The URL can be used to link to this page

Home My WebLink About195-038XHVZE 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. i~,~--O~,~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: Beved~ncent TO RE-SCAN Nathan Lowell Date: Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Isl THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03,2001, PL M ATE T,H IS IA L U N u W M A R K E R Memorandum To; State of Alaska Re: Oil and Gas Conservation Commiasion i BI, Cancelled or Expired Permit Action EXAMPLE: Point Mclntyre P2-36AXX API# 029-22801-95 This memo will remain at the front of the subject well ~e. Our adopted conventions for assigning AP! 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 ddll. 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 preexisti~ redfills and or muitilaterais 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 ddil. 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 AP! numbenng methods descnbed in AOGCC staff memoranaum "Multi-lateral (weiibore segment) Ddiling Permit Procedures. revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician BP EXPLORATION Memorandum From: To: Bob Crandall Date: July 20, 1995 Alaska Oil & Gas Conservation Commission Steve Robinson Doyon 16 Drilling Engineer Permit 95-38, PBU Z-29A Subject: COMM _ ICOMM _ COMM RES ENG ~ , SR ENG ~ NRO ,~ STAT TEC.. ~ STAT TE,,~H'- ~ _ _ _ _ ~:ILE '"'---~ ~%._ The Permit To Drill for this well was not used due to the fact that the well was successfully repaired by fishing multiple obstructions, thus eliminating the need to drill to a new target. Please cancel the permit issued for PBU Z-29A (95-38). /tlh Als. siva Oil & Gas Cons. 6ommissi0il Anchor:' ' , . .,\ , ,; / / ALASKA 0IL AND GAS ,, 'CONSERVATION CO~SSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 31, 1995 Terry Jordan Drilling Engineer Supervisor BP Exploration (Alaska) Inc P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit Z-29A BP Exploration (Alaska)~'Inc Permit No. 95-38 Sur. Loc. 715'SNL, 1358'WEL, Sec. 19, TllN, R12E, UM Btmnhole Loc. 640'NSL, 4121'WEL, Sec. 7, TllN, R12E, UM Dear Mr. Jordan: 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. .' David W.,.~°hnst°n 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 2O AAC 25.OO5 la. Type of work Drill [] RedrilliTIIlb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE = 81.11' feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 47450 4. Location of w~e¢~ .¢~surface 7. Unit or property Name 11. Type Bond(see 2o AAC 25.O25) 715' SNL, 1358' WE"L, SEC. 19, T11N, R12E Prudhoe Bay Unit At top of productive interval 8. Well number Number 238' NSL, 4106' WEL, SEC. 7, T11N, R12E Z-29A (14-7-11-12) 2S100302630-277 At total depth 9. Approximate spud date Amount 640' NSL, 4121' WEL, SEC. 7, T11N, R12E 4/1/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MB and TVD) property line ADL 28262-640' feet No close approach feet 2560 11951'MD/9165' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 8zoo feet Maximum hole angle4~.z o Maximum surface 3330 psig At total depth (TVD) 8800'/4390 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 29# L-80 NSCC 1240' 8550' 6799' 11090' 8562' 8-1/2" 7" 29# cRao NSCC 705' 11090' 8562' 11951' 9165' 290 sx Class "G" n ,-,,,-c !111::D 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary MAR 28 1995 Total depth: measured 12105 feet Plugs (measured) true vertical 9111 feet Ai~$k~ 0il & Gas Cons, Commission Effective depth: measured 12063 feet Junk (measured) Ailc[101'a '~ true vertical 9088 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 81' 20" 117' 117' S u rface 2619' 13-3/8" 36~F 2655' 2641' intermediate 11185' 9-5/8" 2426 cuft "G" 11221' 8608' Production Liner 12069' 7" 386 cuft "G" 12105' 9111' Perforation depth: measured 11715;11720', 11768'-11784', 11794'-11840', 11849'-11850', 11850'-11880'(Open) 11880'-11940'(Squeezed) true vertical (subsea) 8808'-8811', 8837;8846', 8852'-8877', 8882'-8882', 8882'-8899' (Open)8899'-8931' (Squeezed 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 requirementsl-I 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ¢~,f,/ I ~ Title Drilling EngineerSupervisor Date Commission Use Only Permit Number APl number IApproval date See cover letter /~'~"-~.~ 50-0.2_.'~-~/ ¢..¢-~2z'.--~::~/ I ~-~'"~'/'"'~"'~'"" for other requirements Conditions of approval Samples required [] Yes ~ No Mud Icg required []Yes ~] No Hydrogen sulfide measures [] Yes J~ No Directional survey required J~ Yes [] No Required working pressure for~B,O[='E, F12M; i~v3M; 1~5M; [-I10M' i-115M; Other: unglna~ 9-i-gne~l..~, ' byorder of e~ /~h.~ Approved by David W. dohnston Oommissioner tne commission Dar ~)licate Form 10-401 Rev. 12-1-85 Submit I WellName: IDS Z-29A Redrill Plan Summary Type of Redrill (producer or injector): I Producer Surface Location: 4565' FSL, 3595' FEL, S 19, T11N, R12E, UM Target Location: 238' FSL, 4106' FEL, S7, T1 IN, R12E, UM Bottom Hole Location: 640' FSL, 4121' FEL, S7, T1 iN, R12E, UM I AFENumber: 14J8016 I I Estimated Start Date: [ 4/1/95 I I Rig: I Doyon 16 I Operating days to complete: I 19 IMD: I11951. I ITVD: 19165'rkb I IKBE: I81'11' Well Design (conventional, slimhole, etc.): I Sidetrack IObjective: I Retrieve existing fish in the well or sidetrack above the fish to restore Zone 4 I production. Mud Program: A 9.9 - 10.2 ppg Biozan polymer/KC1 water based mud will be used. Special design I considerations none RECEIVED MAR 28 199~ / '_Nasa Oil & Gas Cons. Commission , Anchora ~ 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: 18700' MD IMaximum Hole Angle: Close Approach Well: 45.70 degrees (sidetrack portion) NONE The above listed wells will be secured during the close approach. Redrill Plan Summary Page 1 Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 8.5" 7" 29# L-80 NSCC 1240' 8550'/6799' 11,090'/8562' 8.5" 7" 29# Cr80 NSCC 705' 11,090'/8562' 11,951'/9165' TBG 3.5" 9.3# Cr80 NSCT 11,190 30 11,190 Cement Calculations: I Liner Size: 17" I Basis:I 80"shoe joint + T~)C @ 1000' above Sag River using 50% o~enhole excess Total Cement Volume: 290 sxs of Class G Blend @ 1.19 ft°/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-29 on 1/1/94 to be 11 ppm. Pore Pressure: Sadlerochit pore pressure in Zone 4 is expected to be 4129 psi at 8800' TVDSS or equivalent mud weight of 9.0 ppg. The maximum anticipated surface pressure assuming a gas gradient to surface of 0.1 psi/ft is 3716 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 is 262' TVD below the Kuparuk and the 9-5/8" is cemented to approximately 6100' (by calculation). Therefore, no hazard of Kupamk overpressure is expected. Lost Circulation: A fault in the Kingak will likely be crossed which may cause lost circulation problems. No faults are expected to be encountered in the Sadlerochit which reduces the likelihood of circulation problems in the reservok. The original Z-29 well penetrated the Sadlerochit with 9.5 ppg, reporting only minor seepage of 5 bbls. RECEIVED MAR 28 1995 Alaska Oil & Gas Cons. Commission gnchora ,'. Redrill Plan Summary Page 2 Z-29A INFORMATION Objective: The purpose of this RWO is to pull and replace the 3-1/2" production tubing with a 13Cr completion. A 1700' wireline fish and a rope spear is stuck in the 3-1/2" tubing at about 8942' MD and all rigless fishing options have been exhausted trying to recover the fish. The presence of this fish also makes the ability to recover the entire tubing string questionable. The overshot seal assembly was pinned to the sealbore receptacle at 85,000# of pull. Records indicate that the assembly was not sheared when run and therefore must be sheared to recover the tubing. If the assembly will not shear after multiple attempts, options for continuing this workover will be limited. If the tubing is parted or backed-off above 10,700', the risk of leaving WL on top of the packer is high, leading to the probability of junking the hole. Shearing off the SBR is therefore the critical path for this workover. Inflow performance indicates that a large hole has developed somewhere below the fish (or the packer has failed) suggesting the presence of corrosion which decreases the probability of shearing the SBR. If efforts to repair the well are unsuccessful, the well will be sidetracked to a Sadlerochit Zone 4 target per the attached directional plan. Timing: Doyon 16 will be making a well to well move from well Z-21 to Z-29 on or about April 1, 1995. RECEIVED Scope of Planned Operations: MAR 28 1995 Pre-rig: Alaska 0il & Gas Cons. Commission Anch0ra -. 1. Dummy mandrels above top of fish. Circulate well w/seawater. Bullhead to perfs. 2. Dump-bail 15.8 ppg cement until a tag can be made 10' above the fish. (TOF @ 8983'). Do not dump more than 5 ft3 of cement. 1 ft3 - 20' in 3-1/2" tubing & 4.75' in 9-5/8" x 3-1/2" annulus. 3. Chemical cut tubing in middle of first full joint above fish and cement. 4. Freeze protect and install BPV. Test BPV from below w/100 psi. Rig Workover Operations: , ND tree. NU BOPE. Test BOP's to 5000 psi. Test annular to 250/2500 psi. Pull tree test plug and BPV. Note AOGCC witness or waiver on the morning report. Pull tubing from chemical cut. . TIH w/OS fishing assy PU 5" DP. Engage fish & attempt to shear SBR. OS is pinned to SBR at 85,000#. Redrill Plan Summary Page 3 · If OS will not shear, attempt to release latch with 18 turns to right @ packer. · If OS will not shear and latch will not rotate out, attempt a blind backoff with neutral point close to packer. If tubing and fish recovery attempts fail, skip the remainder of this RWO program and proceed with the sidetrack option. 3. Fish latch. Mill & fish packer w/PRT tool. . TIH w/globe basket on tapered 5" x 3-1/2" DP w/250' of washpipe. Wash over perforating assemblies @ 11,775' & 11,850'. Note: bottom guns (at 11,850') are live and were left in the hole on 7/91. POH LD fish. 5. TIH w/6" bit & cleanout to desired PBTD. POH. 6. TIH w/9-5/8" RTTS & test casing from 10,900'. POH. 7. Run 3-1/2" 13Cr completion 8. Set packer @ 10,900'. ND/NU. RDMO. Rig Sidetrack Operations: , Pre-sidetrack work: Pull SSSV. Dummy mandrels. Cut 3-1/2" tubing just above fish. Top of fish @ 8983'. Kill well. Freeze protect. Install BPV. MIRU Doyon 16. ND tree. NU B©PE. Test. Pull tubing from chemical cut. Attempt to recover remaining tubing and fish. 2. TIH w/EZSV on DP & set same at 8950' above tubing 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 +8695' 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. 2426 cu. ft were pumped during the primary 9-5/8" job when the well was drilled, giving a calculated TOC @ 6160' assuming a 50% washout. Considering the volume pumped, it is highly likely the 9-5/8" is cemented above the proposed window. If there is evidence the window is cut in an uncemented area, increased plug volume to 310 sx. 5. 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. . Drill with a 8-1/2" directional assembly to TD @ 11,938' MD/9118' TVD. Multi- Shot survey w/Sperry-Sun ESS on final trip out of the hole for AOGCC survey requirements. RECEIVED Redrill Plan Summary MAR 28 1995 Aiaska Oil & Gas Cons. Commission Anch0r~..- Page 4 , RU Atlas wireline and Icg with GR/CNL/DLL/BHCS. If hole conditions dictate - the logging sonde length may be reduced and two logging runs may be used. RFT's will be run from TSAD to 30' below OOWC at approximately 10' intervals. Upon completion of logging, make wiper trip prior to running 7" liner. . Run 7" 29# 13CR80 NSCC standard liner assembly to TD with liner top packer and 150' lap. Crossover to 7" 29# L80 liner 300' md above top of Sadlerochit. Space marker joint at top of Sadlerochit (~11,390' MD). 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. 9. Cement liner with the standard sidetrack liner cement blend noted in the "Recommended Sidetrack Practice Version 3.0". Note: Use 20% excess over caliper volume for open hole if the caliper Icg was run from TD to the 9-5/8" casing. If the Icg was not run from TD to the 9-5/8" casing use 50% excess over gauge hole volume. 10. Clean out liner to PBTD and test to 3500 psi. Change over to clean inhibited seawater. Test to 3500 psi for 30 minutes. 11. RIH with 3-1/2", 9.3# 13 Cr80 completion string w/Z" packer positioned +200' md above top of Sadlerochit. Expected packer depth is 11,190'. 12. M/U 3-1/2" 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. 13. Back out & L/D the landing joint. Set blanking plug. N/D BOPE. N/U tubing head adapter and 3" tree. Test control lines to 5000 psi. Test tree and adapter to 5000 psi. Pull the test plug with a lubricator. 14. 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. 15. 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. 16. 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. Drilling Engineer: Steve Robinson, 564-5480 ~ F_ C.;,,. F.. ~V F.. D Redrill Plan Summary sHARE D S~Dv ! el- s DRTLLT..NG ...... Anadri ] ] Schlumbe, rger . Z-2DA (P2) VERTICAL SECTION VIEW ~ ~-,~, L_ '-~--~F ........ . ............................. TVD Scale.: ] inch : 500 leBt .. ,~. ..i .~ ...... ~ : I. ~Dep Scale.: :l. inch :..500 feet '~'~ i ~ ' '"1 -- , L_ ................... ' IDrawn ..... :03/22/§5 : '~u- ~: ................. ~ .......... ~ ..................... ' ' ~ ' ; ..... : Mar~er Identification ~ BKB SECTN INCL " D~ ' A) lIE-IN 8689 6889 4316 49.6 I '-:~ B) 1~ OF WINDOW 86~ 6893 4320 49.5 ' / C) g~ CURVE 6/100 8700 6896 4324 49.5 ..........................~ D) E~ 6/100 CURVE 8765 6940 4372 45.7 '~~-~ ............. ' . E) TARGET-150 FI ~DIUS I~3Bg 877~ 6250 45.7 F) lD !195] 9~65 ~53 45.7 .... '.~.T_~~ , I ' , · i r~rr ix~ ~ · ,~- ~ ..... t ..... ~- '-----~ .......... i ___'~ ........... : .............N . ................[ MA_~___~ S E95 l~i ~ .......... ~ .......... ~ ....................... , lb ITIA[ . ,, - ~ , ! i i i ~ ! I I I I m i i ! i i ~[B$.~$iFi,i~: [::=:=:::=::=':-- - -::=:-::: : :::::::: I . , ~ ;~2 ~ ~[ ................. 4 ........................ ~ ..... I . ~, .,.~ ...... ' i --~ _. ~.~,'~7~~'~¢" ...... ~,.:::,:::::~:::::: , , ~ I ' ,- - I ' i' ' i- ',t i ' I I , - ............ I I ' I "- I ' 'i " I iB .. 3.5.00 3150 4000 4250 4500 4750 5000 5250 5500 5750 6000 6250 6500 6750 7000 7250 7580 7750 eooo Sect ion De)arture ~AflaarIll ic)~ z~&2 BI.5~ II:OI Al !1 MRR-22-1995 11: 24 FROM FtNRDK 1 L_I_ ~ u .... SHARED SERV TcE'S' DRILL I NG ' I L--. II In illl i j ii III I ~n I I I TOP OF WIkq)OW 8695 ,4305 ,458 .- .... D) END 6/100 CURVE 875§ 4357 460 CLOSURE 6659 feet at Azimuth 355.24 E) TARSEl-tSO FT R~DIUS ~1389 6233 536 DECLINATION,' 28.995 E F) TD ]195~ 6636 552 SCALE ...... ;: ] inch -- 500 feet iDRAWN " 03/28/95 ~nadrl 7] $£h]umberger .... ~ooo . J ", I , ~7,o ................. ~ i ......................... ~,--- t ..... , J ! AN,~ DRILL I AKA-[:,PC · j ~F - ,' Ij 1 62,50 ..... ~'A~F_..Z_~.~0 I:T l:lAi]TllC; ~ I ~ .... ,, ......... : 6ooo i. ..... i '' 5'750- ' I Z ' _ ........ L ...... II · 5500 I 5250- ................. m .......... R [6 ...... ! ~ooo ,, I .. ~o r / ' I .......... ~ ........... / ........................ 4750--- ...... j I . ~ ,! '--- ~ ~250 ............................... I ................... I ~000 i :. : , : . , i i : ' i I 3750-,-.-----i-- ...... '. ..... 1 _ ' ~oo , I · 2000 ~750 1500 1250 1000 750 500 250 0 250 500 750 ]000 1250 i500 ,.___. ..' <- WEST' EAST -> i TOTRL P, 07 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon x Suspend__ Alter casing __ Repair well __ Change approved program __ Operation Shutdown ~ Re-enter suspended well ~ Plugging x Time extension Stimulate__ Pull tubing )~ Variance__ Perforate__ Other X Plugback for redrill 2. Name of Operator BP Exploration 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 715' SNL, 3594' WEL, SEC. 19, T11N, R12E At top of productive interval 4983' SNL, 3477' WEL, SEC. 7, T11N, R12E At effective depth 4551'SNL, 3320'WEL, SEC. 7, T11N, R12E 5. Type of Well: Development Exploratory Stratigraphic Service RECEIVED MAR 2 8 1995 6. Datum elevation (DF or KB) KBE = 91.81 7. Unit or Properly name Prudhoe Bay Unit 8. Well number Z-29(24-7-11-12) 9. Permit number 89-65 10. APl number 50- 029-21954 feet At total depth , ~8SkS. 0il & Gas Cons. Commission 11. Field/Pool 4517' SNL, 3310 WEL, SEC. 7, T11N, R12E ' Anch0ra~. Prudhoe Bay Field~Oil)Pool 12. Present well condition summary , ~'"~ ~./'~, Total depth: measured 12,105 MD feet Plugs (measured) true vedical 9,111' TVD feet BKB '-' ~ Effective depth: measured 12,063'MD feet Junk(measured)/ 0 true vertical 9,088'TVDfeetBKB Casing Length Size Cemented Measu~ True~dical depth Structural . Conductor 81' 20'; 117' / 117' Surface 2619', 13-3/8',, 3698cuft Permafrost 2655', ~/ 26411 Intermediate 11,185 9-5/8 2426 cu ft Class G 11221 / 8608' Production , ,~ , Liner 12,069' , 7' 386 cu fl Cl, ass G , , 12,1~, ' , , 91,1' Perforation depth: measured 11715-11720', 11768'-11784', 11794-11840, 11849-11,8'50', 11850'-11880'(Open) 11880'- 11940' (Squeezed) , /~, , , , _ _ true vedical (subsea) 8808'-8811', 8837'-8846', 8852'-8877'~8 2', 8882'-8899' (Open) 8899'-8931' (Squeezed Tubing (size, grade, and measured depth) 3-1/2" 9.2# L-80 w/3-1/2" tailpipe to 11006'. Packers and SSSV (type and measured depth) 9-5/8" TIW Packer @ 10928'; SSSV @ 2303' 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 3/29/95 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 certify that the foregoing is true and correct to the best of my knowledge. Signed Cf,~ 7~/~,~ Title Drilling Engineer Supervisor Date :~' [ ? ''~ <~ FOR COMMISSION USE ONLY Conditions of approval: No. ti~ Commission so representative may witness Plug integrity" BOP Test Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- [Approval No.,~:~-.. 06/ Approved by order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE WELL PERMIT CHECKLIST WELL NAME GEOL AREA UNIT# PROGRAM: exp [] dev~ redrll~ .serv [] ADMINISTRATION 1. 2. 3. 4. 5. 6. 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 ......... Permit can be issued without conservation order ..... Permit can be issued without administrative approval. Can permit be approved before 15-day wait ....... ENGINEERING APPR DATE 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. CMTwill 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 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 .......... / N 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: HOW~o - A:%FORMS\cheklist mv 03/94