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Home My WebLink About190-004 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak. us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska)Inc. , Prudhoe Bay / PBU / WGI 06/15/03 John Petty John Crisp Packer Depths (ft.) I Pretest Initial 15 Min. 30 Min. P'T'D'I1900300WelIIWGI'06 I Type Inj. MD/TVDI 8,298'I 7,660'I TubingI '36001 36001 36001 36001 Inter~aI 4 Type test[ ~ 'TestpsiI ~9~sl I Casin~l 9~01 25'001 24601 24901 I~/FI P Notes: 4-year MITIA { I~ l U~,~Wl ~,0,~,I 7,869,I TubingI 36501 36501 36501 36501 Interva~ 4 P.T.D.I1900400 Type test I P I Test psiI 19671 I CasincjI 5401 20401 20201 20001 P.'/FI P Notes: 4-year MITIA Type Inj Notes: WellI P:T,D.I Notes: WellI P.T.D.I Notes: Type Type l~. Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form Revised: 06/19/02 2003-0615_MIT_PBU_VVG 1-06_-07.xls MEMORANDUM TO: Randy Ruedrich Commissioner R THRU: Jim egg P.I. Supervisor FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 15, 2003 SUBJECT: Mechanical Integrity Tests BPX Prudhoe Bay Field WGI Pad Prudhoe Bay Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. I WellI W-06 I Type,nj.I G I ~.v.D. I~o ]Tubing I ~o I ~o I ~o I~o I,nterva, I 4 I P.T.D.I 1900300ITypetestl P I Testpsil 2000 ICasingl 1270 I 2500 I 2460 I 2490 I P/FI PI Notes: OA 880 psi. during test. 2.2 BBL. Pumped I WellI WGI-07 I Type Inj.I G I T.V.D. I ~ ITubing I ~o I ~o I ~o I ~° I lntervall 4 I P.T.D.I 1900400 ]TypetestI P ]TestpsiI 2000 ICasingI 540 I 2O4O I 2020 I 20001 P/F I _P I Notes: OA 200 psi. during test. 7 BBL. Pumped. I Welll ITyPe'"j' I I T.v.D. I I Tubing I I I I ]Interval[ ] P.T.D.[ ]Typetest] ]Testpsi[ I Casing] I I I I P/F I I Notes: Well] P.T.D.] Notes: I We,I Type Inj. P.T.D.I Notes: j, Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS IN J, S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey 'A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to PBU to witness 4 year MIT's on WGI. WGI 07 's pressure test started ~ 2500 psi. After 15 minutes the pressure had dropped to 2280 psi. The pressure on W-07 after 30 minutes was 2040 psi. The pressure on W-07 stabilized ~ 2040 psi. & had no change for 30 minutes. M.I.T.'s performed: 2 Number of Failures: 0 Attachments: Total Time during tests: 3 hrs. cc: MIT report form 5/12/00 L.G. 2003-0615_M IT_PBU_WG 1-07ic.xls 6/24./2003 PLUGGIN~ & LOCATION CLEARANCE REPORT State of Alaska ALASKA 0IL & GAS CONSER%'ATION COM/~ISSION casing size, w=, deur_h, cz:: vol, & procedurm. q Review the well file, and' c~en= on plugging, well head and !oca=i~n clearance - provide loc. c!e~r, code.~ Code Signed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [] GAS E~ SUSPENDED E~ ABANDONEI~ SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-04 & 398-214 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20123 4 Location of well at surface 9 Unit or Lease Name 269' FNL, 94' FEL, Sec. 11, T10N, R8E, UM i~i Kuparuk River Unit At Top Producing Interval !I ~~' ' 10 Well Number 1240' FNL, 809' FWL, Sec. 14, T10N, R8E, UMit__i ..... ~t~'_)~ ! 2K-21 At Total Depth~~~'~ ,~~! 11 Field and Pool 1519' FNL, 581' FWL, Sec. 14, T10N, R8E, UM .:% ,~,~.;~,:~ KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. Kuparuk River Oil Pool RKB 154'I ADL 25605 ALK 2679 12 Date06.Jan.90Spudded 13 1Dates-Jan-90T'D' Reached 14 1Date0-Sep-98Comp'P&A' Susp. or Aband. 15 WaterNADepth, if offshorefeet MSL 16 No. 1cf Completions 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 10800' MD & 6502' TVD 10664' MD & 6426' TVD YES U NO M 1810' feet MD 1600' APPROX 22 Type Electric or Other Logs Run 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5# H-40 SURF. 115' 24" 170 sx AS II 9.625" 36.0# J-55 SURF. 3919' 12.25" 850 sx AS III, 400 sx Class G 7" 26.0# J~55 SURF. 10756' 8.5" 400 sx Class G cement pluc, l @ 10664' 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) 10001' & 10189' all perfs abandoned · 26 ACID, FRACTURE, CEMEt, DEPTH INTERVA,L (MD) AMOUNT & KIND OF MATERIAL USED down squeezed 24 bbls 20 ppb cement below retainer; set balanced cement plu~l from packer at 10664' MD up 27 PRODUCTION TEST 0Klbil /AL Date First Production I Method of Operation (Flowing, gas lift, etc.) N/A .4;.,, Date of Test Hours Tested PRODUCTION FOI OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RA¥~I~/,,~ ~l'(~//~/,''-- Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE: 28 CORE DATA "'~,~ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ., 29. 130. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C Bottom Kuparuk C Top Kuparuk A Bottom Kuparuk A 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. Signed _ ;~: Title .~/-~.,. ~.~-~. DATE ,~' ~ ..... ~'~/ Prepared b~ Name/Number Sharon AIIsup~r~k~/~3~4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 CTD: Daily Summary of Sidetrack Operations Kuparuk 2K-21 Date 09/06/98 1 09/07/98 2 09/08/98 3 09/09/98 4 09/10/98 5 09/11/98 6 09/12/98 7 09/13/98 8 09/14/98 9 09/15/98 10 09/16/98 11 09/17/98 12 09/18/98 13 09/19/98 14 09/20/98 15 09/21/98 16 Report Number O9/22/98 17 O9/23/98 18 O9/24/98 19 O9/25/98 20 O9/26/98 21 09/27/98 22 Depth 0 0 0 0 10674 10355 1O383 10425 10424 10426 10435 10523 1070o 11261 11538 11660 12O20 12410 12578 12578 12578 12578 Daily Summary Rig move. MIRU. Continue to RU. Continue to RU. MIRU CTU #4 Continue to RU. Work on BOPS. Test BOPE. Load well. Set cement kick-off plug in 7' liner. Wait on cement. Wait on cement. RIH. Mill nipple. Trip for MWD. Check injector. Log GR tie-in log. Log gr tie-in. Mill pilot hole. Trip for MWD failure. MU & test MWD. RIH. Log tie in. Mill pilot hole. POOH. Un-deploy. Re-deploy. RIH. Mill pilot hole. Displace'well. POOH for window mill. POOH. RIH w/window mill assy. Orient. Time mill window. POOH. MU 2nd window BHA. Replace pipe/slip inserts. Deploy BHA. RIH. RIH w/2nd window assy. Log tie-in. Complete milling window. FIT. Displace well to rio-pro. POOH. RIH. Orient. Begin drilling. Drill to 10444', POH for MWD failure, RIH and att. to drill,Motor failure,POH and replace motor (Bad transmission) RIH tie in GR and drill from 10444' to 10523' (ROP at 35 fph) Drlg. from 10445' to 10700' and landed build section,POH and LD BHA #8,Test BOPE and choke skids,PU BHA #9,Rih maintaining 1000 psi on well head. (whp 1000 to 650 psi while SI.) Drtg. from 10700' to 11261 ', Avg. ROP about 50 FPH., 1.5 bpm at 3200 psi. LD bha # 10 and pu bha # 11 ,drill from 11275' to 11538',average ROP 35-45 FPH. Drlg. from 11538' to 11652',POH to c/o motor(Bearings worn),replace washed out bleed sub. PU BHA #12 w/.75 dg. motor,RIH,drlg from 11650' to 11660'. Change out mud system, short trip to window 2x to clean hole and increase ROp. Drill from 11669' to 12020'. Drlg. from 12020' to 12410', hard time getting mwd to work properly,charge up pulsation dampner on rig pump. Better data from mwd. Drill f/1241.0' to 12578' (TD). ~ Prep hole for liner. Displace well to 12.5 ppg mud. POOH for liner. Run 2-3/8" liner, work pipe f/11950'-12340', Pull liner back OOH, after finding problem with coil, LD 4 Jts of Liner assy, PU 30 Jts 1-1/4" CS Hydril to keep bad spot in coil covered on the Reel. MU 1-1/4" CSH. RIH and release from liner. POOH. RIH. Displace well to sea water & diesel. RDMO CT unit. RDMO Nabors 3S. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Alter casing _ Change approved program 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 269' FNL, 94' FEL, Sec. 11, T10N, R8E, UM At top of productive interval 1240' FNU 809' FWL, Sec. 14, T10N, R8E, UM At effective depth At total depth 1519' FNL, 581' FWL, Sec. 14, T10N, R8E, UM Suspend _ Repair well _ Plugging __ Pull tubing 5. Type of Well: Development Exploratory _ Stratigraphic _ Service Operation Shutdown __ Re-enter suspended well _ Time extension_ Stimulate_ Variance Perforate Other Datum elevation (DF or KB) 154' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-21 9. Permit number 90-4 10. APl number 50-103-20123 11. Field/Pool Kuparuk River 12. Present well condition summary Total Depth: measured true vertical 10800 feet 6502 feet Plugs (measured) None feet Effective depth: measured true vertical 10670 feet Junk (measured) None 6428 feet Casing Length Structural Conductor 80' Surface 3884' Intermediate Production 10725' Liner Size Cemented 16" 170 sx AS II 9.625" 850 sx AS III & 400 sx Class G 7" 400 sx Class G Measured depth 115' 3919' 10756' Trueverticaldepth 115' 2923' 6477' Perforation depth: measured 10120'-10122', 10368'-10378', 10432'-10452', 10486'-10526' true vertical 6138'-6139', 6266'-6271 ', 6299'-6309', 6327'-6349' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 10240' Packers and SSSV (type and measured depth) Baker 'HB' Pkr @ 10001' & 10189' MD, Camco TRDP-1A-ENC SSSV @ 1810' MD 13. Attachments Description summary of proposal X Detailed operation program __ BOP sketch 14. Estimated date for commencing operation September 1998 Oil X Gas_ 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certi fvth at the foT/~s tru e~rrect to the best of my knowledge. Signed '~ ~,,"~~/",/~/',~,~,¢~ Title Area Drilling Engineer Date ~ ' ' ' ~ FOR COMMISSION USE ONLY I Conditions of approval: Notify Commission so Teprese.ntative may witness BOP Test ,,'"' Locabon clearance Plug integrity_v'/ _ ' . __ Mechanical Integrity Test_ Subsequent form require 10- Approved by the order of the Commission n~vid W. Johnston Form 10-403 Rev 06/15/88 15. Status of well classification as: Suspended _ IAppEovaLNo. _ ,-.O Commissioner Date ~b.t-'~ I~/' SUBMIT IN TRIPLICATE Gas Cons. A~chora9e Kuparuk 2K-21 Intended P&A Procedure Objective: P&A existing interval in preparation for CT sidetracking operations. Intended Procedure · RU SL. Tag bottom. ° RU coiled tubing unit, load and kill well. Pump 20 bbls Class 'G', 17 ppg cement. · Clean cement top to -10390' md (KOP for CTU drilling at 10423') ° WOC, Tag top of cement. July 27, 1998 C T Drilling Wellhead Detail- Methanol Injection Quick Connect ~ CT Injector Head Stuffing Box (Pack-Off), 10,000 psi Working Pressure ----- 7" Riser Annular BOP (Hydril),7-1/16" ID 5000 psi WP Alignment Guide Flange 7-1/16", 5M Ram Type Dual Gate BOPE ~ Flanged Fire Resistant Man Kelly Hose to Dual HCR Choke Manifold Cutters or Combination Cutter/Blinds Slip/Pipe Rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Manual over Hydraulic Ram Type Dual Gate BOPE 7-1/16" ID with Pipe/Slip Rams Manual Master Valve 0.458' (5.5") 2" Pump-In Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold Hanger 9-5/8" Annulus 13-3/8" Annulus STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1, Operations Performed: Operation Shutdown__ Stimulate X 2. Name of Operator Pull tubing Alter casi'i"5."" Type of W';I~I~air~'''' well I Development X ARCO Alaska, Inc. I Exploratory __ 3. Address I Stratigraphic __ P. O. Box 100360, Anchorage, AK 99510 I Service ~ Plugging ~ Perforate Other 6. Datum elevation (DF or KB) RKB 154 7. unit or Property name Kuparuk River Unit feet 4. Location of well at surface 269' FNL, 94' FEL, SEC 11,T10N, R8E, UM At top of productive interval 1240' FNL, 809' FWL, SEC 14, T10N, R8E, UM At effective depth 1437' FNL, 650' FWL, SEC 14, T10N, R8E, UM At total depth 1519' FNL, 581' FWL, SEC 14, T10N, R8E, UM 12. Present well condition summary Total Depth: measured feet feet 10800 true vertical 6 5 0 2 measured I 0 6 7 0 true vertical 6 4 2 8 8. Well number 2K-21 9. Permit number 90-4 10. APl number 50-1 03-201 23-00 11. Field/Pool Kuparuk River Field/Oil Pool Effective depth: feet feet Plugs (measured) None Junk (measured) None ORIGINAL Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' 1 6" 170 Sx AS II 1 1 5' 1 1 5' Surface 3884' 9-5/8" 850 Sx AS III & 391 9' 2923' Intermediate 400 Sx Class G Production I 07 25' 7" 400 Sx Class G 1 07 5 6' 6 4 7 7' 13. @ the perfs. 14. Liner .,~ Perforation depth: measured 10120'-10122', 10368'-10378', 10432'-10452', 10486'-10526' true vertical 6138'-6139', 6266'- 6271', 6299'-6309', 6327'-6349 Tubing (size, grade, and measured depth) ,, - I ' ~" ~, ~.'. 35, 93# J 55 @ 10240 P;ckers ;nd ~SSV (type and measured depth) Packers: Brown HB's @ 10001' & 10189'; SSSV: Camco TRDP-1A-ENC @ 1812' (Locked Out~'z¢~...."o~.. ;Y..~ Stimulation or cement squeeze summary "'~'.~2~... °.~, FRAC "al' Sand 7~7~97 ~'~" '~/,/~,:~ Intervals treated (measured) 1 0368'-1 0378', 1 0432'-1 0452' Treatment description including volumes used and final pressure "A" Sands REFRAC complete, screened out to surface, injected 208000# of Prop in the formation w/10# PPA Maximum pressure 7800 psi and F.G. @ (.88) Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1 2 3 8 7 2 1790 260 Subsequent to operation 3 0 9 88 5 1800 253 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas __ Suspended ~ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ,.,,.~ ~ ]3'/~-'J"l/'/d Form 1 /88 Title Wells Superintendent Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT ,4, WELL SERVICE REPORT ~ K1(2K-21(W4-6)) WELL JOB SCOPE JOB NUMBER 2K-21 FRAC, FRAC SUPPORT 0630970537.4 DATE DAILY WORK UNIT NUMBER 07/07/97 "A" SAND REFRAC DAY OPERATION COMPLETE ] SUCCESSFUL KEY PERSON SUPERVISOR 2 (~ Yes O NoI (~ Yes (~ No DS-YOAKUM CHANEY FIELD AFC# CC~ DALLY COST ACCUM COST Si.ened' ESTIMATE KD 1280 230 D S28KL $146,508 $157,782 , Initial Tb.q Press Final Tb(:l Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Anrr 1500 PSI 2000 PSI 560 PSI 500 PSII 400 PSII .350 PSI DAILY SUMMARY "A" SAND REFRAC COMPLETE. SCREENED OUT TO SURFACE. INJECTED 208000 LBS OF PROP IN THE FORMATION W/10# PPA @ I I THE PERF'S. MAXIMUM PRESSURE 7800 PSI AND F.G. @ (.88). TIME 06:30 08:00 08:15 09:15 10:25 13:15 14:00 15:00 LOG ENTRY MIRU DOWELL FRAC UNIT, HOT OIL TRUCK, & APC VAC TRUCK. HELD SAFETY MEETING (15 ON LOCATION) PT'D BACKSIDE LINES TO 4000 PSI AND RAISED INNER CSG AS REQUIRED. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 10700 PSI. PUMP BREAKDOWN W/50# DELAYED XL GW @ 30 TO 15 BPM. VOLUME PUMPED 553 BBLS. USED 9949 LBS OF #20/40 PROP. MAXIMUM PRESSURE 7900 PSI AND ENDING PRESSURE 4500 PSI. S/D AND OBTAINED ISIP OF 2755 PSI W/F.G. OF (.88). MONITORED WHTP AND PULSED FOR CLOSURE. PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. VOLUME PUMPED 291 BBLS. MAXIMUM PRESSURE 6000 PSI AND ENDING PSI 5100 PSI. S/AND OBTAINED ISIP OF 3117 PSI W/F.G. OF (.94). STOOD-BY AND MONITORED WHTP FOR CLOSURE. PUMP FRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. SCREENED OUT TO SURFACE. MAXIMUM AND ENDING PRESSURE 7600 PSI. VOLUME PUMPED 2158 BBLS. PUMPED 235712 LBS OF PROP ( 25000 LBS OF #20/40 & 210712 LBS OF #12/18). INJECTED 208000 LBS IN THE FORMATION W/10# PPA @ THE PERF'S. LEFT 27712 LBS OF PROP IN THE WELLBORE. STARTED R/D. DEPRESSURED THE INNER CSG TO 500 PSI AND R/D THE HOT OIL TRK. REMOVED TREESAVER(ALL CUPS RETURNED). CONTINUED R/D. R/D COMPLETED AND DOWELL LEAVING LOCATION. WELL SECURED AND NOTIFIED DSO OF STATUS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $714.00 APC $7,800.00 $7,800.00 DIESEL $250.00 $250.00 DOWELL $136,258.00 $136,258.00 HALLIBURTON $0.00 $5,500.00 LITTLE RED $2,200.00 $7,260.00 TOTAL FIELD ESTIMATE $146,508.00 $157,782.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate Plugging Perforate X Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service -- 4. Location of well at surface 269' FNL, 94' FEL, SEC 11,T10N, RSE, UM At top of productive interval 1240' FNL, 809' FWL, SEC 14, T10N, R8E, UM At effective depth 1437' FNL, 650' FWL, SEC 14, T10N, R8E, UM At total depth 1519' FNL, 581' FWL, SEC 14, T10N, R8E, UM 12. Present well condition summary Total Depth: measured 1 0 8 0 0 true vertical 6 5 0 2 Effective depth: measured I 0 6 7 0 true vertical 6 4 2 8 Casing Length Size Structural Conductor 8 0' I 6" Surface 3884' 9-5/8" Intermediate Production 1 0 7 2 5' 7" Liner Perforation depth: 6. Datum elevation (DF or KB) RKB 154 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-21 9. Permit number 90-4 10. APl number 50-1 03-201 23-00 11. Field/Pool Kuparuk River Field/Oil Pool feet feet feet feet feet Plugs (measured) None Junk (measured) None Cemented Measured depth True vertical depth 170 SxAS II 115' 115' 850 SxAS III & 391 9' 2923' 400 Sx Class G 400 Sx Class G 1 0756' 6477' measured 10120'-10122', 10368'-10378', 10432'-10452', 10486'-10526' true vertical 6138'-6139', 6266'- 6271', 6299'-6309', Tubing (size, grade, and measured depth) U I Ul I I/" L 3.5", 9.3#. J-55 @ 10240' Packers and SSSV (type and measured depth) Packers: Brown HB's @ 10001' & 10189'; SSSV: Camco TRDP-1A-ENC @ 1812' (L~e~(~)V 13. stimulation or cement squeeze summary Perforate 'C' sand on 5/22/97. Intervals treated (measured) 1 0368'-1 0378', 1 0432'-1 0452' Treatment description including volumes used and final pressure ,.,.~aSk~ 0ii & ~-as C01'~s. C0l't'll'l~iSSi0ft Perforated using 2.5" HSD guns w/ DP charges, 6 SPF, 60° phasing, fp = l ouu ps~. 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1 2 3 8 7 2 1790 260 Subsequent to operation 3 0 9 88 5 1800 253 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service__ 17. I hereby,~rtify that the foregoing is true and correct to the best of my knowledge. Signed ./,~ Title Wells Superintendent Form 10,~(~4-/R~v/0'6f-'1'5¢~r~- "'- / SUBMIT IN DUPLICATE ~ A'RCO Alaska, Inc. KUPARUK RIVER UNIT ,~' WELL SERVICE REPORT '~ K1(2K-21(W4-6)) WELL JOB SCOPE JOB NUMBER 2K-21 PERFORATE, PERF SUPPORT 0407970801.6 DA~-E DAILY WORK UNIT NUMBER 05/22/97 PERFORATE F/10,368-10,378' ELM & 10,432-10,452' ELM UNIT #1 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 3 (~) Yes O NoI (~) Yes (~ No SWS-WALSH B,J.,ACK ESTIMATE KAWWRK 230DS28KL $10,446 $22,621',A,~. c-~ "~~ Initial Tb.q Press Final Tb.q Press Initial Inner Ann Final Inner Ann I Initial Outer AnnV ] Final Outer Ann 1700 PSI 1800 PSI 1 750 PSI 1750 PSIJ 450 PSI] 450 PSI DALLY SUMMARY I PERFORATED F/10,368-10,378' ELM & 10,432-10,452' ELM W/SWS 2.5" HSD DP'S @ 6SPF & 60 DEG PHASED. J TIME LOG ENTRY 13:00 13:30 RU SWS (WALSH & CREW) MU GA#1 (10'-2:5" HSD/WT/GR/CCL) TL-21'. TGSM & PT BOPE 3000. RIH TO 10,520' ELM. TIE IN TO 1/16/90 SPERRY EWR/DGR. PERFORATE F/10,368 - 10,378' ELM W/2.5" HSD DP'S @ 6 SPF & 60 DEG PHASED. SAW SURFACE INDICATIONS. POOH W/GA#1. 16:30 AT SURFACE. ALL SHOTS FIRED. MU GA#2 (20'-2.5" HSD/WT/CCL) TL-26'. PT & RIH TO 10,520' ELM. TIE INTO SPERRY LOG & 5/5/90 HES PET LOG. PERFORATE F/10,432-10,452' ELM W/SAME GUNS AS ABOVE. SAW SURFACE INDICATIONS. POOH W/GA#2. 19:30 AT SURFACE. ALL SHOTS FIRED. RD SWS. 20:30 TURN OVER TO PRODUCTION TO BRING ON LINE. OFF LOCATION. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $o.oo $40.00 APC $250.00 $3,050.00 ARCO $0.00 $600.00 DOWELL $0.00 $4,500.00 HALLIBURTON $0.00 $1,270.00 LI~-FLE RED $0.00 $2,965.00 SCHLUMBERGER $10,196.00 $10,196.00 TOTAL FIELD ESTIMATE $10,446.00 $22,621.00 ARCO Alaska, Inc. Date: April 28, 1995 TRANSMITTAL #9231 RETURN TO: ARCO Alaska, Inc. Attn: Brian Hebert Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following pressure items. receipt and return one signed copy of this transmittal. 2U-12 Fluid Level Report ~K-21 · Fluid Leve~/~port / Receipt Acknowleged: /Y./c4,,-,~cL. Please acknowledge 4/1 1/95 Casing 4/1 6/95 Casing 7" Date' DISTRIBUTION: Petrotechnical Data Center BP Exploration (Alaska) Inc. MB 3-3 P.O. Box 196612 Anchorage, AK 99519-6612 Barbara Sullivan Mobil ,,.,,, Corporation 12450 Greenspoint Drive #700 Houston, TX 77060 Debra Childers UNOCAL P.O. Box 196247 Anchorage, AK 99519-6247 Holly Fuller c/o Chevron U.S.A., Inc P.O. Box 1635, Rm 1817 Houston, TX 77251 Mr. Vernon E. Pringle, Jr. DeGIoyer and MacNaughton One Energy Square Dallas, TX 75206 Larry Grant AOGCC 3001 Porcupine Drive Anchorage, AK 99501 RECEIVED MAY - 2. 1995 Oil & Gas Cons. Commission Anchorage CC: DS Engr. OP Engrg. Files Prod. Foreman sssv 1%1) GLM DV or ~ P'~"- G L V )35 c/S?g Cl~, ~ · Fluid Level Found @ ~'5~,J~ Et KUPARUK FLUID LEVEL REPORT Well 2/-./'/3 Fluid Level Shot Down: ~'"/Casi ng Tubing CSG Press During Shot -- 1,.~O"O # TBG Press During Shot-- # Reason For Shooting FL: ~,i' To Determine Operating Valve Well Status: v//~-' On Continuous GL I/2,g77 Operating CSG Press= 13'20 # GL Rate (If Available)= ~'Z(2 MCFD On Intermittent GL On Time--~ Min. Off Time -- Hr. Min. Delta Time From End Of On Cycle = .... No GL Comments: Min. ORIGlaAL'" , ~ ~- STATE OF ALASKA : . ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ,, I Status of Well Classification of Service Well OIL [-~ GAS E~ SUSPENDED r~] ABANDONED [-"] SERVICE [--~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-4 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360._~..____ - 50-1,03-20123 4 Location of well at surface :~ -:;~i'?.~':'~::*-~'~ 9 Unit or Lease Name 269' FNL, 94' FEL, SEC 11, T10N, R8E UM ~'WiTM I''I KUPARUK RIVER , ,, At Top Producing Interval ~ ~~'~ ~~f:|r''~D i;'10 Well Number 1240' FNL, 809' FWL, SEC 14, T10N, RSE UM Depth J ~'~['~ '~ I 2K-21 . At Total ,~~~,--.~.~,..~[~.__-- _~ 11 Field and Pool 1519' FNL.~ 581' FWL, SEC 14, TION, R8E UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 154'I ADL: 25605 ALK: 2679 , 12 Date Spudded1/6/90. 13 Dete T.D. Reached1/15/90. 14 Date Comp., Susp. or Aband.7/3/90.. J 15 Water Deplh. if offshOreNA feet MSL 116 No. of Completions1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 6502' TVD 10670' MD & 6428' 'I'VD YES [~ NO ~ 1812' feet MD 1 MD & 1 40O' APPROX 22 Type Electric or Other Logs Run DIL/SFL/GR/SP/FDC/CNL/CAL/CBL/GYRO 23 cASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 1170 SX AS II 9 5/8" 364t J-55 SURF 3919' 12-1/4" 850 SX AS 111,..400 SX CLASS G 7" 26# J-55 SURF 10756' 8-1/2" 400 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). 3ACKER SET (MD) .. 3-1/2" 19.3# J-55 10288' 10238' 10482' - 10522' W/4-1/2" @ 4 SPF MD 6325' - 6346' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED SEE ATTACHED ADDENDUM , , 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BB'L CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD , , , Flow Tubing Casing Pressure CALCULATED OIL~BBL GAS-MCF WATER-BBL OIL GRAVITY~API (coif) Press. 24-HOUR RATE 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Alaska 0il & Gas Cons. c0mmissi0.n Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS ,, NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP '10368' 6265' NA KUPARUK C BOTTOM !10384' 6274' KUPARUK A TOP 10410' 6287' KUPARUK A BOTTOM 110645' 6414' 31. LIST OF ATTACHMENTS GYRO, Frac addendum, Da!l¥ Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 1/08/91 2K-21 Frac KRU "A" sand perfs from 10,486'- 10,526' @4spf in 7 stages as follows: Stage 1. Pmp 335 bbls GW; Pre Pad @ 25 bpm 6026-5492psi Stage 2 Pmp 95.5bbls Slick Diesel Flush @ 25-20 bpm 5492-6380-6096 psi ISIP: 2791 Frac Grad: .80 Perf Fric: 895 Stage 3 Pmp 2500 bbls YF240D, GW Pad@ 25 bpm 6100-5126 psi Stage 4 Pmp 160 bbls YF240D.GW w/2# 16/20 CL@ 25 bpm 5126-5277 psi Stage 5 Pmp 180 bbls YF240D G/W w/4# 16/20 CL @ 25 bpm 5277-5489 psi Stage 6 Pmp 200 bbls YF240D G/W w/6# 16/20 CL@ 25 bpm 5489-5886 psi Stage 7 Pmp 168 bbls YF240D G/W w/8 # 16/20 CL@ 25-20 bpm 5886-5693-682 Cut rate f/25-20 bpm not to exceed maximum tbg pressure of 6500 psi. Screen out 168 bbls. into the 8th stage. (7.4 ppg @perfs) Average Press: 5400 psi Fluid to recover: 3680bbls H20 + 80bbls Diesel Sand in zone: 94,014# 16/20 C.L. Sand in casing: 24,121# 16/20 C.L. Date RECEIVED Alaska Oil & Gas Cons. Commission Anchorage ARCO Oil and Gas Company,~, Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after, a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ICounty. parish or borough ARCO ALASKA INC. I NORTH SLOPE ILease or Unit FieldKUPARUK I ADL: 25605 I Auth. or W.O. no. ITM AK4371 I COMPLETIONS IState ALK: 2679 AK Well no. KR~ 2K-21 Operator ARCO Spudded or W.O. begun l iARCO 55,8533 IHour Prior status il a W,O, 00:00 SPUD Date and depth as of 8:00 a.m. 05/04/90 (13) TD:10800 PB:10670 SUPV:GB 05/05/90 (14) TD:10800 PB:10670 SUPV:GB 05/06/90 (15) TD:10800 PB:10670 SUPV:GB 05/07/90 (16) TD:10800 PB:10670 SUPV:GB The above ,~orrect Signatu~ ~ For form preparatiq/f ~n~ distribution, see Procedures M~n94al, Section 10, Drilling, Pages 86 a'~d 87. IDate 01/06/90 Complete record for each day reported NORDIC DRILLING OUT CEMENT 7"@10755' MW:10.1 NaCl MOVE RIG F/2K-19 TO 2K-21, ACCEPT RIG @ 1800 ON 5/3/90. ND LOWER XMAS TREE, NU BOPE, DIG OUT FOR MOUSE HOLE. TEST BOPE, ALL MUD LINES, VALVES, CHOKE, RAMS, LOWER KC, ANNULUS, CHECK PRESSURE ON ACCUM. SYSTEM. SET BOWL PROTECTOR, RU TO RUN DP, MU 6 1/8" BIT, B.S., DC & TIH W/ 3 1/2" DP, TAG CEMENT @ 9870' PU KELLY & TEST UPPER KELLY COCK TO 3000 PSI, DRILLING CEMENT. DAILY:S30,605 CUM:$1,228,053 ETD:$1,228,053 EFC:$1,487,000 PREP TO RIH W/7" CSG SCRAPER 7"@10755' MW:10.1 NaCl DRILL CMT TO 10353'. PU SINGLES & RIH TO 10610'. TAG CMT @ 10610'. DRILL CMT TO 10660', ON PLUG @ 10660', CIRC HOLE CLEAN, MIX HEC PILL, BLOW DOWN KELLY & LINES & SET KELLY BACK. REVERSE CIRC HEC PILL TO CLEAN CUTTINGS & RUBBER DEBRIS FROM HOLE. POOH W/BIT #1, PREP TO PU 7" CSG SCRAPER. DAILY:S29,435 CUM:$1,257,488 ETD:S1,257,488 EFC:$1,487,000 MU GYRODATA ON HLS WIRLELINE 7"@10755' MW:10.1 NaCl TIH W/ 7" CSG SCRAPPER TO 10660', REVERSE CIRC, PUMP 100 BBL H20 SPACER FOLLOWED BY 10.0 PPG CLF. AN BRINE, FILTER DIRTY BRINE RETURNS W/ MI UNIT, POOH RD FLOW NIPPLE AND FLOW LINE. PU HLS WIRELINE, MU PET & TEST LUBE, RIH W/ PET & LOG F/ PBTD TO 8792', POOH W/PET TOOL, LD PET TOOL & MU GYRODATA GYRO o DAILY:S52,620 CUM:$1,310,108 ETD:S1,310,108 EFC:$1,487,000 TIH W/ 7" CSG SCRAPPER 7"@10755' MW:10.1 NaCl RIH W/ GYRO ON HLS WIRELINE & GYRO FROM 10660 TO SURFACE, RD GYRO, MU HLS PERF GUN & RIH TO 10660', PULL UP TO 10270' & STICK GUN, UNABLE TO WORK GUN FREE, PULL 4250# ON LINE & PRES CSG TO 1700 PSI & PERF GUN ~ FREE. POOH W/ GUN#l, MU GR/JB & RIH TO 10287', UNABLE TO GO DEEPER, RECOVER RED RUBBER & CEMENT FROM JB, RD HLS & RU FLOW NIPPLE & FLOW LINE, SLIP & CUT DRILL LINE, MU BIT, 7" CSG SCRAPER, DC'S & TIH. DAILY:S67,095 CUM:$1,377,203 ETD:S1,377,203 EFC:$ RECEIVED AJaska OiJ & Gas Cons. Cor,qmjssio[l Anchorage IDete/ / AR3B-459-1-D Number ell dally well history forms consecutively no. as they are prepared for each well. Page ARCO Oil ana Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of ail cores. Work performed by Producing Section will be reported on "lnlerim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or {2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District County or Parish ~,Rco A~s~ ~NC. I NORT. SLOPE Field ILease or Unit KUPARUK I KRU 2K-21 Date and depth Complete record for each day while drilling or workover in progress as of e:0o a.m. NORDIC #1 05/08/90 ( 17 TD:10800 PB:10670 SUPV:GB IState AK RE RUN PERF GUN #2 7"@10755' MW:10.0 NaCl CONT. RIH, WORK BIT/SCRAPER 10,200-10,350, CONT. RIH TO 10660, CIRC, POH, RU HLS E-LINE, RIH W/6.125" GR/JB, STOPPED AT 10307, POH, RIH W/ 5.92 GR/JB, STOPPED AT 10605, POH, RIH W/ PERF GUN #1, PERF 10502-10522, POH, ASF, RIH W/GUN #2, CCL NOT WORKING, POH, REPAIR CCL, RIH W/ GUN #2, DAILY:S30,012 CUM:$1,407,215 ETD:S1,407,215 EFC:$1,487,000 R'ECEIVED Anchorage JWell no. The above is correct Drilling, Pages 86 and 87 AR3B-459-2-B Number all daily well history forms consecutively las hey are prepared for each well. ARCO O,~ and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or 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 availabie. District ICounty or Parish ARCO ALASKA INC. I NORTH SLOPE Field Lease or Unit ~UPARUK ADL: 25605 Auth. or W.O. no. ITit[e AK4371 I COMPLETIONS ALK: 2679 iAccounting cost center code State IWell no. Kgu 2I<-21 Operator ARCO Spudded or W.O. begun Date and depth as of 8:00 a.m. 05109/90 (18) TD:10800 PB:10670 SUPV:GB A.R.Co. W.I. tDate 55.8533 I 01/06/90 Complete record for each day reported NORDIC ~1 RIG RELEASED 7"@10755' MW:10.0 NaC1 CONT. RIH W/PERF GUN #2, PERF 10482-10502, POH, ASF, RD HLS E-LINE, RU & RIH W/ 3-1/2" SINGLE COMPLETION ASSEMBLY, MU CONTROL LINE AND TEST, CONT. RIH, MU TBG HGR AND CONTROL LINE, TEST CONTROL LINE, LAND TBG, RILDS, DROP BALL, PRESS TBG TO 2500 PSI TO SET PKR, BLEED PRESS, BOLDS, PU & SHEAR PBR, RELAND TBG, RILDS, TEST SSSV, SET BPV, ND BOPE, NU TREE AND TEST TO 5000 PSI, TEST ANNULUS TO 2500 PSI, PRESS TBG TO 4300 PSI AND SHEAR BALL, BLEED PRESS, DISPLACE ANN-JLUS W/ 6 BBLS DIESEL, BULLHEAD 2 BBLS DIESEL DOWN TBG, RELEASE RIG AT 0100 5/9/90 DAILY:S212,593 CUM:$1,619,808 ETD:S1,619,808 EFC:$1,487,000 I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our ] Prior status if a W.O. I 00:00 Old TD PB Depth Released rig Kind of rig Classifications (oil, gas, etc.) INew TD Date Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval loll or gas Test time Production Oil on test Gas per day Pump Size, SPM X length Choke size T.P. C.P. I Water % GOR Gravity Allowable Effective da,e corrected The above is cor~ct Date Drilling, Pages 86 and 87. AR3B-459-3-C INumber all dally well history forms consecutively aa they are prepared for each well. iao DIvI-Jon of AtlanllcR~hlletdComwy ORIGINAL Gyrodata Incorporated PO. Box 79389 Houston, Texas 77224 713/461-3146 May I1, 1990 Mr, 5ames Drilling ARCO Alas P.O. Box Anchorage Blatack Engineer , Alaska Huparuk River. Unit 2K-21 (!1-10-8) North Slope Alaska Dear Mr. Blalack: Enclosed please find one (t) original and nine the completed survey of Well KRU 2K-21. Ue would like to thank you for using Gyrodata's we look forward to serving you in the future. (9) copies of services and ~incere ! y, A 1 t<udr 1 e Representative ICROFILMED Gyrodata Services, Inc. Houston, TX / Lafayette, LA / New Orleans, LA, Ventura, CA,' Aberdeen, U.K. /Calgary. Alberta GREAT LAND DIRECTIONAL DRILLING, INC. o5/11/9o' Client .... : ARCO ALASKA, INC. Field ..... : Kuparuk River Unit Well ...... : 2K-21 (11-10-8) Section at: $,34,25,W Mag Dcln..: 0,0 E Computation...: RADIUS OF CURVATURE Survey Date...: 05'/09/90 RKB Elevation.: 154.00 ft Case ID ....... : KRU2K21 RECORD OF SURVEY MEAS INCLN DEPTH DEG MN 7 100 0 10 7 200 0 17 7 300 0 21 7 400 0 25 7 500 0 20 VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE DEG MIN FROM-WELL-HEAD 100.0 -54.0 -0.0 S 57 3 E 0.0 S 0.1 E 200.0 46.0 -0.2 S 87 11 E 0.2 S 0.5 E 300.0 146.0 -0.3 S 64 56 E 0.3 S 1.0 E 400.0 246.0 -0.4 S 46 48 E 0.7 S 1.6 E 500.0 346.0 -0.1 S 21 13 E 1.2 S 2.0 E CLOSURE DISTNCE DEG MIN /lOC O. 1 S 73 32 E 0.16 0.5 S 72 29 E 0.13 1.1 $ 74 19 E 0.06 1.7 S 67 i7 'E 0.07 2.3 $ 58 i7 E 0.08 7 600 1 52 7 700 4 50 7 800 8 29 7 900 10 14 7 1000 12 8 600.0 446.0 1 .'4 S i9 i0 W 3.1 S 2.0 E 699.8 545.8 7.2 S 46 13 W 8.0 S i.i W 799. i 645. i i8.6 s 43 16 w 16.2 $ 9.3 w 897.8 743.8 34.7 S 40 29 W 28.3 $ 20.1 W 995.9 841.9 54.1 S 37 11 W 43.4 S 32.3 W 3.7 S 32 50 E i.52 8.0 S 8 3 W 2.98 18.7 S 29 50 W 3.66 34.7 S 35 26 W 1.74 54.1 S 36 39 W 1.91 7 1100 14 8 7 1200 17 2 7 1300 19 50 7 1400 24 51 7 1500 29 58 i093.2 939.2 76.8 $ 35 il W 6i.7 S 45.7 i189.6 i035.6 i03.6 S 31 28 W 84.2 $ 60.5 i284.4 1130.4 135.2 S 30 9 W lii.3 S 76.7 1376.9 1222.9 173.1 $ 3i 22 W 144.0 S 96.1 1465.6 i3ii.6 219.i S 32 44 W 183.0 S 120.5 76.8 S 36 31 W 2.01 103.7 S 35 41 W 2.91 135.2 S 34 33 W 2.80 173.1 S 33 43 W 5.02 219.1 S 33 22 W 5.12 7 1600 30 41 7 1700 36 43 7 1800 40 52 7 1900 45 23 7 2000 47 6 i551.9 1397.9 269.5 S 34 41 W 225.0 S 148.5 W i635.1 1481.1 325.0 S 34 39 W 270.6 S 180.1 W 1713.0 1559.0 387.6 S 35 52 W 321.8 S 216.2 W 1786.0 1632.0 456.0 S 35 54 W 377.1 S 256.3 W 1855.1 170i.1 528.1 S 38 12 W 434.8 S 299.8 W 269.6 S 33 26 W 0.88 325.0 $ 33 38 W 6.04 387.6 S 33 54 W 4.18 456.0 S 34 12 W 4.52 528.1 S 34 35 W 2.11 7 2100 52 19 7 2200 57 42 7 2300 58 13 1919.8 1765.8 604.2 S 37 13 W 495.1 S 346.4 W 1977.1 1823.1 686.0 $ 36 45 W 560.5 S 395.7 W 2030.2 1876.2 770.7 S 36 31 W 628.5 S 446.3 W 604.3 S 34 59 W 5.25 686.1 S 35 13 W 5.40 770.8 S 35 22 W 0.54 'Survey Codes: 7/GYRO 2K-21 (11-10-8) S MEAS INCLN C DEPTH DEG MN 7 2400 57 31 7 2500 57 50 7 2600 56 11 7 2700 55 33 7 2800 55 6 7 2900 55 57 7 3000 55 43 7 3100 55 31 7 3200 55 17 7 3300 55 32 7 3400 56 36 7 3500 56 45 7 3600 56 24 7 3700 57 12 7 3800 58 38 7 3900 58 17 7 4000 58 27 7 4100 58 28 7 4200 58 2 7 4300 57 42 7 4400 57 4 7 4500 57 5 7 4600 56 58 7 4700 56 43 7 4800 56 49 7 4900 57 44 7 5000 59 42 7 5100 59 59 RECORD OF SURVEY VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE DEG MIN FROM-WELL-HEAD 2083.4 1929.4 855.3 S 38 33 W 695.7 S 497.8 W 2136.8 1982.8 939.7 S 36 0 W 762.9 S 549.0 W 2191.3 2037.3 1023.5 S 37 41 W 830.0 S 599.3 W 2247.4 2093.4 1106.2 S 36 21 W 896.1 S 649.1 W 2304.3 2150.3 1188.3 S 36 47 W 962.2 S 698.1 W 2360.9 2206.9 1270.7 S 36 47 W 1028.2 S 747.5 W 2417.0 2263.0 1353.4 S 37 11 W 1094.3 S 797.3 W 2473.5 2319.5 1435.8 S 37 20 W 1160.0 S 847.2 W 2530.3 2376.3 1518.0 S 37 44 W 1225.2 S 897.4 W 2587.1 2433.1 1600.2 S 37 58 W 1290.3 S 947.9 W 2642.9 2488.9 1683.0 S 38 3 W 1355.6 S 999.0 W 2697.8 2543.8 1766.4 S 37 38 W 1421.6 S 1050.3 W 2752.9 2598.9 1849.7 S 37 36 W 1487.7 S 1101.2 W 2807.7 2653.7 1933.3 S 35 45 W 1554.8 S 1151.2 W 2860.8 2706.8 2018.0 S 35 39 W 1623.6 S 1200.6 W 2913.1 2759.1 2103.2 S 35 54 W 1692.8 S 1250.5 W 2965.5 2811.5 2188.3 S 35 27 W 1761.9 S 1300.1 W 3017.8 2863.8 2273.6 S 34 41W 1831.7 S 1349.1 W 3070.5 2916.5 2358.6 S 33 40 W 1902.1 S 1396.8 W 3123.6 2969.6 2443.3 S 32 37 W 1973.0 S 1443.1 W 3177.6 3023.6 2527.4 S 31 47 W 2044.2 S 1488.0 W 3231.9 3077.9 2611.2 S 31 9 W 2115.8 S 1531.8 W 3286.4 3132.4 2695.0 S 30 39 W 2187.8 S 1574.9 W 3341.0 3187.0 2778.6 S 33 32 W 2258.7 S 1619.4 W 3395.9 3241.9 2862.2 S 33 31W 2328.5 S 1665.6 W 3449.9 3295.9 2946.4 S 34 37 W 2398.1 S 1712.7 W 3501.9 3347.9 3031.8 S 37 16 W 2467.3 S 1762.8 W 3552.1 3398.1 3118.2 S 36 46 W 2536.4 S 1814.9 W Page 2 05/11/90 CLOSURE DL DISTNCE DEG MIN /100 855.5 S 35 35 W 1.61 939.9 S 35 44 W 1.86 1023.8 S 35 50 W 2.02 1106.5 S 35 55 W 1.11 1188.8 S 35 58 W 0,54 1271.2 S 36 1 W 0.85 1353.9 S 36 5 W 0.35 1436.4 S 36 9 W 0.24 1518.7 S 36 13 W 0.35 1601.0 S 36 18 W 0.29 1684.0 S 36 23 W 1.06 1767.5 S 36 27 W 0.32 1850.9 S 36 31 W 0.35 1934.6 S 36 31 W 1.53 2019.3 S 36 29 W 1.43 2104.6 S 36 27 W 0.39 2189.7 S 36 25 W 0.36 2274.9 S 36 22 W 0.56 2359.9 S 36 18 W 0.86 2444.4 S 36 11 W 0.81 2528.5 S 36 3 W 0.87 2612.1 S 35 54 W 0.44 2695.7 S 35 45 W 0.37 2779.2 S 35 38 W 2.03 2862.8 S 35 35 W 0.09 2946.9 S 35 32 W 1.21 3032.4 S 35 33 W 2.78 3118.8 S 35 35 W 0.46 'Survey Codes: 7/GYRO 2K-21 (.11-10-8) RECORD OF SURVEY MEAS INCLN DEPTH DEG MN 7 5200 60 16 7 5300 60 31 7 5400 60 32 7 5500 59 43 7 5600 59 28 VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE DEG MIN FROM-WELL-HEAD 3601.9 3447.9 3204.8 S 36 35 W 2605.9 S 1866.7 W 3651.3 3497.3 3291.7 S 36 23 W 2675.8 S 1918.4 W 3700.5 3546.5 3378.7 S 36 15 W 2745.9 S 1969.9 W 3750.3 3596.3 3465.4 S 35 23 W 2816.3 S 2020.7 W 3800.9 3646.9 3551.6 S 34 54 W 2886.8 S 2070.3 W 7 5700 59 2 7 5800 58 55 7 5900 59 2 7 6000 58 40 7 6100 59 42 3852.1 3698.1 3637.5 S 34 6 W 2957.6 S 2119.0 W 3903.6 3749.6 3723.2 S 33 25 W 3028.9 S 2166.6 W 3955.1 3801.1 3808.9 S 32 56 W 3100.6 S 2213.5 W 4006.9 3852.9 3894.5 S 33 58 W 3172.0 S 2260.7 W 4058.1 3904.1 3980.4 S 35 8 W 3242.7 S 2309.4 W 7 6200 59 53 7 6300 59 18 7 6400 58 52 7 6500 58 46 7 6600 58 47 4108.4 3954.4 4066.8 S 34 46 W 3313.6 S 2358.9 W 4159.0 4005.0 4153.0 S 33 56 W '3384.8 S 2407.5 W 4210.4 4056.4 4238.8 S 33 10 W 3456.3 S 2455.0 W 4262.2 4108.2 4324.3 S 32 33 W 3528.1 S 2501.4 W 4314.0 4160.0 4409.8 S 32 14 W 3600.3 S 2547.2 W 7 6700 59 13 7 6800 58 13 7 6900 56 46 7 7000 56 59 7 7100 57 4 4365.5 4211.5 4495.4 S 31 57 W 3672.9 S 2592.7 W 4417.5 4263.5 4580.8 S 32 55 W 3745.1 S 2638.6 W 4471.2 4317.2 4665.1 S 36 12 W 3814.5 S 2686.4 W 4525.9 4371.9 4748.9 S 35 47 W 3882.3 S 2735.6 W 4580.3 4426.3 4832.7 S 35 33 W 3950.4 S 2784.5 W 7 7200 57 8 7 7300 56 37 7 7400 57 2 7 7500 57 16 7 7600 57 17 4634.6 4480.6 4916.7 S 35 14 W 4018.9 S 2833.1 W 4689.2 4535.2 5000.4 S 37 35 W 4086.3 S 2882.9 W 4744.0 4590.0 5084.0 S 37 29 W 4152.7 S 2933.8 W 4798.2 4644.2 5167.9 S 37 14 W 4219.4 S 2984.8 W 4852.3 4698.3 5251.9 S 36 50 W 4286.6 S 3035.5 W 7 7700 57 35 7 7800 57 37 7 7900 58 37 4906.1 4752.1 5336.1 S 36 20 W 4354.3 S 3085.7 W 4959.7 4805.7 5420.5 S 35 50 W 4422.5 S 3135.5 W 5012.5 4858.5 5505.4 S 36 34 W 4491.0 S 3185.6 W 'Survey Codes: 7/GYRO Page 3 05/11/90. CLOSURE DL DISTNCE DEG MIN /100 3205.5 S 35 37 W 0.31 3292.4 S 35 38 W 0.30 3379.5 S 35 39 W 0.10 3466.2 S 35 40 W 1.04 3552.4 S 35 39 W 0.44 3638.4 S 35 37 W 0.73 3724.0 S 35 35 W 0,.52 3809.6 S 35 31 W 0.37 3895.2 S 35 29 W 0.84 3981.0 S 35 27 W 1.36 4067.4 S 35 27 W 0.33 4153.7 S 35 25 W 0.85 4239.4 S 35 23 W 0.72 4324.9 S 35 20 W 0.46 4410.3 S 35 17 W 0.23 4495.9 S 35 13 W 0.47 4581.2 S 35 10 W 1.21 4665.5 S 35 9 W 2.72 4749.3 S 35 10 W 0.37 4833.2 S 35 11 W 0.18 4917.1 S 35 11 W 0.23 5000.9 S 35 12 W 1.71 5084.5 S 35 14 W 0.42 5168.4 S 35 17 W 0.30 5252.5 S 35 18 W 0.28 5336.8 S 35 19 W 0.47 5421.2 S 35 20 W 0.36 5506.1 S 35 21 W 1.12 2K-21 (11-10-8) S MEAS INCLN C DEPTH DEG MN 7 8000 59 10 7 8100 59 10 7 82O0 59 2 7 8300 58 9 7 8400 57 48 VERTICAL-DEPTHS BKB SUB-SEA DISTNCE 5064.1 4910.1 5115.4 4961.4 5166.8 5012.8 5218.9 5064.9 5271.9 5117.9 7 8500 57 26 5325.5 5171.5 7 8600 57 24 5379.3 5225.3 7 8700 58 13 5432.6 5278.6 7 8800 58 38 5484.9 5330.9 7 8900 59 5 5536.6 5382.6 7 9000 59 20 5587.8 5433.8 7 9100 59 58 5638.4 5484.4 7 9200 60 27 5688.0 5534.0 7 9300 60 59 5737.0 5583.0 7 9400 61 4 5785.4 5631.4 7 9500 60 36 5834.1 5680.1 7 9600 61 18 5882.7 5728.7 7 9700 61 50 5930.3 5776.3 7 9800 60 26 5978.6 5824.6 7 9900 60 18 6028.0 5874.0 7 10000 60 5 6077.7 5923.7 7 10100 59 32 6128.0 5974.0 7 10200 58 53 6179.2 6025.2 7 10300 59 20 6230.6 6076.6 7 10400 58 47 6282.0 6128.0 RECORD OF SURVEY 7 10500 57 31 6334.7 6180.7 7 10600 56 22 6389.3 6235.3 7 10660 55 37 6422.8 6268.8 SECTION DIRECTION RELATIVE-COORDINATES DEG MIN FROM-WELL-HEAD 5590.9 S 36 34 W 5676.8 S 35 37 W 5762.6 S 35 34 W 5847.9 S 34 56 W 5932.7 S 34 50 W 4559.8 S 3236.6 W 4629.2 S 3287.2 W 4698.9 S 3337.2 W 4768.6 S 3386.4 W 4838.2 S 3434.9 W 6017.1 S 34 25 W 6101.4 S 34 16 W 6186.0 S 35 31 W 6271.2 S 36 23 W 6356.7 S 36 2 W 4907.7 S 3482.9 W 4977.2 S 3530.4 W 5046.6 S 3578.8 W 5115.6 S 3628.9 W 5184.7 S 3679.4 W 6442.6 S 35 43 W 652'8.9 S 35'47 W 6615.6 S 35 52 W 6702.8 S 35 20 W 6790.3 S 34 54 W 5254.3 S 3729.8 W 5324.3 S 3780.2 W 5394.7 S 3831.0 W 5465.6 S 3881.7 W 5537.2 S 3932.1 W 6877.6 S 32 10 W 6965.0 S 32 4 W 7052.8 S 32 4 W 7140.3 S 30 25 W 7226.9 S 30 0 W 5610.0 S 3980.3 W 5684.0 S 4026.8 W 5758.5 S 4073.4 W 5833.4 S 4118.9 W 5908.5 S 4162.6 W 7313.4 S 29 46 W 7399.6 S 30 24 W 7485.4 S 32 55 W 7571.2 S 35 22 W 7656.9 S 38 5 W 5983.7 S 4205.8 W 6058.5 S 4249.1 W 6131.7 S 4294.2 W 6202.7 S 4342.4 W 6271.4 S 4393.6 W 7741.7 S 38 53 W 7825.2 S 39 22 W 7874.7 S 39 50 W 6337.9 S 4446.5 W 6402.9 S 4499.4 W 6441.3 S 4531.1W 'Survey Codes: 7/GYRO Page 4 05/11/90 CLOSURE DL DISTNCE DEG MIN /100 5591.7 S 35 22 W 0.56 5677.6 S 35 23 W 0.70 5763.4 S 35 23 W 0.15 5848.7 S 35 23 W 0.9.° 5933.5 S 35 22 W 0.36 6017.9 S 35 22 W 0.48 6102.2 S 35 21 W 0.10 6186.8 S 35 21 W 1.22 6272.0 S 35 21 W 0.76 6357.6 S 35 22 W 0.52 6443.5 S 35 22 W 0.34 6529.8 S 35 22 W 0.64 6616.6 S 35 23 W 0.48 6703.8 S 35 23 W 0.67 6791.3 S 35 23 W 0.,34 6878.5 S 35 21 W 2.13 6965.8 S 35 19 W 0.70 7053.6 S 35 16 W 0.53 7141.0 S 35 14 W 1.88 7227.6 S 35 10 W 0.34 7314.0 S 35 6 W 0.28 7400.1 S 35 3 W 0.73 7485.8 S 35 0 W 1.95 7571.6 S 35 0 W 1.87 7657.3 S 35 1 W 2.05 7742.1 S 35 3 W 1.39 7825.7 S 35 6 W 1.20 7875.3 S 35 7 W 1.37 2K-21 (11-10-8) RECORD OF SURVEY Page 5 05/11/90 S MEAS INCLN C DEPTH DEG MN X 10800 55 37 VERTICAL-DEpTHs SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE DEG MIN FROM-WELL-HEAD 6501.9 6347.9 7989.7 S 39 50 W 6530.0 S 4605.1 W CLOSURE DL DISTNCE DEG MIN /100 7990.5 S 35 12 W 0.01 ~Survey Codes: X/EXTRAPOLATED 2K-21 (11-10-8) Page DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 6. o5/11/9o SUBSEA DEPTH 0 100 2OO 30'0 4O0 5OO 6OO 7OO 8OO 9OO 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 MEAS DEPTH 154 254 354 .454 554 654 754 856 957 1060 1163 1268 1375 1487 1602 1724 1855 1998 2158 2345 2532 2712 2888 3066 3242 3420 3602 3787 BKB MD-TVD VERT DEPTH DIFF CORRECT 154 0 0 254 0 0 354 0 0 454 0 0 554 0 0 RELATIVE COORDINATES FROM WELL HEAD 0.12 S 0.30 E 0.20 S 0.79 Iii 0.47 S 1.34 Iii · 0.95 S 1.83 E 1.90 S 2.09 E 654 0 0 5'.34 S 0.88 E 754 0 0 11.84 S 5.07 W 854 2 1 22.5'8 S 15.15 W 954 3 2 36.55 8 26.96 W 1054 6 2 53.94 S 40.13 W 1154 9 3 75.26 S 54.89 1254 14 5 102.09 S 71.27 1354 21 7 135.22 S 90.71 1454 33 12 177.50 $ 116.81 1554 48 16 225.99 S 149.20 1654 70 21 1754 101 32 1854 144 43 1954 204 60 2054 291 87 2154 378 87 2254 458 80 2354 534 76 2454 612 78 2554 688 76 2654 766 79 2754 848 82 2854 933 85 282.44 S 188.15 W 351.78 S 237.91 W 435,02 S 297.36 W 532.24 S 374.99 W 660.18 S 467.61 W 785.54 8 563.76 W 903.99 8 654.71 W 1020.06 S 741.42 W 1137.64 S 829.64 W 1252.62 S 918.05 W 1368.64 S 1009.76 W 1488.88 S 1102.39 W 1614.29 S 1194.67 W 2K-21 (ll-10-S) Page 7 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL o5/11/9o SUBSEA MEAS BKB MD-TVD VERT DEPTH DEPTH DEPTH DIFF CORRECT 2800 3978 2954 1024 91 2900 4169 3054 1115 91 3000 4357 3154 1203 88 3100 4541 3254 1287 84 3200 4724 3354 1370 83 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 5100 5200 53OO 5400 5500 4908 5104 5305 5507 5704 5898 6092 6290 6484 6677 6868 7052 7236 7418 7603 7789 7980 8175 8366 8553 8741 8934 9131 3454 1454 84 3554 1550 96 3654 1651 102 3754 1753 102 3854 1850 96 3954 1944 94 4054 2038 94 4154 2136 98 4254 2230 94 4354 2323 93 4454 2414 91 4554 2498 83 4654 2582 84 4754 2664 83 4854 2749 85 4954 2835 86 5054 2926 91 5154 3021 95 5254 3112 91 5354 3199 87 5454 3287 88 5554 3380 93 5654 3477 97 RELATIVE COORDINATES FROM WELL HEAD 1745.06 S 1876.52 S 2010.78 S 2143.98 S 2275.17 S 2404.26 S 2538.95 S 2679.56 S 2821.09 S 2960.04 S 1291.35 W 1386.70 W 1472.07 W 1551.00W 1630.29 W 1714.39 W 1816.93 W 1921.27 W 2024.68 W 2121.08 W 3094.95 3244.37 3369.86 3511.53 3654.34 2217.96 W 2290.62 W 2412.06 W 2500.85 W 2585.70 W 3798.40 3916.14 4047.36 4164.39 4288.55 2633.37 W 2762.62 W 2835.87 W 2943.97 W 3037.36 W 4409.17 S 4546.14 S 4681.03 S 4813.90 S 4943.51 S 3137.30 W 3226.52 W 3325.61W 3419.86 W 3509.52 W 5078.61 S 5206.43 S 5346.71 S 3591.36 W 3698.59 W 3795.50 W 2K-21 (11-10-8) Page 8 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL o5/ 1/9o SUBSEA MEAS BKB MD-TVD VERT DEPTH DEPTH DEPTH DIFF CORRECT 5600 9335 5754 3581 104 5700 9541 5854 3687 105 5800 9750 5954 3796 109 5900 9952 6054 3898 103 6000 10151 6154 3997 99 6100 6200 6300 10346 6254 4092 95 10536 6354 4182 90 10715 6454 4261 79 RELATIVE COORDINATES FROM WELL HEAD 5487.99 5639.42 5777.39 5945.85 6094.98 3902.70 4000.01 4110.43 4188.35 4236.49 6234.34 6363.99 6476.23 4331.18 W 4461.06 W 4560.22 W 2K-21 (11-10-8) ~ Page 9 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL o5/11/9o MEAS BKB SUBSEA DEPTH DEPTH DEPTH 1000 996 842 2000 1855 1701 3000 2417 2263 4000 2966 2812 5000 3502 3348 6000 4007 3853 7000 4526 4372 8000 5064 4910 9000 5588 5434 10000 6078 5924 RELATIVE COORDINATES FROM WELL HEAD 43.40 S 434.77 S 1094.30 S 1761.95 S 2467.31 S 32.30 W 299.78 W 797.28 W 1300.11 W 1762.84 W 3172.00 S 3882.27 S 4559.77 S 5254.29 S 5983.74 S 2260.67 W 2735.60 W 3236.63 W 3729.76 W 4205.81 W GREAT LAND DIRECTIONAL DRILLING, INC. for Gyrodata Services, Inc. o5/11/9o Client .... : ARCO ALASKA, INC. Field ..... : Kuparuk River Unit Well ...... : 2K-21 (11-10-8) Section at: S,34,25,W Hag Dcln..: 0,0 E Computation...: RADIUS OF CURVATURE Survey Date...: 05/09/90 RKB Elevation.: 154.00 ft Case ID ....... : KRU2K21 INTERPOLATED MARKERS REPORT Surface Location: 269 SNL 95 WEL Sll T10N RSE MARKER IDENTIFICATION RKB 9-5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A MEAS INCLN VERT-DEPTHS SECT DEPTH DEG MN BKB SUB-S DIST 0 0 0 0 -154 3919 58 19 2923 2769 10368 58 58 6265 6111 10384 58 53 6274 6120 10410 58 40 6287 6133 DEG MIN DIRECTION REL-COORDINATES FROM-WELLHEAD 0 N 9O 0 E 2119 S 35 49 W 7630 S 37 13 W 7643 S 37 39 W 7665 S 38 10 W ON 0 E 1706 S 1260 W 6250 S 4377 W 6261 S 4385 W 6278 S 4399 W BASE KUPARUK A PBTD 7" CASING TD EXTRAPOLATED 10645 55 48 6414 6260 10670 55 37 6428 6274 10755 55 37 6477 6323 10800 55 37 6502 6348 7862 S 39 43 W 7883 S 39 50 W 7953 S 39 50 W 7990 S 39 50 W 6432 S 4523 W 6448 S 4536 W 6501 S 4581 W 6530 S 4605 W Harker Identification HO N/S A) RKB 0 0 N 0 B) 9-5/8' CASING 39t9 ~706 S 1260 C) TOP KUPARUK C J0368 6250 S 4377 D) BASE KUPARUK C t0384 826! S 4385 ~ TOP KUPARUK A ~04tO 6278 S 4399 F) BASE KUPARUK A ~0645 6432 S 4523 ~ PBTD ~0670 6448 S 4536 HI 7' CASING 10755 650! S 458! I) TD EXTRAPOLATED ~0800 6530 S 4605 PLAN VIEW ARCO ALASKA, INC. 2K-2~ (~-~0-8) CLOSURE ..... : 7990 ft S 35 12 ~ DECLINATION.: 0,0 E SCALE ....... : ! inch = 1100 feet DRAWN ....... : 05/11/90 55O 0 55O riO0 t650 2200 2750 3300 3850 4400 4950[ 5500 6O5O 6600 7t50 6050 5500 4950 4400 3850 3300 2750 2200 t650 1100 550 0 550 <- ~EST · EAST -> <KB>O ,L___~ _ 75O , f t4arker Identification ' ! A} RK8 --+- I B, 9-5/8' CASIN6 · C} TOP KUPARUK C VERTICAL SECTION VIEW 1500i T 2250[ ARCO ALASKA. INC. 2K-2! [11-10-8) Section at: S 34 25 W TVD Scale.: 1 inch = 1500 feet Dep Scale.: 1 inch = 1500 feet Drawn ..... : 05/11/90 { D 3000 3750 4500 5250 6OOO 675O 7500 82.50 9000 750 "'--.3 1 ,, 750 i500 2.250 3000 3750 4500 5250 6000 6750 7500 8250 Departure MD TVD DEPRT INCLN 0 0 0 0.00 3gig 2923 2ti9 58 32 10368 6265 7630 58 96 t D) SASE KUPARUK C 10384 6274 7643 58 88 E) tOP KUPARUK A 10410 6287 7865 58 68 [ F) BASE KUPARUK A 10645 64t4 7862 55 80 I S) PBTD i0670 6428 7883 55 6! ! H) 7' CASING 10755 6477 7953 55 6! PE.urr ?° -w u_.,aE _ .. ~U~LC,,u. DATE ~ I ~ I ~o CO.~u,,,~, ~~0 ~ - ..... AOGCC GEoLoGIcAL MATERIALS INVENTORY LIST ( check of[ or list data as it is r~eceived ~ ~!0'7 ! 3,/~d'/~/' drillin~] history,v" SarVe~ ! '"'1 Weli t,,sts I core d"sril]ti°n cored i~tervals core ,analysis dr~ d!,tch intervals digital data Il 11 Il I I ,Ill , I I III I I LOG '[YPE RUN INTERVALS SCALE NO. 1 ! 4l ,, ,,, ,,, , , , , ,,, ....... , .... ,, 16] 17] ...... , , ~9) ~ ...... i i i i i ARCO Alaska, Inc. RETURN TO: ARCO Alaska, Inc. ATTN: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #: 7771 Transmitted herewith are the following items. signed copy of this transmittal. 1L-11 2K-21 Cased Holee Gamma Ray 5" Pulse Echo Cement Evaluation Please acknowledge receipt and return one 5-14-90 200-8549 5-5-90 8792-10600 Receipt Acknowledged: Date' 'DISTRIBUTION: Drilling NSK ... State of Alaska(+Sepia) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program_ Operation Shutdown ~ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate m Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 269' FNL, 95' FEL, Sec. 11 T10N, R8E, UM At top of productive interval 1163' FNL, 859' FWL, Sec. 14, T10N, R8E, UM (approx) At effective depth 1428' FNL, 660' FWL, Sec. 14, T10N, R8E, UM (approx) At total depth 1515' FNL, 595' FWL, Sec. 14,T10N, R8E, UM (approx) 12. Present well condition summary Total Depth: measured (approx) true vertical 10800' feet Plugs (measured) 6504' feet None 6. Datum elevation (DF or KB) RKB 154' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2K-21 9. Permit number 90-4 10. APl number 50-103-20123 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool Effective depth: measured (approx) true vertical 1 0670' feet Junk (measured) 641 6' feet None 13. Casing Length Structural 8 0' Conductor Surface 3883' Intermediate Production 1 071 9' Liner Perforation depth: measured Size Cemented 16" 9 5/8" 850 Sx AS III & 450 Sx Class G 7" 300 Sx Class G None true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None Attachments Description summary of proposal Measured depth True vertical depth 115' 115' 3919' 2930' (approx) 1 0755' 6478' (approx) RI{ IV D MAR -1 1990 Naslm Oil & Gas Cons, commisSlotm Anchorage Detailed operation program BOP sketch 14. Estimated date for commencing operation March, 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas __ Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned /~~ ~'~ ~-~~ Title Area Drillincj Engineer / 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- ~-~ ORIGINAL SIGNED BY LONNIE C. SUITH Approved b)/the order of the Commission Commissioner IApproval No. I ~ .-/:..z ? ,' Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ARCO OII and Gas Company Well History - Initial Report - Daily Prepare and I!Jblli!t the ~ ~IT' on the first Wednesday after a well is spudded or workover operations are started. Dally work prior tOel~add~i!~ld be summarized on the form giving inclusive dates only. District ]County, parish or borough ] State ARCO ALAS~ Z.C. I NORTH SLOPE I AK Field ILease or Unit IWell no, KUPARUK I ADL: 25605 ALK: 2679 KRU 2K-21 I Auth. or W.O. no. ITItle AK4371 I DRILLING Operator ARCO W.I. ARCO I 55.8533 Date and depth Complete record for each day reported as of 8:00 a.m. DOYON 14 01/07/90 (1) TD: 1484' ( 1484 SUPV:SC 01/08/90 (2) TD: 2940'( 145( SUPV:SC 01/09/90 ( 3) TD: 3940'( 100¢ SUPV:SC 01/10/90 (4) TD: 3940'( a SUPV:SC 01/11/90 (5) TD: 4202' ( 262 SUPV:CD RECEIVED 01/12/90 (6) TD: 7085'( 2883 SUPV:CD MAR- J[ Ol/13/9o (7) ~ : ' : 8886' ( 1801 AJ~k~ 0il & Gas Cons, (;ommtSSt°sPoPV:CD Anchorage 01/14/90 ( 8) TD: 9950'( 1064 SUPV:CD DRLG 12.25" HOLE MW: 9.0 VIS: 81 RU DIVERTERS, PU SPOOL OF DRILL LINE, MU BHA, SPUD, DRLG . ACCEPT RIG @ 0600 ERS- 1/6/90, SPUD @ 1400HRS-1/6/90. DAILY:S86,301 CUM:$86,301 ETD:SO EFC:$1,487M DRLG MW: 9.3 VIS: 71 DRLG , HUNT FOR HOLE IN DRILL PIPE, COULD NOT FIND IT, CHANGED OUT NAVIDRILL , CHANGE OUT BIT, RIH LOOK FOR HOLE, DID NOT FIND, NOW DRILLING AHEAD W/ HIGHER PRESSURE THAN ANTICIPATED, PROBABLY ONE PLUGGED JET. DAILY:S51,470 CUM:$137,771 ETD:S137,771 EFC:$1,487M RU TO RUN CSG MW: 9.4 VIS: 78 DRLG TO 3940', POOH, TITE HOLE, PU HOLE OPENER, RIH, CIRC, POOH, RIH, CIRC, POOH, RU TO RUN 9.875" CSG. DAILY:S76,853 CUM:$214,624 ETD:S214,624 EFC:$1,487M RIH TO DRILL OUT CMT MW: 8.4 VIS: 29 RUN AND CMT 100 JTS 9.625",J55,BTC, 36#,CASING W/ ~50 SX ASIII & 450 SX CLASS G, NU BOPE, TEST BOPE, MU BHA DAILY:S218,147 CUM:$432,771 ETD:S432,771 EFC:$1,487M DRLG MW: 8.6 VIS: 30 h/-:TIH DRLGCMT TO FC, TEST CSG TO 2000PSI,DRLG CMT PLUS 10 ~iFOIH~TI~; TEST FORMATION TO 12.7 EMW, OK, DRLG F 3948 TO -'i~02~;~I'D AND TURBINE FAILURE, POOH CHANGE OUT BOTH RIH,DRLG ~OM'4026 TO 4202. DAILY:S73,789 CUM:$506,560 ETD:S506,560 EFC:$1,487M DRLG DRLG FROM 4202 TO 7085. MW: 9.3 VIS: 41 DAILY:S52,916 CUM:$559,476 ETD:S559,476 EFC:$1,487M TRIP FOR MWD FAILURE MW: 9.4 VIS: 37 DRLG FROM 7085 TO 8886, POOH FOR MWD FAILURE. DAILY: $56,775 CUM: $616,251 ETD:S616, 251 EFC:$1,487M DRLG MW: 9.3 ViS: 34 C.O. MWD TOOL, TIH, CUT DRLG LINE, RIH AND REAM FROM 8855 TO 8886, DRLG AHEAD. DAILY:S52,940 CUM:$669,191 ETD:S669,191 EFC:$1,487M The above is correct For form p?epara_fl~and' distribution, see Procedures Ivan./al, Section 10 Drilling, Pages 86"A~d 87. ' IDate , T AR3B-459-1-D JNumber all dally well history forms consecutively iPage no. as they ara prepared for each well. ARCO Oi, .,~d Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work 13erformed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlerlm" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "interim" sheets when filled out but not tess frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin~ until completion. District County or Parish IState ARCO ALASKA INC. I NORTH SLOPE IAK Field JLease or Unit IWell no. KUPARUK I ADL: 25605 ALK: 2679 KRU 2K-21 Date and depti3 as of 8:00 a.m. 01/15/90 (9) TD:10290' ( 34 SUPV:CD 01/16/90 (10) TD:10800'( 51~ SUPV:CD 01/17/90 (11) TD:10800'( SUPV:CD Complete record for each day while drilling or workover in progress DOYON 14 DRLG MW: 9.8 VIS: 40 DRLG FROM 9950 TO 10031,TRIP FOR BIT #4,TEST FORMATION TO 10.5 EMW, DRLG FROM 10031 TO 10290. DAILY:S59,855 CUM:$729,046 ETD:S729,046 EFC:$1,487M REAMING FOR RLL MAD PASS MW: 9.9 VIS: 39 DRLG FROM 10290 TO 10671, REPAIR ROTARY CHAIN, DRLG FROM 10671 TO 10800, CIRC, POOH LD 25 JTS, PULL 10 STDS SHORT TRIP, REAM FROM 10000 TO 10300 FOR RLL REPEAT PASS. DAILY:S75,230 CUM:$804,276 ETD:S804,276 EFC:$1,487M RUN 7" CSG MW: 9.9 VIS: 38 REAMING WITH RLL TOOL(10300 TO 10800), HOLE TIGHT, CIRC.,SPOT DIESEL PILL, POOH, LDDP, RU AND RUN 7" CSG. DAILY:S82,370 CUM:$886,646 ETD:S886,646 EFC:$1,487M RECEIVED IVIAr -1 1990 Alas/e.Oil & Cons, Commissio chorago The above is c.~ect Signature / / /~ For form-p'~eparation a~ di~trib~'~ion ..~ see Procedures Manu{[I ~Section 10, ~ Drilling, Pages 86 and'"~'7 AR3B-459-2-B Number all daily well history torres consecutively as hey are prepared for each well, IPage no. ARCO , and Gas Company Daily Well History-Final Report .Instructions: Prepare and submit the "Fhla~l~rt" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitti~l also-whew operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, rel3ort~com~letl~,a~d rel3reSentative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available.": "_~ ~ I Accounting cost center code District I State ARCO ALASKA INC. IAK I County or Parish NORTH SLOPE Field Lease or Unit J Well no. KUPARUK ADL: 25605 ALK: 2679 KRU 2K-21 Auth. or W.O. no. Title AK4371 DRILLING Operator A.R.Co. W.I. ARCO 55.8533 Spudded or W.O. begun Date SPUD 01/06/90 Date and depth as of 8:00 a.m. 01/18/90 (12) TD:10800 PB:10670 SUPV:TM Complete record for each day reposed DOYON 14 Iotal number of wells (active or inactive) on this dst center prior to plugging and bandonment of this well I our I Prlor status if a W,O. 14:00 RELEASED RIG 7"@10755' MW: 9.9 NaC1 CONTINUE RUNNING 7" CASING SHOE AT 10788, COLLAR @ 10670, CTC PKR @10060' BREAK CIRC, CMT W/ 400 SX CLASS G, SET PKR, ND BOPE RELEASE RIG @ 0430 HRS - 1/18/90. DAILY:S310,802 CUM:$1,197,448 ETD:S1,197,448 EFC:$1,487M RECEIVED MA -1 1990 /ila,ska Oil & Gas Cons. Commisslo.~ AnChorage Old TD JNewTD I PB Depth Released rig ] Date JKind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method I Officia reservoir name(s) Potential test data Well no, Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form-preparah n; distribution. see Pro~ePd~erPe~r~li~l, Section 1;,' Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. jPage no. DIvlNon o! AtlsntlcRIchfleldCompany ARCO Alaska, Inc. Date: January 30, 1990 Transmittal #: 7654 RETURN TO: ARCO Alaska, Inc. ATTN: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith is the following items. signed copy of this transmittal. 2K-21 2K-21 2K-24 2K-24 Electromagnetic Resistivity/Dual Gamma Ray Dual Gamma Ray/Compensated Neutron Porosity/ Simultaneous Formation Density Electromagnetic Resistivity/Dual Gamma Ray Dual Gamma Ray/Compensated Neutron Porosity/ Simultaneous Formation Density Please acknowledge receipt and return one 1-16-90 8-7-g~- 10031 1-16-90 ~-10800 I -04-903~'?~-9826 I -04- 90 3~7-50-9826 Receipt Acknowledged: DISTRIBUTION: RECEIVED BP(+sepia) Susanne Baxter Chevron(+sepia) D&M Drilling Drill Site Foreman File Doyon 14 Rig Supervisor Franzen Johnston(+sepia) NSK State of Alaska(+sepia) James Trantham ^nnuler prave~tep , Pipe rems 81~nd ram~ Choke l~ne valve~ H:R valve g{11 line valves Check valve TRST R~ULT$: ~685 H~ .............. ii Lower Kelly Bell typ~ ! ._ Teat pre~uee ..... 3,_~00 .... Inside BoP -_L_. Test ~tes,ure ~r-_~(~,. · . .- i i il '--' Namber wlvea Number flanges ~ _(~3. ....... , = H~l~rlUl ~l'ea l 1 ¥ eperlted ehoko ~_~ ~ Repair ar replaoe~ent af faa}ed equipment to be made ~th~n · e - Operator January 5, 1990 Telecopy No. (907) 276-7542 P J Archey~ Area Drilling Engineer ARCO Alaska P 0 Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 2K-21 ARCO Alaska inc ' Permit # 90-4 Surf Loc 269'FNL, 94'FEL, Sec 11, T10N, R8E, UM B~mho%e Loc 1547'FNL, 695'FWL, Sec 14, T10N, R8E, UM Dear Mr Archey: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you £rom obtaining additional Permits required by law from other governmental agencies, and does no-c authorize conducting drilling operations until all other required permitting determinations are made. To aid us in scheduling field work, please notify this o£iice 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present ~o witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notifY this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Very truiy~ours, Ghaimn Ala~ka 0/1 and Gas Conservation Gom/sston BY O~ER OF THE COPR~iSSiON jo Enclosure Department oi' Fish & Game, Habitat Section - w/o enci Department of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill ~; Redrill -- I lb. Type of Well Exploratory__ Stratigraphic Test _ Development Oil .~X Re-Entry _ Deepen _I Service _ Development Gas __ Single Zone ~ Multiple Zone .. 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc, RKB 154. Pad 115' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchoracje, AK 99510-0360 ADL 25605 ALK 2679 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 269' FNL, 94' FEL, Sec. 11 , T10N, R8E, UM KuDaruk River Unit Statewide At top of productive interval (TARGET) 8. Well number Number 1320' FNL, 850' FWL, Sec. 14, T10N, R8E, UM 2K-21 #U630610 At total depth 9. Approximate spud date Amount 1547' FNL, 695' FWL, Sec 14, T10N, R8E, UM 01-05-90 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2K-20 10780 MD 695'@ TD feet 21' at 700 feet 2560 6497TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 600 feet Maximum hole angle 58° Maximum surface 1731 pslg At total depth (TVD) 6497 3400 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement , Hole Casing Weight Grade Coupling Length IVD TVD IVD TVD linclude stage data/ 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 CF 12.25 9.625 36.0# J-55 BTC 3871 35' 35' 3871 2924 1400 Sx AS III & HF-ERW 450 Sx Class G 8.5 7" 26.0# J-55 BTC 10780 35' 35' 10780 6497 300SxClassG & ~F-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured true vertical feet Casing Length Size Cemented Measured depth True Vedical d.e,~th Structural RI ¢EIVED Conductor Surface Intermediate ProductionJAN - Liner Perforation depth: measuredNasle 011 8as Cons. Commlsst l true verticalAnchorage 20. Attachments Filing fee X~ Property plat __ BOP Sketch X Diverter Sketch ~ Drilling program Drilling fluid program X~ Time vs depth plot __ Refraction analysis _ Seabed report _20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed 7~J,~ ~'~.~ Title Area Drilling Engineer Commission Use Only m~J ~. I I 0~See c°ver letter ,°r 'l~er am APl number Approval date 0 ]. / 0.~ / 9 '-' 50-//~ ~ - ~,O/~ other recluirements Conditions ~f approval Samples required __Y e s ,~ N o Mud log required __ Y e s z~ N o Hydrogen sulfide measures ' '~~;;y required ,z~'Yes. N o Required working pressure for __ 10M' __ 1 5 M Other: J by order of ...Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 it in triplicate HO, .ZONTAL PROJECTION SCALE 1 IN. -- 1000 FEE]' ARCO ALASKA. Inc. Ped 2K. Well No: 21 Revleed Propoeal Kuperuk Field, North Slope, Aleeke 1000 ~ 1000 _ 2000 _ o ~ 3000 _ 4000 _ 5000 _ 6000 _ 7000 _ WEST~EAST 5000 4000 3000 2000 I I I 1000 0 I I SURFACE LOCATION, 269' FNL. 94' FEL SEC, 11. TION. RBE SURFACE S 34 DEO 24 MI N W 7673' (TO TARGET) TARGET CENTER TVD=6330 TMD=104$8 DEP=?673 SOUTH 6331 WEST 4336 RE,.¢EIVED JAN-4 ~990 TAROET LOCATION, 1320' FNL. 850' FWL SEC, 14, TION. R8E TD LOCAT[ONt 1547' FNL. 695' FWL SEC, 14. TION. RSE 1 000 ARCO ALASKA, Ins. Pad 2K, Well No~ 21 Revised Proposal Kuparuk Field, North Slope, Alaska 0 RKB ELE¥^TION~ 154' | ,~ I~ g BUILD 3 DEO luuul~ 15 PER I00 FT I \ 21 B/ PERMAFROST TVD=1424 TMD=I452 DEP=187 ~~'EO~ TVD=2233 TMD=2559 DEP=919 = ~8/ W SAK SNDS /VD=2724 1HD=3506 DEP 1729 3000_ "~,,,,.9 5/8" CSO Pr 1VD=2924 TMD=3891DEP=2059 ~D=3174 TMD-4373 DEP=247! 4000_ K-$ TVD=4574 TMD=707~ DEP=4779 5000 58 DEG 46 ~IN 60_00__ _ .... ~ ...... ~T/ ZONE C TVD=6250 TMD=10304 DEP=7542 T/ ZONE A TVD=6266 TMD=10335 DEP=7568 TAROET CNTR TVD=6330 /MD=lO458 DEP-7673 B/ KUP SNDS TVD=6393 TMD=10580 DEP=7777 TD (LO0 PT) TVD=6497 TMD=10780 DEP=7948 7000., i I i I I I I i 0 1000 2000 3000 4000 5000 6000 7000 8000 VERTICAL SECTION RECEIVED JAN-4 1~ Alasla 011.~; Gas Cons. ~nc~orag~ 150 100 50 0 50 100 150 200 250 150 I , , ~00 / / / 1900 / / I 150 100 I 50 1700 1500 O0 3OO / / 500 / / 1100 oo / / 7'11 0 50 1 O0 150 I I I 1300 ~ 7nn ' 5OO ~ I 1 300 500 ~ 900 100 50 0 500 500 500 700 500 ~0 900 1100 RECEIVED JAN-4 !~ Alaska Ol!.& gas Cons. Anchorage ! i 50 ! O0 1 50 150 100 50 0 5O 100 150 200 250 DRILLING FLUID PROGRAM (2K-21) Spud to 9-5/8" Drill out to Weight up surface casing weight up to TD Density 8.8-9.0 8.6-9.4 10.0 PV 15-30 8-10 12-16 YP 20-40 5-8 8-1 2 Viscosity 70-80* 35-40 35-50 Initial Gel 5-15 2-4 4-6 10 Minute Gel 15-30 4-8 5-12 APl Filtrate 10-15 7-9 4-5 pH 9-10 8.5-9 9.0-10 % Solids 10 +/- 4 - 7 <12 Drilling Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. - Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. - The nearest well to 2K-21 is 2K-20. As designed, the minimum distance between the two wells would be 21' at a depth of 700'. The wells would diverge from that point. - Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 to drill gravel beds. KUPARUK RIVER UNIT 20 DIVERTER SCHEMATIC J L DESCRIPTION 1. 16' CONDUCTOR 2. FMC SLIP~)N WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY wrrH TWO 2-1/16' 2000 PSI BALL VALVES 4. 20" 2000 PSI DRILLING SPOOL W/10' OUTLETS 5. 10" HCR BALL VALVES WI10' DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTEFL VALVES CAN BE REMOTELY ~ TO ACHIEVE DOWNWIND DIVERSION. 6. 20' 2000 PSI ANNULAR PREVENTER ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERll;R SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 3 MAINTI~NANCE & OPERATION 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES RECEIVED JAN-4 ~'~-. Alaska Oil.a; eas Cons. Anchorage ,,, i 7 I , i I' 5 I3 2 I I 13 5/8" 5000 Pcil BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOP, 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 EMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACKTEST 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. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3(X)0 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTORAND MANUAL KILLAND CHOKE UNE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE MNES. 6. TEST TO 250 PSI AND 3(X)O PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3(X)O PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOTA FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3(X)O PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PUM. OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3(X)0 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND MNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWO[JT PREVENTER TEST FORM. SIGN AND SEND TO DRILMNG SUPERVISOR. 14. PERFORM COMPLETE BOPE TESTONCE A WEEKAND FUNCTIONALLY OPERATE ELOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11' - 3(XX) PSI CASING HEAD 3. 11 ' - 3000 PSI X 13-5/8' - 5(X)O PSI SPACER SPOOL 4. 13-5/8' - 5000 PSI PIPE RAMS 5. 13~5/8' - 50(X) PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8' - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8' - 5000 PSI ANNULAR R,E¢I IVED JAN-4 SRE 8/22/89 DOYON 14 GENERAL DR{LL[NG PROCEDURE KUPARUK RIVER F[ELO DEVELOPMENT gELL$ HIRU. Znsta11 FI( dtverter system. 0rtli 1Z-1/4' hole to g-S/8" surface ¢astng potnt ecco~ltng to dj rKttonal plan. Run and c~nt 9-S/8" castng. Znst, 11 ,~ t,g 8OPE. Test castng to ~ pstg. 0rtll ~t cmnt and Z0' n~ hole. Pe~om 1ilk off test. · Dr111 8-Z/Z' hole to loggtng point acco~tng to dt~t?onll plan. Run open hole logs. · Conttflue drt111flg 8-~/~H hole to p~vtde Z~' be~fln ~ and bott~ of Kulak sands. Run and cmnt 7n castn~ Pressuq test to 3S~ pstg. D~squ~ze Arcttc pack~ and c~nt tn 7' x 9-S/8' annulus. NO B0K and tns~11 t~porary Xms tree. 13) Secu~ well and release rtg. 14} Run cased hole logs. 15 Hove tn borkover rtg. NU 80PE. 16 PU 7" castng scraper and tubtng, TZH to PBTD, CfKulate hole wtth clean brtne and TOH standtng tubtng back. 17) Perforate and run completion assembly, set and test packer, 181 ND BOPE and tnsta11 Xmas tree. 19 Change over to dtesel. 201 Flow well Co tanks. Shut In. ~O 21 Secure well and release rig. REC~IV 22) Fracture stimulate. OIQAIIIR MUO CLIANIR SHALl SHAKERS STIR STIR TVDI~A ! Ul ir1 QVmTI:U * HFIdATIC2 N.TS. SECTION SECTION I I · WELLS 1-12 ARE LOCATED IN SECTION 2, T lO N., R. 8 E., UMIAT MERIDIAN. WELLS 13'24 ARE LOCATED IN SECTION I I, T. ~0 N., R. 8 E., UMIAT MERIDIAN. SECTION I PROTRACTED SECTION CORNER SECTION RECEIVED DEC; 1 1988 Notes: 35 36 THIS I ~,, \ I ~U~V~ ~ D.S. 2K [ "~ ,, ~m ,z [ vICINITY MAP T ION · I. COORDINATES ARE A.S.P. ZONE 4. ?. ALL DISTANCES SHOWN ARE TRUE. 3. ELEVATIONS ARE B.P.M.S.L. 4. OG. ELEVATIONS FROM CED-RIXX-3$11,re~(4. 5. HORIZONTAL POSITION BASED ON 2-K CONTROL MONUMENTS PER LOUNSBURY 8, ASSOCIATES. 6. REFERENCE FIELD BOOK; L88-40, pgs. 55,56, 58,59, 65 ~ 66. Well A'SP's Alasii a uil & ¢,~s Cui;$. ~orr,m;ss::::: Dist. Dist. O.G. Pod No. 'Y' 'X' L~'~ t;~dl~l~ LONGITUDE F.S.L. F.E.L. Elev. Elev. I 5,938,600.18 498,3i0.17 70°14'36.519" 150o00'49.153'' 2~6' 94' !14.0 118.5 2 5,938,575.14 498,$10.28 70° 14' 36.273" 150o00'49.130" 271' 113.9 3 5,938,550.30 498,:310.35 70° 14.' 36.029" 150o00'49.128" 246' 113.8 4 5,9:58,525.46 498,310.06 70o14' $5.784" 150o00'49.156" 222' 113.8 5 5,938,500.19 498,310.1z 70o14' 35.536" 150o00'49.154" 196' 113.8 6 5,958,475.14 498,:510.33 70014'35.289" 150o00'49.128" 171' I 1~3.8 7 5,958,450.36 498,310.36 70o 14' $5.046'' 150o00' 49.127'' 146' I 115.8 8 5,938,425.30 498,$10.18 70° 14' $4.799'' 150° 00' 49.132:'' 121' 113.8 9 5,9:38,400.30 498,309.98 70o14' 34.555" 150°00'49.137'' 96' 113.8 , I0 5,958,$75.19 498,510.14 70° 14' 34.$06" 150°00'49.155'' 71 113.9 I I 5,9..'38,350.22 498,3,10.14 70o14' :54.061 " 150°00'49.133'' 46' 11.:3.9 12 5,938,325.20 498,$10.17 70°14'33.815" 150 °00'49. 131'' 21' 94' 11.5.9 118.5 FN.L. 13 5,938,£$5.$1 498,;310.37 70° 14' 32.930" 150 ° 0 0' 49.125'' 69' 94' I I.:3.7 118.5 14 5,938,210.14 498,310.16 70 °14' 32.685" 150° 00' 49. I$1'' 94' 113.7 15 5,938,185.1Z 498,310.16 70o14'3?_.437" 150°00'49.131" 119' 11.'3.8 16 5,938, 160.11 . 498,$10.20 70o14' 32_. 191" 150°00'49.130" ~44' 113.8 17 5,938, 135.21 498,.310.18 70°14':31.946'' 150°00'49.1:30'' 169' I I;3.9 18 5,958, 110.19 498,310.29 70°14'$1.700" 150°00'49.127'' 194' 114.0 19 5,938,085.20 498,310.27 70°14' 31.454" 150°00'49.127'' 219' 1.14.0 20 5,938,060.14 498,310.22 70o14' 31.207" 150°00'49.128" 244' 114.1 21 5,9 38,055.16 498,:510.16 70° 14' 30.962'' 150° 00'49. I.~0" 269' 114.0 22 5,938,010.40 498,,310.19 70o14' 30.718 " 150° 00'49. IZ9" 294' 94' 114.0 23 5,937,985.32 498,310.1:5 70°!4':50.471'' 150° 00'49. 150'' 319' 95' !14.0 24 5 ~957,960.29 498,$10.08 70 °14' 50.225" 150° 00'49. 132'' ;544' 95' I !13.9 118.5 I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED ~'..'"~ ,* TO PRACTICE LAND SURVEYI, ,N 3TATE OF ALASKA AND THAT THIS ~,,,,·,·,,oo ...... ,,o,.t.,.~ PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPER- VISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF NOVEMBER ZO~ 1988. AnCO AlaSka, 'b c, _ DRILL SITE 2.K CONDUCTOR AS-BUILTS Z~. ~)'.' M.O'~) ] C~'.~,y.~'(-:,,,,t'/ Is, t , ~i~ I ~fe.'ll/21/88 I/:hrg. A/O. NSK 6,2ll. d 4 ARCO Alaska, Inc. Post Office Box 100360 ^nchorage, Alaska 99510-0360 Telephone 90'7 276 1215 December 12, 1988 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Conductor As-Built Location Plat- 2K Pad ~/ (Wells I - 24) Dear Mr. Chatteron' Enclosed is an as-built location plat for the subject wells. any questions, please call me at 263-4618. Sincerely, If you have D. Martin Engineering Aide DM:hf Enclosure RECEIVED DEC 1 3 ]988 Alaska Oil & Gas Cons. Commissim] Ancl]orage GRU13/010 ARCO Al,'tska, Inc. i~ a Sl,'bsidi,'tr¥ of Atl~)~licIt[ichfieldC,)~npF)ny CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (~ thru ~5 '' ' - (8) (3) Admin /~/P. ///__//z~ 9. ('9'~nru '13) 10. (10 and 13) 12. 13. C,as (14 thru 22) (23 thru 28) Company ~d_zo ~//~'~, ~t_~.. Lease & Well No. /~z~: , YES NO Is the permit fee attached .......................................... ~ ' 2. Is well to be located in a defined pool ............................. 3. Is we~] located proper distance from property line .................. 4. Is we-~,[_located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ L 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... / Does operator have a bond in force .................................. . Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~_ Does the well have a unique name and number ......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings o.. Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate~ Are necessary diagrams and descriptions of diverter and BOPE attached. D~es BOPE have .sufficient pressure rating - Test to ~O~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (6) OTHER '(29 thzfu ~1) (6) Add: ~.~.~, Geolo ~y: Engi.neerin~: DWJ ~---'~LCS ~.::':/' BEW /'" rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of Seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE / Additional Remarks: .~ ~ v~r Or~_..~ , _ - I O mm