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Home My WebLink About194-070XHVZE 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: ~ Dianna Vincent Nathan Lowell Date: [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ Memorandum State of Alaska Oil and Gas Conservation Commission To: Re: Cancelled or Expired Permit Action EXAMPLE: Point McIntyre P2-36AXX API# 029-22801-95 BI, This memo will remain at the from of the subject well file. 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 AP! number and in some instances the well name reflect the number of preexistin~ reddlis and or muitilaterals in a well. In order to prevent confusing a cancelled or expired permit an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to drill. The AP! number for this cancelled or expired permit is modified so the eleven and twelfth digits is 9.r 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 memorandum "Multi-lateral (weiibore segment) Ddiling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. e McMains ' ~ Statistical Technician BP EXPLORATION To: Alaska Oil & Gas Conservation Commission 3001 Porcupine Ddve Anchorage, Alaska 99501 Attention' David Johnston Date' June 15, 1994 Subject: 1-10A Permit (#94-70) 1-10 Plug and Abandonment Sundry (Approval #94-114) · Enclosed is a 10-404 Sundry report for a Workover perfomed on well 1-10. A redriil had been scheduled and approved, however, we were able to complete the work as a workover of the original wellbore. Please cancel permit # 94-70 and Plug and Abandonment Sundry # 94-114. Yours Sincerely, Terry ;Jordan Drilling Engineer Supervisor MS RECEIVED N 2 1 i994 Gas Cons. Commission Anchorage 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 May 3, 1994 Russ Strickland Drilling Engineer ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit 1-10A ARCO Alaska, Inc. Permit No. 94-70 Sur. Loc. 3851'NSL, 3692'WEL, Sec. 8, T10N, R15E, UM Btmnhole Loc. 1535'NSL, 3837'WEL, Sec. 8, T10N, R15E, UM Dear Mr. Strickland: 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 [] Redrill Dllb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []1 Service [] Development Gas [] Single Zone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KBE =72 feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. 0. Box 196612. Anchoraae. Alaska 99519-6612 ADL 28329 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 Mc 25.025) 3851'NSL, 3692' WEL, SEC. 8, TION, R15E Prudhoe Bay Unit At top of productive interval 8. Well number Number 1563'NSL, 3895' WEL, SEC. 8, TION, R15E 1-10A U-630610 At total depth 9. Approximate spud date Amount 1535' NSL, 3837' WEL, SEC. 8, TION, R15E 5/5/94 $200,000.00 12. Distance to nearest 113. Distance to nearest well 4. Number of acres in property15. Proposed depth(uDandTVO) property line ADL28330-1535' feet No close approach feet 2560 9656' MD~9117' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (s~e 20 ^^c 25.035 Kickoff depth 813o feet Maximum hole angle 24 o Maximum surface 3330 psig At total depth (TVD) 8800'/43~)0 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 29t/ L-80 NSCT 100°' 8000' 7500' 9000' 8631' 8-1/2" 7" 2911 13CR80 NSC T 656' 9000' 8631' 9656' 9117' 300 sx Class "G" RE :EIVED 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 9996 feet Plugs (measured) APR 2,9 1994 true vertical 9320 feet Aisska Oil & Gas Cons. Commission Effective depth: measured 9855 feet Junk (measured) Anchorage true vertical 9185 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 100' 20" 100' 100' S u rface 2591' 13-3/8" 7000 sx PF II 2663' 2663' I nte rmed i at e P rod u cfi o n 9870' 9-5/8" 1200 sx "G" & 9942' 9268' Liner 125 sx PF II Perforation depth: measured 9514'-9528', 9548'-9570', 9570'-9584', 9591'-9601', 9612;9622', 9637'-9658' true vertical 8922;8935', 8954;8975', 8975;8988', 8995;9004', 9015'-9024' 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program l'~ Drilling fluid program [] Time vs depth plot~,l-I Refraction analysis I-1 Seabed report[] 20 AAC 25.050 requirementsl-I 21. I hereby certify that the for~oing,~i~tr~u? and correct to the best of my knowledge Signed ~~>~'"-" /' .~"~J~::~ Title DrillingEn~/ineerSupervisor DaIoL{,I'~'/~~- Commission Use Only Permit Number IAPI number IApproval date See cover letter I5°'°~'''~'~'/~'~'''~7 I '~--~.---~:~--~'~--/'"' for other requirements Conditions of approval Samples required .1~ Yes J~ No Mud Icg re~ired'l%Yes ~ No Hydrogen sulfide measures [] Yes ,B;] No Directional survey required )~ Yes [] No Required working pressure for BOPE 1-12M; 1-13M; ~5M; []1OM; I-I15M; Other: Original Signeo By by order of Approved by David W. Johnston Commissioner [ne commission Date Form 10-401 Rev. 12-1-85 Submit in ~)licate I Well Name: IDS 1-10 A Redrill Plan Summary Type of Redrill (producer or injector): I Producer ISurface Location: Target Location: Bottom Hole Location: 3851 FSL 3692 FEL S08 T10N R15E UM 1563 FSL 3895 FEL S08 T10N R15E UM 1535 FSL 3837 FEL S08 T10N R15E UM I AFE Number: I unknown I Estimated Start Date: [ May 1994 I m: 196 6 I [ Rig: [Nabors 2ES [ [ Operating days to complete: [ 16 ITVD: 1904s'ss I IKBE: [72' I Well Design (conventional, slimhole, etc.): I conventional Objective: A sidetrack is recommended for well 1-10 because the tubing is significantly corroded. The remaining rate and reserves that will be recovered from well 1-10 justifies the expected expenditure of a sidetrack. A video log was recently run that confirmed that the tubing from surface to POGLM #2 (6973') is significantly corroded. There is a significant hole at 4039', and the well is currently labeled as an FTS well. A video log has not yet been run below POGLM #2 because, after several attempts, POGLM #1 has not yet been completely fished out of the hole. Well 1-10 has produced 31 MMSTB oil, 10 MMSTB water, and 51 MMSCF gas since it was brought on production in 1975. The original completion is still in place, which will have it's 19th birthday 9/26/94. For a well that has produced 10 MMSTB water, there is a 75% chance that the tubing is corroded beyond repair (See Cumulative Tubing Frequency Attachment). A sidetrack is recommended over either patching the hole or replacing the tubing for the following reasons: A water shut-off would have to be completed to optimize production after patching the hole or replacing the tubing, resulting in possible squeeze-re-squeeze cycle. If the hole is patched, it is very likely that the tubing will need replacement within 1 or 2 years. If the replacement is delayed, there is risk that the tubing could part or be in worse condition than it is today resulting in higher costs to pull the tubing later. If the hole is patched, the well may still FTS due to additional problems at POGLM #2 or below. If only the tubing is replaced, it will not address the probable problem with a corroded liner. If the tubing is corroded, field data has demonstrated that the liner is in at least as poor condition as the tubing. ~ [C[[VF D APR ~ 9 1994 Ai~.ska 0il & Gas Cons. C0rnrnission Anchorage Mud Program: A 9.5 - 10.00 ppg Biozan/KC1 water based mud will be used. Special design considerations I none Depth Density PV YP INT 10MIN FL OIL SOLIDS (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) KOP' 10.0 18 30 15 30 6 0 8 to to to to to to to to to TD' 10.0 18 30 15 30 6 0 8 Directional: [KOP: 18130 MD [ Maximum Hole Angle: [ 24 DEGREES Close Approach Well: NONE Casin: bin: ram: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 8.5 7" 29# 13cr80 NSCT 656 9000/8631 9656/9117 7" 29# L-80 NSCT 1000 8000/7500 9000/8631 4.5" 12.6g 13cr80 NSCT 640 9000-8457 9020/8380 5.5" 17# 13cr80 NSCT 9000 SURFACE 9000/8457 Cement Calculations: I Liner Size: 17" I Basis:[ Total Cement Volume: SHOE JT PLUS 20% EXTRA OVER OH CALIPER @ 300 SKS CLASS 'G' PLUS 7" x 9-5/8" LINER LAP + 100' ON TOP OF LINER INSIDE OF 9-5/8 W/O DRILL PIPE. [Liner Size: [N/A u~s~s:l ' ' ~ E L L: i ~' E u Total Cement Volume: N/A i ,1 i iltllllJllh~lHtl Well Control: ^.0~0~ 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. BOPE and mud fluid system schematics on file with AOGCC. April 26, 1994 DS 1-10A AFE Worksheet Timing: Nabors 2ES will be making a pad to pad move from DS 5 to DS 1-10A in the early part of May 1994. DS 1-10A SUMMARY PROCEDURE: , 10. 11. -12. 13. 14. 1. Pre-rig work: Kill well. Lay cement plug across perforations. Cut 7"x 5-1/2" tubing @ 8958' md (first full joint above packer assembly). Circulate to seawater, freeze protect. 2. MIFIU workover rig. 3. Pull BPV. Circulate out freeze protection fluid. 4. Set BPV. ND tree. 5. NU BOP's. Install tree test plug. Test BOP's to 5000 psi. Pull tree test plug and BPV. Pull and lay down 5-1/2" 17# L80 tubing. Test 9-5/8" packoff at 3500 psi for 15 minutes. Inspect all LDS and replace if needed. 7. Test 9-5/8 casing to 3500 psi for 30 min. If the casing doesn not test the leak will be isolated and USIT or Vertilog-log will be ran. 8. RIH and install bridge plug @ 8330' md. Displace well to Xanvis milling fluid after setting bridge plug. Spot 18 ppg hi-vis pill from bridge plug to base of proposed 9- 5/8" section. POOH. 9. RIH with a 9-5/8" section mill and cut a @ 40' section in the 9-5/8" casing starting at +/- 8130' 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. RIH with 6-1/2" steerable drilling assembly and dress off cement to 5' below the top of section. Kickoff well and directionally drill to align well with target. Drill with a 8-1/2" assembly to total depth of 9656' MD/9117' TVD or 150' MD .below the WOC. Multi-Shot survey on final trip out of the hole for AOGCC requirements. (NOTE: Geology requests that we catch samples from 8850 TVD to target TVD. RU Atlas wireline and log with the triple combo (DDL/Sonic/Neutron/MSFL/4-Arm Caliper). Upon completion of logging make wiper trip prior to running 7" liner. Run 7" 29# 13Cr x N-80 NSCC standard liner assembly to TD with liner top packer and +_150' lap. XO to 7" 29# L80 liner +_300' md above Sag river sand. The placement of marker joint will be determined after the OH logs are completed. RECEIVED ,: 9 i994 Gas Cons. Commission A~;cf]orage April 26, 1994 DS 1-10A AFE Worksheet 15. 16. 17. 18. 19. 20. 21. 22. Cement liner calculating cement volume by using information obtained from 4-Arm caliper run while logging. L/D extra 4-1/2" DP - that will not be required for clean out run. Clean out liner to PBTD and test to 3500 psi. Change over to clean inhibited seawater. RIH with 5-1/2" 17# x 4-1/2" 12.0# 13Cr-80 NSCT completion string w/7" packer positioned +/- 200' md above top of Sadlerochit. M/U tubing hanger - test SSSV lines to 5000 psi for 10 mins. 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 6" tree. Test control lines to 5000 psi. Test 6" 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 5-1/2" x 4-1/2" 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 tubing pressure to shear out the.RP valve in the top GLM position. Displace the tubing w/enough diesel to freeze protect the annulus to 2000'. Allow the diesel to U-tube to the tubing. If possible have the well freeze protected by gas by the PE's in the WOA or DSM in the EOA. RECEIVED Oil & 6as Cons. 6ornrnissior, .Anchorage PRUDHOE BAY DRTLLTNG GROUP PLAN VIEW ~1 ~.~ oF ~,'~.oo o~,v~ a~o ~;~ ,, ' D) TD 9656 2316 CLO~URE ' 2320 feet at Azimuth ~83.40 DECLINATION.' 30.000 E SCALE ' ~ ~nch = ~00 feet DRAGON ' 04/24/94 Ana¢il] Schlumberger , ~ ~g5o ..... ~ ; ...... ¢ / ! ~ 2000 -' ~ ! ~ ~ : ~ ...... '~ 2050 ........ ' ~ ~ -- ~ - .-i ........ ; .......... I ~ ' ~ 2~00 .... ' I ,, I ; ~ ? .............. . ..... : ................. i 2300-- : '~ ,, /i ~,oo ! ,, FCE VEl) , ..F F~ , Z'} i/ ¢~i~.sk~ 0~ & Gas dons. Com:nission a5oo-- ' ~ ,' ~ ~ t AnchOrage .... ~. ~ ....... 600 550 500 450 ~00 350 300 250 ~00 JSo ~00 50 0 50 ~00 <- NEST' EAST -> TOTAL F'.O? "' PRUDHOE BAY-"I RT_LTNG ( 'ROUP A) lIE-iN 81:]O 762! 6c_7 ,~ ~,oo~;,oo~,~ ~o ~oo~ ~o~ ~.,~ VERTICAL SECTION VIEW D) TO 9656 9i~7 89J 9,~B Sec[~on at' ~J5.99 TVO Sca]e.' J inch = 300 feet Oep Scale.' J inch = 300 feet 7500 ~ ,r- I ~ Dnawn · 04/24/94 7fi50 ........ ¢ ~ ~ ............... ~ ......... I ~ 7950 ...... ~ . · '~ ~ ~ - . ~ ....... ~ ...... 8~oo.- ~ ! ..... ~ ! [ I f .................. ' ~ ~' ' ~ i 8P50J ....... 'I~~ ~ ~ I - ~ 8400 ..... . ~ ~ ~ ~ '"~ ......... ~ i ,r.~¢ ....... ; .......... F ' ' '~' ~o .... ~ ', ~ ~ , , ........................ 8700 .............. '- ................ ~-. : ' I ~ '¢~ - ~' ...... ..... ~ ..... i.-.~_~ .... ~ ..... ~ .......... ~ ..... B ~50 ~ ~ ~ D ....... ; ............. - ~ ....... ~'- i .................. ' ~,)'0~¢ ..... 0 iS0 300 ~50 600 750 900 I050 i200 t350 iS00 J550 1800 ~950 2~00 Section Departure BP EXPLORATION ARCO Alaska, Inc. To: M. Kennedy/L. Lash PBR- 20 Date: April 26, 1994 From: Z. Runje MB 12-1 Subject: .DS 1-10A Pre Rig Work The DS 1-10A well is currently scheduled to be sidetracked by Nabors 2ES. Current estimate for the start of rig work on DS 1-10A is the first week of May 1994. Contact the Prudhoe Bay Drilling Representative on Nabors 2ES (659-4835) for the most accurate moving schedule update. The AFE and Permit for the program have not been approved. Contact Zeljko Runje at 564-4825 if there are any questions regarding this matter. To prepare for the redrill, the following actions will need to be taken prior to the rig move' 1. Notify an AOGCC representative prior to commencing operations. 2. Rig up slickline unit - RIH and pull Otis's SSSV located at @ 2215' md . RIH w/coiled tubing unit and position abandonment plug from PBTD ( 9658' md) to +/- 100' md above upper perforation top @ 9400' md. Note: Cement top tag to be witnessed by AOGOO representative. 4. RU E-line - RIH and make tubing cut @ first full joint just above the packer assembly which is located at @ 8978' MD. 5. Circulate well over to filtered seawater and freeze protect the upper ~ [ C .~IV [ D 2000' md of the well. 6. Bleed tubing, inner annulus, and outer annulus to 0 psi. !-;I':~R '~ ;,,.,..~_:-:t~ ~ii & Oas Cons. Commission 7. Set BPV. Remove the well house and flowlines. Level the pad and A~chorage dig out the cellar if required. Prepare pad for RWO. NOTE #1' if 13-3/8 x 9-5/8 annulus valve is oriented towards the pad it will have to be re-installed so that it faces the reserve pit. The rig can not rig-up on this well unless the valve is facing the reserve pit. NOTE #2: This procedure is written with an assumption that POGLMs have been recovered from the wellbore. Z.R. April 26, 1994 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISb,~ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Al~mdon x Suspend ~ Operation Shutdown~ Re-enter suspended well__ Alter casing ~ Repair well ~ Plugging ~ Time extension ~ Scmula~e __ Change approved program ~ Pull tubing Variance__ Perforate ~ Other x __ Plugback for redrill 2. Name of Operator ARC° Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development x Exploratory ~ Stradgraphic __ Service 4. Location of well at surface 1432' SNL, 1581' EWL, SEC. 8, TION, R15E At top of productive interval 1178' NSL, 1148' EWL, SEC. 8, TION, R15E At effective depth At total depth . 995' NSL, 1048' EWL, SEC. 8, TION, R15E RECEIVED /.'-.,PR 2 8 i994 ~ 6as Cons. CotrlllTlJss[ort Anchorage 12. Present well condition summary Total depth: measured true vertical 9996 feet 9320 feet Plugs (measured) 6. Datum elevation (DF or KB) RKB-- 72 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 1-10 9. Permit number 75-43 10. APl number 50- O29-20169 11. Field/Pool Prudhoe Bay Field/Off Pool Effective depth: measured 9855 feet Junk (measured) true vertical 9185 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 100' 20" 100' 100' S u dace 2591' 13-3/8" 7000 sx PF II 2663' 2663' Intermediate Production 9870' 9-5/8" 1200 sx "G" & 125 sx PF II 9942' 9268' Liner Perforation depth: measured 9514'-9528', 9548'-9570', 9570'-9584', 9591'-9601', 9612'-9622', 9637'-9658' true vertical 8922'-8935', 8954'-8975', 8975'-8988', 8995'-9004', 9015'-9024' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, NPCT @ 8992'MD; 4-1/2", 12.6¢/, MN-80, NPCT tail @ 9116' MD, Kinley Buttons @ 4042' MD and 6960' MD Packers and SSSV (type and measured depth) Baker SAB Packer & K-Anchor @ 8978' MD; Otis RQ SSSV @ 2215' MD 13. Attachments Description summary of proposal x Detailed operations program ~ BOP sketch __ 14. Estimated date for commencing operation 4/30/94 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 certify that the foregoing is true and correct to the best of my knowledge. Signed ~c_; ~~--~---- Title Drilling Engineer Supervisor FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity . ~ BOP Test__ Location clearance__ Mechanical Integrity Test__ Subsequent form required 10- ~o ? Original Signed B! Approved by order of the Commission D3V!¢.. ?,J. J0hnstnr~ , Approved Copy Returned Form 10-403 Rev 06/15/88 lAppr°val N°i? ¢--~,' Com missioner Date .-'C/z/¢"V S%M T IN 'm UCATS WELL PERMIT CHECKLIST v COMPANY ~NIT CLASS WELL NAME GEOL AREA UNIT# PROGRAM: exp [] dev~ redrll ~ serv [] ADMINISTRATION 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............ 5. Well located proper distance from drlg unit boundary. 6. Well located proper distance from other wells ..... 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 ....... N Y N Y N .Y N .Y N Y N Y N Y N .Y N .Y N Y N .Y N N ENGINeerING APPR _. D&~. 14. Conductor string provided ............... ~Y~/ N~ 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 ...... Y~ N 19. Casing designs adequate for C, T, B & permafrost .... Y~) N 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 ~ N 25. BOPEs adequate .................... .~ N 26. BOPE press rating adequate; test to ~ psig. N 27. Choke manifold complies w/API RP-53 (May 84) ....... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............. y GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y /N 32. Seismic analysis of 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: BEW DW~ Comments/Instructions: HOW/]o - A:%FORMS%cheklist rev 03/94 Z