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Home My WebLink About192-114XHVZE 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. / ¢2"///¢ 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 vadous kinds . [] Other COMMENTS' Scanned by: ~ Dianna Vincent Nathan Lowell Date: [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: ~si THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 13, 2000 P M .1~ A T TH E E E W 'E R IA L UNDER IS M A R K.E R Memorandum State of Alaska Oil and Gas Conservation Commission Cancelled or Expired Permit Action EXAMPLE: Point Mclntyre P2-36AXX API# 029-22801-95 Re: 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 in 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 remain unchanged. The AP! number and in some instances the well name reflect the number of preexisting reddils 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 95. The well name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the AP! numbering methods described in AOGCC staff memorandum "Multi-lateral (weilbore segment) Drilling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician ALASKA OIL AND GAS CONSERVATION COMMISSION October 30, 1992 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Michael Zanghi Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Point McIntyre P2-25 ARCO Alaska, Inc. Permit No: 92-114 Sur. Loc. 122'SNL, 1411'EWL, Sec. 14, T12N, R14E, UM Btmhole Loc. 1878'SNL, 1325'EWL, Sec. 7, T12N, R15E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill 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) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~C~ pti.lied on recycled paper STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25. OO5 la. Type of work Drill [] Redrill FIIl b. Type of well. Exploratory r-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenFlI 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 = 49'feet Point Mclntyre 3. Address 6. Property Designation p, O. Box 196612. Anchorage. Alaska 99519-6612 ADL 365548 4. Location of well at surface 7. Unit or property Name 11. Type Bond(s~e 20 AAC 25.025) 122'SNL, 1411'EWL, SEC. 14, T12N, R14E, UM Point Mclntyre At top of productive interval 8. Well number Number 1944'SNL, 1129'EWL, SEC. 7, T12N, R15E, UM P2-25 U-630610 At total depth !9. Approximate spud date Amount 1878' SNL, 1325' EWL, SEC. 7, T12N, R15E, UM 11/1/92 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (Ma and TVD) , property line ! ADL 34627- 3400 feet P2-49-66'@ 2300' MD feet 2560 15497' MD/9444' TVDfeet 16. To be completed for deviated wells 17. Anticipated pressure (s,~ 2o AAC 25.o35 (e)(2)) Kickoff depth 5oofeet Maximum hole angle 59 o Maximum sudace 3330psi• At total depth (TVD) 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) 30" 20" 91.5# H-40 Weld 78' 37' 37' 115' 115' 245 cu ft Coldset fl 16" 13-3/8" .68# L-80 B TC 4712' 36' 36' 4745 4000' 3596 cuft AS 111/464 cu ft "G" 12-1/4" 9-5/8" 47# L-80 NSCC 15097' 35' 35' 15130' 9126' 644 cu ft Class "G" 8-1/2" 7" 26# 13CR Fox 513' 14980' 8996' 15497' 9444' 186 cu ft Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor ~i~,~ , .... V ~D Surface Intermediate Production ;-.~,"r' ,",., {-) -' Liner -~,~[,2 (')jj ° ..... -- · Perforation depth' measured :'~'~'~ ''-!' o~ u;,~, L;c.i!.S,. true vertical ......... 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 certify3txat the foregoing is true and correct to the best of my knowledge Signed ~7~,~_ u/~ F)' )¢/'0 ' ~. o~ ~,~ ~.',O.,ommissionTitleuseDri//ingEngineerSuperviSOronly Date Permit Number IAPI number IApproval date See cover letter ~'2. ~//' ¢/' ]5 O- 0 ~ '~- 2_ zz_ ~':~" I / ~ --~:7,¢~ ---¢~ for other requirements Conditions of approval Samples req.uir_ed [] Yes _,~NO Mud Icg required I-IYes/~ No Hydrogen sulfide measures [] Yes ~ No Directional survey required /'l~-Yes [] No Required working pressure for BOPE 1-12M; D3M; ~hM; F'IIOM; 1-115M; Other: ORICtNAL SIGNED BY by order of Approved by RUSSELL A. OOUGLA$$ Commissioner me commission Date./~) Form 10-401 Rev. 12-1-85 Submit in triplicate WELL PLAN SUMMARY WELL NAME: PZ-z5 AFE NUMBER: 2C001 6 SURFACE LOCATION: 1 22' FNL & 1411' FWL, SEC 14 T1ZN R14E UM TARGET LOCATION: 1944' FNL & 1129' FWL, SEC 7 T1ZN R1 SE UM BOTTOM HOLE LOCATION: 1878' FNL & 1325' FWL, SEC 7 T12N R1SE UM TOTAL DEPTH: 1 5497 MD/9444 TVD ESTIMATED SPUD DATE: 11/1/92 CONTRACTOR: AUDI 2 ELEVATIONS: PAD: 1 2' Pad TO RKB: 37' RKB: 49' DIRECTIONAL INFORMATION: KOP: 500 BUILD RATE: 2°/100' EOB: 2957/3452 AVG ANGLE: 59°20' BOD: DROP RATE: EOD: FINAL ANGLE: 7976/13212 2°/100' 9001/14665 30° DIRECTION: DEPARTURE at TD: N71 °24'E 11048 FORMATIONS SS Depth Permafrost 1737 K-15 5160 West Sak 6985 K-10 9066 K-5 NP HRZ NP Kalubik" 9066 Kuparuk 9077 Miluveach 9308 CASING PROGRAM 1. Surface casing point @ 4000' TVD to cover build. Z. , Intermediate casing point picked by geologist on location and approved by ddlling supervisor. In this well the casing point is projected to be within the Kalubik formation. TD picked as 100' md below top of Miluveach. Bit Size 30" 16" 12 1/4" 8 1/2" Casing Size Weight .Grade Connection Top Bottom Length 20" 91.5# H-40 WELD 37 11 5 78 13 3/8" 68# L-80 BTC 36 4745 4709 9 5/8" 47# L-80 NSCC 35 15130 1 5095 7" 2_6# Cr-13 Fox 14980 15497 513 , , , , . . , . , 10. 11. P2-25 .Operations Summary MIRU AUDi 2 drilling rig. Spud well and drill 16" hole to 4000' tvd. Set 13 3/8" casing and cement same. Test casing to 2500 psi for 30 minutes. Nipple up BOPs and test same to 5000 psi. Pick up 12 1/4" BHA and drill 10' of new hole and perform leakoff test. Continue drilling to 15130' md / 9126' tvd. Set 9 5/8" casing and cement same. PU 8 1/2" BHA and test casing to 3000 psi. Drill 10' of new hole and perform formation integrity test to12.5 ppg EMW. Displace well to mineral oil core fluid. Drill to top of sand. Core to 50' below WOC at 9118' tvd, and drill 8 1/2" hole to a total depth of 15,497' md / 9444' tvd. Run open hole logs. Set 7" liner and cement same. Clean out 9 5/8" casing. PU 6" BHA and clean out 7" liner; test to 3000 psi for 30 minutes. Circulate well to 9.8 ppg inhibited brine with oxygen scavenger. Recover core fluid. Run cased hole logs. Freeze protect well with 600' of diesel. NU dry hole tree and test to 3000 psi. Release rig. Run tubing string at later date with workover rig. Prudhoe Bay Drillin Poin[ McInLyre Well' P2-25 VERTIGAL VI£W SCALE 500 -F't:, / ]3IVISIBN REFERENCE: WELL HEAD 1000--1 1 20002 2500~ 2546 3000-- 3500-- 3881--. 4000 4500--- 5000-- 5209 5500-- 6000-- 6500-- 7000~ 7034 7500-- 8000 8013 8500-- 9000-- 9186 I 1 I 000 500 0 0.00' 8 0 MD R,K.B. ELEVATION (49,0' ABOVE SEA LEVEL) 0,00' 8 600 MD KOP BUILD 1.0/100' 2.00' 8 800 MD 4.00' ~ 1000 MD 6.00' ~ 1200 MD 8.00' 8 1400 MD : ~ 10,00' 8 1600 MD KOP BUILD 1.5/100' ~ 13.00' e 1800 MD ' \ 16.00' 8 2000 MD ~ 19,00' ~ 2200 MD \ 22.00' e 2400 MD ~ 25,00' @ 2600 MD KOP BUILD 2,0/100' ~7\187 ~k, 31.00' e 2900 MD ' qN 37.00' ~ 3200 MD x,x 43.00' ~ 3500 MD ~ 49.00' ~ 3800 MD . .... ~-~ 55.00' 8 4100 HD ~o~v ~ 62.70' ~ 4485 MD END OF BUILD 1900 ~HL: See... "'7 'T-IZN (Z~ 15H97' mD / c~444'-m,,o ,. MD 13 3/8 CSG. PT. 4243 BHL TVD 9443,60 MD 15496,79 VS 11026,59 North 3515,86 ,~ 6~.70' 87381~DK- 15 . Eas~ 10451.05 ~~~361 MD W. SAK.-- ....... ~ 62.70' 8 13495 MD START OF DROP 9676 ~ 54.70' 8 13895 MD xx 48.70. e 14195 MD ~ 36.70' 8 14795 MD ~ 30.00' @ 15397 MD NILUVEACH 7780 11027 30.00' 8 15497 MD TOTAL DEPTH 500 10001500200025003000350040004500500055006000650070007500800085009000950010000 11000 12000 VERTICAL SECT ION PLANE: 71,41 ° Prudhoe Ba~ Drillin~ ?oint McIntyre Well' P2-25 ( IS iITHI .... I00 HE]RIZBNTAL SCALE 4 O0 REFERENCE: VIEW (TRUE NBA TH) Ft, / DIVISIBN WELL taEA]] 4800 -- BHL -- TVI~ 944S.'gO ~ : MD t5496,79 -- VS 11086.59 : North 3515,86 ~ ~ ~ -- East 10451.05 ~ $ ~ · ~ ~ , ¢· ~ · ~ ~ o . ~ 2 - . I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 441 4000-- 3601 3200-- 2800-- 2400-- '2000-- 1600"--" 1200'"-- B00-- 400-- '" ",?';ii' 80 -:~'" ,1200'"-- · 1600 1200 800 400 0 400 800 1200 1600200024002800380036004000 440048005200560060006400680072007600800084008800920096001000(10400 11200 12000 General Purpose Worksheet ilSubject IPage No. Of By IDate AR3B-6287 d" / / / / / / / / / / / / / / / / O L'II'"/~ 5' mi:)/ urOV....~' TVD 13//oZ,:t / rno 7 '/ 2(,=,~ 13 C~ ~bo Fox ct/q.u,ur '-'rvO MUD PROGRAM - P2-25 SPUD MUD PROPERTIES 0'-4000' TVD Density Marsh Vis Yield Pt. 10 sec gel Spud 8.7 300 40-60 30-60 Mud 9.5 100 20-40 15-20 10 min gel 60-80 20-30 9-10 9-10 APl F.L. 15-25 15-25 Hardness <200 <200 INTERMEDIATE HOLE MUD PROPERTIES: 4000' TVD - 9126' TVD Lightly Dispersed FW Polymer Mud Mud Weight Yield Point 10 sec Gel 10 min Gel 9.5 - 10.2 10 - 20 5 - 10 10 - 20 PRODUCTION HOLE/ CORING FLUID PROPERTIES 9126' TVD - 9444' TVD Versacore LVT-200 Mineral Oil Mud APl Fluid Loss 30 - 6.0 9.5 - 10.0 Hardness < 200 Weight PV YP 10 sec Gel 9.8-10.2 15-20 7-12 5-9 10 min Gel 15-20 HTHP F.L. <2cc i,S, 2000 Pt. Mc Intyre P2-25 Casing Design Specifications SURFACE CASING 13-3/8" 68#/FT K-55 & L-80 BTC CASING BURST COLLAPSE K-55 3450 1950 L-80 5020 2260 PBYS (#) TJYS (#) DEPTHS 1069000 1300000 (0'-80' TVD) 1556000 1585000 (80'-4000' TVD) Burst Pressure Calculation Burst rating based on shutting in the well on a gas kick equivalent to the LOT (14.0 ppg) at the surface casing shoe. Worst case will be in the K-55 casing, which has no back up gradient. LOT (ppg) TVD (FT) SIPRESSURE 14 4000 2912 Burst S.F. 1.1 8 Collapse Calculation Collapse rating based on losing returns until the fluid level is below the surface casing shoe Mud weight behind the surface casing is 9.5 ppg Mud Wt. (ppg) TVD (FT) Collapse press 9.5 4000 1976 Collapse S.F. 1.1 4 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 68 4745 PBYS Tension S.F. 3.88 Mud Wt. 9.5 ppg TJYS 4.71 String Wt. (#) 275810 Pt. Mc Intyre P2-25 Casing Design Specifications SURFACE CASING 13-3/8" 68#/FT K-55 & L-80 BTC CASING BURST COLLAPSE K-55 3450 1950 L-80 5020 2260 PBYS (#) TJYS (#) DEPTHS 1069000 1300000 (0'-80' TVD) 1556000 1585000 (80'-4000' TVD) Burst Pressure Calculation Burst rating based on shutting in the well on a gas kick equivalent to the LOT (14.0 ppg) at the surface casing shoe. Worst case will be in the K-55 casing, which has no back up gradient. LOT (ppg) TVD (FT) SiPRESSURE 14 4000 2912 Burst S,F, 1.18 Collapse Calculation Collapse rating based on losing returns until the fluid level is below the surface casing shoe Mud weight behind the surface casing is 9.5 ppg Mud Wt. (ppg) TVD (FT) Collapse press 9.5 4000 1976 Collapse S.F. 1.1 4 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 68 4745 PBYS Tension S.F. 3.88 Mud Wt. 9.5 ppg TJYS 4.71 String Wt. (#) 27581 0 Pt. Mc intyre P2-25 Casing Design Specifications Production Casing 9-5/8", 47#,L-80,NSCC Casing GRADE BURST L-80 6870 COLLAPSE PBYS (#) TJYS (#) 4750 1086000 1161000 Burst Pressure Calculation Burst rating based on have a tubing leak on top of full column of fluid Worst case will be at the surface, which has no back up gradient. srTP 3420 Burst S.F. 2.01 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/ft) Collapse press 10.2 9126 0.1 3928 Collapse S.Fo 1.21 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 47 15130 PBYS Tension S.F. 1.81 Mud Wt. 10.2 TJYS 1.93 String Wt. (#) 600248 Pt. Mc lntyre P2-25 Casing Design Specifications PRODUCTION LINER 7", 26#,L-80,FOX Casing GRADE BURST L-80 541 0 COLLAPSE PBYS (#) TJYS (Cf) 7240 604000 667000 Burst Pressure Calculation Burst rating based on formation pressure on top of 9.7 ppg fluid Fluid wt (ppg) back up (ppg) Burst Pressure SITP 9.7 9.5 351 2 3420 Burst S.F. 1.54 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg Mud Wt. (ppg) 10.2 Collapse S.F. · Gas Grad. TVD (FT) (psi/ft) Collapse Press 9444 0.1 4065 1.78 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 26 517 Mud Wt. String Wt. (#) 10.2 11346 Tension S.F. PBYS TJYS 53.23 58.79 Surface Casing Depth: Surface Casing Size: Surface Casing Weight: Bit Diameter: Excess Factor Intermediate Casing Depth: Intermediate Casing Size Intermediate Casing Weight: Proposed Top of Cement Bit Diameter: Excess Factor: Liner Size: Liner Weight: Hole TD Bit Diameter: Excess Factor: P2-25 Cement Volumes Surface String 4745 LEAD 13 3/8 68 16 2 TAIL Yield Density # sacks Yield Density # sacks TOP JOB # sacks Intermediate String 15130 9 5/8 47 13629 12 1/4 1.3 Liner LEAD TAIL Yield Density # sacks # bbls Yield Density # sacks # bbls 7 26 15497 8.5 1.4 TAIL Yield Density # sacks 2.17 12 1657 1.16 15.8 400 250 1 .g8 '15 0 0 1.16 15.8 555 115 1.2 15.7 155 (3596 Cuo Ft.) (464 CU. Ft.) ( 0 Cu. Ft.) (644 Cu. Ft.) (186 Cu. Ft.) Computed by the SE Win-CADDS System ~._..~ Calculated using the Minimum Curvature Meth~ Normal Plane Method Date: 10/14/92 REFERENCE WELL: Prudhoe Bay Drilling Point Mcintyre Well: P2-25 File: P2-25WP1 TVD, N/S and E/W are measured from the WELLHEAD WeLlpath SLot Distance Pl-1/pm7 PI-1/PM7 7111.09 P1-11mwd P1-11 6880.33 p1-11 P1-11 6900.11 Pl-12/pm11 P1-12/PM11 8221.66 P1-2/pm3 P1-2/PM3 8221.98 P1-2OWP2 P1-20 8479.15 P1-25/pm12 P1-25/PM12 8553.73 P1-3/pm4 P1-3/PM4 6584.38 P1-7 P1-7/PM8 8285.58 P1-GlWP1 P1-G1 8094.79 p2-30wp2 P2-30 72.32 P2-49 P2-49 66.41 P2-50A P2-50 7833.15 P2-5OMI~) P2-50 404.56 p251mwd P2-51 379.44 P2-55WP P2-55 . 479.43 P2-55mwd P2-55 477.09 p2-56wp P2-56 494.85 P2-57/pm10 P2-57/PHlO 509.82 P2-58/pm6 P2-58/PM6 544.65 P2-59/PM9 P2-59/PM9 428.59 P2-60/pm13 P2-60/PM13 127.26 pm1 PM1 7318.44 I:,a2 PM2 8166.44 Closest Points Direction Ref MD Ref TVD 268.91 272.87 269.33 250.47 242.98 243.56 243.63 274.79 243.39 241.06 191.37 107.83 165.43 202.29 224.28 202.67 204.48 202.12 201.85 217.18 258.28 144.50- 255.42 242.95 2226.24 2200.00 2887.55 2800.00 2772.53 2700.00 1605.15 1600.00 100.00 100.00 0.00 0.00 100.00 100.00 2887.55 2800.00 200.00 200.00 0.00 0.00 900.14 900.00 2332.79 2300.00 9542.16 6200.00 100.00 '100.00 1605.15 1600.00 700.01 700.00 900.14 900.00 100.00 100.00 100.00 100.00 0.00 0.00 1912.37 1900.00 2887.55 2800.00 3005.38 2900.00 300.00 300.00 AUDI #2 13 5/8" 5,000 psi Stack 2.00 · 4.12 12.72 4.50 I3.01 I 3.01 1.83 3.01 2.52 1.5 RKB I I RIG FLOOR GROUND LEVEL DRIP PAN HYDRIL PIPE RAM 17.88 BLIND RAM MUD CROSS PIPE RAM MUD CROSS ASE FLG / 22.38 25.3~ 30.23 34.25 35.75 SUF,., CE hoLE DIVERTER SYSTE?vl ...... Two lines venting gO deg. ap~rt in directions that ensure safe down wind venling, and ex- tending to a point at least 100' from any potential source of ignition. 10' Fu[[ Opening Valves 35' or as required ,._1 Dresser Sleeve 10' Oiverter Line 1. All pipe connections 150# ANSI Flanges or welded connections and secured to prevent movemenL 2_ Manual 10' full opening valves m~hanic~lly connected to ensure that one valve is fail-safe open at ali limes. ,.3. All tums are go deg. and targeted. 1 O' Full opening ball valve w/Hydraulic Actuator Cellar 20' Diverter Spool wf 10' Side Oude~. MEM 1/'3/90 -i~~it ii_~ ...... ['1LID D~t~O qlb'll D£tlC o I]. ] ~0 BBL . 50 Po/. 50 ~;~JD., I q,~#· - TO T^,j · 4BI! w/16 oones (Desil~er) 1 - Driloo Rhrospheric Mud Degasmer 1 - 200 gpm Operating Capacity. Centrifuge 15 - Brandt MA5 Hud Mix AgJ. tators 1- 150 bbl. Trip TaD. k 1 - Raoording drilling fluid pit level indicator with boU] visual and audio warning devices at driller's console ' 1.-Drilling fluid flc~4 sen~or with readout at drili~/k~.',s console Alaska P~,,,25 Pt. Moln ,tyre '10/2.'I /9'2,, M, lk4inder Casing Iht !nt IDeso D~.:;~, s a tD c,,,,,s c: 'Tension ~' ~ · ;.,~ ze Bott(~ m To p I.,,,e n gth L,b s L~rade 'T'h read L,,,b s 1A 20 'f 15 37 78 gt. 5 H.,,4,CI Weld 0 aA 'I 3.(~'75 102 36 88 (.~8 1(-,55 Et'T'C 0 3A ~ 3.375 4.000 38 4:712 68 L,.80 E]'T'C 0 4A 9,8~S 9i 26 35 15097 4.7 r~"FS0,,,S NSCC 0 ~LA 7 94.4,& 8996 5'f 3 ~6 'f 3C1:::~ Fox 0 8A 0 O 0 0 0 0 0 0 7A 0 0 0 0 0 0 0 0 $~ 0 0 0 0 (:) 0 0 9A 0 0 0 0 0 0 0 0 10A 0 0 0 0 0 0 0 '7~,~ 1 Wie,ght PPg 9,5 10,2 0,0 Q.0 0.0 I,..4ydra~ulic~ Gr~die, nf psi/ft 0.000 O.4"94" 0,494. 0.530 0.530 0,000 0.000 0.0O0 0,000 0,000 Mao4Jmum 8830 ,'.~,'.],:~0 3"7'18 3'718 0 0 0 0 0 IVfinimum Yield psi 0 5020 687O '724-0 0 O. 0 #. VAL~J~E [ 1.9 1 ¢: 3C 6C 7C 9C 10C: 'T'ensior~ I~Lbs 7.137 4,.4.88 320,4.16 '7Qg,559 1..:~ ..:~..~ 0 0 O. 0 Stt'en gd-'~ l~Lbs 0 1069 'I (386 0 0 0 0 CJ r,::.'r...[.]o, t-.F:"s i 0 60 1976 4494,0 5009 0 0 0 0 0 Re,~sist, 0 2260 4.750 54.10 0 0 0 0 0 # ITEM APPROVE DATE El) Fee E 2) Loc [~ thru 8] ' Company ** CHECK LIST FOR NEW WELL PERMITS ** YES Is permit fee attached ............................................... ~__ Is well to be located in a defined pool .............................. z[~ thru 13] ' - -" [ 10 & 13] . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. [14 thru 22] NO REMARKS . 2. 3. Is well located proper distance from property line ................... ~ 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. ~ 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ · (5) BOPE '~,~ ?~)'-M~~ [23 thru 28] Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease nLrnber appropriate .......................................... Does well have a unique name & number ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Wi l 1 cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wel l bore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ,~o~> psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... E29 thru 31] E7) Contact (8) Addl -.-,.',.,:i"'. l&-~;-~... geology' engineering: RP ,.~. BEW "O D~7~I~uL/- rev 08/18/~2 jo/fi. Oil 29. 30. 31. 32. 33. FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone number of contact to supply weekly progress data ...... Additional requirements ............................................. ///.,4 , //' Additional remarks' INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE 0 --I 'TZ