The URL can be used to link to this page

Home My WebLink About195-079XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages' Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy Dian~han Lowell Is~ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03, 2001 PL M A T E E IA L UN W DER C:LOR_EI~ILM.DOC T H IS M A R K E R Memorandum State of Alaska Oil m~d Gas Conservation Commission To: Well File: DATE Cancelled or Expired Permit Action EXAMPLE: Point McIntyre P2-36AXX API# 029-22801-95 This memo will remain at the from of the subject well fie. Our adopted conventions for assigning APl numbers, permit numbers and well names did not soecifically address expired or cancelled permits. This omission has caused some inconsistencies i' tl~e treatment of these kinds of applications for permit to ddil. Operators have asked us to adopt formal procedures for this class of permit application in order to prevent future database disparities. If a permit expires or is cancelled by an operator, the permit number of the subject permit will remair unchanged. The APl number and in some instances the well name reflect the number of preexisti~ reddlls and or muitilaterals in a well. In order to prevent confusing a cancelled or expired permit with an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to ddll. The AP! number for this cancelled or expired permit is modified so the eleven and twelfth digits is 9[ The well name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the APl numbering methods descnbed in AOGCC staff memoranoum "Multi-lateral (weitbore segment) Ddlling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician AI~SKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, OOVERNOF~ 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 1, 1995 Michael Zanghi Drill Site Development Supv. ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kupamk River Unit 2F-05A ARCO Alaska, Inc. Permit No. 95-79 Sur. Loc. 683'FSL, 1590'FEL, Sec. 28, T1 IN, R9E, UM Btmnholc Loc. 1610'FNL, 1646'FEL, Sec. 28, T1 IN, R9E, UM Dear Mr. Zanghi: ' Enclosed is the approved application for permit to redrill the above referenced well. 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 installed prior to drilling new hole. Notice may be given by contacting the Commiss~roleum field inspector on the North Slope pager at 659-3607. David W. ¢ox~~ ) Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA OIL NqD NS CONSERVAIION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill D Redrill X lb Type of Well Exploratory r"] Straligraphic Test [--] Development Oil X Re-Entry D Deepen D Service [~] Development Gas n SinfileZone X Multiple Zone n 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 123', Pad 98' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25657, ALK 2583 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20/sAC 25.025) 683' FSL, 1590' FEL, Sec. 28, T11N, RgE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 1685' FNL,1514' FEL, Sec. 28, T11N, RgE, UM 2F-05A #U-630610 At total depth 9. Approximate spud date Amount 1610' FNL, 1646' FEL, Sec. 28, T11N, R9E, UM 6/5/95 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and '[VD) property line 2F-03 7216' MD 1113'@ TD feet 105.0' @ 1550' TVD feet 2560 6252' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 6020' feet Maximum hole angle 35° Maximumsudace 2495 osia At total deDth CTVDI 3150 Dsio 18. Casing program Setting! Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6-1/8' 5' 18.0# L-80 LTC 1350' 5850' 5024' 7200' 6238' 156 sxs Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. I.= ~ ~ '"' '"' Present well condition summary Total depth: measured 7 3 8 0' feet Plugs (measured) true vertical 6283' feet MAY,3 e 1995 Effective depth: measured 7276' feet Junk (measured) AI~S~[ OiL & Gas Cons. Commission true vertical feet Anch0ra? Casing Length Size Cemented Measured depth True Vertical depth Structural 80' 1 6 ' 175 sx ASI 109' 109' Conductor Surface 3121' 9-5/8' 850 sx ASIII 3150' 2852' Intermediate 650 sx Class G Production 7329' 7 · 280 sx Class G 7358' 6265' Liner 250 sx ASI Perforation depth: measured 6896'-6914', 7000'-7011' 7026'-7040', 7102'-7108' MD true vertical 5877'-5892', 5963'-5973', 5985'-5997', 6049'-6053' TVD 20. Attachments Filing fee X Property plat ['"] BOP Sketch X Diverter Sketch [--~ Drilling program X Ddlling fluid program X Time vs depth plot D Refraction analysis [-1 Seabed report J--~ 20 AAC 25.050 requirements X 21. I hereby certify th~. the foregoing is true and correct to the best of my knowledge S~ned ~J!... ('~~ Title Dr,II Site Develop. Supv. D at e ~"-"~¢'7~'~ ~"~'.~' Commission Use Only, Permit Number I AP', number I Approval/date / ,,C...~- I See cover letter for ~,.~'-- -7 C~ 5 0- ~'~,. c/ _ ¢~ / ~ ~ - ~ ~ ~/'~ y,,~ olher requirements Conditions of a..roval Sam. es re. uired !--i Yes El. No re.uired D Yes 121 No Hydro.qen sulfide measures [~ Yes E] No Directional survey required ~[' Yes D No Required working pressure foraOPE I--J 2M ~J~ 3M r~ 5M r'1 1OM J-1 15M Other: Original Signed By by order of _Approved by Oavid W, Johnston Commissioner the commission Date ~- /-- ~"- Fnrm 1fi-41'il RP.v 7-24-R.Cl R, ahmit in tHnlic, nln REDRILL PLAN SUMMARY Well 2F-05A Type of well (producer/injector): Surface Location: Target Location: Bottom Hole Location: MD: TVD: Rig: Estimated Start Date: Operation Days to Complete: Producer 683' FSL, 1590' FEL, SEC 28, T11N, R9E, UM 1685' FNL, 1514' FEL, SEC 28, T11 N, R9E, UM 1610' FNL, 1646' FEL, SEC 28, T11N, R9E, UM 7216' 6252' Nordic Rig 1 6-5-95 13 Drill Fluids Program: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Milling Section in 7" casing 9.6-9.8 >25 15-35 85-95 20-30 30-40 8.5-9.5 Kick off to weight up 9.4-9.8 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 10.4 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Bariod Model 2 Tandem Shale Shaker Swaco 6 cone desilter Triflow vacuum Degasser, Poor Boy Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators RECEIVED MAY ;30 1995 Alaska 0il & Gas Cons. Commission Anch0ra.? Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Page 1 Casing/Tubing Hole size 6-1/8" Program: Csg/Tbg 5", 18#, L-80, LTC Tubing 3-1/2", 9.3#, J-55, EUE Length Top (MD/'FVD) Btm (MD/I'VD 1350' 5@507 5024' 7200'/6238' 6768' 22'/22' 6790'/5857' Cement Calculations: Casing to be cemented: 5" in 6-1/8" open hole Volume: 156 sxs of class G Blend @ 1.19 cu ft/sx Based on: Shoe volume, open hole volume + 50%, & 150' liner lap. Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed. Maximum anticipated surface pressure is estimated at 2,495 psi and is calculated using a gas collumn to surface. The expected leak-off at the section cut in the 7" casing is estimated at 14.5 ppg EMW. With an expected formation pressure in the Kuparak of 3150 psi and a gas gradient of 0.11 psi/fi, this shows that formation breakdown would not occur before a surface pressure of 2,495 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3500 psi. See attached BOPE schematic. Directional- KOP: Max hole angle: Close approach: 6020' MD / 5163' TVD 35.1° (in sidetrack portion) No Hazards Logging Program: Open Hole Logs: None Cased Hole Logs: CNTG/GR/CCL R £CF..iV F..D M/XY 30 1995 A~ska 0ii & Gas Cons. Commission Anchora? Notes: 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. Page 2 KRU 2F-05A GENERAL SIDETRACK PROCEDURE NOTE - CURRENT WELL STATUS: There is collapsed casing across the A Sand perfs. The wellbore below the bottom packer has been plugged off with sand and clay. The A Sand will not flow and recent attempts to inject into the A Sand were unsuccessful. The C Sand is capable of being injected into. PRE-RIG WORK: 1. Dummy off all GLMs, leave deepest GLM open. Pull dummy valves from all C Sand mandrels. 2. Set BPV in tubing. Install VR plug in annulus valve if necessary. RECEIVED WORKOVER RIG WORK: 1. MIRU Nordic Rig. Lay hard-line to tree. Pull BPV and VR plug. MAY 30 1995 0ii & Gas Cons. Commission Anchora,iP 2. Load pits w/kill weight brine (expected kill wt = 10.4 ppg). Circulate well to kill weight brine. Ensure well is dead. 3. ND tree. NU and test BOPE. 4. Screw in landing joint. POOH w/tubing, inspect for corrosion, and change out seal rings. Stand back tubing and LD all jewelry. . PU DP and RIH with cement retainer. Set retainer at 6205'. Pump cement squeeze below retainer into C Sand perfs filling 7" casing to top of bottom packer. Unsting from retainer and spot 3 bbl cement plug on top of retainer. Circulate well to milling fluid. POOH standing back DP. 6. RIH w/section mill. Spot an 18 ppg balanced mud pill from PBTD to the base of proposed section. Cut a 50' section in the 7" casing from 6005'- 6055'. POOH w/mill. . RIH w/open ended DP. Wash down through section and circulate any metal shavings from well. Mix and pump balanced cement kick-off plug f/100' below base of section to 200' above top of section. . RIH w/6-1/8" bit, mud motor, MWD, and steerable drilling assembly. Dress off cement to top of section. Kick-off well and directionally drill to total depth as per directional plan. Short trip to window in casing. POOH w/DP. Page 3 . 10. 11. 12. 13. 14. 15. 16. Run 5" liner to TD w/150' of overlap to top of milled section. Cement liner. Set liner hanger and liner top packer. POOH w/DP. RIH w/4-1/8" mill on 2-7/8" x 3-1/2" tapered drill string. Clean out liner to PBTD. Pressure test liner to 3500 psi. Circulate well to filtered sea water and POOH. R/U E-line. RIH with CNTG/GR/CCL and Icg from TD to +/- 50 above the base of the HRZ interval. RIH w/3-1/2" x 7" permanent packer and 3-1/2" x 2-7/8" tubing tail. Set packer +50' above liner top. POOH LD DP. RIH w/tubing and sting into permanent packer. Space out. Test tubing and annulus. ND BOPE. NU and test tree. Freeze protect well with diesel. RDMO Nordic. Perforate through tubing once rig has moved off the well. Lower Limit: Expected Case: Upper Limit: 11 days 13 days 19 days No problems milling section, drilling new hole, or running completion. Difficulties encountered pulling completion, milling section, or drilling new hole. WSI 5/25/95 R rcCF..l'V ~,,~A¥ 30 1995 Gas Cons. Commission Anchora. Page 4 Created by : jones For: B ISAACSON {Dote p{otted : 26-May-95 !P}ol: Reference is ..SA Version #7. iCoord{notea are in feet reference alot ~5. iTrue Verticoi Dep~nce RKB (Nordic). © I I V ARCO ALASKA, Inc. Structure : Pod 2F Well : 5A Field : Kuparuk River Unit Location : North Slope, Alaska WELL PROFILE DATA 5600_ _ 5700_ _ 5800_ 5900_ _ 6000_ 6100_ _ 6200_ _ 6300_ _ 6400_ Point MD Inc Oir TVD KOP 6030 55.52 7.56 5172 Target 6817 22.15 293.22 5880 End of Hold 7023 22.15 293.22 6071 End of Hold 7223 22.13 293.22 6256 N 1.5 DEG E ~,:~.~ East --> 2913' (TO TARGET) ***PLANE OF' PROPOSAL*e* 200 100 0 100 200 ID LOCA~ON: 1625' FNL 1655' F-EL SEC. 28, T11N, R9E SEC. 28. 'r,~.. RgE I ~ J ! TAROET ~ / TVD=5880 ~/ TMD=681 7 ~f DEP-2913 ~ NORTH 2912 ~ 28. EAST 76 ~ KOP - Sidetrack Ptt 23.32 TARGET AZIMUTH ~ 4.s2 o~ / ,oo. o,, 293.22 DEG ~ 21.86 21.24 21.52 TARGET ANGLE 22.13 DEG Nodh East Oeg/lO0 2617 186 0.00 2912 76 4.52 2943 5 0.00 2972 -65 0.00 300 400 I I I _3tOO _3000 _2900 _ _2800 _ _2700 _ _2600 f 2500 2400 SURFACE LOCATION: 683' FSL, 1590' FEL SEC. 28, T11N, RgE TARGET - T/ KUP SNDS (EOC) TVD=5880 TMD=6817 DEP=2913 T/ ZONE C TVD=S891 TMD=6829 OEP=2915 T/ ZONE A TVD=5955 TMD=6898 DEP=2924 B/ KUP SNDS %/D=6071 TMD=7023 DEP=2942 TD TYD=6256 TMD=7223 DEP=3970 I i I I I I I I II II I I II II II 2500 2600 2700 2800 2900 ,.3000,.31 O05200 ,3'300,3400 ,.3500 Scale 1 : 50.00 /X _1 I Z Vertical Section on 1.50 azimuth with reference 0.00 N, 0.00 E from slot #5 7-1/16" 5000 PSI BOP STACK I~ANNULAR h REV~NTE~ 5 BLIND RAM> MUD 3 P PE RAM ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC 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 LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER 2. CHECKTHAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THATTEST 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 5 MINUTES. INCREASE PRESSURE TO 3500 PSI AND HOLD FOR 5 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND INSIDE MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS, HCR VALVE ON CHOKE LINE, AND OUTSIDE MANUAL VALVE ON KILL LINE. 6. TEST TO 250 PSI AND 3500 PSi AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3500 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 BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3500 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. 10. CLOSE BLIND RAMS AND TESTTO 3500 PSI FOR 5 MINUTES. BLEED TO ZERO PSI. 11. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 12. TEST STANDPIPE VALVES TO 3500 PSI. 13. TEST KELLY COCKS AND INSIDE BOP TO 3500 PSI WITH KOOMEY PUMP. 14. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 15. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1.11" - 3000 PSI CASING HEAD 2.11" - 3000 PSI x 7-1/16" 5000 PSI TUBING HEAD 3.7-1/16"- 5000PSI SINGLE GATE W/PIPE RAMS 4. 7-1/16"- 5000 PSI DRLG SPOOL W/CHOKE & KILL LINES 5.7-1/16" - 5000 PSI SINGLE GATE W/ BLIND RAMS 6. 7-1/16" - 5000 PSI SINGLE GATE W/PIPE RAMS 7.7-1/16" - 5000 PSI ANNULAR PREVENTER RECEIVED ,50 1995 Alaska 0[~ & Gas Cons. Commission Anchon; ~5 UUD ROOM , .r~ . t,a , ..2 .... I.L.I .:.~.? ,. .. , . 11 . - ,,,, ', ,,~ . ~ ~ .' ;:' '1 ;~oP T~ ! '" I .: I ,, I NORDIC RIG # 1 LEVEL 2 · MUD PIT I1 ~'~o · II · .' :SL~G'PiT" · ,. 50 Bl~ ,-' · ' ~ II . "11 II ' II ,I I " I I I UOOUI**[ TRIP T~IK " ..... 20 ILkCK XREA NOI~DIC RIG # ! LEVEL 3 · .'/./', /,* //l */' · ../." ,/' 1 , /, · ,/. ' '/,',/. / TOOL ~OARD FrI'DR~UUC DIULL PIPE 40' PIPE DOOR ST[AU COIL °1 RECEIVED WALl(WAY MAY 30 1995 Oil & Gas Cons. Commi~ion ' 'Arlchore, :~ STATE OF ALA~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~X Suspend_ Operation Shutdown Alter casing _ Repair well_ Plugging ~ Change-approved Program_ Pull tubing _ Variance 2. Name of Operator ARCO Alaska. Inc, 3. Address ,P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 683' FSL, 1590' FEL, Sec. 28, T11N, RgE, UM At top of productive interval 1482' FNL, 1318' FEL, Sec 28, T11N, RgE, UM At effective depth 1281' FNL, 1275' FEL, Sec. 28, T11N, RgE, UM At total depth 1227' FNL, 126..4' F_EL~. Sec. 28, T11N, RgE, UM 12. Present well condition summary Total Depth: measured 7 3 8 0' (approx) true vertical 6283' feet Plugs (measured) feet _ Re-enter suspended well Time extension Stimulate _ Perforate _ Other _.~_Plugback for Redrill 6. Datum elevation (DF or KB) RKB 127'. Pad 98' GL 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2F-05 9. Permit number 84-16 10. APl number 50-029-21073 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool Effective depth: measured 72 7 6' (approx) true vertical 61 95' feet Junk (measured) feet None Casing Length Size Structural 8 0' 1 6 ' Conductor Surface 31 21' 9- 5 / 8 ' Intermediate Production 7329' 7 ' Liner Perforation depth: measured 6896'-6914', 7000'-7011', Cemented 175 Sx ASI Measured depth True vertical depth 109' 109' 850 sx ASIII 3150' 2852' 650 sx Class G 280 sx Class G 7358' 6265' 250 sx ASI 7026'-7040', 7102'-7108' MD RECEIVED true vertical 5877'-5892', 5963'-5973', 5985'-5997', 6049'-6053' Tubing (size, grade, and measured depth) 3-1/2', 9.3#, J-55, @ 6981' MD Packers and SSSV (type and measured depth) Baker 80/40 @ 6788'~ BAKER HB @ 6768'~ FB-1 PERM @..6953'~ CAMCO TRDP-IAENC SSSV @ 1806' 13. Attachments Description summary of proposal X Detailed operation program .. BOP sketch TVD MAY 30 199,5 Alaska 0il & Gas Cons. Commission Anch0ra.j~ 14. Estimated date for commencing operation 6/6/95 I 15. Status of well classification as: Oil. X Gas__ Date approved Service 16. If proposal was verbally approved Name of approver 17. I hereby ,certify. that/the foregoing Sic, lned is true and correct to the best of my knowledge. Title Kuparuk Development Supervisor FOR COMMISSION USE ONLY Suspended Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance Mechanical Integrity Test N Subsequent form require 10-~ Approved by the .order of the CommisSion Form' 10-403 Rev 06/15/88 ~ Commissioner IApproval No~,.~_, Date SUBMIT IN TRIPLICATE 'WELL PERMIT CHECKLIST COY~ WELL NAME GEOL AREA PROGRAM: exp [] dev [] redrll ~ aery [] II O U ADMINISTRATION 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached ................... Lease number appropriate ................ Unique well name and number ............... Well located in a defined pool ............. Well located proper distance from drlg unit boundary. Well located proper distance from other wells ...... Sufficient acreage available in drilling unit ...... If deviated, is wellbore plat included ......... Operator only affected party .............. Operator has appropriate bond in force ......... Permitcan be issued without conservation order ..... Permit can be issued without administrative approval. 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 H2S gas probable ............ GEOLOGY DATE 30. Permit can be issued w/o hydrogen sulftd~_e~me~ures .... Y 31. Data presented on potenttal ov~Dpz~e zones .. .... Y N 32. Seismic analysis~f~I~gas zones .......... Y N 33. Seabed cond~~ survey (if off-shore) ......... Y N 34. Co~ name/phone for weekly progress reports ..... Y N / [exploratory o~ly] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: O HOW/jo - A:~FORMS~cheklist rev 03/94