The URL can be used to link to this page

Home My WebLink About195-053Pages NOT Scanned in this Well History File XHVZE 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. I R~' '- o 5"~ 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~ Vincent Nathan Lowell Date: ('-/-f [] 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 200__!_1 PL M ATE T H IS E IA L U-N D M A R K E W E R R C:LORlXMFILM.DO C Memorandum State of Alaska Oil and Gas Conservation Commissima To' Well File: ~0'" (~~~ DATE Re: 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 f'fle. Our adopted conventions for assigning APl numbers, permit numbers and well names did not specifically address expired or cancelled permits. This omission has caused some inconsistencies i the 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 preexistin! reddlls and or muitilaterais in a well. In order to prevent confusing a cancelled or expired permit witl", 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 numbenng methods descnbed in AOGCC staff memorandum "Multi-lateral (wellbore segment) Ddiling Permit Procedures. revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. e McMains ~ ~ Statistical Technician .heared tilling BP Exploration/Arco Alaska O11 & Gas Conservation Commission D~e: February 19, 1996 Fram: Terrie Hubble Technimal Assistant Permit #95-$3, Z-02A P. 1/1 We submitted a new 'Permit To Drill' well Z-02A on Friday, 02/16/96. Whereupon we were reminded that a 'Permit To Drill' well Z-02A had been submitted back in April of 1995. Please cancel the old permit, #95-53, as we would prefer to use the newest submission. Thank you. /tlh ALASKA OIL AND GAS CONSERVATION COM~HSSION TONY KNOWLE$, (30VEFtNOFI 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 27, 1995 Dan Stoltz Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re .' Prudhoe Bay Unit Z-O2A BP Exploration (Alaska), Inc. Permit No.. 95-53 Sur. Loc. 4303'NSL, 3492'WEL, Sec. 19, TllN, R12E, UM Btmnhole Loc. 2933'NSL, 3070'WEL, Sec. 19, TllN, R12E, UM Dear Mr. Stoltz~ 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 Commission petroleum field inspector'on the North Slope pager at 659-3607. 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 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrilll~l lb. Type of well. Exploratory[] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen[] Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool .BP Exploration KBE = 81.21' feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612, Anchoraqe, Alaska 99519-6612 ADL 28262 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o ^AC 25.025) 4303' NSL, 3492' WEL, SEC. 19, T11N, R12E Prudhoe Bay Unit At top of productive interval 8. Well number Number 2884' NSL, 3162' WEL, SEC. 19, T11N, R12E Z-O2A (22-19-11-12) 2S100302630-277 At total depth 9. Approximate spud date Amount 2933'NSL, 3070' WEL, SEC. 19, T11N, R12E 5/2/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 47455-2933' feet No close approach feet 2560 9882' MD/9219' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 7285 feet Maximum hole angle3¢.49 o Maximum surface 3020 psig At total depth (TVD) 8800'/3900 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD -I'VD M D TVD (include stage data) 8-1/2" 7" 29# L-80 NSCC 2747' 7135' 6753' 9882' 9219' 250 sx Class "G' '~9. To be completed for Redrill, Re-entry, and Deepen Operations. '' "' """" ' Present well condition summary Total depth: measured 9900 feet Plugs (measured) APR ~ 2. '~995 true vertical 9225 feet AlaS[~ 0il & Gas Cons. Commission Effective depth: measured 9854 feet Junk (measured) /~ch0ra~i. true vertical 9182 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 110' 20" 8 cu yds 110' 110' S u rface 2638' 13-3/8" 3580 cu ft 2675' 2675' I n t e r m e d i at e 9222' 9-5/8' 1865 cuft 9259' 8634' Production L i n e r 901' 7" 325 cu ft 8999'-9900' 8396'-9225' Perforation depth: measured 9600'-9615', 9634'-9656', 9660'-9667', 9672'-9682', 9686'-9698', 9702'-9708' true vertical 8947'-8896' (six intervals) Subsea 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 :~ qa~!,-n, ce 'y that ~,~e ~or~'g, lng is true and correct to the best of my knowledge Signed ~.* ' Title Drilling Engineer Supervisor Date ¢'~_/'~ Commission Use Only Permit Number APl number Approval dat__.~ ,.., .~. See cover letter ~',.~'- ~K-,.~ 50-O.2.'F--- .2./,¢/¢- o/ .~--~Z,- ~-/J~¢',..~, for other requirements Conditions of approval Samples required [] Yes J~'No Mud Icg required []Yes ~ No Hydrogen sulfide measures :~I Yes [] No Directional survey required ]~ Yes [] No Required working pressure for BOPE 1-12M; 1-13M; 1~5M; []10M; []15M; Other: ,,~.~' Signed By by order of Approved by 3Vid W, J0.h..n. stdn Commissioner tne commission Date/it, x// Form 10-401 Rev. 12-1-85 Submit plicate I Well Name: I Z-02A Redrill Plan Summary I Type of Redrill (producer or injector): ] Producer Surface Location: 4303' FSL, 3492' FEL, S19, T1 iN, R12E, UM Target Location: 2884' FSL, 3162' FEL, S19, T1 IN, R12E, UM Bottom Hole Location: 2933' FSL, 3070' FEL, S19, T11N, R12E, UM I AFE Number: 14P0663 I I Estimated Start Date: I 5/2/95 I IMD: 19882' I ITVD: I Well Design (conventional, slimhole, etc.): ling: [Doyon 16 I Operating days to complete: I 16 19219'rkb I IKBE: I81'2~' I Sidetrack IObjective: I Sidetrack the present well to establish an offtake point for a voidage point for primary and potential WAG reserves needed in the area. Mud Program: A 9.9 - 10.2 ppg Biozan/gel LSND fresh water-based mud will be used. ISpecial design considerations I none Depth Density PV YP INT 10MIN FL OIL SOLIDS (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) KOP' 9.9 10 15 5 10 10 0 5 to to to to to to to to to TD' 10.2 18 30 15 30 5 0 8 Directional: I KOP: 1 7285' MD IMaximum Hole Angle: Close Approach Well: 31.49 degrees (sidetrack portion) NONE Redrill Plan Summary RECEIVED APR 1 2 1995 0il & Gas Cons. Commission Anchora ~, Page 1 Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MDfFVD MD]TVD 8.5" 7" 29# L-80 NSCC 2747' 7135'/6753' 9882'/9219' TBG 4.5" 12.6# L-80 TDS 9030' 30 9380'/8733' Cement Calculations: I Liner Size: 1 7" Basis:I 80"shoe joint + Ti3C @ 1000' above Sag River using 50% o~enhole excess ' Total Cement Volume: 250 sxs of Class G Blend @ 1.19 ftD/sx Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, B OPE and mud fluid system schematics on file with AOGCC. Hazards: H2S: H2S levels at Z-pad are generally low. H2S was last measured at Z-02 to be 7 ppm. Pore Pressure: Sadlerochit pore pressure is expected to be 3900 psi at 8800' TVDSS or equivalent mud weight of 8.5 ppg. The maximum anticipated surface pressure assuming a gas gradient to surface of 0.1 psi/ft is 3020 psi. The Kuparuk interval in this area warrants attention. This zone typically has a pore pressure between 10.3 and 10.6 ppg. The planned window at 7280' MD is 137' TVD below the Kuparuk and the TOC behind the 9-5/8" is calculated to be between 3448' MD (gauge hole) and 5384' MD (50% washout over gauge hole). A loss zone at 6755' MD was encountered above the Kuparuk (top Kuparuk at 7015') which probably thieved some of the cement, but the window should be isolated since the thief zone is above the Kuparuk and sufficient cement was pumped to cover the Kupamk. Therefore, no hazard of Kuparuk overpressure is expected. Lost Circulation: A fault in the Kingak with a 50-70' throw will be encountered at 7940' TVDSS which may cause lost circulation. The original well intersected a shallow fault in the Cretaceous which caused lost circulation but did not have problems in the Kingak. The proposed sidetrack will not intersect the Cretaceous fault. The well plan is specifically designed to avoid faults in the Sadlerochit which may cause circulation problems. The nearest faults expected in the reservoir are located 630' north and 620' south of the target. The original well drilled the Sadlerochit with 9.7 ppg mud without problems. ECEiVED Redrill Plan Summary APR 1 2 199,5 0il & Gas Cons. Commis~ge 2 Anchora ~ Z-02A INFORMATION Objective: The purpose of this ST is to abandon the present BHL, replace it with a BHL that establishes a new voidage point in the target area for primary and potential WAG reserves, and run a 4-1/2" L-80 completion. The well is currently shut-in due to high GOR. It is thought that the primary cause of this high gas production is the proximity of Z-02 to gas injection well Z-33A. An attempt was made to set an inflatable straddle packer assembly in the liner on 9/28/90, but ultimately the assembly was stuck in the tailpipe where it now remains. The fish does not restrict flow and therefore will not complicate plugback of the existing perfs. The proposed trajectory kicks off in the 9-5/8" casing, builds angle, then drops through the target area in a partial S-shape. It is predicted that the targeted sidetrack location will be conducive to a hydraulic fracture stimulation. Timing: Doyon 16 will be making a well-to-well move from well Z-23A to Z-02 on or about May 2, 1995. Summary of , 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. Planned Operations Cut tubing above the packer. Circulate to 9.1 ppg brine and freeze protect. Move rig on location, pull tubing. Set retainer at 8890' and squeeze perfs (9600-9708') Mill window. Lay kick off cement plug. Drill 8.5" hole to proposed location. Run open hole logs. Run and cement 7" liner. Pressure test to 3000 psi. Run 4.5" production tubing with 5 Camco KBG-2LS 4-1/2" x 1" gas lift mandrels, 7" packer, and 4.5" tailpipe w/Camco DB-6 3.50" No-Go nipple. Move rig off location. Perf with E-line. Hydraulically Fracture. RECEIVED APR 1 2 199,5 0il & Gas Cons. Commission ~Ch0ra~ '~ Redrill Plan Summary Page 3 Z-02A SIDETRACK SUMMARY PROCEDURE LEFT OFF HERE 1. Pre-rig work: Pull SSSV. Dummy mandrels. Cut 4-1/2" tubing at 8890'. Kill well. Freeze protect. Install BPV. 2. MIRU rig. 3. Pull BPV. Circulate out freeze protection fluid. Insure packoff has been tested. If not, have Drill Site Maintenance test packoff. 4. Set TWC. ND tree and tubing head adapter. 5. NU BOP's. Test BOP's to 5000 psi. Test annular to 250/2500 psi. Pull TWC. Note AOGCC witness or waiver on the morning report. 6. Pull and lay down 4-1/2" tubing. Note on the morning report the visual condition of the tubing. It is intended to reuse as much of the tubing as possible. 7. TIH w/EZSV on DP & set same above stub. Squeeze perfs. Change packoff at this time if necessary. , RIH with a 9-5/8" section mill and displace well to Biozan milling fluid - spot 18 ppg hi-vis pill from EZSV to base of proposed 9-5/8" section. Cut a 45' section in the 9-5/8" casing starting at +7280' md. , RIH with open-ended DP. Mix and pump a minimum of 180 sacks of cement to spot balanced kick-off plug from 100' below the base of the section to 200' above the top of the section. 10. RIH with 8-1/2" steerable drilling assembly and dress off cement to 5' below the top of section. Kickoff well and directionally drill to align well with target. 11. Drill with a 8-1/2" directional assembly to TD @ 9882' MD/9219' TVD. Multi-Shot survey w/Sperry-Sun ESS on final trip out of the hole for AOGCC survey requirements. 12. RU Atlas wireline and log with GR/CNL/DIL/BHCS. Run RFT's through LOC and below OOWC at approximately 10' intervals. Wiper trip. Note: If an extended period of time was needed to reach TD, a four arm caliper log may be run to calculate hole size for a more accurate cement volume. Caution should be used while running this tool because of the extra length (18'). RECEIVED Redrill Plan Summary APR 1 2 199,5 Oil & Gas Cons. Commission Page Anchora. '~ 13. 14. 15. 16. 17. 18. 19. 20. 21. Run 7" 29# L-80 standard liner assembly to TD with liner top packer and +150' lap. Liner top packer and hanger assembly are to be plain 4140 grade carbon steel. Note: To ensure the 9-5/8" x 7" liner top packer is fully sheared and set, pressure up to 4200 psi when setting. Cement liner with the standard sidetrack liner cement blend noted in the "Recommended Sidetrack Practice Version 3.2". Note: Use 20% excess over caliper volume for open hole if the caliper log was run from TD to 1000' above the Sag. If the log was not run to that height use 50% excess over gauge hole volume. Clean out liner to PBTD and test to 3500 psi. Change over to clean inhibited seawater. Test to 3500 psi for 30 minutes. RIH with used 4-1/2", 12.6#, L-80, TDS completion string w/7" packer positioned +_200' md above top of Sadlerochit. M/U 4-1/2" tubing hanger- test SSSV lines to 5000 psi for 10 mins. Orient SSSV balance line towards reserve pit. Land tubing hanger and RILDS. Test tubing hanger packoff to 5000 psi. Back out & L/D the landing joint. Set blanking plug. N/D BOPE. N/U tubing head adapter and 5" tree. Test control lines to 5000 psi. Test 5" tree and adapter to 5000 psi. Pull the test plug with a lubricator. Pressure up on the tubing to 4000 psi to set the production packer. Maintain tubing pressure at 4000 psi for 30 minutes after setting packer and record as the tubing test. Bleed off tubing pressure to +1500 psi. Pressure test tubing x 9-5/8" annulus to 3500 psi for 30 minutes. Record the test on a Barton chart. Bleed off the annular pressure prior to bleeding off the tubing pressure. Bleed off the tubing pressure. Pressure up to 2900 psi on the annulus to shear out the RP valve in the top GLM position. Displace the tubing w/enough diesel to freeze protect the annulus to 2200' tvd. Allow the diesel to U-tube to the tubing. REEEIVED APR 1 2_ 1995 0ii & 6as cons. I;;;0rnmissi0n Redrill Plan Summary Page 6 APR-10-1995 09:22- FROM RNP~)RILL lU ~l~ ~r~ulH=m~ n.~ · SHARED SFR --02A (P7) I ", VERTICAL SECTION VIEW ~ ~ ,~ Section al:: 52 34 , , ,., . Dep Scale 1 inch = 400 feet ,~ One~n · 04/07/95 . i Narker Identifica{Jon MD 9K8 SECTN INCLN ,o . "; ~ / I~ A] TIE-INSURVEY 7189 8800 -1~7629.87 ~ I ~ ,. i. ) B) T~ ~ WINDD'~ 7280 6878 -1213 29.72 I / [ C) K~ ~RVE g/lo0 7285 6883 -1215 29.71 ......... i ....... ~ ' ~ .... ~ D) END 9/~00 CURVE 79~6 7468 -J~77 31.0~ lO ' ~ ~' ~: )' ~ E) OR~ 9/t00 93~8 8706 -444 .31.05 ~ ,: ~ F} E~ g/~O0 DROP' 9582 8924 · i ,,, ~ ' __ G) T~GET-150 FI RADIUS 958~ 8924 -362 ~O.O0 )0 .... ; i · ~ H)TD ~882 9219 -310 10.00 I H ' ~ ~ ' . . · -aooo -~8oq -~soo' -~oo -~eoo -tooo -8oo - -~oo -4oo -2oo :. o 2oo 400 600 800 Section Departure : -. SHARED SERV] bES DRTI I'TNi " ~ A) TIE-IN SU~qVEY 71Bg 1586 ,444 ~ PLAN VIEW 7 E) DROP 9/~00 9348 1457 263 CLOSUF~ · ~447 feet at Azimuth 164~ 2 F) END g/J00 DROP ' 9582 1420 335 DECLINATION.' 28.980 E ; o) TA)qGET-tSO Fl" ~OZUS S5~2 1~20 335 SCALE : · 1 inch : 200 f~et, · H) TD 9882 )~95 381 . i · ANADRILL AKA-DPC DRAWN.! ..... : 04/07/95 , ' APPROVED , ! . ...... .. m mlm m iAnadrY]/. Schlumberger,. '; .APR 1 ¢1995 , ~ooo " ~ · , ' I I~ ~ , , i. l...: .......... , ............ 1 lOO- i : , I : ; J I ! . : ' i : i ";~ J ' J ~200 .... Ij ' : .... [ " ' . ,, = I. · ,~I I :~ : ; · J o , , .. I I ] , . , i ] .kt : ! '~ :i,~ .... ~ ! i I : ' i ' t ~ i · ! / ' : / ........ tSOOfi .......... i i : 1 ' I I . ) .. ~ / I. I I ; : i : ! '" i : I / , , ' , ' ....... L_.-:-_ " ' :' i i : , i ti ' : ' ' , #/ ! j i, ;! ' ' 2000 : - . , ~. j i ,' i : , , i J 2!O0 ,- - ............... ~ ' ':' ,. , . i j ! ; · ~// -" : ; I l . ~00 ...... / I . ~ , ,: .~h i ., I ] i:i : : ~ i Ancho[~ ~ , 23o0 .... ; ..... '" I ; I ; i' ;~ ,I . '. ~ :' 2,40'3 ~ ~ - I ~ '- I ]~ ' BOO 700 BO0 500 400 300 200 100 0 100 : -~00 300: 400 '500 600 ; i <- WEST · EAST -> ' i mi I ! I i I I I i Il m I I I STATE OF ALASKA~ ,fl' ,-,~.ASKA OIL AND GAS CONSERVATION COMM. ~ 51ON . APPLICATION FOR SUNDRY APPROVALS' 1. Type of Request: Abandon X Suspend ~ Operation Shutdown Re-enter suspended well ~ Alter casing __ Repair well Plugging x Time extension ~ Stimulate __ Change approved program ~ Pull tubing Variance ~ Perforate ~ Oth~;' X Plugback for redrill At top of productive interval 1720'NSL, 515' EWL, SEC. 19, T11N, R12E At effective depth 1877' NSL, 460' EWL, SEC. 19, T11N, R12E At total depth 2. Name of Operator 5, Type of Well: BP Exploration Development x Exploratory 3. Address Stratigraphlc 7. P. 0. Box 196612, Anchorage, Alaska 99519-6612 Service 4. Location of well at surface 5- r~ 8. N~s~ Dit & Gas Cons. Commission 6. Datum elevation (DF or KB) KBE = 91.76 feet Unit or Property name Prudhoe Bay Unit Well number Z-02(13-19-11-12) 9. Permit number 88-54 10. APl number 50- 029-21814 11. Field/Pool Prudhoe Bay Field/Off Pool 12. Present well condition summary Total depth: measured true vedical Effective .depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 9900 feet Plugs (measured) 9225 feet 9854 feet Junk (measured) 9182 feet Length Size Cemented Measured depth 110' 30" 8 cu yds 147' 2638' 13-3/8" 3580 cuft 2675' 9222' 9-5/8" 1865 cuft 9259' 901' 7' 325 cuft 8999'-9900' measured 9600'-9615', 9634;9656', 9660'-9667', 9672'-9682', 9686'-9698', 9702'-9708' True vertical depth 147' 2675' 8634' 8396'-9225' true vertical 8947'-8896' (six intervals) Subsea Tubing (size, grade, and measured depth) 4-1/2", L-80 tubing wi4-1/2" tailpipe to 9040' MD Packers and SSSV (type and measured depth) 9-5/8" TIW Packer @ 8939' MD; 4-1/2" Camco SSSV @ 2111'MD 13. Attachments Description summary of proposal x Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 4/2O/95 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas Suspended Service 17. I hereby:? that the~e Signed .;~,/~? ~'~~~4_-~ and correct to the best of my knowledge. Title Drilling Engineer Supervisor FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE WELL PERMIT CHECKLIST COMPANY WELL NAME GEOL AREA UNIT# PROGRAM: exp [] der [] redrll ~ serv [] //J o ADMINISTRATION 1. Permit fee attached .................. N 2. Lease number appropriate ............... N 3. Unique well name and number .............. N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary.. N 6. Well located proper distance from other wells ..... N ' 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party .............. N 10. Operator has appropriate bond in force ......... N 11. Permit can be issued without conservation order .... N 12. Permit can be issued without administrative approval.. N 13. Can permit be approved before 15-day wait ....... N ENGINEERING 14. Conductor string provided ................ Y N 15. Surface casing protects all known USDWs ......... Y N 16. CMT vol adequate to circulate on conductor & surf csg.. Y N~ 17. CMT vol adequate to tie-in long string to surf csg . . . Y N 18. CMTwill cover all known productive horizons ...... 19. Casing designs adequate for C, T, B &-permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. ~ N 22. Adequate wellbore separation proposed .......... ~/ N 23. If diverter required, is it adequate ........... 24. Drilling fluid program schematic & equip list adequate . O N ~~~N 25. BOPEs adequate ............. _~ ~ ..... N 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 ............ ~ N GEOLOGY ? 30. Permit can be issued w/o hydrogen sulfide measures .... Y N / 31. Data presented on potential overpressure zones ..... Y~/~ 32. Seismic analysis 9f shallow gas zones .......... Y/N 33. Seabed condition survey (if off-shore) ........ 34. Contact name/phone for weekly progress reports .... /. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: DWJ~~--~ Comments/Instructions: HOW/jo - A:~FORMS~,cheklist rev 03/94 Z