5250 ......... 5300 ........ 5400 5500 5461.27 ~.-5600 ......... 5553.28 5700 5645.33 737. s? .............. 5900 ........ 5829,50 6000 5921.7S 6100 6014.05 5231.13 5157.13 527.7.37 ............ 5203..3.7. ..... 5369.36 5295.36 5387.27 ........ 5479.28- 5571..33 5663.39 .......... 5755.50 ....... 5847.73 5940.05 21 43' '..S 61.80 W .2.52 . 60.82 S 146.14 W 157.67 2~.__58..~:S!.~.62~--.0--W 2.~48 69-~-~-8 $ ...... i~J~-W !76;36. 23..13 ........... S..61,80. W ................. 0,26 ................... 88,25 S 197,51...W ............................. 214,93 ............ 23... 10 ............... S...bl,80W ................. 0,04 .................. 106,..87.....S 232,23...W ........................... 253,64 23 3 S 61,6~.W 0,12 143,~3.S 301,13 W' 330,52 , 335,52.W 368,8~ 22 55 S..61.6~ W 0.14 162 22 .... 53 ...... .,,~Si,611.-3~-.W~ 0.-.1.2 ........... 180~.~.~36~...~5--W ........ 407~.1-1 22 .34 ........... S 61..50. W 0.32 1~.47.,.S .... 403.71-W ..... 445.06 . 22 37 ............. S. 61.3~,.W 0.05 217.84,.S ..... 437.46 W 482.78 .... 6200 ..........6106,41 ........ 6032~41 ....... 22 28- S--6-1-r6:,-W 0,-1-8. ,236-.-i-0~ 47-1~1.8-W 520, 6300 6198.84 6124.84 22 23 ~;, ,':.' S :!'61 W 0.091:'::.'.:. 254.20.S 504' 78 W 557. 6400 6291.2~ 6217.29 22,. 25 .:..:.::...:Si:!:61'. 6~.'W '.0' 04, :..272.27. S 538.35 W 595. ................. 6500 ...... 6383,, 68 ........... 630~, 68 ................. 22.--~3-: S~2,-.69-W 0.,..40~ .::.:-. --290-,-.~.t-~ ........... 572,...1.8,.-.W ~3~,-03-..' 6600 6475,87 6401,87. 23 2 ........... S.,,65,19,W ....... 1.09 ................. 307,11 ~ 606,~9.W ......... 671,34 6700 6567.72 64~3,72 23 32 S,,.67.80 W 1.14 ............. 322.87,S ..... 643.24 W ......... 710.65-.- ........... 6800 ........ 665~...21 .............. 6585,2..1: ........ 24 ...... ~: .... S.-70,--O-W --.1,.,03 .,.~37:3~ : 580W8--W 75~2 6~00 6750.48' 6676.48 24 ll ,,..... , s :70,30 W 0,18.'::.::',:. 351..26 S 71~,33 W 7~1.76 7000 6841.56 6767.5~ 24 :::.S.:.'70,8~ W . 0.45 364.~7 S 758,26 W 833'02 ................... 7100 ..... 6932,57 ............ 6858,57: ................ 24-.-~24---:- S--70,.8~:-.-W ................ 0,-t.6.----' ...... 378,-54---~ ......... 7~7,4~.-W 874,46 7200 7023,68 6~49.68,. 24 ..... 15 ................ $..,.71.1~.W 0,.20 3~1,~1S 836,40 W ........ ~1~,~4 7300 7115.02 7041.02 23 ..... 47 S-:72.19 W 0,61 404,70 S. 875,04 W ~56,34 .............. 7400 ............ 7206,61 ................ 71.32,-6t .........23:38 .... ~--78.,.-.50-W 0,-57 4t6.,.54--.~ .... ~..t7~40,-N ~~~ 7500 72~8,34 7224.34 23 .22 S 74.50 W 0,44 427,51S 951.67 W 1036.28 7600 7390.18 7316,18 23 16 S 75,3~ W 0.37 437.79~S ~8~,~0 W 1075.83 ...... 7700 7482,14 7408,1~ .............. 22 ....... 59 .................. $..-76,19.-W ...... 0,42 . 447,43..S · 7800 7574.28 7500.28 22 44 S77.50 W 0.56 456.27 S 7900 7666.64 7592.64 22 19 8 78.10 W 0.48 464.37 S ......... 8000 7759.18 7685.18 ..... 22 ...... 13 ....... S -78.60-W ............ 0.21 ...... 472.02 S 8100 7851.80 7777.80 22 5 S 79.39 W 0.33 479.22 S 1027.~8.W .... 1115.04 ........ 1065.81 W 1153.78 1103.26 W 11~1.93 1140.38 W ............. 1229..6~ ................ 1177.40 W 1267.09 SOHIO ALASKA PETROLEUM COMPANY S-4 (SEC35 T12N R12E) PRUDHOE BAY SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE AUGUST 15, 1983 ALASKA VERTICAL SECTION CALCULATED ALONG CLOSURE TRUE SUB-SEA MEASURED VERTICAL. VERTICAL DEPTH ............... DEPTH ........... DEPTH PAGE 4 DATE.-OF-.$URVEY-AUGUST--t3~ BOSS GYROSCOPIC SURVEY dOB NUMBER AK-BO-30088 KELL~--BUSHING-ELE~.--=---7~OO--F-T. OPERATOR-MCGUIRE/SELLERS COURSE COURSE DOG-LEG TOTAL INCLINATION DIRECTION,SEVERITY,. RECTANGULAR COORDINATES .DEG--.MIN DEGREES. DEG/~O0 NORTH/SOLLTH EAST~WEST VERT I CAL SECTION · 8200 7944.45 7870.45 22 7 S 80.60 W 8300 ........... 8037..16 ........... 7963.16 ........ 2L--52 .- 8400 8130.00 8056.00 21 46 ...... S 83. 8500 8222.95 8148.95 21 ,.30 ........... ......... 8600- .8316.08 ........ 8242,08 - ,21 ..... ~------~3~89--W. 8700 8409.37 8335.37 21 0 S,84.60 W 8800 8502.88 8428.88 20 30 S 84,60 W ............... 8~00 ............ 8596~90 ...... 8522..~0 ......... 0.45 485.75,S 1214.4& W 1304.40 --0.,55 4~1-,.45-S --1.251~48-W 134~g~42 ............. 0.42 4~6.34 S,.. 1288.34 W ......... 1378.03 ............. 0.33 ......... 500.68 S ....... 1324.~6 W ............. 1414,26 0-.-34 .... 504.-6~-S ..... 1361..-.16---W 1-44.9~98 0.32 508.28 S 1396.98 W 1485.22 0.51 511.62 S 1432.2& W 1519.87 1..~i8 .......... 51.4~...,85-.S~' .... 1466.-1L-,-W 1.55~-'~-1~ 9000 8691.26 8617.26 9100 8785.79 8711.79 ....... 9200 ......... 8880.66 ..........8806-,~6 .......... 18 6 .., S-85,50--W 9300 8975.73 8901.73 18 0 :i,,':'S 85,80"W 9400 9070.95 8996.95 17 34 S, 86.:60 W ............... ~500 ............... 9166.37... 9092,.,37 ........... 1-7- ..... 9575 9238.00 9164.00 17 1,4 -,, S 86,80 W 19 .21 ................ S 85.39, W 18 43 ................... S-85,.50-W ...... 0.30 ..........517,7~.S 0..~2 ................... 520.35.,.S .- 1531.~6..W 0,,-62 . . 522~~ , 15~i.&-W 0.14 525.18 S 1594.07 W 0,.50 .~'i, 527-21',S 1624. S& W 0.00 .... 530.17 S 1676.~1W ................ HORI-ZONTAL.,-DISPLACEMENT--= ..... i758,..44---,FEET--AT--SOU~H-7-2-DEG,, ....... ~7-MIN, .... WEST-AT-MD-= ....... ~575 THE CALCULATION PROCEDURES ARE BASED ON THE:USE OF THREE DIMENSIONAL RADIUS OF CURVATURE ...... 1585. 49 .. .... 1617.27 ............ 1648-r0~ , 1678.24 1707.92 1758· 44 ' METHOD. SOHIO ALASKA PETROLEUM COMPANY S-4 (SEC35 T12N R12E) PRUDHOE BAY ALASKA .................................... SPERRY-SUN WELL SURVEYING COMPANY PAGE 5 ANCHORAGE ALASKA .............................................. DATE.-OF-$URVEY---AUGUST-~3~--19Ek3 ............. COMPUTATION DATE AUGUST 15, 1983 dOB NUMBER AK-BO-30088 KELLY-BUSHING-ELEV-r-------74-rOO-~T. OPERATOR-MCGUIRE/SELLERS ............................. INTERPOLATED---VALUES--FOR-£VEN-~.OOO-FEET--OP-MEASURED-DEP-TH- TRUE SUB-SEA TOTAL MEASURED .......... VERTICAL ....... VERTICAL REGTANGULAR L?JDORD.INATE$~.MD-TVD .VERTIGAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .............. 0 ........... 0.00 .............. -74..00 1000 999.96 925.96 2000 1999.89 1925.89 ~-3000 ...... 2999.-83 ...... 2925.-83 4000 3999,67 3925,67 5000 4993,82 4919,82 ............. 6000 ............ 5921,...73 .............. 584Z,73 O, O0 0, O0 0...00 7,47 N ...... 1.,86 W 0,04 .16,06..N 4,79 E 0.11 .......... · 17.,-00-N 1-,.7-1-E Orl-7 10,11 N 11,04 W . 0,33 22,00.8.i.... 78,46 W. 6.!8 . ' . . -- 1.99,.47--8-'. .... ' 403,-7-t-W· ' 78,-27- O. 04 ...................... O. 07 0,,06 0.16 5.85 .72~0~ 7000 6841.56 6767.56 .... 364.97 S ........................ 758.26,W ...................... 158.44 ..................... 80.17 ....................................................... ' 8000 7759.18 7685.18 .... 472.02..S .............. 1140.38 W .... 240..82 .................. 82.38 .................................................... 9000 .... 869.1-~26 ....... 8617.26 51--7-r7-6--S ~.. 149-9~1/~-W .308~-7-4 67--r~-3 9575 9238,00 9164,00 . .530,17 8":Y:. '-....'i676.,61W 337,00.:: . 28.25 ....: . I . . ·., . · . . . .. ~HE-.CALCULA~I ON--PROCEDURE.,S-ARE-~BASED'ON-.-THE'~E · .OF-- THREE-D.ZMENGIONAL--RADIU$ OF-~URYAT--URE--ME~HOD. ( SOHIO ALASKA PETROLEUM COMPANY S-4 (SEC35 T12N R12E) PRUDHOE BAY ALASKA ..... SPERRY-SUN WELL SURVEYING COMPANY PAGE ANCHORAGE ALASKA ............. DATE OF.-SURVEY AUGUST-13, .... 198~---- COMPUTATION DATE AUGUST.15,.1983 dOB NUMBER AK-BO-30088 ............................................................................. KELLY-BUSHING-ELEV.--= .... 74.00--F-T. OPERATOR-MCGUIRE/SELLERS INTERPOLATED VALUES--FOR-EVEN.-IOO-FEET OF-SUB-SEA DEPTH ................................. MEASURED DEPTH TRUE SUB-SEA TOTAL VERTICAL ..... VERTICAL ........ RECTANGULAR COORDINATES ....... MD-TVD DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION .......... 0 ....... 0.00... -74,.00 ............................. 0..00 ..................... 0.00 ................... 0.00 ...... 74 74.00 0.00 0.21N 0.01W-. 0.00 174 174.00 100.00 1.01 N ..............0.08 W 0.00 .......... 274 ......... 274.00 .......... 200.00 ....................... 1-..-48-N O...I~-.W 0-.-0.1 374 374.00 300.00 1.83 N 0.39 W 0.01 474 474.00 400.00 2.37 N 0.74 W 0.01 ............. 574 ....... 574.00 ........ 500..00 ................................. 3.01---N .i.~5--W 0.-.01 674 674.00 600.00 3.87 N - 1.66 W 0.02 774 774.00 700.00 4..76 N 874 ............. 874.00 .......... 800,-00 5r72-N 974 974.00 900.00 7.08 N~ 1074 1074.00 1000.00 8,61N ................ 11.74 .............. 1174.00 ........... 1100.-00, --tO,-.t-6-N. .. 1274 1274.0'0. 1200.00 11.57.,-.N 1374 1374.00 1300.00 12.48..N ................ ........ 1474 ............... 1474.00 ........... 1400..-,00 ~.~O0-N. 1574 1574.00 1500.00 13.46 N 1674 1674.00 1600.00 14.17 N ........ 1774 ............ 1774...00 ............ 1700..-00 1.88 W ...... 0.02 2rOS-W .0,03 1.92 W 0.04 1.57 W 0.05 .0 .- 8.3-. W ...... 0..-0 ~ 0.04 E ................................ 0.,,08 0.98 E ........................... O. 09,, · t=.-83-E .... 0.-09 2.66 E 0.10 3.40 E" 0.10 -~4Z=N -3,-94-E~--=-0:.-1-0- 0.00 ................ O. O0 .......................... 0-.-00 O. O0 O. O0 0 .-00 .... O. O0 ........................... O. O0 ............................... 0 r01 0.01 0.01 0..--0-1 0.0~ .................................... 0.01 ............. -- 0.-00 O. 00 0.01 SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE' ALASKA SOHIO ALASKA PETROLEUM COMPANY .................. S-4 (SEC35 T12N R12E) COMPUTATION DATE PRUDHOE BAY AUGUST 15, 1983 ALASKA PAGE 7 DATE OF SURVEY AUGUST--13,~1983 .... dOB NUMBER AK-BO-30088 · ~KELLY BUSHING-ELEVt-=--74.00--FT,- ...... OPERATOR-MCGUIRE/SELLERS INTERPOLATED VALUES-FOR..EVEN-IOO...FEET OF SUB-SEA-DEPTH ............... TRUE MEASURED ......... VERTICAL DEPTH' DEPTH SUB-SEA TOTAL VERTICAL ........ RECTANGULAR--COORDINATES DEPTH NORTH/SOUTH EAST/WEST ....... MD-TVD DIFFERENCE VERTICAL CORRECTION .......... 1874 ....... 1874.00 ..1800.00 ................... 15.-45_N 1974 1974.00 1900.00 15.96 N 2074 2074.00 2000.00 ,16.20~N _ 21~74 ............. 2174. D0 .......... 2100,00 2274 2274.00 2200.00 15.78 N 2374 2374.00 2300.00 15.45 N ........... 2474 ...... 2474.00 ..... 2400.00 ........................ 15.39,-N 2574 2574.00 2500.00 15.32 N ... 2674 2674.00 2600.00 15.03.N ...... 2774 ......... 2774,00 ............. 2700,-00 1.5-,34-N. 2874 2874,00 2800,00 16,05 N. 2974 2974.00 2900.00 16.75 N ........ 3074 ..... 3074,00 ...... 3000,00 --1,7~74-N 3174 3174,00 3100,00 18,39.,..N ................... .4,23-.E ............................. 0,1.1 4.70 E 5.07 E 5,53--E 5.90 E 6.27 E c%42-. E 6.55 E 6.61 E 5~,-80-E 4.21 E 2.21 E 0-.~-43-.E 0.78 W O. 11 0.00 O. 11 0.00 .0..1.-1 ......................... 0..00 O. 11 0.00 O. 11 0.00 0.4-1 ............................ 0.-00 ......................................................... 0.12,., 0.00 0.12 0.00 Orl-.2 O.rO0 0.14 0.02 0.16 0.02 Or18 0.-02 .......... 0.19 0.01 3274 :3274. O0 3200.,00 ....... 3374 ............. 3374...00 ........3300,,-.00 3474 3474,~0 3400,00 ......... ........ oo.-oo 18,87-,..,N ............................ 1.90 W i-9-.-02-~N 3,3~-W 18,:'35'..i?:N 4, 70 W 17,32 N 5,70 W -1~5~2-N ... 0.20 ......... 0.01 ,0.~t 0.-0t 0.22 0.01 0.23 0.01 --Or2~ 0...0t-- 3OHIO ALASKA PETROLEUM-GOMPANY~ $-4 (SEC35 T12N R12E) ~RUDHOE BAY ALASKA SPERRY-SUN WELL SURVEYING COMPANY PAGE ANCHORAGE ALASKA COMPUTATION DATE AUGUST 15, 1983 DATE OF SURVEY AUGUST-~13,--1983 ..... dOB NUMBER AK-BO-30088 KELLY BUSHING ELEV. = -74.00 FT,- OPERATOR-MCGUIRE/SELLERS INTERPOLATED VALUES FOR EVEN-lO0 FEET OF SUB-SEA DEPTH TRUE MEASURED .VERTICAL DEPTH DEPTH .3774 3774.00 3874 3874.00 3974 3974.00 ........ 4074 4074.00 4174 4174. b0 ..... 4374. 4374,00. 4474 4474.00 SUB-SEA TOTAL VERTICAL .... RECTANGULAR ........ COORDINATES MD-TVD- DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 3700,00 ...... 14,36.-N ............... 8,.03 W ............... 0,27 ......... 0.02 3800,00 12,66 N 9.34 W 0,29 0,02 3900.00 10.60 N 10.70 W 0.32 0.03 4000,00 ...................... 8,-88--N ............... 12,03-W .................. 0,35 ............................. 0,02 4100.00 7,78 N 13.29 W 0.36 0.02 4200.00 7.01.N 14.42 W 0.37 0.01 4300,00 ...................... 6,.64..--N ...................... 15,.56W ......................... 0,37 ................................. 0,-00 ..................................................... 4400.00 5.89 N- 16,81 W 0,39 0,02 ............. 4574 4574, ........ 4674 ....... 4674, 4775 4774, 4.876 4874. 4979 ....... 4974. 5083 5074, 5188 5174. ...... 5296 ....... 5274. 5405 5374. 5513 5474. ............... 5622 .............. 5574. O0 4500.00 O0 ...... 4600,00 O0 47OO, O0 O0 4800.00 O0 ........ 4900..00- O0 5000.00 O0 5100.00 O0 ...... 5200,00 O0 5300.00 O0 5400.00 4.56 N 19.76 W 0.45 0.05 ,2..50-N 27-.-06.- W ................. 0...74 O. 30 0.57 S 39.37 W 1.56 0.82 '7.70 S 54.69 W 2.99 1.43 -- 1.9,--32-S 7.4 ,-1,-1 .... W -5,54 ................................. 2.54 33.67 S ........ 97.,77 W 9.30 3.77 50, 34 S 126.87 W 14.80 5.50 69-,-1-1--S 1 ~1-,~4- W 22.,--34 7-,-54 89.19 S 199.26 W 31.05 8.71 109.44 S 237.03 W 39.84 8.79 QO ........ 5500,-00 .................. t29..~-5-7--~P ....'2.74-.,45' W ................ 48,-50 ................................. SOHIO ALASKA.PETROLEUM COMPANY S-4 (SEC35 T12N R12E) PRUDHOE BAY ALASKA SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE AUGUST 15, 1983 PAGE DATE-OF-SURVEY--AUGUST 1~, 1-983 dOB NUMBER AK-BO-30088 KELLY-BUSHING-ELEV~~4~O FT. OPERATOR-MCGUIRE/$ELLERS ............................. INTERPOLATED-VALUES-FOR-EVEN--1OO-FEET-OF-SUB-SEA-DEPTH TRUE SUB-SEA ~TOTAL MEASURED ....... VERTICAL ........ VERTICAL----RECTANGULAR COORDINATES DEPTH DEPTH DEPTH 5731 5874.00 5800.00 5839 5774.00 5700.00 5948~ 5874.00 5800.00 6056 .... 5974.00. ~5900.00 6164 6074.00 6000.00 6273 6174.00 6100.00 6381 6274.00 .. 6200.00 6489 6374.00 6300.00 6597 6474.00 6400.00 6706 6574.00 .... 6500.00 6816 6674.00 6600.00 6925 6774.00 6700.00 7035 6874.00 6800.00 7145 6974.00 6900.00 7255 7074.00 7000.00 7364 ..... 7174.00 ............... 7100. 7473 7274.00 7200. 7582 7374.00 7300. .......... 7474.00 ............ 7400 · NORTH/SOUTH EAST/WEST 149.72..S 311.88 169.79 S 349.15 18~.98 S 386.23 209.-85--S ............... 422,81 229.75 S 459.37 249.35 S 495.77 268.8~-S ............... 532.-07, 288.27 S 568.61 306.788 323,.,,90:-S ......... 645,77 339.64 S 687.0~ 354.82 S 729.28 ........... 36~.,82-S .................... 772.28- 384.68 S 815.20 37~.15 S 857.81 O0 ........................ 41-2.-50-S ...... O0 424.70 S 941.53 O0 436, 04 S ~83.17 O0 ..................... 44~6,1-.S ..... --t.024,,63.-. MD-TVD ................ VERTICAL DIFFERENCE CORRECTION W ..... 57.16 ....... 8.66 ........................................... W 65.75 8.59 W 74.29 8.55 W ................ 82.61 ............ 8.32 .............................. W 90.93 8.32 W 99.14 8.21 W .................... 107.,30 ......................... 8..16 .............................................. W . 115.52 8.22 W 123.~7 8.45 W ..................... i32..85 ................................. 8.88 W 142.19 9.34 W 151.79 ~.59 w .................. .................................. .ee ................ .._ W 171.50 9.83 W 181.16 9.66 , W .................. 190,-.48 ........................ 9..27 W 199.48 9.05 W 2~8.39 8.91 W ................... 2.1.7.--16 ........................ 8,77- 3OHIO ALASKA PETROLEUMCOMPANY ~-4 (SEC35 T12N R12E) ~RUDHOE BAY ALASKA ................................... SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE AUGUST.15, 1983 PAGE 10 DATE--.OF.-SURVE~ AUGUST---13~ 19:83 dOB NUMBER AK-BO-30088 KELLY,,.-BUSHING.-.ELEVr-= ..... 74~O0-F-T, OPERATOR-MCGUIRE/SELLERS MEASURED DEPTH INTERPOLATED-VALUE~FOR--~VEN---1-O~..FEET-OF.~UB-SEA DEPTH- TRUE SUB-SEA TOTAL -VERTICAL ....... VERTICAL--_-RECTANGULAR---COORD.INATES ......... MD-TVD DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE ........... 7799 ........... 7574. 7907 7674. 8016 7774, ...... 8123 ......... 7874. 8231 7974. 8339 8074. 8447 8174. 8554 8274. 8662 8374. .. 8769.. 8474 8875 8574~ 8981 8674. 9087. 8774. 9192 8874. 9298 8974. .......... 9403-- 9074. 9507 9174, 9575 9238. VERTICAL- CORRECTION O0 7500.00 ............... 456.25.-..S .........1.065.70-W ................ 225.70 ........................... 8.54 O0 7600,00 464,99 S 1106.22 W 233,95 8,25 O0 7700.00, 473.22 S 1146.31W 242.00 8.05 O0 ....... 7800,00 .._480.~88 $ .... 1-1.86.25-W 249,.96 7,95 O0 7900.00 487.72 S. 1226.32 W 257.90 7.95 O0 8000.00 493.54 S 1266.12 W 265.69 7.79 pO 8100,-00 ............. 498,.47---..S~-.. ....... 1305,77- O0 8200,00 502,93 S 1344,92 O0 8300. Oo ....... 8400. bO 8500. O0 8600. O0 8700. O0 8800. O0 8900. O0 9000. OD O0 9164. O0 507.00 S 1383.46 O0 .................. 510.60.-S .... 1421.51 O0 514.08 S 1458.17 O0 517.28 S . 1493.10 O0 ............. 520,...04.--S-.-.: ..... 152.7,68 00 522.66 S . 1560.99 O0 525.14 S-., 1593.51 O0 ............527,-27--S ..... 1625,52 ..... O0 529.06 S 1656.78 O0 530.17 S 1676.61 W 280.86 W 288.11 W .... 295.16 W 301.74 W 307.71 W .......... 313,55 W 318.99 W 324.18 W ................. 273,38 ....................... 7.69 ...................................................... 7.48 7.25 7.05 .............................................................. 6,57 5.97 ............... 5.84 ............................... i' '-'- 5.44 5.18. W .................. 329,.20 .............................. 5,02 W 333.98 4.79 W 337.00 3.01 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM,RADIUS OF. CURVATURE) POINTS Sohio Alaska Petroleum Company Our Boss Gyroscopic Survey Job No. AK-BO-30088 Well: S-4 (SEC 35 T12N R12E) Prudhoe Bay. Field North Slope, Alaska Survey Date: August 13, 1983 Operator: McGuire, Sellers Scale: 1" = 500' -20~0.00 TRUE NOSIH Surface Location 1633SNL 1085 EWL .... O.-CO -~5[0.00 -~0~0.00 ~5s'~' ~ s~sO --500.00 HORIZONTAL- -lO00. O0 PROJECTION DIRECTIONAL CUSTOMER : SOHIO LOCATION : PRUDHOE BAY, ALASKA WELL PAD : S WELL NO. : 4 DRILl_lNG SURVEY REPORT TELECO OILFIELD SERVICES OF ALASKA, INC. 6116 NIELSON WY., ANCHORAGE, ALASKA,. 99502 TEL : (907) 562-2646 PAGE DRILLING CO. : AK. UNITED CUSTOMER JOB NO. -' TELECO JOB NO. : 303-AK MAGNETIC DECLINATION : 31.30 E · PLANE OF PROPOSED DIRECTION IS : RIG NO. : 2 S 69.06 W DATA REDUCED BY RADIUS OF CURVATURE METHOD TYPE OF SURVEY : MAGNETIC START DATE : 07/22/83 FINISH DATE : 08/01/83 REPORT PREPARED BY : COLBY COLOMB MEASURED DRIFT TRUE DEPTH ANGLE VERTICAL DEC MIN DEPTH VERTICAL SECTION DRIFT DIRECTION DEG MIN TOTAL COORDINATES CLOSURES D I STANCE ANGLE DD MM SS DOG - LEG SEVERITY DEG/100 FT. 4500 0.00 4500.00 4572 2.24 4571.98 4664 5.24 4663.77 4788 7.48 4786.95 4850 9.54 4848.21 4951 13.24 4947.13 5044 15.421 5037.15 5138 18.30 5126.99 5231 21.18 5214.44 5564 23.00 5522.86 5870 22.54 5804.64 6176 22.24 6087.04 6333 22.18 6232.25 6552 22.42 6434.58 6802 24.06 6664.02 7032 24.48 6873.39 7313 24.06 7129.19 7479 23.30 7281.07 7783 23.00 7560.39 8160 22.18 7908.31 8537 21.24 8258.23 8851 19.48 8552.15 8900 19.48 8598.25 0.00 1.50 7.76 22.01 31.50 51.66 74.71 102.02 133.44 258.23 376.75 493.84 553.22 636.79 736.08 831.18 947.21 1013.87 1132.71 1275.32 1411.50 1517.76 1533.69 S 63. S 64. S 74. S 66. S 61. S 59. S 59. S 61. S 63. S 62. S 62. S 62. S 63. S 66. S 70. S 72. S 73. S 75. S 78. S 81. S 84. S 85. S 85. 00 W 00 W 00 W 18 W 00 W 36 W 36 W 00 W 06 W 24 W 24 W 48 W 30 W 00 W 54 W 18 W 42 W 48 W 18 W 24 W 36 W 18 W 18 W 0.00 S 0.67 S 2.92 S 7.75 S 11.99 S 22.09 S 33.92 S 47.61S 62.45 S 119.93 S i75.21S 229.44 S 256.41 S 292.16 S 328.63 S 358.68 S 392.68 S 410.30 S 437.19 S 462.78 S 479.88 S 489.60 S 490.96 S 0.00 W 1.35 W 7.19 W 20.60 W 29.14 W 46.86 W 67.01 W 91.02 W 118.98 W 230.60 W 336.34 W 440.96 W 494.23 W 570.03W 662.37 W 752.70 W 863.93 W 928.56 W 1045.51 W 1188.42 W 1327.68 W 1437.73 W 1454.28 W 0.00 1.51 S 63 30 00 W 7.76 S 67 55 58 W 22.01 S 69 22 06 W 31.51 S.67 38 24 W 51.81 S 64 45 25 W 75.11 S 63 09 17 W 102.72 S 62 23 13 W 134.38 S 62 18 27 W 259.93 S 62 31 16 W 379.24 S 62 28 59 W 497.08 S 62 30 39 W 556.78 S 62 34 45 W 640.54 S 62 51 47 W 739.42 S 63 36 44 W 833.79 S 64 31 16 W 948.98 S 65 33 24 W 1015.17 S 66 09 38 W 1133.24 S 67 18 25 W 1275.34 S 68 43 25 W 1411.75 S 70 07 41 W 1518.81 S 71 11 39 W 1534.91 S 71 20 43 W 3.333 3.331 2.059 3.630 3.476 2.473 3.011 3.107 0.517 0. 033 0. 171 0. 181 0. 473 0. 958 0.395 0.323 0.625 0.364 0.367 0.396 0.516 0.000 JOB NUMBER : 303-AK CUSTOMER : SOHIO MEASURED DRIFT DEPTH ANGLE DEG MIN DIRECTIONAL DRILLING SURVEY REPORT PAD : S WELL NO. : 4 TRUE VERTICAL DRIFT TOTAL VERTICAL SECTION DIRECTION DEPTH DEG MIN COORDINATES CLOSURES D I STANCE ANGLE DD MM SS PAGE SEVERITY DEG/100 FT. .. · .. BOTTOM HOLE CLOSURE: 1534.91 PRINTED : 26 AUG, 1983 11:00:17 AM FEET AT S ?1 20 43 W COPYRIGHT (C~ 1983 ABACUS COMPUTER SERVICE 820 W. 71st AVENUE ANCHORAGE, AK. 99502 ( 90? ) 344-0761 Suggested form to be inserted in each "Active" well folder to check £or timely compliance with our ro:julations. - Operator, W~I Na~e and Nufnbe~ ' Reports and Materials to be received by: Required Date Received Remarks Completion Report Yes · &._-x~ ? ~--~ · . _s~ples /~0-' ~1 .. dA."' ~ · x. - . : )%% . ...Core Chips /~x4~~_ Core I~scription -r~/~d~) '/~'~-~ Registered Survey Plat y ~-",~ ~--~ -'~'l-.~L'-~. ~ ~ ,Xq,,,,,'l:' ' ~ .. % · .~ -~ Inclination Su~ey ~'~ '*/' 5%, Dire~ional ~ey ~~._ [~] Drill St~ Test Re~s ~~/e-- _ . KUPAF4JK ~ I NEERI bC TO- William VanAlen F-R~,4: D.W. Bose/She ! by j. l~Aa t thews Transmitted herewith are the followin9- PLEASE 1', , F FILM. T - TAPE, FC_. - H-DTOOOPY AP-tED ALAS,O,, lb,E:. ATTN: SHELBY J. tCAT1TID,~S - ATO/1115-B P. O. P__.OX 100360 AI',E1-EPCGE, AK. 99510 ARCO Alaska, Inc.~.,..,...~ Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 June 24, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Subsequent Sundry Reports Dear Mr. Chatterton' Enclosed are subsequent sundry reports for the following wells' 1A-4 1Y-6 1Y-7 If you have any questions, please call JoAnn Gruber at 263-4944. Sincerely, District Drilling Engineer PAV/GRU3L54'sm Enclosures RECEIVED - JUN 2 9 !98,3 Alaska Oil & Gas Cons, Commission Anchorage / ? / ? STATE OF ALASKA ~ ALASKA'~OI'L AND GAS CONSERVATION C~--~I'MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-78 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20958 4. Location of Well Surface: 571' FNL, 1911' FWL, Sec. 1, T11N, RgE, UH 5. Elevationinfeet(indicate KB, DF, etc.) 96' RKB 6. Lease DesignationandSerialNo. ADL 25646 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1Y-6 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [~ Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other [] Other [] Pulling Tubing [] Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ND adapter flange & master valve. RU Dresser-Atlas WL unit w/mast. Ran CBL/GR/CCL/VDL f/8001'-2400'. Ran gyro f/7950'-surface. RD Dresser-Atlas. NU adapter flange & master valve. Secured well. Accepted rig ~ 0001 hfs, 06/09/83. ND adapter flange & master valve. NU BOPE & tstd - ok. Perf'd the following intervals w/12 spf: 7565'-7659' 7796'-7800' 7809'-7834' 7859'-7863' Ran 3-1/2" completion assy w/tail ~ 7484', pkr @ 7454', & SSSV ~ 1880'. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well to diesel. Dropped ball & ~et pkr. Closed SSSV. Set BPV. Secured well & released rig @ 1030 hfs, 06/11/83. ~ECE ~VE~ ,JUN 2 9 ~'~"~'"'~.s~a Alaska Oil & Gas Cons. Commissior~ Anchorage 14. I hereby cert. j~y that the foregoing is true and correct to the best of my knowledge. // Signed The space b/~Cow~l'or C(:~nmission use Condition2Cof Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10403 Rev. 7-1-80 CRU3/SN30 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate I<UPAFAJK ENG I NEERI bE; TR~4SMITTAL #/,~ V~ ' TO: William VanAl en FF4~4: D. W. Bose/Shelby J. k~tthews Transmitted herewith are the following- PLEASE hD11E: BL- BLUELINE, S- SEPIA, F- FILM,~ PC - PHOTOODPY ylPT /CKI',DNI Fl}GED: LEASE RE'i'UP~ RECEI PT TO: ~ ALASKA, Ih,E;. ATTN' SHELBy J MATIHB¥5 ~aI ~i~ ~ _.¢8s Cons. Commission ' - ~' ~'rfchorage P. O. BOX 100360 ANEHOR/~E, AK. 99510 ARCO Alaska, Inc..._.._.? Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 June 15, 1983 Mr. C. V. Chatterton Commi ss ioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Enclosed are the Monthly State Reports for the following wells- * West * Ciri 1A-4 1Y-4 1Y-5 1Y-6 1Y-7 1Y-8 1E-14 Sak SWPT #1 Wolf Lake 2Z-1 2Z-2 2Z-3 2Z-6 2Z-7 2Z-8 * Due to the confidential material contained in these reports, please handle and file in a confidential manner. Thank you. Sincerely, P. A. VanDusen District Drilling Engineer PAV/SH7'sm Attachments ../UN .o 0 Alaska Oil & Gas Con~. uomm~sslor~ Anchorage ,~. STATE OF ALASKA ~--. ALASKA ,_AND GAS CONSERVATION C(. MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well I~X Workover operation [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well 571' at surface FNL, 1911' FWL, Sec. 1, T11N, R9E, UM 6. Lease Designation and Serial No. ADL 25646 5. Elevation in feet (indicate KB, DF, etc,) PAD 67' , 96' RKB 7. Permit No. 83-78 8. APl Number 029-20958 50-- 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 1Y-6 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of May , 19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1800 hfs, 05/15/83. Drld 12-1/4" hole to 2488'. Circ& cond hole. Ran,, cmtd & tstd 9-5/8" csg. Performed top job on 9-5/8" x 16" annulus. Drilled 8-1/2" hole to 8112' TD. Ran open hole logs. Drld & reamed f/8106' to 8120' TD. Ran, cmtd & tstd 7" csg. Displ top 360' of well w/diesel. Secured well & released rig ~ 0100 hrs, 05/24/83. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 9-5/8", 40#/ft, J-55 HF-ERW, BTC csg w/shoe I~ 2458'. Cmtd w/1000 sx AS III & 250 sx AS I. 7" 26 O#/ft, J-55 HF-ERW, BTC csg w/shoe ~ 8064' Cmtd w/900 sx Class "G" cmt SEE DRILLING HISTORY 14. Coring resume and brief description N/A 15. Logs run and depth where run GR/SP/DIL/SFL/FDC/CNL/Cal f/8088'-2458' 16. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~.~f// //~Z-_ '. Area Drilling Engineer SIGNED (////~ //'//--~ TITLE _ 7/- _r ~ / ~ ................ DATE NOTE--Rep~ on/th'is f/~rm is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas~:~onservation Commission by the 15th of the succeeding month, unless otherwise directed, Form 10-404 H I LL/HR28 Submit in duplicate 1Y-6 DRILLING HISTORY NU 20" Hydril & diverter & tstd same. Spudded well @ 1800 hrs, 05/15/83. Drld 12-1/4" hole to 2488'. Ran 63 jts 9-5/8" 40#/ft, J-55 HF-ERW, BTC csg w/shoe @ 2458'. Cmtd 9-5/8" csg w/lO00 sx Arctic Set III & 250 sx Arctic Set I. ND 20" Hydril & diverter. Perform top job on 9-5/8" x 16" annulus. Pumped 118 sx Arctic Set I. Bumped plug w/1500 psi - held ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 11.9 ppg EMW - ok. Cont. drlg 8-1/2" hole to 8112'. Circ & cond hole. Ran GR/SP/DIL/SFL/FDC/CNL/Cal f/8088'-2458'. Ream 40' to btm. Drld f/8106' to 8120' TD as of 05/22/83. Circ. & cond hole. Ran 207 jts 7" 26#/ft J-55 HF-ERW, BTC csg w/shoe @ 8064'. Cmtd 7" csg w/900 sx Class "G" cmt. Bumped plug w/2000 psi. Floats held - ok. Cut off 7" csg, install 7" emergency slips, set BOP. Instld & tstd FMC head. Displ top 360' of well w/diesel. NU top of tree. Secured well & released rig 0100 hrs, 05/24/83. HILL/DH22 06/13/83 JUN .2 Oii ~?~ Gas [;~n'], ARCO Alaska, Inc.~ Post Office E~,~.~- 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 t~iay 16, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1Y-6 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to complete this well with our workover rig. Since we expect to start this work on June 4, 1983, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, Area q)rilling Engineer JBK/GRU3L9' sm Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA,_ .L AND GAS CONSERVATION CC..,MISSION SUNDRY NOTICES AND RE ORT$ ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER I~X 2. Name of Operator 7. Permit No. ARCO Alaska, Inc, 83-78 3. Address 8. APl Number P, 0, Box 100360, Anchorage, AK 99510 50- 029-20958 4. Location of Well Surface: 571' FNL, 1911' FWL, Sec. 1, T11N, R9E, UN 5. Elevation in feet (indicate KB, DF, etc.) 9R~ RKB 12. 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1Y-6 11. Field and Pool Kuparuk River Field 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool ADL 25646 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [~X Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [~X Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to complete this well with the Westward Well Service Rig #1. The procedure will be as follows: 1) A mast truck will be utilized to run the CBL/VDL/GR and Gyro. 2) The rig will be moved on location; the BOPE will be nippled up and tested. 3) Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. 4) The well will be completed with 3-1/2", 9.2 #/ft, J-55, BTC tubing. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. The BOP equipment will be pressure tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated start: June 4, 1983 Subsequent Work l~eported 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ConditiOns of Approval, if any: Date ORIGINAl. SIGNED Approved by COMMISSIONER Approved Copy Returned .._.5'-/,F t' 3._ By Order of the Commission Date Form 10-403 Rev. 7-1-80 GRU3/SN6 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ~5 '1. · .LOCATED IN PROTRACTED SE_C,_ I,T..Wp.. I!N;,RGE. 9 E._,UMIAT M. ER.!D.!A..N... _ :5.! . . RESERVE PIT o RESERVE, PIT · , oo, -0 , ,, ..... ,. ~ ~ 380' ' . , SUF~VEY 6 I ,. ..q ~.4, VICINITY MAP ~cal~: I"=1~. .I. ALL Y 8~ X COORDINATES ARE ALASK~ ' STATE PLANE~ZONE 4. ! · ~ ~:.?;.~ I , .~; ,.;.;, _.~,~_,,~,,~,~,. ~. DISTANCES TO SECTION LINES ARE GEOD~IC. :"~': ~"~'~ --~ OF Al~t~ ~ SEE REE DWG. 229'~8, SH~ 7~-12-~I,REV. 7A. ~-"' ~--.~ ~~ee~e,~,~.~ 4. DRILL SITE AND Y 6 X COORDIt~,~TE~ ARE 9 t'h' ...... ~~ , ~ -~ ~,~ I.Y MIDDLE BY L H D ASSOCIATE~. .... ' ;2~' ~e~,~eee~,~e~,el.ee:~ 5, EL. BASED ON ~H. I'Y MILLE BY l..:it) AS~C. 'f.~..~__0AVIO ~CI', / L'~ I HEREBY CERTIFY THAT'I AM PROPERLY REGISTERED AND Y=5975115.~ 4. ~ 5975115.44 'l~r~,e%,~..~.eee~~ LICENSED TO P~ACTICE LAI]D sURv~YINe IN ~HE STATE OF LAT. 70~0'55~ 18" LAT. 70°[O'55.0260" UNDER MY DIRECT SUPERVlSlON~ AHD THAT. ALL DETAILS ARE LONe. 149~ 44'~.8 LONe. 149°~~ 55.5~~ 211 '~L~I792'FWL 211'FNL~I97~' FWL ,' CORRECT AS OF' MARCH I~ 1~85. Y=597511 5.50 5.Y=597475fi.49 7. Y, Se7470~.~l .*.RCO~Xi~81<a, Inc. X= 531520.06 X= 5~164~,4~ ' X, 5~152~21 ,, ~. Kup~ruL [.reject North Slope Drilling LAT. 70020'35.0296'' LAT. 70°20 31. 857" [ LAT, ~°ZO ~1,4~09 j ~,_ 211 FNL,,leS2' FWL 571' FNL, 1971'FWL I .57C FNL,185I' FWL · AS EUILT LOCATIONS X= ~31580.12 X= 531580.41 , Xw 531460.~ ..... · ......... LAT. 70° 20' 35.0275" ~T. 70° 20' 51,4881'* .' LAT. ?Oe20*~l. 49]1" · 54" date: MArl. 1985 211'FNL~ 1912' FWL 571~ FNL~ 1911* FWL 570~ FNL,1791. FWL drawn by:J.D. . Jdwg. no.9.05 '~5.12d28 -. ., May 13, 1983 Mr. Jeffrey B. Kewin Senior Drilling Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Re: Kuparuk River Unit 1Y-6 ARCO Alaska. Inc. ~~ ~o. 8~-7o Sur Loc 517 '~{L, !91I' ~P~ Sec 1 TllN R9E ~t~hole Loc. 4336'FV~, 4t95'~L, Sec. 1, TllN, R9E, U~.~. Dear Mr. Kewin~ ._ , ~_ill the Enclosed is the approved application for-oermit to ~r above referenced well. If coring is conducted, a one c~ic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape -containing the digitimed log infor~ation shall be submitted on all lo~s for copying except experimental logs, velocity surveys and dipmeter surveys. r-~any rivers in Alaska and their drainaKe systems have been classified as important for the spawning or r~igration of anadromous fish. Operations in these areas are subject to AS !6.u5.~Tf) and the regulations promulgated thereunder (Title 5, Alaska A~min~=tratzve Code). Prior to commencing operations you r~ay be contacted by the Habitat Coordinator s o_..zce,~ Depart~nent of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Ci~apter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution :Control Act, as an~ended. Prior to commencing operations you may be contacted by a representative of t~e D.~oartment. of Environmental Conservation aid us in $che~u!ins field work, please notify this office mourn, prior ~o ~ ~ ~ ~ co~e,~.ng 5nstallation of the blowout Jeffrey B. K~in Kuparuk River Unit 1Y'6 -2- [~ay 13, 1983 prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Connnission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Verd~L. trul~ YoU~zS_, ~ / / C. V. Chatterton' " . _. ~ ~air~n of ~w o.n~:~ O~ vM~ Alaska Oil and Gas Conservation Commission Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. be ARCO Alaska, Inc. Post Office Anchorage, Alaska 99510 Telephone 907 277 5637 May 11, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1Y-6 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 1Y-6, along with an $100 application fee. o A diagram showing the proposed horizontal and vertical projections.of the wellbore. o A diagram and description of the surface hole diverter system. o A diagram and description of the BOP equipment. Since we estimate spudding this well on, May ~ ~ 1983, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, Area Drilling Engineer JBK/JG:sm Attachments ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~.,_ AND GAS CONSERVATION CC..,vllSSION PERMIT TO DRILL 20 AAC 25.005 SERVICE [] SINGLE ZONE MULTIPLE ZONE la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL~ DEVELOPMENT GAS [] 2. Name of operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 571' FNL, 1911' FWL, Sec. 1, TllN, R9E, UM At top of proposed producing interval Target @ 6103' TVD; 4180' FWL,' 3960' FNL, Sec. 1, T!iN, At total depth R9E, UM 4336' FWL, 4195' FNL, Sec. 1, TllN, R9E, UM 5. Elevation in feet (indicate KB, DF etc.) RKB 96' Pad 67' 6. Lease designation and serial no. ADL 25646 9. Unit or lease name Kuparuk River Unit' 10. Well number 1Y-6 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool 12. Bond information (see 20 AAC 25.025) Federal Tnsurance Co. Type St-atewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 32 mi. NW of Deadhors~,es 16. Proposed depth (MD & TVD) 8056' MD, 6403' TVD feet 14. Distance to nearest property or lease tine . 3,369 ' FEL @ surface feet 17. Number of acres in lease 2560 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 1000 feet. 20. Anticipated pressures MAXIMUM HOLE ANGLE 43 o (see 20 AAC 25.035 (c) (2) Proposed Casing, Liner and Cementing-Program 15. Distance to nearest drilling or completed 1Y-7 we~l 60' @ surface feet 18. Approximate spud date 05/:1.4/83 ~psig@ 60° Surface 2970 psig@5949 ft. TD (TVD) SIZE Hole Casing Weight 24" 16" 65# 112-1/4 ' 9- 5/8" 40.0# ]8-1/2' 7" 26# 22. Describe proposed program: CASING AND LINER Grade Coupling H- 40 PEB J-55/ BTC HF-ERW · BTC K-55 Length SETTING DEPTH MD TOP TVD 80' 29' I 29' I 2269' 29' 29' .I I 28' I 28t 8028' MD BOTTOM TVD o9' 2298 ' I 2200".. I 8056' 16403' I I QUANTITY OF CEMENT (include stage data) ±200 cf 800 sx~ III'~ 250 s: 246 sx Class "G" Neat 258 sx Class 'G' extel ~:ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approx, 8056 ':(6403'TVD). A 20", 2000 psi annular diverter will be installed on the '16" conductor while '.drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 19-_5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pres: will be 3000 psig (1800 .psi for annular). Expected.maximum surface pressure will be 2511 Pressure calculations are based on latest rese~roir pressure data. Surface pressure calcul; iw~th unexpanded gas bubble at surface including temperature effects. Selected intervals wi'. :~be logged. The well will be completed with' 3-1/2", 9.2#, J-55 buttress tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected interval will be perforated within the Kuparuk formation and reported on subsequent reports. A dowr~ isafetx valve will be installed and tested upon completion of the job2 1Y-7 will be 60' awa' !from IY-6 @ the surface. There are no~closer'wellbores anywhere downhole. Top of cement f{ the product/i~n st~ring 5~il~be placed @ 2611' MD, approximately 500' MD above the Wes~ Sak SIGNED ~/~)~..~~. ,/f.~'~~ TITLE Area Drillin~ Engineer DATE The space belo~fc;r ~ro~mii/io ~u se/~"' - ~ CONDITIONS OF APPROVAL Samples required I~YES ~.NO Permit number APPROVED BY ~ //~ Form 10-401 Mud log required i--lYES [~O Approval date . BS/13/g3 Directional Survey required I APl number ~YES I-]NO 50- SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE May 13, 1983 by order of the Commission Submit in triplicate ded ure ig. .ted L1 Es ~ole )r ~nds. , ..~._. ~ q f i I!i ',I i ~ il ,, , .j iii ~illi , , i l ii i t , I i , i : : t -{' 'l 'il '' 'J il ii i ~ , i{Ji J Ii {iii Iii i i m~ fiji {II! J ~ , . , , , , ,, . . , , ,: , ~i ~, n i ~ , iil[l~' i ~ ~i~i~i i ~i', I ~ ~{ji n ~r :t;'= , i ~l J i~ ~ r~ ~ . , .... i " Ii { } {LI ;~ I 2-L2.1- _ , ~ J 1222 I __I 2_ I I I ! i j I ! , I I ~ { j, i I I i I ~, - ' ' ...... 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' i ', I i :: Fi :ii ~,ii ~ :~,i '~ ~'~' ~'~ ~ iii~ i~ i i~ ~ ~i!i '.'i~ ; ii i :f ~ i~j &lii i~1, . ilil i'i I i I i ~li -!?-.~rJ~---~-'-~'- .- -,. ;., , ;.. , ~ ; ~. · ~i ~.~ .~-. - ! J ~ ' ~ ' _~~.jj __~.~t j ~_kJJ i j j lj I J i ~ J ' ~' '' ~ ti ii, , ;iii ,,. i !li~i;i ~ i jm I I J ~ 'i illi '~;J ii J] J J J J [ iJlJljJll i i liar I ! J I Jill i~',' ~! i ,, : ' ~lll I J j j ': '"" ii ' " -, , I : ' i~ ' : ' -J ~ ] :I,UU~ := t ~ ~ ~ i J i I J , itl I i , J i i i i i I ~ I I . , i ! l ''~ ~;~ : ~ ~ J i I ~ I Jill i'i · , -; * ' '--- I ' . [ i : I~ i ,,,, ,-d ~+ ,' ~' , '-T *-~, ,,, , ''' ~ " -' '"" ' ' ' '- '"' ~iii "' '4 I ; '-%--T- i ~iJill Tq'F i j ' ' ~ ~l~i iii ~' ~ ~=--4.-;-~ ..... ~_~ __L_F_L_~__~_~_~_ I ~ ~ ~ i J i ~ ~ i i ~ i i i!~ ~-~--~ ......... ~ ..... m'-F~' ,. , ; : ~ ~, , i ] ~ ~ i ~ i J i l~ i il j ill~ i Surface Dive-'~,~.. Syssem 1. 16" - 2000 psi Tankco starting head· 2. Tankco quick connect assy. 3. 16" x 20" 2000 psi double studded adapter. 4. 20" 2000 psi drilling spool w/!O" side outl ets. 5. 10" ball valves, hydraulically actuated, w/lO" lines to reserve pit. Valves to open automat'ically upon closure of annular preventer. 20" 2000 psi annular'preventer. · · 7. 20" bell nipple. Maintenance & Operation 1. Upon initial installation close annular preventer and verify that ball valves have opened properly. 2, Close annular preventer and blow air through diverter lines 'every 12 hours. 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line.. Do not shut in well under any circumstances. 16" Conductor m ANNULAR PREVENTER i BLIND RAMS _1 ADR ILL lNG I ) PIPE ARMS , I. CSG x HD D[AGRAM -.-1 13-5/8" 5000 PS! RSRI~A BOP STACK 1o 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11" o 3000 psi x 13-5/8" - 5000 psi spacer spool ¢. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 13-5/8" - 5000 psi pipe rams $. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi blind r~ms 'g. 13-5/8" - 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'PS! WITH 1500 PSI OOWNSTREAM 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. RECORO ON NAOC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME ANO 1200 PSI REMAINING PRESSURE. 13-5/8' BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC. DIESEL. 2. ,CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- EO. PREOETERMINE OEPTH 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 MANIFOLO. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. ' *- S. INCREASE PRESSURE TO ~ANO HOLE FOR 10 MINUTES. BLEEO TO ZER Oq~SL 6. OPEN ANNULAR PREVENTER ANO CLOSE TOP SET OF PIPE RAMS. INCREASE PRESSURE TO ~ANO HOLO FOR 10 7. MINUTES. 8. 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 ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. g. OPEN TOP SET OF PIPE RAMS ANO CLOSE BOTTOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSI. 11. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 1S. RECORD' TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. .e , ANNULAR PREVENTER 11 BLIND RAMS -) I0 PIPE ARMS 9 DRILLING SPOOsL DIAGRAM .~2 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 7-1/16" - 3000 psi tubing head 4. 7-1/16" - 3000 psi x 11" - 3000 psi double studded adapter 5. 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool 6. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool - 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 9. 13-5/8' - 5000 psi pipe rams 10. 13-5/8" - 5000 psi blind rams ll. 13-5/8" - 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 ANO RECORO THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORO ON NAJ)C REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND i200 PSI REMAINING PRESSURE. PIPE ARMS ) 7 m c' HD I CSG ' 13-5/8= BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTI.C OIESEL. 2.. CHECK THAT-ALL HOLD DOWN SCREWS ARE FULLY RETRACT- EO. PREJ)ETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT Itl WELLHEAO. RUN IN LOCK DOWN SCREWS IN HERO. 3. CLOSE ANNULAR PREVENTER AND._CHOKES AND BYPASS VALVES ON MANIFOLO. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. S. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD' FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED OOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH. 3000 PSI UPSTREAM OF VALVE ANO ZERO PSI OOWNSTREAN. BLEED SYSTEM TO ZERO PS/. 9. OPEN TOP SET OF PIPE RAMS ANO CLOSE BOTTOM SET OF PIPE RAHS. 10. INCREASE PRESSURE TO 3000 PSI ANO HOLD FOR 10 MINUTES BLEEO TO ZERO PSI. 11. OPEN BO1TOM SET OF PIPE RAHS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLO ANO LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANOPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS ANO INSIOE BOP TO 3000 PSI WITH KOOMEY PUMP. 15. RECORO TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPLETE DOPE TEST ONCE A WEEK AND FUNCo TIONALLY OPERATE BOPE DAILY. ~HECK LIST FOR NEW WELL PERMITS Company .~'~ ~v Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc (2 thru 8) 1. Is the permit fee attached ......................................... 2. Is well to be located in a defined pool ............................ 3. Is well located proper distance from property line . . 4. Is well located proper distance from other wells ..[ ~[~[[ [i!i!!ii 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is well bore plat included ............ .. 7. Is operator the only affected party ..................... ~ [ 8. Can permit be approved before ten-day wait .......... (3) Admin~oCz/. ~---.. jUl~.~ 9. .(,.,~' thru 11) 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. ( 4 ) C a s g '~.~ ~/~/f~r (12 thru 20) YES NO REMARKS Does operator have a bond in force .................................. ~_ · Is a conservation order needed ...................................... Is administrative approval needed ................................... 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 well bore separation proposed ........................... (5) BO PE ~M.J~. S~/~ (~i thru, ~) , 21. 22. 23. 24. 25. Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ....... Z~ Does BOPE have sufficient pressure rating - Test to ~O~... psig ..~. Does the Choke manifold comply w/AP1 RP-53 (Feb.78) .................. Additional requirements ............................................. Additional Remarks: Geolog · Engi ,er' rev: 1~/06/$~- -- INIT IAL CEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE