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Home My WebLink About195-112THE MATERIAL UNDER THIS COVER HAS BEEN MICROF'ILMED. ON OR BEFORE ~ PL M A T E T H IS E .IA L U N D M A R K E R W E R C:LORNV[FILlvI. DOC PLUGGIN~ 2 LOCATION CLEAk~_fCE REPORT State cf Alaska .ALAS/(A 0IL & GAS CONSERVATION COHMI$SION -. Review the well file, and-comment on plugging, well head status, and location clearance - urovide loc. clear, code. Well head cut off: -~~_ · ~a~ker 'post or plate: Location Clearance: Code ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 10, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2T-38 (Permit No. 95-112, 397-191) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the recent abandonment of KRU 2T-38. This well was sidetracked and re-drilled to an alternate bottom hole location and renamed 2T-38A. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well O~L r-1 GAS I--1 SUSPENDED I---1 ABANDONE® SERWCE I---I 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 95-112, 397-191 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20229-00 4 Location of well at surface ? ;'.:,'- . ..... ~~_ 9 Unit or Lease Name 65' FSL, 556' FWL, Sec. 1, T11N, R8E, UM : ~.~.,:'i.' :~ :' .~-~ . ; 't~~i Kuparuk River Unit At Top Producing Interval ~ ~.~/:, !'!~ ~ 10 Well Number ; '" ;~'~ .......... ; 2T-38 At Total Depth ~ :.~..-;:~ :' f-r ~ i. 11 Field and Pool 2487' FSL, 442' FVVL, Sec. 10, T11 N, R8E, UM ~ :: ~' -' '7;~i¥-'~7 ~7~;' ? KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. Kuparuk River Oil Pool RKB 122', Pad 81' ADL 25568 ALK 2666 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 16 No. of Completions 27-Jui-95 03-Aug-95 16-Nov-97 NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 13363' MD & 6095' TVD 13264' MD & 6029' TVD YES U NO M NA feet MD 1465' APPROX 22 Type Electdc or Other Logs Run 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16' 151.5# X-65 SURF. 121' 36' 103 sx AS I 9.625' 40.0# L-80 SURF. 4630' 12.25' 870 sx AS III & 810 sx Class G 7' 26.0# L-80 SURF. 13353' 8.5' 230 sx Class G set bddge plug in 3.5' tubing at 12864' MD 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) All perfs were abandoned 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12bbls 15.8 ppg cement spotted on top of bridge plug & production packer @ 12877' MD 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I N/A Date of Test Hours Tested PRODUCTION FOJ OIL-BBL GAS-MCF WATER-BBl. CHOKE SIZE I GAS-OIL RATIO TEST PERIOI: Flow Tubing Casing Pressure CALCULATED OIL-BBL GASoMCF 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. :~:"i'; -- ,-.. [. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH 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. Signed ' , .~. ~ ~, ~ Title ~L- ~.r~ ~4,~ EEl1, DATE ~._ ~ Prepared by Name/Number Sharon AIIsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 1/7/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2T-38A RIG:NORDIC WELL_ID: AK9101 TYPE: AFC: AK9101 AFC EST/UL:$ 850M/ 1000M STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: BLOCK: SPUD:il/26/97 START COMP: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20229-01 11/15/97 (D1) TD:13264' (13264) SUPV:RWS DAILY:$ 11/16/97 (D2) TD: 0'( SUPV:RWS 0) DAILY:$ 11/17/97 (D3) TD: 0'( 0) SUPV:RWS DAILY:$ 11/18/97 (D4) TD: 0'( 0) SUPV:RWS DAILY:$ 11/19/97 (D5) TD:12823'(12823) SUPV:RWS/MC DAILY:$ 11/20/97 (D6) TD:12823' ( 0) SUPV:RWS/MC DAILY:$ 11/21/97 (D7) TD:12510' ( SUPV:RWS/MC o) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 CIRC & DISPLACING WELL TO MUD Began move @ midnight, icy road @ north end of 1E pad, rear wheel of rig slid off of road. Secure rig with cats, crib up rig and drive back onto road. No spills or damage. Continue move to 2T-38A. Accepted rig @ 1800 hrs. 11/15/97. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 MW: 9.4 VISC: 54 PV/YP: 14/19 APIWL: 9.8 Circ and condition mud. Thaw out hardline f/choke manifold to 2T-14 flowline. ND tree. NU test stack. Test BOPE to 300/3500 psi. Pump cement. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 MW: 9.4 VISC: 45 PV/YP: 8/18 CONTINUE L/D 3.5" CMT CONT TBG Pull 3.5" tubing. 0 CUM:$ 0 ETD:$ 0 EFC:$ APIWL: 10.4 MW: 9.4 VISC: 32 PV/YP: 5/ 8 APIWL: 16.0 RIH W/DRLG BHA Safety meeting. Continue to lay down 3.5" tubing. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 MW: 9.4 VISC: 45 PV/YP: 10/ 7 APIWL: 21.0 POOH W/3.5" DP TO PU CMT BHA Safety meeting. RIH with 3.5" DP. Tag top of cement @ 12823' 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 MW: 9.5 VISC: 41 PV/YP: 9/ 9 APIWL: 32.0 POH F/PACKER MILLING BHA ASSY Pre-job safety meeting. Pump cement slurry. RIH with packer. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 MW: 9.4 VISC: 40 PV/YP: 9/10 APIWL: 30.0 STANDING BACK MILLING BHA Continue RIH w/ 3.5" DP and bridge plug to 5397', gauge ring hung in coupling damaging bottom slips on bridge plug. Unable to continue RIH. POH w/damaged bridge plug. Bridge plug hung @ 4954' and sheared off. RIH to mill up bridge Date: 1/7/98 ARCO ALASKA INC. Page: 2 WELL SUMMARY REPORT plug. Tag top of bridge plug ~ 4952' Milled 1'+ bridge plug dropped downhole. RIH chasing bridge plug to top of cement plug @ 12510' DAILY:$ 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 11/22/97 (D8) TD:12510' ( SUPV:RWS/MC 0) DAILY:$ MW: 9.4 VISC: 40 PV/YP: 9/10 APIWL: 30.0 RIH W/3.5" DP RO RUN SCH. CCL RIH with bridge plug ~2. Bridge plug taking weight unable to continue. Pull plug to surface. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 11/23/97 (D9) TD:12510'( SUPV:RWS/MC 0) DAILY:$ MW: 9.6 VISC: 80 PV/YP: 19/26 APIWL: 7.0 MAKING UP WHIPSTOCK & PREP RIH RIH w/Schlumberger CCL to 6295' Cable drag stopped tool. Tag bridge plug $ 12509'. RIH w/Schlumberger CCL. Log to T.D. POH left CCL tool & 300' e-line in hole. POH 24 stands wireline & CCL tool stuck in DP. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 11/24/97 (D10) TD:12144' ( 0) SUPV:RWS/MC DAILY:$ MW: 9.4 VISC: 71 PV/YP: 14/37 APIWL: 7.0 MILLING WINDOW, 15' CUT RIH with Whipstock assembly to 12447' MD. Mill window in 7" casing. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 11/25/97 (Dll) TD:12173' ( 29) SUPV:MC DAILY:$ MW: 9.4 VISC: 60 PV/YP: 15/33 APIWL: 8.0 PREP TO RIH W/6.125" PDC BIT Continue milling window from 12150' to 12173' Perform FIT to 13.0 ppg EMW. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 11/26/97 (D12) TD:12360' (187) SUPV:DW/MC DAILY:$ MW: 9.4 VISC: 60 PV/YP: 15/35 APIWL: 4.5 DRILLING AHEAD Test BOPE to 300/3500 psi. Slide thru window to 12171' Slide and rotate from 12171' to 12360' 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 11/27/97 (D13) TD:13177' (817) SUPV:DW/MC DAILY:$ MW: 11.4 VISC: 46 PV/YP: 19/23 APIWL: 4.0 TD HOLE @ 13360' POOH TO SHOE Continue directional drilling 6.125" hole from 12360' to 13177', sliding and rotating as needed. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 11/28/97 (D14) TD:13360' (183) SUPV:DW/MC DAILY:$ MW: 11.4 VISC: 55 PV/YP: 18/24 APIWL: 4.0 RIH W/3.5" LINER TO 13360' Continue drilling from 13177' to 13360' RIH w/3.5" liner. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 11/29/97 (D15) TD:13360'( 0) SUPV:DW/MC DAILY:$ MW: 11.4 VISC: 46 PV/YP: 16/29 POOH L/D 3.5" DP RIH w/3.5" liner. Pump cement. Set packer. 0 CUM:$ 0 ETD:$ 0 EFC:$ APIWL: 4.0 Date: 1/7/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 11/30/97 (D16) TD:13360' ( 0) SUPV:DW/MC DAILY:$ MW: 11.4 VISC: 46 PV/YP: 16/19 APIWL: 4.0 R/U TO RUN 3.5" PROD TBG POOH 3.5" DP. Load 3.5" production tubing in pipe house. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 12/01/97 (D17) TD:13360' ( 0) SUPV:DW/MC DAILY:$ MW: 11.4 VISC: 48 PV/YP: 16/29 N/D BOPS AND N/U TREE Run 3.5" production tubing w/jewelry. 0 CUM:$ 0 ETD:$ 0 EFC:$ APIWL: 4.0 12/02/97 (D18) TD:13360' ( 0) SUPV:DW DAILY:$ MW: 8.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED @ 1700 HRS. 12/2 Freeze protect well. N/D BOPE. N/U tree. Test packoff to 5000 psi, test tree to 250/5000 psi. Move rig off well. Release rig @ 1700 hrs. 12/2/97. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 End of WellSummary for Well:AK9101 !i'[J4AM AF~(J0 ALASJ~[A l~(J ~o, UOV] h ]/3 _,~SKA OIL AND GAS CONSERVATION OOMMI~,~,ON APPLICATION FOR SUNDFIY APPHOVAL$ 1~ Type of Request: Abandon X Suspend -- 'Operation Shutdown Re-enter suspended well Alter =asing _ Repair well _ Plugging X Time extension _ Stimulate ,,, Plugba=k for Change al)proved program _ Pull tubing _ Varl,ance _ Perforate --. Other ,_~__, Redrlll 2. Name of Operator' 5, Type of Weih 6. Datum elevation (DF or KB) Development X ARCO Alaska,. Inc. . Exploratop/ _ 122' RKB. Pad 81' rest 3. Address Stratigraphic _ 7. Unit or Property name P, O, Box 100360, Anchora~le, AK 99510 Service _ Kuparuk River Unit ~_. i i i . i il 4. Location of well at ~urface $. Well number 65' FSL, 556' FWL, Sec, 1, T11N, R8E, UM 2T-3e ,, At lop el productive interval 9. Permit number 95.112 , , , At effeotive depth 10. APl number _.50-_1.03-20229 At total depth 11. Reld/Poo~ 2487' FSL~ 4,42' FWL, Sec. 1.0~ T11Nr R, BE, UM , Kuparuk,, River 1'5. Present well condition summa[y Total Depth: measured 13363 feet Plugs (measured) None (approx) true vertical 6095 feet Elfeclive depth: measured 13264 test ,Ju~l~ (meaeur~l) (approx) true vertical 6029 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80' 1 6' 103 sx AS I 1 21' 1 21 ' Surface 4589' 9.625' 870 sx AS III 4630' 2871' Intermediate & 810 SX Class G Production 13312' 7m 230 SX Class G 13353' 6088' Liner - iiii III · 13018'-13030' ~' ~ ..... ' ~. .~. Tubing {size, grade, and measured depth) ORIGINAL 3,5', L-80, tbg w/tail ~ 12902' Alaska t,01]ilTl|$$. Packers and S$$V (type and measured depth) Anch0ragr~ l~ker SABL-3 Permanent Packer ~ 12877' MD _ "i3, A~tachments DescriptiOn summary o! proposal X_ 'Detsiled operation program _..." BOp sketch _ _Contact William Isaacsan at 263-4622 with any cjuestions. ,, 14, E~{imated d'~'ta for commencing operation 15. Status (~! well classification as: _.October 2{t, 1997 Oil X _ Gas ~ Suspended 16. If proposal was verbally approved Name of, approver Date approved Service ~ . 17. I hereby cattily' that the, 'foregoing is true and c~rrect to the best of my knowledge. Signed ~,~ ~.~_/! Title Orillinc. I ,Superinte~ndant Date } b"~,"~ ~ 7 - ~ FOR ~OMMISSION USE ONI-~Y ..... f / _ ~;ondil~ons of a~Proval; Not'ih/ Commission so ~epresentative may wiiness Plug integrity ~ BOP Test ~- Location clearance __ I --~.~'~ . Mechanical Integrity Te${ _.. Subsequ, B,e:nt f_o,r.nl require 10-~ original oign~u A~l)roved by the order of the Commi.~sion David W. Johnston ..... )Irt Form 10-403 Rev 06/15/88 SUBMIT INTRIPLICATE i i:~34AM ARCO ALASKA KRU 2T-38 SUNDRY OBJECTIVE P & A WELL FOIl SIDETRACK OPERATIONS (reference attached plugback a~hemati¢) CURRENT W..ELLBORE STATUS: The 7" ca~ing across the perf interval is believed to be damaged, allowing rock and sand production from the well. A rock screen was nm and set in the landing nipple at 12892' MD to control the sand and rock production, After limited mccess of controlling sand production and continued plugging of production form the well, the decision was made to sidetrack. Recent attempts to pull the rock screen were unsuccessful and attempts to inject into the well were also unsucc.~sful. WithOut access to the peris or the ability to inject into the well, down squeezing cement into the peris is not possible. Therefore, the plan to P & A the well for the upcoming sidetrack will be to set a bridge plug in the tubing at the production packer and spot a cement plug on top of the permanent packer and bridge plug. PRI~-RIC~ WORK; 1. RU slickline unit. RIH and pul1 orifice valve £rombottom GLM at 12,823' MD RKB, leaving an open pocket. Dummy off all other GLM's. . RU E-line unit. RIH with 3-I/2" Baker 'N-2' bridge plug for 9.3g/ft robing and set at 12,863' MD RKB (5' above the 'W-I' landing nil~ple).Once bridge plug ia set, bleed wellhead pressure to 0 psi and verify positive set of bridge plug. RIH with chemical cutter. Cut 3-1/2" tubing +/-5' above the 'N-2' bridge plug (as close as possible to top of bridge plug). RDMO E-line. WORKOVER RIG WORK; 1. MIRU Nordic Rig 2. Lay hard-line to tree. 2. Verify well is dead. Load pits w/water. Circulate well to water, 3. Set BPV. ND tree. NU and test BOPE. Screw in landing joint. Pull tubing hanger to rig floor. Spot a 250' cement plug on top of permanent production packer and bridge plug in 3-I/2" tubing. Pull above cement plug top and reverse circulate robing clean. POOH standing back tubing and laying down all jewelry. 5, PU Baker 7" 'N-I' permanent bridge plug on DP. RIH and set bridge plug at 12,195' MD RKB. Release from bridge plug and test wellbore to 3500 psi, testing bridge plug and cement plug to ensure isolalion from perforations. POOH standing back DP. - 6. Whipstock will be set immediately above bridge plug to allow milling of 7" casing and kicking-off for sidetrack. :, i~Y'/ i i'~4AM 1~. ~/[J Abandoned A Sand Perfs 7", 26#, t.-80 Milling Fluid AFDC0 ALAS~A !~C I',lo. 2T-38 Proposed PIL, Oack APl if: 50-103-20229 RKB = 122' Pad Level = 81' · 9-5/8" 40#, L-80 set Q 4630' MD 7" Baker'N-l' Bridge Plug @ 12,195' MD. Cement plug spotled an top of production packer up to 12,625' MD. 3-1/2" Baker 'N-2' Bridge Plug set in tubing @ 12,863' MD. 3-1/2" x 7" Baker 'SAB-I-t' permanent production packer @ 12,877' MD. ~ Rock screen set In 'D' nipple in tubing tail to help control rock/sand production. ~ .uF .... ~,orforation @ 13,01_8' M,,D - ~ /~ ~' /~ % ~"T' ~ Bottom perforation @ 13,030 MD PBTD --- 13,264' MD TD -- 13,363' MD 7" Baker 'Window Master - Bottom Trip Whipstock System' set or~ top of bridge plug. W$1 10/24/97 ,.~' E iR iq I T A u,., ,... ,.. I n d 'i' v -)' ~:J u ,~ 1 '¢/,3 'l 'J G(}ological lqa'Eer"ia'J:-z, Inver~i.:or"'/ DAT/-.',, i" DATA .... F;' t.. U S A r' ,.'.~; d r' y d i t: c h :s 8 m p 1 e s r' e q u i "' e d '¢ y ,4.~ .5' ~_ A n d r' e c e 'i v ,':: d o i,,,,,,,,,:~ s i.: h e v,,,' e 1 '1 c o r' e d ? y e s ~ A n a 1 y s i' ::i; 8: d e ::; c r" i' p -I;. 'i o i"~ t" e ,:'.': :: '¥ v ,::~ ~.t ? i~.___ R e c e i v ,.'.~ ,:J '.? y e: r'l o ARCO Alaska, Inc. Date: December 27, 1995 RETURN TO: ARCO Alaska, inc. Attn: Julie Nash Kuparuk Operations File Clerk i .~, ~,, ATe- 1119B ~ '~~% P.O. Box100360 ,~ ~.,.' "J'--_ '_~. Anchorage, AK 99510-0360 ~ Transmitted below are the following pressure items. receipt and return one signed copy of this transmittal. · 2W-05 ~-~ I Well Pressure Report 11/09/95 2 - ~s-~H Well Pressure Report 11/09/95 , ~- ~'~- ~t'z. Well Pressure Report 1 1/1 1/95 . '~H-I~H Well Pressure Report 1 1/11/95 2%37 ~ ¢-~ ~ ~ Well Pressure Report 1 1/11/95 2T-31 ~ ~--~ Well Pressure Report 1 1/12/95 Well Pressure Report 1 2T-30 ~-os-/Well Pressu~rt Receipt Acknowleged: TRANSMITTAL #9313 DISTRIBUTION: Petmtechnical Data Center BP Exploration (Alaska) inc. MB 3-3 P.O. Box 196612 Anchorage, AK 99519-6612 Please acknowledge AMERADA AMERADA AMERADA AMERADA AMERADA AMERADA AMERADA AMERADA Date: Holly Fuller c/o Chevron U.S.A., inc ~','o,,-~ '~" C,, P.O. Box 1635, Rm 3008 Houston, TX 77251 Barbara Sullivan Mobil Oil Corporation 12450 Greenspoint Drive Houston, TX 77060 Mr. Vernon E. Pringle, Jr. DeGioyer and MacNaughton One Energy Square Dallas, TX 75206 Debra Chiiders UNOCAL P.O. Box 196247 Anchorage, AK 99519-6247 :Larry Grant ~, AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Kuparuk Well Pressure Report Date Key Well ~'~ Satisfies i-I Yes l-q No ' State E] Yes · ~;~ Requirement Service Company P~ure Measurement Device: "; ~- ~r~ -.- .~ ~:~- -~- ~-.~.:~;-'*~;~;_2~:x~-~x'~:~~ ' ~.'-~'~ · ': ~-- ...... 'aLYNES' '" ' '; ~ TorqUe Turn .. ,~~~. i~me~ Identification No.. -'--~?,,;x;,~::;.:;:;;~,.~Calibration Date. ........ .. , .~ .., ..... -: ..... ~ ...... _ ~-.~:~~ · (Upper Bomb) .... (Lower Bomb) 70 .. T~e 'of Test: WL MD- RKB TVD- SS. Final Pressure Upper Bomb /fi 5/ Lower Bomb Datum Time -@/.' Pressure Dep~ '. TVD-S.S. 6200' .. End · '.; _ Start /¥ .?", Maximum Recorded Temperature: ..r~, ,,./~. -,~- ~. ,.t.~ ~.- ~. · ., -q".-, /, d-t.-... · ~ ~ '-','~ ,~ ~ ', Well SI Prior to Pressure Measurement (Date/Time): ' ~""'...,~.,~'""-,.,~. """,:.- ~'' 'Chart Quality: Operations/Engineering Representative Kuparuk Well Pressure Report Well Key Well ~ Yes F~ No Date Satisfies State- ,-, Requirement' Sewice~Company ~ Pre~ure-~Measurement Device: E] Hp I~AMERADA IZ! LYNES / .. !-I Other: ......... ; I~ment Identtficatio~ No.: (Upper Bomb) (Lower Bomb) Type-of Test: I~Static MD- RKB TVD- SS. Torque Turn Yes [] No Calibration Date:' Sand: I-] A [] C l-I Both Datum Pressure TVD-S.S. 6200' WL [] PBU Final Pressure Upper Bomb Time @ De 3th Start End Lower Bomb ~07~ .~ ~,.?? Meximum Recorded Temperature: Well SI Prior to Pressure Measurement (Date/Time): Chart Quality: Operational Engineering R~ve ARCO Alaska, Inc. Date: December 27, 1995 RETURN TO: ARCO Alaska, Inc. Attn' Julie Nash ITRANSMITTAL #9313 Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following pressure items. Please acknowledge receipt and return one signed copy of this transmittal. . ,("//2W-05 ~¢-I (1.,(Well Pressure Report 11/09/95 AMERADA //~.v 2X-08 ~r~'"'~'l Well Pressure Report 1 1/09/95 AMERADA / "- /2T-38 Well Pressure Report 11/11/95 AMERADA ~ ~-/ 22T 37¢/~'--~o~ Well Pressure Report 11/11/95 AMERADA ~ 2W_-06 ~ q-l~i~'l Well Pressure Report 11/11/95 AMERADA T-31 rf:F-~ Well Pressure Report 11/12/95 AMERADA ~, 2T-30 4-:F'-%7 Well Pressure Report 11/13/95 AMERADA k,~T-38 Well Pressu re/l~eport/,, 11/26/95 AMERADA Receipt Acknowleged,:/~/_.,~v/.//._~~'uate:~-'''cr'¢--'-''' ~ !ii~ '7 :-./?/ Petrotechnical Data Center BP Exploration (Alaska) Inc. MB 3-3 P.O. Box 196612 Anchorage, AK 99519-6612 Holly Fuller .4f~;~-.~ f///~, ~, · ~- 'COmrnbs[or~ c/o Chevron U.S.A., Inc ,~,uttorage P.O. Box 1635, Rm 3008 Houston, TX 77251 Barbara Sullivan Mobil Oil Corporation 12450 Greenspoint Drive Houston, TX 77060 Mr. Vernon E. Pringle, Jr. DeGIoyer and MacNaughton One Energy Square Dallas, TX 75206 Debra Childers UNOCAL P.O. Box 196247 Anchorage, AK 99519-6247 Larry Grant AOGCC 3001 Porcupine Drive Anchorage, AK 99501 ARCO Alaska, Inc. Date' December 26, 1995 Transmittal #: 9310 RETURN TO: ARCO Alaska, Inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATO-1119 B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. Please acknowledge receipt and return one signed copy of this transmittal. 'fj'~)(, 2T-27 CDR 04/17/95 REF #50-103-20217 r 2T-32 CDN 04/30/95 REF #50-103-20218-00 ~E'-, ,-f, ~ '--2T-32 CDR 04/30/95 REF #50-103-20218-00 ,/5'-r? 2T-30 CDR 05/12/95 REF #50-103-20219-00 ~ ~--(,"Z,~ 2V-06 TDTP 06/11/95 REF #95219 ¢y'-~'~ 2T-31 CDR 0713/95 REF #50-103-20226-00 )..~.2T-36 CDR 07/25/95 REF #50-103-20228-00 2T-36 ~¢,~ CDN 07/25/95 REF #50-103-20228-00 fC2T-38 CDR 08/03/95 REF #50-103-20229-00 %~,ll % )_2.T-38 CDN 08/03/95 REF #50-103-20229-00 ~'~-~ lo ~ 2T-37 CDR 08/10/95 REF #50-103-20227-00 ~_~ 1 Q-24 ARC5 Array Resistivity Comp. 08/30/95 4206-7270 ~_ ~-~,. 1Q-26 ARC5 Array Resistivity Comp. 09/22/95 3820-7010 ~-~ 1Q-23 ARC5 Array Resistivity Comp. 09/30/95 5156-9982 Acknowledged: DISTRIBUTION' Mr. Vernon E. Pringle Jr. DeGloyler and MacNaughton One Energy Square Dallas, TX 75206 Erickson/Zuspan NSK Central Files NSK 69 Sharon AIIsup-Drake DS Development ATO - 1205 Larry Grant AOGCC. 3001 Porcupine Drive Anchorage, AK 99501. Clifton Posey Geology ATO - 1251 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 12, 1995 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2T-38 (Permit No. 95-112) Well Completion Report Dear Mr. Commissioner: o Enclosed is the well completion report for the recent operations on KRU 2T- 38. If there are any questions, please call 265-6206. Sincerely, Supervisor Kuparuk Drill Site Development MZ/skad STATE OF ALASKA ,- .... ~KA OIL AND GAS CONSERVATION CO,vi, MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG , Status of Well Classification of Service Well OIL E~ GAS F'I SUSPENDED [~ ABANDONED [~ SERVICE ['~ .' · 2 Name of Operator 7 permif Numbgl: .. ARCO Alaska, Inc 95-112 / ,' .. , · 3 Address 8 APl Number "- /' /" ~,. P.O. Box 100360, Anchorage, AK 9951~0360 50-103-20229 ~ / / 4 Location of well at sudace 9 Unit or Lease Name 65'FSL, 556'~L, Sec. 1 T11N, R8E, UM ~ '¢'/;~;?; ;"; :.': ~ Ku~ruk River Unit At Top Producing Inte~al ; ..... '~- ~ ~ LO(~T~ ' lO Well Numar 2487'FSk, 442'FWL, 8~.lO, Tll~,~Sfi, UM .: ~ :. :~-~ ~ ':') K~UK 5 [Iovation in ~oot (indicato KB, ~F, otc.) I ~ koaso Dosi~nation and 8odal ~o~ ..... Ku~ruk ~ivor Oil ~ool I RKB 41' Pad 81' ~ ADL 25568 ALK 2666 12 Date Spudded 13 ~,e T.D. Reached 14 ~te Comp.. Susp. or A~nd. 115 Water Dep,h. i, o~hore 1~6 No. o, Comp, e,ions July 27, 1995 August 3, 1995 27-Sep-95 (~¢d)~ NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 ~r~tional Su~ey ~20 ~pth where SSSV set 21 Thic~ess of ~rmafrost 11 I 3363' M D & 6095' TVD 13264' M D & 6029' ~D YES ~ NO ~ NA feet MD - 1380' ss APPROX 22 Ty~ Electric or Other Logs Run GR/CDR/CDN 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE ~ GRADE TOP ~ HOLE SIZE ~ME~~ 16" 151.5¢ X-65 Sud. 121' 36" 103 sx AS I 9.625" 40.0¢ L-80 Sud. 4630' 12.25" 870 sx AS III ~ad, 810 sx Class G Tail 7" 26.0¢ L-80 Sud. 13353' 8.5" 230 sx Class G 24 PeRorations o~n to Production (MD+TVD of Top and BoSom and 25 TUBING RECORD inte~al, size and numar) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 12902' 12877' 13018'-13030' MD 6 spf 5866' - 5874' ~D 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13018-13030' 222,369¢ in formation (20/40 = 9240¢, 12/18=202281¢, 10/14 = 12541 27 PRODUCTION TEST Date First Production J Method of ~ration (Flowing, gas lift, etc.) ~to~r, 1995~ Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 11/29/95 18 TEST PERIOD ~ 994 1690 1 1 124 1700 FIowTubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVIS-APl (~rr) Press 350 1392 24-HOUR RATE ~ 828 1182 8 28 CORE DATA Brief description of lithology, ~rosity, Eactures, apparent dips and presen~ of oil, g~ or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 12991' 5848' Bottom Kuparuk C 13018' 5866' Top Kuparuk A 13018' 5865' Bottom Kuparuk A 13173' 5968' 31. LIST OF A-FI-ACHMENTS Daily Drilling History, Directional Survey 32. I hereby cedify that the foregoing is true and correct to the best of my knowlege. S gned Title D^T (?'""(&'- [__k' 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 Date: 10/12/95 Page: 1 ARCO Alaska Inc. DAILY DRILLING REPORT WELL:2T-38 RIG:PARKER 245 WI: 55% SECURITY:0 WELLID: AK8269 AFE: AK8269 TYPE:DEV AFE EST:$ OM/ 2223M AREA/CNTY:NORTH SLOPE STATE:AK API NUMBER:50-103-20229 FIELD: KUPARUK SPUD:07/27/95 START COMP: FINAL: 07/27/95 ( 1) TD: 135' (135) SUPV: 07/28/95 ( 2) TD: 4460' (4325) SUPV: JT 07/29/95 (3) TD: 4640'(180) SUPV:JT 07/30/95 ( 4) TD: 5651'(1011) SUPV:JT 07/31/95 ( 5) TD: 9747' (4096) SUPV: JT 08/01/95 (6) TD:11847' (2100) SUPV:JT 08/02/95 (7) TD:13018'(1171) SUPV:RLM 08/03/95 (8) TD:13363'(345) SUPV:RLM 08/04/95 (9) TD:13363'( 0) SUPV:RLM 08/05/95 (10) TD:13363' ( 0) SUPV: RLM MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 DRILLING Move from 2T-36. Accepted rig @ 0130 7/27/95. Drill to 135' . DAILY: $47,575 CUM: $47,575 ETD:SO EFC: $47,575 MW: 9.6 DRILLING Drilled from 136' to 4460'. DAILY:S92,638 CUM:$140,213 PV/YP: 16/18 APIWL: 8.2 ETD:SO EFC:$140,213 MW: 9.4 PV/Y?: 9/ 6 APIWL: 9.2 NU BOPE Drilled to 4640'. Run 9-5/8" surface casing. Cement casing. CIP @ 0110 hrs. DAILY:S206,515 CUM:$346,728 ETD:SO EFC:$346,728 MW: 9.0 PV/YP: 8/ 4 APIWL: 8.2 DRILLING Drilled to 5274'. Well control problem. Drilled to 5651' DAILY:S114,174 CUM:$460,902 ETD:SO EFC:$460,902 MW: 9.2 DRILLING Drilled from 5651' to 9747'. DAILY:S75,622 CUM:$536,524 PV/YP: 12/ 8 APIWL: 6.8 ETD:SO EFC:$536,524 MW: 9.2 DRILLING Drilled from 9747 to 11847'. DAILY:S79,302 CUM:$615,826 PV/YP: 10/ 7 APIWL: 6.8 ETD:SO EFC: $615,826 MW: 10.6 PV/YP: 18/16 APIWL: 4.8 POOH Directional drill 8.5" hole from 11847' to 13018' DAILY:S73,693 CUM:$689,519 ETD:SO EFC:$689,519 MW: 10.7 PV/YP: 18/16 APIWL: 4.6 CIRCULATE FOR CASING Directional drill 8.5" hole from 13018' to 13363'. DAILY:S78,082 CUM:$767,601 ETD:SO EFC:$767,601 MW: 10.7 RUNNING CASING Run 7" casing. DAILY:S201,863 CUM:$969,464 PV/YP: 18/14 APIWL: 4.5 ETD:SO EFC:$969,464 MW: 10.7 PV/YP: 18/14 APIWL: 4.5 RIG RELEASED Run 7" casing. Cement casing, CIP at 1227 8/4/95. Freeze Date:10/12/95 Page: 2 ARCO Alaska Inc. DAILY DRILLING REPORT protect 9-5/8"x7" annulus. Release rig 0200 8/5/95. DAILY:S101,993 CUM:$1,071,457 ETD:SO EFC:$1,071,457 REMEDIAL AND COMPLETION OPERATIONS WELL:2T-38 WELLID: AK8269 AREA/CNTY: FIELD: SPUD: RIG:NORDIC WI: 0% SECURITY:0 AFE: AK8269 TYPE:DEV AFE EST:$ OM/ 2223M STATE: API NUMBER: START COMP: FINAL: 09/20/95 (11) TD:13363' PB:13264' SUPV:MDD NU BOPS MW: 0.0 Move rig from 2T-37 to 2T-38. Rig accept at 0130 hfs 9/20/95. DAILY: $18,450 CUM:$1,089,907 ETD:S0 EFC: $1,089,907 09/21/95 (12) TD:13363' PB:13264' SUPV:DCL RIH W/ 3-1/2" DP MW: 0.0 Test casing. Run in hole with BHA and 3-1/2" DP. DAILY:S31,200 CUM:$1,121,107 ETD:SO EFC: $1,121,107 09/22/95 (13) TD:13363' PB:13264' SUPV:DCL RACK, STRAP & DRIFT 3-1/2 MW: 0.0 Run in hole to 13,143'. POH LD 3-1/2" DP. Stand back 50 stds DP in derrick. LD BHA. Pull wear bushing. Rack, strap and drift 3-1/2" completion tbg. DAILY:S36,200 CUM:$1,157,307 ETD:SO EFC:$1,157,307 09/23/95 (14) TD:13363' PB:13264' SUPV:DCL PREP TO FREEZE PROTECT W/ MW: 0.0 Rack, strap and drift 3-1/2" completion tubing. Run in hole with 3-1/2" completion assembly. Prepare to freeze protect well with diesel. DAILY:S145,682 CUM:$1,302,989 ETD:SO EFC:$1,302,989 09/24/95 (15) TD:13363' PB:13264' SUPV:DCL RIG RELEASED MW: 0.0 ND BOPE. NU tree. Test tree and packoff. Secure well. Release rig at 1000 hfs 9/23/95. DAILY: $5,210 CUM: $1,308,199 ETD:SO EFC: $1,308,199 9/28/95 Initial perforations shot 13018' - 13030', 2-1/8" BH enerjet charges. 12' @ 6spf (oriented at 90° and 270° from the lowside of the hole. Used a total of 680 bbls of diesel assisting guns down hole. End of WellSummary for Well:AK8269 z<-?:,.2,- 1- .,'" '~ ********* SCHLUMB£RCER *********************************************************** AP! ~£LL .t 50-103-20227' *********** ~URVEY PROCRAM COMPANY ARCO AL.D~A W~LL NAME 2T-3~ :::LOCATION i .-"IUPARUI : i- LOCATION 2 ALASXA MAGNETIC DEC£INATION 28,45 GRID CONV~RGEHC~ ANGLE 0,00 DA?E: 03-AUG'~5 W~LL HUMBER 0 W~LL HEAD LOCATION: ~A?(N/-D, 0,00 ~AztMU?H pROM ROTARY TABLE ?0 TARGE?-ZS ; ::-::TI£ iN pOINT(TIP) M£ASURED D£P?H 121,00 TRUE V~RT DEPTH !21,00 INCLINATION 0,00 AZIMUTH LATITUDE(N/-~) 0,00 D~PAR?URE(E/-~) 0,00 D~P(~/-W) 0.00 254,~3 D~P?H ft !2!-,~~,~ 357,00 447.00 537,00 627,00 921,16 !0!2,06 1103.63 i273,10 !479,B5 1573,20 16o/,:6 1761,51 1854,48 !948,04 2040.30 2135.25 2229~0 2324,41 2418,16 2511,07 2605,35 2698,97 2866,25 3169,09 344~,24 3727,86 4007,72 4290,61 4550,46 // 5172,72 5264,9~ 5445~a4 5636.0~ iN?ERVAk U~R?ICAL ?ARGE? ~:.~u. AZI~U?H D~P~H S~C?ION ZNCLN, ft ft ft deg d~g ~,O !2!,00 O.O0 o,00 Q,O0 O,O0 ~,.0 ~ A~ n,20 0 ~ 90.0 447,00 0,44 0.50 1B9,00 -1,0~ 70.0 536.92 3.72 4,00 261,00 -1.97 yv,v 626,26 14,26 ?,50 259.00 !12.5 736,2~ 37.61 14,53 250.52 -!0,37 92.4 )25,19 62,79 17,t4 257,47 -17o19 89,2 909,95 90.62 19,27 258,47 -22,99 90,9 995,33 !21,75 20,86 257,82 -29,4~ 91.6 t080.54 155,27 22,13 256,56 -36,84 95.6 I168,79 191,87 22,95 257.69 -45.00 93.9 1255,I7 228.69 23,27 257,57 -52°?0 ~6~4 24,20 ~4o4 1424,82 306,64 27,03" 255,35 -7!,5! 93,4 i507,88 349,24 27,28 255,I1 94.I 1590,~3 3~3.3~ 28o71 255,85 -93,43 94.3_i 1671,85 441.67 32°93 255.36 -105,45 ~3.0 1748,33~ 4?4;48 36,34 252.45 -~20,14 93,6: !821.~6~ 552,I5 3~;84 253,48 -137,03 92,8 !891.29 613,74 43.43 252,~2 -154,91 94,4 I957,49 681.02 47,54 252;59 -174,73 94,6 2018,45 ~,24 52,16 253,83 -1~5,77 ?4,6 2074.03 82?°78 55,87 254,62 -216,57 93,7 2124,39 908,83 51,14 254,31 -237,74 ?2,? 2169'43 990,08 ~2,87 254,41 -259,64 V4'3 2210,02 1075,!5I 66,13 254,75 -282,26 93,6 2246,09 i161,54 ~8.54 254.77 -304,96 187.3 2309,26:- !337,81 72,03 254°98 '350,96 282,8 2396,83 1606,73 71,70 255,97 -418,42 279,2 2488,60 1870,30 69.71 255,~! -482.47 279,6 2583,67 2133,25 70,54 254,15 -550,4t 279,9 2675,4~ 2397,57 71,i6 256.92 -616,42 283.1 2765,20 2666,01 71~..v~ ..~2,98 -A86,15. 259,6 2845,49 2912,82 72.07 253,22 -757,94 243,3 ~2 379,0 3053,4! ~oo ~-- :.,,u~ 68,50 255,13 -924,24 ?2,2 '^ o ' 65 ~ JvSV,l~ 3583.?8 ,o~ 255,82 -945,55 ,~,9 3125,56 3670,49 68,58 256,73 -966,07 86.6 Z156,12 3751,52 ?0,1! 256,2~ -984,78 · 190.6 out~ 75 3931, ~ ~., 48 71 ~ 255~53 -1028,81 D£PAR?URE DISPLAC~M~N? ~t AZIMUTH ft ft de9 0,00 0,00 0,00 -0,07 0,51 188,00 4,!6 i.10 188,36 -~ ~ 3.86 239,32 -!3,72 14,26 254,21 DLS de~/ lOOft 0,00 0,II 0.28 4,31 6,12 -3&,16 37,62 254,00 4,73- -60,37 .~.~7 254,1! 3.48 -87,6& ?0,62 255,31 2,41 -!18,18 121,78 256,03 "1F76- '!50,89 155,72 256,28 1,48 -186,59 19!,?4 256,44 -222,60 228,~0 256,63 0.34 -258.79 265,97 256,65 1,22 -2~8,~ 306;77 256,52 3,01 -339,~.~ 349,37 256,36 0.29 -382,26 393,51 256,26 -429,02 441,79 256,19 -479,75 494.57 255,94 -534,93 552,20 -593,90 613.77 255,36 -727,3 753,24 254,94 -a01,02 e t,7 254,87 -BZZ.la 908.83 254,84 -955,4 9?0,0a 254, o -!o37 44 io75,15254,7 -129o, 1337, 254, ? '!551,30 1606,73 -1807,01 1870,31 255,05 "1 4,4~'- '4,07 .3~0'-...... 3,?0__ ._ ... . 4.36 4,?~ 3,78 3,50 .4]02 0,34 O,19 -2061,04 2133,26 255,05 0.66 -2317,00 2397,60 255,10 0,96 -2576,23 2666,04 255.09 1.35 -2812,49 2912,83 254,92 0,11 .jO~~? ~+ ~ l/ ji4a,.~ ~ 254,77 0,48 -3374,76 3499,04 254,68 '3457,01 3583,V9 254,70 -354t,08 3670,50 254,74 -36i?,?0 3751,52 254,7~ -3794,48 3931,48 254,83 O,V1 2,98 3.06 1,63 0,83 M£ASURED :NT~RVAL VER?!CAL 59!5,i0 279,! 3307,7~ .~c~.64 367,5 3422,37 6658,6? 376,0 3536,61 7404,70 366,6 3775.88 7777,44 815'1,03 8525,7? 8900,55 9272,76 374,7 3901,56 371.6 4025,10 374,8 4147,81 374,8 4268.81 372.2 4386,53 9647.22 '374,5 4506,35 i0022,07 374,8 4629,8! t0397,66 375,6 4752,27 10771,70 374,0 4872,27 11147,?7 S76,~ 4990,80 11428,42 11520.32 11611,75 11703.68 11794,25 11887.05 11976.87 12067,98 12160.63 12344.51 12435.44 12527.02 12617.45 12709.44 TARGET STATION AZIMUTH LATITUD£ S~CTiDH iHCLN, ft deg de9 ft 4!~5,~5 .7t,27 . ~RK ~.. ,., ~7 -i094,~i . 4545.15 72.40 255.12 -i183.i7 4903.42 72.23 255.24 -i274.79 5609.91 70.77 256,01 -!449.7~ E/..W ft ft -4050,60 4195,95 -4388,45 4545,15 -4734,82 4903,43 -5419,38 5609,~5 12800.21 !2917.?0 13072.60 13285.57 I3a6..o0 5962.69 70.04 ..~",74 6313,32 71.12 254.85 6667.41 70.65 254,8? 7022.!1 71.68 254,66 7375,21 7!,45 254,83 7729.97 7i,23 254,25 8083,68 Z0,31 255.95 8438,87 7!,63 256,03 ~793 'e - ,~g 70,95 255,07 9150.20 72o~a 255.2J 280,5 5085.36 9414,14 68,25 253,18 91.? 91.9 90,6 92.8 ?1.1 92.0 90.9 :91.6 ~0.4 92.0 5120'17 cY4?9.U 67,24 5232,48 9748,95 65,30 5272,80 9832,5~ 5313,68 9912,46 62,66 5355,55 9993,35 62,63 5398,3t I007~,5I 62,41 5440,86 10156,96 62,44 _ 5526.5~ 10318,53 6t,87 5570,70~ 103~8,77 60,54 5617.!2 10476.38 57.69 5669,21 10552.I6 53.32 253.63 253,62 ~253.92 253,43 253.46 253.61 252,~2 253.24 255,73 255,07 254,6~ 254,49 255.0! I17.7 154,7 213.0 77.4 5724.98 10623.76 50.86 5800.45 lOZI4.0J 49.38 5901.96 10830.78 48.61 6043,53 10989,75 48,07 PROJ~C?~D ?O TD 6095,27 11047.26 48.07 255.21 255,70 256.28 257,79 ~57,79 -1535,?1 -5761,74 -t624,88 -6100,70 -1717,31 -6442,52 -1810,45- -6784,76 -1903,36 -7125,43 -t997,93 -7467,36 -2088,94 -7809,37 -2!74,91 -B!53,86 -2263.34 -8496,?i -2354,86 -~842,09 -2450,61 -~I77,64 -2474,30 -9250,!2 -2497.68 -9338,47 -2520,82 -9417,46 -2544.62 -9497,5& -2567.27 -9574.27 -25'"/0.,.~'7_,, -Q651,. . ,76 -2614,50 -9730,40 -2636,29 -2756,4! -10259,98 -2779,09 -I0347,39 -2807,36 -10460,65 -2843.05 -I06i5,69 -2855,23 -I0671,99 5962,74 6313.39 6667,47 7022.16 7375,2J 7730.02 8083.93 B438.~4 '8793.'16 9150 ~ 9414,2! 9499,24 9583,06 9666,72 9749,00 9832,55 9712.50 9993.38 10075,53 10156,~8 10238.34 i0318.55 10398.80 10476,40 !0552.19 10623.7? 10714.09 I0830.81 !0989.80 11047.34 AZIMUTH 254,5~ 255,02 255,07 255,09 255,07 255,06 255,04 255,02 255,02 255,06 255,09 255,06 255,05 255,04 255,03 255,01 255,00 254,99 254,98 254.96 254.~6 254,96 254,~6 254,96 254,95 ~54,96 254,96 254.97 254.98 255.01 255.02 DLS deg/ lOOft 0,09 0,33 0,05 0,33 0,11 0,2I 0,37 0,13 0,28 0,07 0,16 0,49. 0,35 0,30 0,37' 1,6I 1,28 0,52" 0,50, 2.28 0.6I 0,68 0.39 .2/~0 0.82 1,46: 3,19 4,81- 2,77 1.30 0.57 0,59 0,03 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9841 10/25/95 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 LIS Well Job # Log Description Date BL RF Sepia DIR MWD Tape 2T-38 CDR 950803 I 1 2T-38 CDN 950803 I 1 2T-38 95299 CDR/CDN 950803 I SIGNED' Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: ,. ...... , 00'i" /-\lasi,,a u~; & fir::? 5' ":s :. ......... ,:ssior~' Anchorage ALASKA OIL AND GAS ' CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 24, 1995 Michael Zanghi, Drill Site Develop. Supv. ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2T-38 ARCO Alaska, Inc. Permit No 95-112 Surf Loc 65'FSL, 556'FWL, Sec. 1, T11N, R8E, UM Btmhole Loc 2415'FSL, 308'FWL, Sec. 10, T11N, R8E, UM Dear Mr Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector 659-3607. David W. "-'~--~' Chairman ORDER BY OF'THE~COMMISSlON /enci c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA AL~JKA OIL AND GAS CONSERVATION COMMI3o,ON PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [] lb Type of Well Exploratory [] Stratigraphic Test [] Development Oil X Re-Entry [--1 Deepen [] Service [] Development Gas E] single zone X Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 81' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25568, ALK 2666 4. LocaUon of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.025) 65' FSL, 556' FWL, Sec. 1, T11N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 2500' FSL, 623' FWL, Sec. 10, T11N, R8E, UM 2T-38 #U-630610 At total depth 9. Approximate spud date Amount 2415' FSL, 308' FWL, Sec. 10, T11N, R8E, UM 7/27/95 $200,000 1 2. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2T-14 13540' MD 2500 ~ TD feet 9.0' ~ 625' MD feet 2560 6152' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 500' feet Maximum hole angle 70.58° Maximurnsudace 1700 pslg At total depth (TVD) 3100 pslg 18. Casing program Settin~ Depth size Specifications Top Bottom Quantit~ of cement Hole Casin~ Weight Grade Coupling Length MD TVD MD TVD (include stage dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +P00 CF 12.25" 9.625" 40.0# L-80 BTC 4529' 41' 41' 4570' 2872' 890 Sx Arcticset III & HF-ERW 760 Sx Class G 8.5" 7" 26.0# L-80 BTCMOE 13499 41' 41' 13540' 6152' 230SxClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary . Total depth: measured fee't Plugs (~;as'~red) true vertical feet ..,, Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured deoth .- True Vertical depth ....: ...'. ~,--, ~" r~' t ~ ~ ',~ Structural .,,; {7, i,, t~ ~ Conductor i;'- i~. ~... ~,~ ~i ;~ ~, ~-''~ Surface Intermediate Production L]' U !__ r-~(. {:!- -,, ;7, .-,,~.. Liner Perforation depth: measured l>~L:;.~'.,r~ uu ~'~ iiia.S O01i~. COrFh~.qJ~;~iOri true vertical ~[I~;FIU,'.~ ~ 20. Attachments Filing fee X Property plat E] BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot E] Refraction analysis E] Seabed report E] 20 AAC 25.050 requirements X 21. I hereby ce~fy that tt e foregoing i~ true and correct to the best of my knowledge · Title Drill Site Develop. Supv. Date"~' ~" {' ,/'"~ commission use only . Permit_Number ] A-'~I r~a,toer _ ~ I Approval date _~ ~ See cover letter for I other rec~uirements Cond(tions of approval Samples required D Yes ~ No Mud log required E] Yes ~ No Hydrogen sulfide measures J~ Yes [] No Directional survey required ~ Yes E] No Required working pressure forBOPE E] 2M I~1 3M E] 5M D 1OM [] 15M Other: drtg~na.! Signed By by order of Approved by David W. Johnston Commissioner the commission Date "~- 2.-?-- ?~"~ Form 10-401 Rev. 7-24-89 Submit in triplicate GENERAL DRIllING PROCEDURE KUPARUK RIVER FIELD 2T-38 , , . . 10. 11. 12. 14. 15. 16. 17. Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4,570')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE to 3000 psi. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (13,540') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAO 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & either full opening valve (if logging planned) or master valve and upper tree assembly (if no logging planned). Note: As a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. Secure well and release rig. Move in and dg up Nordic #1. Install and test BOPE. Pressure test 7" casing to 3500 psi. Perforate and run completion assembly. Set and pressure test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. DRILLING FLUID PROGRAM Well 2T-38 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 +10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 10.6 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drillina Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, 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/ff. This'Shows that formation breakdown would occur before a surface pressure of 1,700 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 2T-38 is 2T-14. As designed, the minimum distance between the two wells would be 9.0' @ 625' MD. Annular Pumping Activities: Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2T-38 surface/production casing annulus will be filled with diesel after setting 7" and prior to the drilling rig moving off of the well. if isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface. ~. It is requested that 2T-38 be permitted for annular pumping occurring as a result of the ddlling project on DS 2T, per proposed regulations 20 AAC 25.005 (k). Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Surface casing will be set in the Creatceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow since they act as the cap rock for the Tabasco Sands, where hydrocarbon accumulations are present. Generally, the surface casing shoe is set 200' vertical below the base of the West Sak into the heart of the shales. Drillin~ Area Risks- Risks in the 2T-38 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. The 7" casing will be topset above the Kuparuk and a 5" liner run to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 10.6 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. iCreoted by : jones For: D PETRASH iDate plotted : 18-Jul-95 iPIot Reference is 58 Version #4. IC~ordinates are in feet reference slot , !True Vert:ical Depths are reference RKB. ARCO ALASKA, Inc. Structure : Pod 2T Well : 38 Field : Kuparuk River Unit Location : Not"th Slope, Alaska < - - W e s f Scale 1 ' .325.00 11050 10400 9750 9100 8450 7800 7150 6500 5850 5200 4550 3900 3250 2600 1950 1300 650 0 650 · o~ ~ ~,. WD=5878 TMD=1,511 5 TD LOCATION: SOUTH 2845 WEST 10493 2415' FSL, 308' ~L SEC. 10, T~N, R8E ~~% S 74.03 DEG W % 10872' (T0 TARGET) 650 _ O O 650 _ _ ._C ~3o0_ CL - db 1950_ 2600~ 3250_ - 3900_ _ 4550_ -' 5200_ RKB ELEVATION: 122' KOP 7VD=500 TMD=500 DEP=O 5.00 9.O0 15.00 BUILD 3 DEG / 100' 21.00 5850[ 6500J 650 .. 0 g 650 ('~ 0 ~oo ~- 1950 J I _2600 _3250 SURFACE LOCATION: 65' FSL, 556' FWL SEC, 1, Tll, ROE J I I I t I I I i I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 650 0 650 i 300 1950 2600 .$250 3900 4550 5200 5850 6500 7150 7800 8450 9100 9750 10400 11050 11700 Scale 1 ' ,$25.00 Vertical Section on 254.8,5 azimuth with reference 0.00 N, 0.00 E from slot #`58 Created by : jones For: D PETP, ASH ;Date plotted : 18-Jul-95 !Plot Reference is 58 Version #4. · iCoordinates are in feet reference slot #58. ~True Vertical De are reference RKB. ARCO ALASKA, Inc. Structure : Pad 2T Well : 58 Field : Kuparuk River Unit Location : North Slope, Alaska <: West sco,~ ~. 10.oo 280 260 240 220 200 180 160 140 120 100 80 60 40 20 0 20 40 140 F I I I I I I I I I I I I ! I I I I I I ! I I I I I I I I I I I I I 120 100 ~ ~o ~ ~ 0 6O 100 .. ~ ~2o 1900 2000 2100 33O0 34O0 2200 1600 9O0 1000 700 9O0 1000 I I I I I I I I I I I I I I t I I I I I I I I I I I 280 260 240 220 200 180 160 140 120 1 O0 80 60 40 20 0 20 40 < Wesf ~o,~ ~. ~o.oo 140 _ 120 _ _ 100 _ 80 _ 6O 20 I o 22 0 f2o _~ 80 100 120 O O ! I V 92O 120 _ 80 _ _ 4O - ~0 120 160 200 240 280 320 36o _~ 400 920 880 840 800 I I I I I I i I I 880 84-0 800 76O I 720 I A~CO ALASKA, Inc. Structure : Pad 2T Well ; .58 Field : Kuporuk River Unit Location : Nor'Ih Slope, Alaska Created by : jones For: D PETRASHI iDate plotted : 18-Jul-95 ,; Plot Reference is 38 Version #4. i Coordinates are in feet reference slot #.38.1 True Vertical Depths are reference RKB. <-- West 680 640 600 560 520 480 440 400 360 520 280 I I I I I I I I I I 240 f 120 80 ~o0o 0 8O 160 2OO ..____..~--- 240 '~°°o ~ 280 [ oo I I i I I I I I I I I I I I I I I I I I I t I I I I / 760 720 680 640 600 560 520 480 440 400 560 ~20 280 240 < West Scale 1 ' 20.00 I I V UPARUK RIVER UNI: 20" DIVERTER SCHEMATIC 6 4 3 I DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. . MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 11/9/94 I I I J I I 13 5/8" 5000 PS,,..-'3OP STACK A¢CUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURETHAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER UMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD W1TH WATER. 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 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE UNE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE UNES. 7.TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, ENES, AND CHOKES WITH A 250 PSI LOW AND 31300 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOll'OM PIPE RAMS. TEST BO'ri'OM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BUND RAMS AND TESTTO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BUND RAMS AND RECOVER TEST PLIJG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 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 ~PLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13~c~" - 5(XX) PSI SPACER SPOOL 4. 13~/8"-~ PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL UNES 6. 195/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BUND RAMS ON BTM 7. 1:~5/8" - 5000 PSI ANNULAR WELL PERMIT CHECKLIST COMPANY GEOL AREA ~:~ UNIT# PROGRAM: exp [] dev~ redrll [] serv [] o /o F ADMINISTRATION 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary.. 6. Well located proper distance from other wells ...... '7. Sufficient acreage available in drilling unit ...... 8. If deviated, is wellbore plat included ......... 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval.. 13. Can permit be approved before 15-day wait ....... ENGINEERING 14. Conductor string provided ............... .~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg.. N 17. CMT vol adequate to tie-in long string to surf csg . . .,.~Y 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. Y~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate . N 25. BOPEs adequate ..................... N 26. BOPE press rating adequate; test to ~O'/3-~ psig. N 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of ~2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y ~/ 31. Data presented on potential overpressure zones ..... Y/N 32. Seismic analysis gf shallow gas zones .......... y N 33. Seabed condition survey (if off-shore) ........ /Y N 34. Contact name/phone for weekly progress reports . . .j. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: _ Comments/Instructions: Z 0 HOW/jo - A%FORMS~cheldist rev 03/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. ALASKA COMPUTING CENTER SCHLUMBERGER COMPANY NAME : ARCO ALASKA, INC. WELL NAME : 2T-38 FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-103-20228-00 REFERENCE NO : 95299 LIS Tape Veri~|cation Listi'ng Schlumberger Alaska Computing Center 23-0CT-1995 08:45 **** REEL HEADER SERVICE NAME : EDIT DATE : 95/i0/23 ORIGIN : FLIC REEL NAME : 95299 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., KUPARUK 2T-38, API #50-103-20229-00 ***~ TAPE HEADER SERVICE NAME : EDIT DATE : 95/19/23 ORIGIN : FLIC TAPE NAME : 95299 CONTINUATION # : PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., KUPARUK 2T-38, API #59-193-29229-99 TAPE HEADER KUPARUK RIVER MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA 2T-38 591932922899 ARCO ALASKA~ INC. SCHLUMBERGER WELL SERVICES 23-0CT-95 BIT RUN 1 BIT RUN 2 BlT RUN 3 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 9) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 95299 ST.AMOUR MORRISON 95299 ST.AMOUR MORRISON 1 llN BE 65 556 122.99 122.99 89.59 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 8.599 9.875 4649.9 PAGE: LIS Tape Verification Listi',ag ~ Schlumberger Alaska Computing Center 25-0CT-1995 08:45 3RD STRING PRODUCTION STRING REMARKS: Well drilled 2g-JUL through 3-AUG-g5 with CDR & CDN. All data was collected in a two bit runs, $ $ PAGE: *=** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 95/10/23 MAX EEC SIZE : ~024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT': FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH CDR 4630.0 13322.0 CDN 4630.0 [3256.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE LDW~ TOOL CODE BIT RUN NO. MERGE TOP MERGE BASE MWI) [ 4630.0 13018.0 MWD 2 13018.0 13322.0 REMARKS: NO depth adjustments were applied as per Dave Sharer of ARCO. This file also contains the Very Enhanced QRO resisitivit¥ with 2' average that was reprocessed at GeoQuest. $ LIS FORMAT DATA LIS Tape Verification List?ng " Schlumberger Alaska Computing Center 23-0CT-1995 08:45 PAGE: DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 0 SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SiZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CDDE (HEX) DEPT FT 548225 0~ 000 00 0 1 1 1 4 68 00000000~0 RA MWD OHMM 548225 ~0 000 00 0 1 1 1 4 68 00000~000~ RP MWl) OHMM 548225 00 00~ 00 ~ 1 1 1 4 68 00000~00~ VRA MWD OHMM 548225 ~0 000 0~ ~ 1 1 1 4 68 000000~0~0 VRP MWD OHMM 548225 eO 000 0~ 0 1 1 1 4 68 000~0~0~0 DER MWl) OHMM 548225 00 000 00 0 1 1 1 4 68 eOOeO~O ROP MWD FPHR 548225 00 00e Oe e I 1 I 4 68 00000e0000 FET MWD HR 548225 ~0 000 00 ~ 1 1 I 4 68 0000~0~000 GR MWD GAPI 548225 00 000 00 0 1 1 1 4 68 0~00000000 RHOB MWD G/C3 548225 00 000 00 0 1 1 1 4 68 00000~00~0 DRHO MWD G/C3 548225 ~0 000 00 0 1 1 1 4 68 0000000~00 PEF MWD BN/E 548225 ~ 000 00 0 1 t 1 4 68 0~000~0~0~ CALN MWD IN 548225 00 000 00 0 1 1 1 4 68 000e~o~oeo NPHI MWD PU-S 548225 00 000 0~ 0 1 1 I 4 68 00000~00~0 DATA DEPt. 13362.000 RA.MWD -999.250 RP.MWD -999.25e VRA.MWD VRP,MWD -999,250 DER,MWD -999,250 ROP.MWD [04.044 FET,MWD GR,MWD -999,250 RHOB,MWD -999,250 DRHO.MWD -999.250 PEF.MWD CALN.MWD -999,250 NPHI.MWD -999.250 -999.250 -99~.25e -999.25~ LIS Tape Verification Listi'n~ "' Schlumberger Alaska Computing Center 23-OCT-~995 ~8:45 PAGE: DEPT. 4505.900 RA.MWD VRP.MWD -999.259 DER.MWD GR.MWD -999.259 RHOB.MWD CALN.MWD -999.259 NPHI.MWD -999.259 RP.MWD -999.250 ROP.MWD -999.259 DRHO.MWD 59.699 -999.259 VRA.MWD -999.259 FET.MWD -999.259 PEF.MWD -999.259 -999.250 -999.250 END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .991 SERVICE : FLIC VERSION : 991C91 DATE : 95/10/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 95/10/23 ORIGIN ': FLIC TAPE NAME : 95299 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC.~ KUPARUK 2T-35~ API #59-193-29229-00 **** REEL TRAILER SERVICE NAME : EDIT DATE : 95/10/23 ORIGIN : FLIC REEL NAME : 95299 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC.~ KUPARUK 2T-38, API #59-103-20229-99