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Home My WebLink About194-125 • • Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Thursday, December 1, 2016 11:47 AM To: Guhl, Meredith D (DOA); Lastufka, Joseph N (Joseph.Lastufka@bp.com) Cc: Bettis, Patricia K (DOA) Subject: PBU 09-36BL (PTD#194-125) - API Number Conundrum SCANNED Meredith and Joe, J U 2 201x', Recommendation Changing a long-established index number will have a ripple effect outside of AOGCC's records. So, even though the "62" suffix within the API number for PBU 09-36BL does not conform to current practices, I recommend leaving the API number of 50-029-21429-62-00 unchanged in AOGCC's electronic and paper records. A copy of this email will be placed in the PBU 09-36BL well history file and within AOGCC's database to mitigate future confusion. Background Per the well history file, PBU 09-36BL was one of the initial "multilateral"wellbores drilled in Alaska.According to correspondence in the well history file, at that time the AOGCC contacted the American Petroleum Institute seeking guidance regarding proper numbering of these new types of wellbores. At the time the AOGCC issued the Permit to Drill for this wellbore,the AOGCC was apparently in the process of developing a permanent numbering scheme. Explanation Under current practices, the AOGCC would have assigned an API number of 50-029-21429-60-00 and the name PBU 09- 36AL1 to this particular wellbore, as it is the first lateral well branch drilled from well PBU 09-36A. But current naming/ numbering conventions were developed later. If this wellbore were a redrill of 09-36A, it would have been named 09-36B with an API number of 50-029-21429-02- 00. But this wellbore cannot be classified as a redrill because 1) all production was reported against the main well 09- 36A(through June 1995), and 2) this wellbore and the parent wellbore 09-36A were both assigned the same abandonment date of August 28, 1995. So, PBU 09-36BL is most properly classified as a lateral well branch. When the AOGCC assigns an API number to an offshore well, the convention is to add 600 to the three-digit"county code" portion of the API number. For example, a Cook Inlet well drilled onshore within the Kenai USGS Quadrangle begins with the code "50-133-XXXXX-XX-XX", but a well that is drilled offshore begins with the code "50-733-XXXXX-XX- XX". This is a long-established practice. I believe the AOGCC applied similar logic to the initial numbering of the then-new "multilateral" PBU 09-36BL. When this particular wellbore was permitted, it appears as though the AOGCC added "60" to the normal sequential sidetrack code ("02")that would have been applied had this wellbore been a redrill (but it is not). The result is the "62" suffix that was utilized in the API number(50-029-21429-62-00) assigned on the Permit to Drill form and subsequently used on other records for that wellbore. This API number(50-029-21429-62-00) was applied to all of the original records from the well. One of AOGCC's statistical technicians subsequently hand-changed that API number to 50-029-21429-02-00. My review of the well records indicates this change was an error on the part of that particular technician.The originally assigned API number of 50-029-21429-62-00 should be retained to minimize confusion. Please let me know if you have any questions. • • Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 2 O1'4 O1t BEFORE ANtjARy 03 200 ,Seo'iog{ca'l Hater"i::.-'~'is Inven'tor'y P !:! R l,'l i '1" D A T A T D A T A ....F:' L. U S I) a 't e" .j C 8/' / 8/' ~:', 6 .9L~'~'125 L.iP~WD 'SR/'I~D L 9200 .... 9700 J 9,q'"'125 ~HWD GR/TViS' L. 8750'"9000 1 8~'"'~25 L'~i'~WD "2TF/'i~D L 9~00"9850 '1 Ar'e cir'y clutch samp'las r"equi'" '? yes ~And r'ecei'ved'~ J 'e G .,.1 ,:~ ::~i l'l ,:. ':,_ Wa s t h e we J 'J (3 o r'e d ;? y e s i~____i~ iq a i y s ~' s &. d e s c r" 'i p t '¥ o n r' e c e '¥ ~{~ ;,,- e ::-., ~:) PLUGGING & LOCATION CLEARANCE REPORT State of Alaska .ALASKA OiL & GAS CONSERVATION COM~ISSION -. Note casing size, wt, depth, cm= vol, & procedure. Review the well file, and-comment on plugging, well head st. atus, and location clearance- provide.loc, clear, cod~. Well head cut off: -' Marker post or plate: Location Clearance: Conclusions: Code Signed Date STATE OF ALASKA , AL..,.,KA OIL AND GAS CONSERVATION COI~,,.,ilSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of We~l Classification ~ Service Well OIL r~ GAs ~] SUSPENDED [-'"] ABANDONED [~ SERV1CE ~ 2 Name ot Opera~ 7 Permit Number ARCO Alaska. Inc 94-125 3 Address 8 APl Numl:~er P.O. Box 1..00360. Anchorage, AK 99510-0360 50-029-21429~2 4 Location of w~l~ at suriace ................. ~,~.; 9 Unit or Le,~se Narne 1874' NSL 37 WEL Sec 2, T10N, R15E UM ~ '--"~"~'~" ~ ~'¥~'~1~ PRUDHOE BAY UNIT AtTopProduc:mgin~ i! ~f~_ i! 10 WollNumcer 2915' NSL 51' EWL, Sec 1, T10N, R15E UM ii 9.::- - 9-,'.'~BL At Total Dept~ ~...J. ~ ,~ ....... ~. 11 Field anct .~ol 3410' NSL 148' EWL, Sec 1, T10N, R15E UM PRUDHOE BAY FIELD 5 Elevat,:m in f~ (indica'~ KB, DF, etc.) I 6 Lease Designau(m ano Serial No. PRUDHOE BAY OIL POOL RKB 53'{ ADL 28327 12 Date Si3uddec 13 Date T.D. Reached 14 Date Comp., S~;..~m or Aband. 15 Water Depth, if offs'-,are 116 No. ol Completions 4,/1/93. 10/10/94. 8/28/95 (P & A'~. N/A feet MSLI 1 17TotaJDepth(M1D+TVD~. 18 Plug Back Depth (MD+TVD) 19 DireclJonaJSur,,~s,y 120 Depth where SSSV set 121 Thickness ot permafrost 9627' MD / 899~' TVD 9225' MD (8/28/95 TOC) YES ~ NO CI 2200' feet MDI 1900' (approx) 22 Type Electric c~. Other LC(JS Run None 23 CASING, LINER AND CEMENTING RECORD i SETTING DEPTH MD CASING SIZE I WT. PER FT. GRADE TOP BOTTOM :---tOLE SIZE CEMENTING RECORD AMOUNT PULLED . 20' i 91.5 # H-40 Surf 113' 30' 1810 # Polyurebhane 13-,.3/8' i 72 ~. 68 # L-80/K-55 Surf 2496' 17-1/2' 2175 sx PF "E" & 400 sx PF 'C" 9-5/8" i 47.0 # L-80 Surf 8300' 12-1/4' 500 sx G & 300 sx PF "C' 7' ! 29.0 # NT-80/13CR 8126' 9532' 8-1/2' 354 cuft Class "G" 24 Pedora~ns crmen to Pm'duction (MD+'I-VD of Top and Bottom and 25 TUBING RECCRD intenrsJ, size am:l hum:er) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2' 8992' 8853' Nooe. 26 ACID, FRACTURE, CEM~"T SQUEEZE, ETC D~----'TH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Produc-,~n IMethed o1 Operation (Flowing, gas ~ etc.) 10/18/94. I Plugged & Aba,,,,.~,ned - 8/28/95. Date of Test iHoursTested PRODUCTION FOR 'OIL-BBL GA,S-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD 15 Row Tubing ,~=~L,3g Pressure CALCULATED OIL--BBL GA.S-MCF WATER-BBL OIL GRAVITY-APl (corr) ~ - 24-HOUR RA'I'E 15 ~ CORE DATA Brief (:lesc~tion ~:. lilho~o~, porosity, fractures, apparent dips ana presence of oil, gas or wa:l~,'. Submit core chips. *Note: ~ P&A operations summary attached. . ,~.' * This 10-4C';7 su~ as directed per 10-403 approved o~ 7/12_/95 (Apprvl # 95-127). Form 10.-407 Rev. 7-1-.80 CON'rlINRAED ON ~ SINE GE(:~DIGIC ~ ~TION TESTS N,NVE Include interval tested, pressure data, all fluids recoverd and gravity, lVlEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 9037' 8693' N/A Top of Zone 3 9104' 8730' Top of Zone 2 9180' 8770' Top of Zone lB 9530' 8958' 31. LIST OF ATTACI-lvlENTS Summary of 9-36BL Plu~ & Aband~t Operations. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Sigr~,~,~ C, ~ .Title Enoineedr~ Suoervisor Date 1/~/~' /~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification o~ 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 oo 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 set,irate form for each additional ~terval to be separately produced, showing the data pertinent to such ~tervai. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). item 23: Attached supplemental records for this well .st~uld show the details of any multiple stage cement- ing and the location of lhe cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Subrrl~..s~,ibJL~,, .W,~t~r~J~,j jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". JAN 6 1 96 I~.~ .,~. ' ' A! ...... Oi! Ga.~ Cons, Con~m~sslon Anchorage Fem~ 10407 9-36BL DESCRIPTION OF WORK COMPLETED PRE-SIDETRACK CEMENT PLUG & ABANDONMENT 8/27/95 · MIRU CTU & PT equipment. RIH w/CT to tag fill at 7621' MD. Jetted a fill cleanout w/biozan to 7848' MD. POOH w/CT & RU fluid handling equipment. RIH w/CT & continued jerdng fill cleanout w/biozan to 9300' MD. 8128/95: Washed fill down to 9442' MD, then lost returns. Pumped a 30 bbl liquid casing pill & regained partial returns. POOH w/CT. RIH w/cementing nozzle to 9440' MD, then pumped an additional 25 bbls of liquid casing from 9440' to 9400' MD. PU & circulated at 7000' MD w/1:1 returns. RIH & washed LC pill down to 9435' MD. PU to 8992' MD & circulated out LCM w/1:1 returns. Pumped 2 bbls of 17 ppg Neat Class G cement, followed by 18 bbls of Class G cement w/4.5 ppb fibers BWOC, to abandon the openhole wellbore section at: 9452 - 9627' MD (Z1) Ref. Log: BHCS 4/6/93. Contaminated cement w/biozan & jetted contaminated cement from wellbore down to 9225' MD. Jetted OOH w/CT. RDMO CTU. Coil Tubing Sidetrack Drilling operations to 9-36C were started on 9/4/95. ~-" STATE OF ALASKA ALASKA AND GAS CONSERVATION ' AISSION APPLICA FOR SUNDRY APPROVALS pe of Request: Abandon X Suspend Operation shutdown Alter casing Repair well Plugging X Change approved program Pull tubing 2. Name of Operator ARCO Alaska, Inc. Re-enter suspended well Time extension Stimulate Variance Perforate 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development X., Exploratory Stratigraphic ,, _ Service 4. Location of well at surface 1874' NSL, 37' WEL, Sec. 2, T10N, R15E, UM. At top of productive interval 2915' NSL, 51' EWL, Sec. 1, T10N, R15E, UM. At effective depth At total depth 3410' NSL, 148' EWL, Sec. 1, T10N, R15E, UM. 12. Present well condition summary Total depth' measured true vertical 9627 feet Plugs(measured) 8998 feet Effective depth' measured 9627 feet true vertical 8998 feet Junk(measured) Other 6. Datum of elevation(DF or KB) 53 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-36BL 9. Permit number 94-125 10. APl number 50- 029-214294~ 11. Field/Pool Prudhoe Bay Oil Pool ORIGINAL Casing Length Size Cemented Measured depth True vertical depth Conductor 113' 20" 1810# Polyurethane 113' 113' Surface 2443' 13-3/8" 2175 sx PF 'E'& 400 sx PF 'C' 2496' 2496' Production 8247' 9-5/8" 500 sx G & 300 sx PF 'C' 8300' 8195' Liner 1406' 7" 354 cuft 'G' 9532' 8955' RECEIVED Perforation depth: measured Openhole: 9452-9627' ,IUIN 2. 9 1995 true vertical Openhole' 8917-8998' Alaska 0il & Gas Cons. Commission Anchor.'. Tubing (size, grade, and measured depth) 7", NSCC, Tbg @ 31' MD; 4-1/2", 12.6#, 13 CR, Tbg @ 8992' MD. Packers and SSSV (type and measured depth) Baker SABL-3 Packer @ 8853' MD; Camco TRDP-4A SSSV @ 2200' MD. 13. Attachments Description summary of proposal ~ Detailed operations program BOP sketch 14. Estimated date for commencing operation July, 1995 16. If proposal was verbally approved Oil x Gas Name of approver Date approved Service 17. I he~_.~by certify that the foregoing is true and correct to the best of my knowledge. Signed~'~ ~%----~..~ '~-. ~ Title Engineering Supervisor / \ /~ '~ FOR COMMIS~ION USI= ONLY Conditionskef/approval: Notify/Com~n so representative may witness Plug integrity ¢ BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Original Signea By David W. Johnston Approved by order of the Commissioner 15. Status of well classification as: Suspended Date Approved Copy 'V, om m,~ss IO rlef Approval No;~:::~~/~ 7 Date Form 10-403 Rev 06/15/88 RI W cc: KZ. JWP SUBMIT IN TRIPLICATE DS 9-36BL Intended P&A Procedure Objective' P&A existing interval in preparation for CT sidetracking operations. Intended Procedure · RU coiled tubing unit. Clean out fill and tag bottom · Pump 10 bbls Class 'G', 17 ppg fibered cement. · Clean cement top to -~9305' md (KOP for CTU drilling at 9350') · WOC, Tag top of cement, pressure test to 1500 psi. June 26, 1995 6 5 4 3 2 C0],LED TUBINt~ UNIT BOP EOU ! PHENT 1. 5000 PS! 7" WELLHEAD CONNECTOR FLAEGE 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PS! 4 1/16" STUFFING BOX i 4 2 RECEI'¥iE dU~ 2 Alaska Oil & Gas Cons. Commission Anchors H]REL]NE BOP EOU]PHENT I I. 5000 PSI ?" WELLHEAD CONNECIOR fLANGE 2. 5000 PSI WIRELIN£ RAMS (VARIABLE SIZE) 5. 5000 PS~ 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN:. Sherrie RECEIVED APR 1 1995 Alaska 011 & Gas Cons. Commission Anchorage NO. 9391 Company: 4/1 1/95 Alaska Oil & Gas Cons Comm At. tn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log' Description Date BL RF Sepia DIR MWD Disk D.S. 6-9 ~ 95055 CNTD ' 01 2395 1 .......... D.S. 4-35 "~ 95085 DUAL BURST-TDT-P 022895 1 ..... D.S. 14-3 '"'J 94187 REDO CNTD 032894 1 D.S. 2-16A'''-J 95147 REDO MWDGR , 102394 1 D.S. 1-06 "'-J 94399 REDO DUAL BURST TDT-P 061394 1 ..... D.S. 4-19 95106 DUAL BURST TDT-P 031795 1 ,, D.S. 9-36 BL''''J 95025 . ~MWDGR 101294 1 ,, , D.S. 1-06A"--J CBT 032495 1 · 1 .... D.S. 1-06A""-J CNTG 032495 I 1 D.S. 1-22A "'-J PERF RECORD 033095 I 1 ..... , , D.S. 4-12''''''~ CBT 032695 I 1 D.S. 4-12 ~ TUBG PUNCHER RECORD 032395= I 1 ..... D.S. 6-8 "'"4 PERF RECORD 032595 I 1 D.S. 7-24 '"---) PERFRECORD 032695 I 1 D.S. 11-27 "--3 BASE LINE SURVEY 032395 1 1 D.S. 9-36 BL''''J MWD GR (MD) 1 02.! 94 I 1 D.S. 9-36 BL '"J MWD GR (TVD) 1 021 94 I 1 D.S. 9-36 BL '"--J MWD GTF (MD) 1 021 94 I I PLEASE NOTE: D.S. 14-3 REDO - ORIGINAL WAS MISSING FILE #4 D.S. 2-16A REDO - MERGED TWO PREVIOUS RUNS TOGETHER (JOB # 93560 & 93561) SIGNED: ...... Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: 3/9/95 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9304 Alaska Oil & Gas Cons Comm Attn: Larry Grant (~ [ 3001 Porcupine Drive /' Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well # Log Description Date BL RF Sepia DIR MWD Disk Company: D.S. 9-36 BL#1 CT/'. DIR MWD 100394 2 D.S. 7-6, 95048 CNTD 012295 I RECEIVED SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: ~A~ ~ © I9,05 Alaska Oil & Gas Oor~s. Oommission Anchorage " STATE OF ALASKA ~ AL,- .... A OIL AND GAS CONSERVATION COM1vf~SSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Serwce Well OIL E~] GAS E~ SUSPENDED E~] ABANDONED F-] SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 94-125 3 Address 8 APl Number P.Oi Box 100360, Anchorage, AK 99510-0360 50-029-21429-O2 4 Location of well at surface 9 Unit or Lease Name 1874' NSL, 37' WEL, Sec 2, T10N, R15E UM ! ':i.?;;: ~F'~..-~';.?:-~ PRUDHOE BAY UNIT At Top Producing Interval i ' 10 Well Number 29151NSL, 51' EWL, Sec 1, T10N, R15E UM At Total Depth :; "~~i 9-36BL 11 Field and Pool 3410' NSL, 148' EWL, Sec 1, T10N, R15E UM PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. PRUDHOE BAY OIL POOL RKB 53'I ADL 28327 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband, I 15 Water Depth, if offshore 116 No. of Completions 4/1/93. 10/10/94. 10/12/94 (Comp).I N/A feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set 21 Thickness of permafrost 9627' MD 9627' MD YES ['~ NO E]I 2200' feet MD 1900' (approx) 22 Type Electric or Other Logs Run None 23 CASING, LINER AND CEMENTING RECORD SE"i-FING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5 # H-40 Surf 113' 30" 1810 # Polyurethane 13-3/8" 72 #/68 # L-80/K-55 Surf 2496' 17-1/2" 2175 sx PF "E" & 400 sx PF "C" 9-5/8" 47.0 # L-80 Surf 8300' 12-1/4" 500 sx G & 300 sx PF "C" 7" 29.0 # NT-80/13CR 8126' 9532' 8-1/2" 354 cuft Class "G" 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" 8992' 8853' 3.75" Openhole: 9452'- 9627' MD. 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 10/18/94I gas lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 12/6/94 6.0 TEST PERIOD ¢ 527 2231I 4233 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press 336 24-HOUR RATEI~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. * 9-36BL Coiled Tubing Sidetrack Drilling Summary attached. FEB -7 1995 0ii & Gas Cons. Commission Anchora~ Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 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. Top Sadlerochit 9037' 8693' N/A Top of Zone 3 9104' 8730' Top of Zone 2 9180' 8770' Top of Zone lB 9530' 8958' RECEIVED FEB -7 1995 Alaska 0il & Gas Cons. Commission Anch0ra!p 31. LIST OF A'I-I'ACHMENTS SummeR/of 9-36BL Coiled Tubing Sidetrack Drilling Operations. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed 'X..~~ ~.. //} ~ Title EngineerJnq Supervisor Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 9/26 RIH & 9/28 MIRU Milled 9-36 BL DESCRIPTION OF WORK COMPLETED R ECEI VED COILED TUBING SIDETRACK DRILLING / 9 4. FE'i9 - 7 i995 tagged cement plug top at 9446' MD. Alaska 0ii & Gas Cons. Commission / 9 4 · AJlch0ra,~ .~ CTU & PT equipment. RIH w/CT milling BHA while displacing the wellbore w/2% KCI Biozan. to 9464' MD to dress off cement plug. Jetted CCH w/BHA. 9/29/94: MU & RIH w/window cutting BHA. Started milling window through the 7" liner at 9461' MD. Milled window to 9462' MD, then POOH w/BHA. MU & RIH w/window cutting BHA. Continued cutting window to 9465' MD. POOH w/BHA. 9/30/94: RIH w/window cutting BHA & continued milling window to 9467' MD. I 0/1/94: Worked mill on window to 9468' MD. Had difficulty getting through window; PU & redrilled window cut interval several times. POOH w/BHA. MU & RIH w/GR tool w/MWD. Logged w/GR to 9450' MD, but could not pass through window. Jetted CCH w/BHA. 1 0~2~94: MU & RIH w/underreamer BHA. Underreamed pilot hole cement plug down to 9465' MD, then jetted CCH w/BHA. RIH w/CT cementing nozzle & pumped 11.3 bbls Class 'G' cement w/0.5% fibers BWOC, on top of cement plug, to spot kickoff plug. Pressured up to 1000 psi & held for 1 hour. Contaminated cement w/biozan & POOH jetting cement from 9420' MD. 1 013194: MU & RIH w/milling BHA & tagged cement at 9430' MD. Milled cement to dress off plug to 9453' MD. Jetted CCH w/BHA. RIH w/milling BHA w/GR & made Icg run. 10/4/94: Oriented BHA & milled window on high side of liner from 9452.5' to 9458' MD. RIH w/reamer BHA to ream window to 9462' MD. POOH w/BHA. MU & I 0/5/94: POOH w/BHA. MU & RIH w/drilling BHA. Survey at 9545' MD showed 60.3 degree angle. Oriented through window & drilled 3.75" hole to 9577' MD. POOH w/BHA. 1 0~6~94: MU & RIH w/tapered mill BHA. Worked mill to dress window. POOH w/BHA. I 0/7/94: MU & RIH w/diamond speed mill BHA. Continued dressing & milling on window. POOH w/BHA. I 0/8/94: MU & RIH w/window hole opener BHA. Worked mill from 9450' to 9470' MD to clean up window. POOH w/BHA. RIH w/gauge ring; tagged up & could not pass 9462' MD. POOH. MU & RIH w/reamer & nozzle BHA. Milled through window & POOH w/BHA. MU & RIH w/hole opener BHA. Milled window from 9452' to 9462' MD. POOH w/BHA. I 0/9/94: MU & RIH w/3.8" window hole opener BHA. Backreamed hole from 9470' to 9440' MD. POOH w/BHA. MU & RIH w/1 joint 2-7/8" liner dummy BHA & drifted through window to set down at 9513' MD. POOH w/drift BHA. MU & RIH w/3.75" drilling BHA. Could not pass BHA through window. POOH w/BHA. 9-36 BL DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING 10/10/94' MU & RIH w/3.75" milling BHA. Milled & washed to 9577' MD, then POOH to work mill through window. POOH w/BHA. MU & RIH w/3.75" drilling BHA. Oriented & worked BHA through window, then drilled to 9627' MD. POOH w/BHA to fix survey tool. RIH w/multishot; could not get through window. POOH. I 0/1 I/9 4' RIH w/bullnose multishot; could not get past window. POOH w/multishot. MU & RIH w/milling BHA to dress window. Milled from 9459' to 9473' MD without getting through window. POOH w/mill & displaced wellbore to Seawater for video camera. 10/12/94: RIH w/video camera to window. Saw pilot hole below window inside liner. Unable to work BHA's through window. POOH w/camera. RIH w/CT to 9400' MD & displaced well to Crude. POOH w/CT. Rigged down. Drilling operations were suspended due to problems with window. Well was placed on production as openhole completion with all production from 175' of openhole sidetrack. Rates are testing at 450 - 550 BOPD, w/2000 - 3000 BWPD, & 2500 - 3000 Mscf/D Formation Gas. Future drilling operations will be evaluated at a future date. I ECEIVED FEE - 7 1995 Alaska 0il & Gas Cons. Commlssion Anchora,~ ~- 14:58 II~t~UAL 9~¢_ iCAL F" -')ANIqDR ILL ANAl)RILL ~V~ CALCULATIONS ' CIRCULAR ARC TARGE? -Z?ATION AZIMUTH LA?ITUDIi ~qF~"TICtqIblCLN, ,,1.. 1~87,~ ~,70 I4! t,~ I~,~ ~3, ~ I0,~ 1431,8~ 2651336 D~T~ DISPI.q~T al: E/-W ft ft t~0,65 1415.72 i61,4~ 1420,11 16~,4Z 1441,~ 1470,3! 61,70 I0,80 I%4,0B 171,62 I474,1t I517'.17 ~, A. ~-0 ,D 1510,14 1~,4I 1520,87 P. 8._-", I, iO'Ig: 9.1NW~ AI %~7' I$ PRO. J~CT1ED TO ~ Bi,, DLS de c/ IOOf: 0,00 10,01 31. r~ 6, ~,." 4 rn~r,~v~.. ,.,. ARCO :":,LAS)~& INC. ~:L :~HE DS ?-36 BL~i CT LOCATION i PEtIDHOE BAY~ ~SB LOCATION 2 ALASKA -~T~ qo ~ MAG~.!o DECLiNATiON ~.~ WELL NUMBER 0 HEAD DEP',E~ -~ 0~00 AZiP,3TH ~:OM ROTARY ..... ~..:,,.~.~ ~ TO. TAE~ET iS 10,80 TiE iN POiNT<TIP) ME~oUR~ tNCLiNATIO~ ~ ~ ~!MUTH LAT!TUDE(N/-S) 1372,~ DEPARTURE<E/--Y) i~4~40 RECEIVED MAR 1 0 1995 Alaska Oil & Gas Cons. Commiss~p.n Anchorage HlCl OtlLi41 l) · ~B:'ft! L!P T~. .rt ft ft 7453~o0 i4,0 89i7,.60 SECTION iNCLN, t~/-~ ft deg 4e-9 ft i3,7~,51 57~55 ?,ii-. i.37.;',9(~ !389~34 57/~70 ~a~. 1,77 6i '!415,i7 ,~,1,.80 10,80 1410,?0 · kr'-" '~ ?q ~': iO~,~,~' 1431,83 · ..~/ ~*?--.: ._ * ,~ .. ~/'-~ ft ft !56,-'~=~ 1393,36 5,45 i60,65 ,,,~,77 £~£~' ,_ ,~, 161,48 !420,1! 165,47 144i,36 6,5? DLB dec." lOOft 3 o~ i470,3i !,! ,.70 !0,80 !464,09 lc&/,z.','. ,:,,'., .,'~., !0,85 1510,14 '=" '"" ~"" 6,.'-, ~ O0 '~."',,. 80 1535.,.81 ...'"b.2 ~. -...' 2 . ,.- !71,62 !474~,iI 6,.6? i80,41 !85 ,.30 i54,$.,'~ 6,,.68 fi"' ,.j: '3~ i~3TE: SIjRVE¥ AT 9A27' z~ FROJEu~) TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION September 23, 1994 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 James Cawvey Engineering Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Prudhoe Bay Unit DS 9-36BL ARCO Alaska, Inc. Permit No: 94-125 Sur. Loc. 18742qSL, 37'WEL, Sec. 2, T10N, R15E, UM Btmhole Loc. 3701'NSL, 4803'FEL, Sec. 1, T10N, R15E, UM Btmhole Loc. 4217'FSL, 4976'FEL, Sec. 1, T10N, R15E. UM Dear Mr. Cawvey: Enclosed is the approved application for permit to redrill the above referenced well. Please note the Comnfission has consolidated your permit applications for DS 9-36BL1 and 9-36BL2 into a single permit as DS 9-36BL. The Commission appreciates that technological change allows a drilling program that by all accounts was never envisioned by our existing regulations. The Commission is in the process of entertaining suggestions for reforming its regulations. Rather than embark on a new path at this time, the Commission will permit this drilling program with a single permit. This approach to this technology is consistent with recent permit applications approved by the Commission, but should not be viewed as an authoritative statement regarding any conclusion the Commission may reach with new regulations. The permit to redrill 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) must be given to allow a representative of the Commission to witness a test of BOPE (~ prirded on recycled paper b y .C,. t3. ~. Van Cawvey- . dO Alaska, Inc. Permit No: 94-125, DS 9-36 BL September 23, 1994 installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Ch~ilman ~_ ) -- BY ORDER OF TH MISSION dlffEnclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 September 20, 1994 James L. Cawvey, Engr Spvr Prudhoe Bay Engrg ARCO Alaska, Inc P O Box 100360 Anchorage, AK 99510-0360 Re: PBU DS 9-36BL1 and DS 9-36BL2 Application(s) for Permits to Drill Dear Mr. Cawvey: The above referenced drilling program does not constitute two wells; therefore, only one permit is required, and one permitting fee. ARCO check #00231924, dated 09/13/94, is returned herewith. ., Chairman ~ encl .~.~ pdr~md on recycled pope¢ f" STATE OF ALASKA AIJ~, ~ OIL AND GAS CONSERVATION COMMI~,0N PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill _ Redrill X I lb. Type of Well Exploratory~ Stratigraphic Test _ Development Oil .~. Re-Entry ~ Deepen _I Service _ Development Gas ~ Single Zone .~_ Multiple Zone , 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska., Ir~o, RKB 53' 3. Address 6. Property Designation P. O. Box 100360, Anchora~]e, AK 99510-0360 ADL 28327 Prudhoe Ba~//Prudhoe Bay Oil 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1874' NSL, 37' WEL, Sec 2, T10N, R15E, UM Prudhoe Bav Unit Statewide At top of productive interval 8. Well number Numbor 2915' NSL, 51' EWL, Sec 1, T10N, R15E, UM 9-36BL1 #U-63061 0 At total depth 9. Approximate spud date Amounl 3701' NSL, 4803' FEL, Sec 1, T10N, R15E, UM September, 1994 $200~000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed deplh (MD and 'I'VD) property line ADL 28324:1794 feet No Close Approach 2560 Acres 10150' MD / 9003' TVD 16. To be compleled for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 9547' MD Maximum hole angle 91° Maximum surface 2100psi~l At total depth {'rVDI 3450 pstg 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casin~l Weight Grade Coupling! Length MD TVD MD 'I'VD linclude stage dataI N/A 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 9700 feet Plugs (measured) true vertical 9049 feet Effective depth: measured 9644 feet Junk (measured true vertical 9018 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 113' 20' 1810# Polyurethane 113' 113' RECEIVED Surface 2443' 13-3/8' 2175 sx PF E/400 sx PFC 2496' 2496' Production 8247' 9-5/8' 500 sx CIG & 300 sx PFC 8300' 8195' Liner 1406' 7 · 354 cu It Cl G 9532' 8957' S EP 1 9 1994 Perforation depth: measured Open Hole: 9532 - 9700' ~l~Sk~. 0il & Gas Cons. Commission true vertical Open Hole: 8957 - 9049' Anch0r~e 20. Attachments Filing fee ~ Property plat _ BOP Sketch ~ Diverter Sketch_ Drilling program Drilling fluid program ~ Time vs depth plot _ Refraction analysis _ Seabed report _20 AAC 25.050 requirements _ 21. I hereby certify that the loregoing_is true and correct to the best of my knowledge Signed Titlle Date Commission Use Only PerrnitNumber IAPInumber¢' ~,'= ~'?'J Apgrovaldate I See cover letter for Conditions of approval Samples required ~Y e s ~ N o Mud log required~ Y e s .~ N o Hydrogen sulfide measures~ Y e s ~ N o Directional survey required ~' Yes ~ N o RequiredworkingpressurelorBOPE ~2M; ~ 3M' ~ SM' ~ 10M' ~ I 5M ,z~3500 psi lot CTU Other: Original Signed By by order ol Approved by David W. Johnston Commissioner the commission Date ~,,/~ Form 10-401 Rev. 7-24-89 ~it in triplicate ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 265-6306 September 19, 1994 David W. Johnston Chairman Alaska Oil and Gas Conservation Commission 3001 PorcupineDrive Anchorage, AK 99501-3192 Re: RECEIVED Prudhoe Bay Unit DS 9-36BL1 and DS 9-36BL2 ARCO Alaska, Inc. Surface Location (both wells): 1874' NSL, 37' WEL, Sec. 2, T10N, R15E, UM Bottom hole locations: DS 9-36BL1: ~3701' NSL, 4803' FEL, Sec. 1, T10N, R15E, UM DS 9-36BL2: 4217' FSL, 4976' FEL, Sec. 1, T10N, R15E, UM S EP I 9 1994 Aias~ 0il & Gas Cons. Commission Anchorage Dear Mr. Johnston: Enclosed are the applications for Permits to Drill for the above- referenced wells. These wells are among the first examples in Alaska of what are generally referred to as "multilateral" wells, a drilling method that holds the promise of substantially increasing the economic recovery of oil. While the Commission does not have a settled practice of dealing with multilateral wells, we believe drilling multilateral legs from a common conductor casing creates separate wells that require separate drilling permits and well numbers. Our belief is founded upon 20 AAC 25.005(e), which specifies that "[e]ach hole drilled below the conductor casing, unless drilled solely to straighten the original hole, sidetrack junk, or correct mechanical difficultites, is a separate well requiring a Permit to Drill." Here, there are to be two holes below the conductor casing, each drilled to produce oil, and not drilled for purposes of straightening the hole, sidetracking junk, or correcting for mechanical difficulties. Thus, each hole is a separate well, requiring a separate Permit to Drill. This result is supported by the APl numbering system, which has been adopted by the Commission.1 20 AAC 25.040(b) requires that "[e]ach well will be assigned an APl well number by the commission when the drilling permit is approved." By correspondence dated June 23, 1994 from ARCO Alaska's Mark Miller to Mr. Robert Crandall of the 1 It is also consistent with ARCO's naming convention. As indicated in the permit applications, ARCO designates these ~vells separately as DS 9-36BL1 and DS 9-36BL2. Commission staff, ARCO responded to the Commission's request for comment on multilateral well numbering. We understand from talking to your staff, that this correspondence was forwarded to APl for comment. We further understand that APl sent a response to the Commission endorsing ARCO's understanding that current APl conventions provide that each multilateral well off an original wellbore should have a unique APl well number. It follows that the two multilateral wells at issue here should be assigned separate APl well numbers. If you have any questions, please call myself at 265-6306 or S. L. Ward at 265-1305. James L. Cawvey PRB Engineering Supervisor Attachments RECEIVED S EP 1 9 1994 Aiaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA AL, .,.,.~ OIL AND GAS CONSERVATION ~M.~'"iON PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill _ Redrill ~ lb. Type of Well Exploratory.._ Stratigmphic Test . Deve~ent Oil Re-Entry m Deepen _ Service _ Development Gas ~ Single Zone _~_ Multiple Zone. , 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field taxi Pool ARCO Alaska. Inc. RKB ~' ~. Address 6. Property Designation P. O. Box 100360, Anchorage, AK 99510-0360 ADL 28327 Prudhoe Bay/Prudhoe Bay Oil 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (,e. 2o AAC 25.025) 1874' NSL, 37' WEL, Sec 2, T10N, R15E, UM Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 2915' NSL, 51' EWL, Sec 1, T10N, R15E, UM 9-36BL2 #U-630610 At total depth 9. App¢oximate spud date Amount 4217' FSL, 4976' FEL Sec 1~ T10N, R15E, UM September~ 1994 $200~000 12. Distance to nearest 13. Distance to nea~ast well 14. Number of acres in prepe~ty 15. Propoeed depth (MD a~xt TVD) property line ADL 28324:1794 feet No Close Approach 2560 Acres 10500' MD / 9003' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 A.~C 25,035(e)(2)) kickoff depth 9547' MD Maximum hole arkie 91° Maximum surface 2100~1 At to~al depth ~VD} 3 4 5 0 18. Casing program Setting Del~h size Specification Top Boftom Quantity, ol cement Hole Casing Weight Grade Couplir~ Length MD TVD MD 'FVD (include sta(~e dataI 3-3/4' 2-7/8" 6.5 L-80 FL4S 1800' 8920' 10500' 9003 None 19. To be completed for Reddll, Re-entry, and Deepen Of 3em~ions. Present well condition summary Total depth: measured 9700 feet Plugs (measured) true vertical 9049 feel Effective depth: measured 9644 feel Junk (measured true vertical 9018 feel Casing Length Size Cemented Measured deplh True Vertical del)Ih Structural Production 8247' 9-5/8' 500 ax Cl G & 300 ax PFC 8300' 8195' Liner 1406' 7 ' 354 cuft Cl G 9532' 8957' SEP 9 1994 Perforation depth: measured Open Hole: 9532 - 9700' AlaSka 0il & Gas Cons. C0mmissi0 lrue vertical Open Hole: 8957 - 9049' Anch0ra~e~ 20. Attachments Filing fee ~ Property plat __ BOP Sketch .~. Diverter Sketch Drilling program Drilling fluid program ~ Time vs depth plot ._. Refraction analysis ~ Seab~:l report --20 AAC 25,050 requirements _ 21. I hereby certify that the foregoing is true a~d con'e~ to the best of my knowledge Signed Titlle Date Commission Use Only Condition~ o! spproYal ,~ampl~ required ~¥ e · ~ N o MUd ~ required~ ¥ ~ s .~ N o Hydrogen ~ulfide me~ure~~ ¥ o s ~. N o Dir~:tional surly required ~ Yes ~ bi o Required workiag pressure for BOPE ~ 2M; ~ 3 M; ~ 5 M · ~ 1 0 M; ~ 1 5 M .,~..3500 psi for CTU Other: Original Signed ~,yby order of _App~ov.~_ .b_y. _ _n~yirl W. JohnstOn Cor. r.~ss~ner the commission Dale Form 10-401 Rev. 7-24-89 Submit in triplicate DS 9-36BL1 AND DS 9-36BL2 CT Sidetrack and Completion Intended Procedure INTENDED PROCEDURE: Rig up cementing equipment and cement squeeze the open hole, leaving the cement top at + 9545' MD. 2. Rig up CTU, manifold, and lines. Nipple up BOP's and test. . CTU directionally drill +_200' of high angle section ( ~ 25~ / 100') with MWD logging for GR and directional survey. Drilling fluid will be 9.0 ppg FloPro fluid. , DS 9-36BL1: CTU directionally drill -500' of horizontal section in DS 9-36BL1 as per Greatland directional plan. NOTE: 1) Formation is fiat. The horizontal hole will be drilled turning to the right (East) at --25~ / 100'. Plan is to be in the top 20' of the target interval for the majority of the horizontal section. Target interval is 8999' TVD - 9019' TVD. . , . DS 9-36BL2: a) RIH with drilling BHA to - 9800'. CTU directionally drill DS9-36BL2 remaining horizontal and drilling straight ahead for -700' MD in the same target interval. b) Spot Lithium Hypochlorite (bleach) in open hole. Let soak for 2 hours. Displace open hole with 2% KC1. POOH. c) Run 2 7/8" preperforated and plugged liner. Top of 2-7/8" liner will be in 4-1/2" tubing tail. POOH and MU nozzle on CT. Lay in acid across liner. Allow to soak for 20 minutes. POOH and RD CTU. Put wells on production. Run $SSV. RECEIV£D SEP 1 9 1994 A!aska. Oil a Gas Cons. Commission Anchora]~; C T Drilling Wellhead Detail ~ CT Injector Head Methanol Injection Otis 7' WLA Quick Connect ~ 4-1/16' ID CT BOP Stack ~ 10,000 psi Working Pressure i~ I ~- Stuffing Box (Pack-Off), 10,000 psi Working Pressure ~ 7' Riser 2' Pump-In ~ Blind Rams or Combination Cutter/Blinds Cutters or Combination Cutter/Blinds · Slip rams Pipe rams Flange Flanged Fire Resistant Kelly Hose To Dual ChokeManffold Optional Flanged / / Manual Valve HCR 2.0' (24') Test Gauge f 1.67' (20") Approximate top of We,house Optional: Space with spool pieces or valves to top of we,house as shown Alignment Guide Flange Optionally Made-up During Drilling 6"-8" Line To Plant Annular BOP (Hydril), 5-1/8" ID 5,000 psi working pressure 3.167' (38') Ram Type Dual Gate BOPE manual over Hydraulic 7-1/16" ID with Pipe/Slip Rams Manual Valves 5.75' (69') 1 1.427' (17-1/8') o.458' (5.5') f 5.604' (67.25') Top of Pad Level Mandatory SSV Optional Manual Ma~ter Valve or Hydraulic SSV (24,5" for SSV) ~tubing Hanger ~Fire Resistant Kelly Hose to Flange by Hammer Up 1/4 Turn Valve on DS Hardline 10' from Tree ~ 9-5/8' Annulus RECEIVED ~ SEP ]9 1994. Aluska Oil & Gas Cons. Commission t 3-N8' ~nnulus Shale Shaker ~ .. Optional Trico Skid Pressure Release Line Liquid I I Liquid I Returns I [Returns I ........ !! . ..:.::i!::~i ,.:.:.:.:.:.;.:.:.:.:~....=.:;....~.......::;:i:;'"' .'~ Trico HP Relief Tank 1502 3" Hardllne Hammer Ups Standby Equipment ictiOn Centritugal~ anifold~ Purn~.~ Flan( Flanged Fire Resistant Kelly Hose / Dual Choke Manifold w/Bypass Flanged Fire Res. Hose Flan( Hammer up Optional Pump Tie-In/ Reverse Manifold 3oiled Tubing Unit "";::::~.;:: IBOPEI Power I Tool Racks BOPE Console Ext. Locations of equipment may be switched if easier to rig-up 300 Bbls 60/40 400 Bbl ~ Upright / C.T. Pump Preferred Major Equipment Layout for CT Drilling Dowell/Anadrill DrillingEquipment Trailer Gen. ~----I I -~1 I · · -, ._1O "' PRUDHOE '-BAY D' LL'ING GRO'OP ~l~rker Identification ~!0 BKB SECIH INCLN BI END OF R5/IOO BUILD 9676 9003 194 ~.00 C) [U~ RIGHT ~5/100 975I 9003 ~8 ~.00 DJ TD ..... I0149 9003 5iR 90.00 _ ii ii i i lnadrJ 71 $ch]umberger i i ii · iiii i i iiii iii ii i ii iii ,! , DSOg-36BLI (P3} LEG #1 COILED TUBING VERTICAL SECTION VIE~ ~11 i i - Sectior~ at: §0.00 fro Scale.- 1 inch : I00 feet Dap Scale.' I inch : lO0 feel Jora~n ..... · 09/13/94 ,200 k - leo -50 0 50 ]00 tso aoo a~o 300 3so ,,oo 450 soo 550 600 ~so 700 ~5o Sec Lion Oepar ture Ill, II I I I I I I I II , , . · , _ 11· _ _ , , _ ~']', kJ93 93~LIP3 B~.5~' 9:58 ~u~ 21' ITl I SEP-13-19S4 14:24 FBo~I RNRDRILL T~-i. 2651336 P.05 PRUOHOE 'BAY OBILLIN¢ ii i ~) TIE-IN 9547 t468 17! 8) ENO OF ~5/~00 BUILD 9576 t582 194 ¢) TURN R;GHT 25/~00 975~ ~656 808 O) TD t0~49 ~828 DSO 9- 36BL ~ !CLOSURE · DECLINATION.' SCALE ' BRAWN ' GROUP (P3} LEG #1 COILED TUBING PLAN VIEW 1898 feet at Azzmuth ~5.66 29.658 E i inc~ = 500 feet 0B/13/94 Anadri l l $£h lu~¢argsr 1750 1500 ~250 ~000 750 500 250 0 250' 500 750 tO00 ~250 I500 1750 PR'UB'HOE BAY BR "E_E T N6 CROUP - -' ,J -- i i i mllll i~iii i i · i i i i iii i i _ _1 _ _ ! ii i i .... ~r k~.r...! ~.en.t. ~. Lc__~_t.~_~_n_ ............. ~ ....... _e.K.._I)..___SE c ~_N. .... _iN_[;k~. ....................................................................................... A} tiE-l# 97§1 9003 1665 90.00 I))' ID 10451 9003 2365 90.80 Jl ii m m mi ,4nadr ,-----; Y ] $cl~]u,~bercer .... [~O7~'--~d a'l-' ~'" (i~-3-)--i'~:~'' '~'~mmm'~miL d6 ~Od lab ........................... m VERTICAL SECTION VIEW I i mil I i il .............. TVO Scale.' I inch = I00 feet Oep Scale.' I inch = tO0 feet Braan '09/13/94 I · ~ I t ;. . I i ~ r ~ r -¢~ ............ i .......................... ~ ..... ~ ..... ......... ........ ..... t ............. : ....... ~ ~ I ~ ' I I . . ..... ~ ~ - ..... ' i ~ " -' I I I I ......... 200- 25O 554) 1600 t 650 1700 1750 1800, :1. 850 1900 ~ 950 2.000 PO50 ;~ :1, O0 ~150 2200 2250 2300 2.350 240 O 2450 . . .. . .......... Section Departure I I ill iii .... II I I Ill __ II I II~l I I I I I Ic]~3 9368LI:P3 B~.57 t0:22 ~ t) oJ TO ~ 2651336 P.10 PRUDHOE BAY DRI Marker Ident i ficat ion Al TIE-IN E)) TO g75! 339 _LING GROUP lnll Ulllll I OS09-368L~ (P3) LEG #2 COILEO TUBING PLAN VIEW ----' lid I CLOSURE ' 8368 feet at Azimuth 8,23 DECLINATION.- ~9,658 E SCALE ' ~ inch = 500 feet DRAWN ' 09/13/9~ ,mil i ,1 , .............. Anaari ll Sc~Yuml~erger -iiii i ............. J R CEIVED ....... --~, , S~P ~9 1994 ~r m Oil,& Gas"~( ns. ............ I .... 1750 1500 1250 JO00 750 500 850 0 850 500 750 JO00 i250 1500 : W-- ~T · ~A~T DS 9-36BL1 AND DS 9-36BL2 CT Sidetrack Horizontal WELLS 4-1/Z" Tubing 7" Liner Top 8126' SWS Nipple 8795' Packer 8853' --~ SWS Nipple 8883' SWN Nipple 8979' Tbg Tail 8982' 9-5/8" Casing Window @ 8300 - 8350' Top of 2-7/8" Liner in 4-1/2" Tubing tail CONTINGENT ON SUCCESSFUL DRILLING OF 1 ST LEG ?_nd leg of 'Y'-- 3-3/4" open hole 400 to 500' DS 9-36BL1 ®® 7" Csg. Shoe @ 953?_' ® ® © 3-3/4" open hole -7/8" Pre-perfed Liner ' 600 to 700' DS9-36BL2 WELL PERMIT CHECKLIST COMPANY ~ ~ INIT CLASS D~.~/ /~'~,~/ UNIT# PROGRAM: exp [] dev~ redrll [] aery [] ADMINISTRATION 1. Per, it 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 ................ 15. Surface casing protects all known USDWs ......... 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . - 18. CMT will cover all known productive horizons ....... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............ 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate ........... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to ~_~ psig.~ 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of ~2S gas probable ............. GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y/ N 32. Seismic analysis 9f shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ /~Y N ' 34. Contact name/phone for weekly progress reports ..... /. Y N [exploratory only] /," GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: ",io - A:%FORMS~cheklist 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. RE£.EIVED APR 2~'1 t395 Alaska 0 "hlUmt>erqer Al. asK'8 Com[::t].t'.J...fn~ Cent:,eI' f.; F' 5?? R A 't'0 ~;,' v, ! ? !~.~ ~ .?, S: S '(? ~' tr A C Z i..,~ r.? C ~, T T ;"';, SwC7 !r.)."~: F,~,' L,: ?'wf. ; t-'f,F;Vb' Fir~ i [~-T Pa'": ' ~ , , k..' ,'. Gi4.¢~iJ~'~,.. .,., L,F"VF-'.I;".. I ST S.!.'h' !'IG P [~ ~'..~ f...~ H (....; p: !:~ A Y, [)$ 0 9 - 3 6 [::! b, ,-3 o -, 0 2 9 - 2 !. 4 ? 9- 0 2. BAY, Dsog-3(:,~:~.L~ 5()-029-21429-02 D 5 (,~ 9 - 3 6 F~. 15 5 0 (.) 2 o 2:1 4 2 9 0 2 m ~m~ m ~m~ ~m m m~ m m $ E; R V ,l' C E ~:: 2 !. 5q 1. 87q. '37 P A G E: 4 - A, E,:" P - 1995 ,t. !,: 56 3.750 () ¢1 $ S PA ~E, ." c~535.0 94 ~','1: ~' 0 -. [~,,.~ Ta~,e ver]f'],cation List.i'nq 'l~lumberger i~l,~$Ka Comi}t,]t~nO Ce?'~ter ,4-APR-,:1995 J1:56 PAGE: 0 1 0 gx' r°"':S -,-;c9. i.) P [: .-r · q 5 (7: ~..~. i.i 0': G ;.;, ~-: '.,'.'. :', '.: i} 5 7.0 G 0 ,,": ~-. 'f '.,. ,! i,., l.> 5 7.0 (i 0 R 9 P. ~" i,i P., 55.200 47..t O0 18.300 -999.250 7 h 1.. t.~ ,,'~'. b e r 9e ..... r A 1..a $ ~ a C.' ,:.> ,' i::, u t'. J n c.,, C e n t." e* ..... r .~7 P .I '!7' E. [.~ v E ~ C ~: [} ,~I ,~ .0 r, et:>t;h st~J, fte~ and cl,iDr~ed out'yes: all, P,,~AU runs ~erc~ed us.ino earl. lest passes. ~ , i m ill m m ImI~ mm i II ! P A G E: ~9.600 65.926 PAGe: -999,250 34,769 e a c ? F" T L, ['"~ H [?.:' A !3 ~.: k Ctlrve$ and 1..o,:'.~ header data for D ~' P T ,-~ .1 ": r, F: '; "~' ,:" ",; T ' 0 % ('; 0 (:' ~ .... .. ~ , . . , ~':, , · '.'.,T.T;~ TYF:'F (.','~"(:F, 7 or ~:f.'~.f.-f 1~"t.:1): , ~ ;~LT ~(-'T.~.TI~'G ,.%:~7~-'~.1' fFF:~) ~ ',,! I.. [ ~i ~ ~ ",, bit run In $eoarat. e 2 - ':) C .[,; ~ 1,- 92 7 '1 9551 66.0 files. - h 1 u t'~, ;;, e r g e r A i a s K a. C o ~': i~:, t.~ t. i n o C" e n t. e r PAGE: 3. '155 0 8 3 0 O, 0 X ^ N ~' ,T $ /F"i:. !::J P R t',) 0,0 0 0 0.0 0,0 0 (') 0,0 0,0 0 !:'! 0,0 PAGE I 4 6~ 0000000000 !1. 4, 68 0000000000 :1.. 4 68 0000000000 ] 4 68 0000000000 1 4. 66.' C'('iO0OO0000 1 4 68 0(,,00000000 I 4 6~ 0000000000 1. 4 68 0000000000 -999.250 199.900 -999.250 164.900 ~hlun'~berger' ti].aska C!of~:[:~utinq Center t:.,: I. 5 3 0 0 1~ 0 P e.:: >:,',, i::; 1 !. ~ q"" - 9 ? 9.2 5 0 'V D E P .,,~'~, h! 25.00o -999o250 -999.250 P~GE: 33.400 15.300 25.000 -999.25() i'-,ea¢?er dar each t.?.ess of each run .in i 2 ' {. ~C T - 9 ,i Iq h: A t,- [: l ,'4 F: separate ~iles. IS :raoe Feri.f:!catJ. on l..,J.s't, inq PAGE I0 V [: ?,i P, 0 R ~1" 0 (:~ i.., C iF, [; F.: T r)~:.; L T ¥ P $ ... I ...... ' 4 A j! R ] X ..,) E, ~,' S T' '"1,:¥ 3 · 7 5 0 8 3 00.0 PRE) 0,0 0 0 0,0 0, (,! 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