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Home My WebLink About192-105XHVZE 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. (~o~.. File Number of Well History File PAGES TO DELETE RESCAN Complete [] 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 [] TO RE-SCAN Notes:- Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: ~si ON OR BEFORE Memorandum To: Well File: Re: State of Alaska Oil and Gas Conservation Commission Cancelled or Expired Permit Action EXAMPLE' Point McIntyre P2-36AXX API# 029-22801-95 This memo will remain at the front 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 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 remain unchanged. The APl number and in some instances the well name reflect the number of preexisting reddlls 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 APl numbering methods described in AOGCC staff memorandum "Multi-lateral (wetlbore segment) Ddlling 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 CO~I~IISSION / / WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 October 16 1992 Michael Zanghi Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit DS 17-18i ARCO Alaska, Inc. Permit No: 92-105 Sur. Loc. 2535'SNL, 991'EWL, Sec. 22, T10N, R15E, UM Btmhole Loc. 3994'SNL, 1933'WEL, Sec. 22, T10N, 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. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and 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 tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. J~hnston ~ 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 25.005 la. Type of work Drill [] Redrill[]llb. Type of well. Exploratory[Z] Stratigraphic TestE] Development OilFI Re-Entry [] DeepenE]I 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 = 66'feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612 Anchoraoe. Alaska 99519-6612 ADI 28331 4. Location of well at surf-ace 7. Unit or property Name 11. Type Bond(~,e 2o ^^c 2535' SNL, 991' EWL, SEC. 22, TION, R15E, UM Prudhoe Bay Unit At top of productive interval 8. Well number Number 3941'SN!.., 2019' WEL, SEC. 22, TION, R15E, UM DS 17-18i U-630610 At total depth 9. Approximate spud date Amount 3994'SNL, 1933' WEL, SEC. 22, TION, R15E, UM 10/18/92 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property'15. Proposed depth (MD andTVD) property line feet DS 17-10/51'@ 2898'MD feet: 2560 9800'MD/9221'TVDfeet 16. To be completed for deviated wells 17. Anticipated pressure (se~ 2o AAC 25.035 Kickoff depth 255ofeet Maximum hole angle 24 o Maximum surface 3330pslg At total depth (TVD) ~O0'/4390pslg 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD M D TVD (include stage data) . 30" 20" 91.5# H-40 Weld 80' 29' 29' 110' 110' 450 # Poles et 13-1/2" 10-3/4" 45.57/ NZ'aOLHE BTC 3574' 28' 28' 3602' 3566' 1150/250 sx AS 111/11/350 sx "G" 9-7/8" 7-5/8" 29. 7# NT95HS NSCC 9773' 27' 27' 9800' 9221' 368 sx 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 Surface Intermediate Production ()0-,!' '-' 9 Liner Perforation depth: measured Alaska Oii &rcas Cons. true vertical Anchorage 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 FI 21. I hereby cer~, that the foregoing is true and correct to the best of my knowledge Signedi.~.. -~'~CommissionTitleuseDri/fin'En~ineerSuperviS°ronly Date/O'"'~'"'~' ~ '~ Permit Number ~' IAPI number IAppr/o/~¢l d~ ISee cover letter ~'.2-/'O.d' 150-o~, - ~ ~_z ?¢'~ /~ -/~-~/~,¢~, Ifor other requirements Conditions of approval Samples required [] Yes ,.1~'NO Mud Icg requir.ed i-IYes~'NO Hydrogen sulfide measures [] Yes ~_ No Direction~ survey requ~red~ Yes FI'No Required working pressure for BOPE 1-12M; 1-13M; /B~5M; []10M; []15M; Other: ........... by order of Approved by Origina! ~-~,~od,.. By Commissioner [ne commission Date ............... David W. johnston Form 10-401 Rev. 12-1-85 Submit in triplicate WELLNAME: SURFACE LOCATION TARGET LOCATION TD LOCATION ESTIMATED START DATE: ESTIMATED DAYS TO COMPLETE: CONTRACTOR: MAX ANGLE / DEPARTURE: KOP: BUILD RATE: SECTION COURSE: Grnd Elev/RKB-Grnd/RKB Elev: FORMATION & CASING DEPTHS: ITEM 20" Conductor 10-3/4" shoe Ugnu K-lO K-5 7-5/8" x 7" shoe Top Sag River Sandstone Top of Sadlerochit (TARGET) HOT Oil Water Contact Total depth WELL PLAN DS 17-181 2535 FNL 991 FWL S22 T10N R15E UM 3941 FNL 2019 FEL S22 T10N R15E UM 3994 FNL 1933 FEL S22 T10N R15E UM 18 OCT 92 19 days (15 drilling & 4 to complete) NABORS ALASKA DRILLING RIG #18E 24° / 2773' 2550' MD 2.5°/100' S 58.2 E 36.5' / 29.5' / 66 TVD (BKB) MD (BKB) MUD WT (_PPG) 80' 111' 8.5 3566' 3602 8.5 5881' 6139 9.0 -10.0 7386' 7789 9.5 -10.0 8051' 8518 9.5- 10.0 8899' 9447 8899' 9447 8996' 9553 9.5 -10.0 9053' 9616 9.5- 10.0 9084' 9650 9.5 -10.0 9221' 9800 9.5- 10.0 CASING PROGRAM Hole Cs.g Wt 30" 20" 91.5# 13-1/2" 10-3/4" 45.5# 9-7/8" 7-5/8 29.7# Grade Conn Length Top Btm H-40 WELD 80 29 110 NT80LHE BTC 3574 28 3602 NT95HS NSCC 9773 27 9800 COMPLETION Tubing: 4-1/2" 12.6# L-80 TDS 9218 29 9247 GLMs: None Packer: Baker 7-5/~"' x 4-1/2" set @ 200' above Sag River Fmtn LOGGING PROGRAM Open Hole: Cased Hole: 9-7/8" Hole:DIL/GR/SP/SDT Alask~ ~.Ju & ~.::,i.~,..S OOllb ~.,~;ij;IFIjssioi~ CET/CBT/GR in 7-5/8" before running tubing. Ar~cr~0ra~e No Gyro will be run DS 17-181 Procedure , MIRU drilling rig. N/U diverter and function test same. Drill 13-1/2" hole to surface casing point. Run and cement surface casing. Nipple up BOPE and function test same to 5000 psi. 3. PU 9-7/8" BHA and RIH. Test casing to 2800 psi for 30 minutes. of new hole and perform leak off test. 10-3/4" Drill 1 O' 4. Drill 9-7/8" intermediate hole to TD 5. Run open hole logs as programmed. 6. RIH to condition wellbore prior to running casing string. . , RU and run 7-5/8" casing string and cementing top plug w/8.6 ppg filtered sea water. PU 3-1/2" DP. RIH and clean cement clean seawater. Test casing to 3500 psi. cement as per from casing/liner. well plan. Bump Displace well to 9. RU e-line and run cement bond log in bottom of 7-5/8". 10. Run 4-1/2", L-80 tubing and packer assembly with SSSV. with diesel. Set packer and test tubing and casing to 3500 psi.. Freeze protect 11. NU tree and test to 5000 psi. Release drilling rig. o Anticipated BHP: o Maximum Anticipated Surface Pressure: o Planned Completion Fluid: 3600 psi @ 8800' TVD SS 2800 psi 8.6 ppg filtered sea water Notes: a. The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.003. b. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/~. c. Based on previous logs on DS #17, no potential productive zones are anticipated above 8899' TVD. d. No potential hazardous levels of H2S are anticipated in this well. Alask;~ Oil & Gas Cons, DS 17-181 DRILLING DISCUSSION DS 17-181 is a slant slimhole well injector with a 10-3/4"/7-5/8" Iongstring casing program. The option to long string the well will be evaluated after reaching the intermediate casing point ( 10' tvd above top of Sag River Formation ), Open hole conditions and mud weight requirements will determine the use of the Iongstring. Approximately 124 feet of Kingak shale will be exposed above the Sag River formation, Problems with this interval usually respond to moderate mud weight increases, The DS 17-181 well target is prognosed for the top of Sadlerochit ( ZULU flowunit ). There is no expected gas cap in the well. Faulting in the near target area is not a concern and a 250' target radius will be used. There is no evidence of geopressuring in the Cretaceous interval in the intermediate hole section and no preplanned increases in mud weight are recommended while drilling this interval. The completion will include 4-1/2" L-80 TDS (non coated) tubing with no GLMs, ANNULAR INJECTION The DS 17-16 & 17-15 surface annulus is available for injection at present, Fluids can also be injected at the central CC-Z injection facility, AOGCC has informed PB Drilling that only associated fluids from drilling operations can be pumped down the surface x intermediate annulus-ie: completion fluids cannot be pumped, FREEZE PROTECTION The 4-1/?_" tubing along with the 4-1/2" x 7-5/8" annulus will be freeze protected by circulating and u-tubing diesel prior to setting packer, Dry crude needs to be injected down the 10-3/4" x 7-5/8" annulus after the well is completed, CLOSE APPROACHES/SHUT-INS Note near well proximity of wells DS 17-9 and DS 17-10. 17-9 close approach occurs from 19' to 2959' md', A tail plug must be installed and the SSSV will be shut-in. The well can be brought back on line once the surface casing is set. The 17-10 close approach occurs from 19' to 3210' md and a plug will be set in the tail pipe and the SSSV will be shut-in, The well can be brought back on line once surface casing is set, Notify EOC coordinator when wells can be brought back on line, ~~! E ~ i~¥;'~ .L: !;~ Alaska. Oil & Gas (;OHS. FROM:GREAT LAND DIR.DRILL~~=- TO: 90? 564 519J -'.OCT 1, 1992 8:48AM P.02 GR~AT LAND DIRECTIONAL DRILLING~ INC. Corporate Office 1111 East BOth Avenue Anchorage, AK 99518 (907) 349-4511 Fax 349-2487 DIRECTIONAL WELL PLAN for PRUDHOE BAY DRILLING Well ......... : DS 17-18i (P1) Field ........ : PRUDHOE BAY DRILL SITE 17 Computation..: MINIMUM CURVATURE Prepared ..... : 10/01/92 section at...: s,58.24,E KB slevation,: 66,00 LEGAL DESCRIPTION Surface ...... : 2535 FNL 991 FWL S22 T10N R15E UM Target ....... : 3941 FNL 2019 FEL S22 T10N R15E UM BHL .......... : 3994 FNL 1933 FEL 822 T10N R15E UM X ASP ZONE 4 709245,62 5928109.77 711555.81 5926767.14 711643.05 5926716.49 PROPOSED WELL PROFILE STATION IDENTIFICATION KB KOP BUILD 2.50/100 MEAS INCLN DEPTH ANGLE VERT-DEPTHS SECT BKB SUB-S DIST 0 0.00 0 -66 2500 0,00 2500 2434 2550 0.00 2550 2484 P600 1.25 2600 2534 2700 3.75 2700 2634 DIRECTION REL-OOORDINATES BEARING FROM-WELLHEAD 0 N 0.00E ON 0E 0 S 58.24 E 0 N 0 E 0 S 58,24 E 0 N 0 E i S 58,24 E 0 S 0 E 5 S 58,24 E 3 S 4 E DL/ 100 0,0 0.0 0.0 2.5 2,5 2800 6,25 2800 2734 2900 8.75 2899 ~833 3000 11.25 2997 2931 3100 13.75 3095 3029 3200 16.25 3191 3125 14 $ 5@.2~ E 7 S 12 E 27 S 58.24 E 14 S 23 E 44 $ 58,24 E 23 S 37 E 66 $ 58,24 E 35 S 56 E 92 S 58.24 E 48 S 78 E 2.5 2.5 2.5 2.5 2.5 END OF 2,50 BUILD T-5 3300 18.75 3287 3221 3400 21,~5 338~ 3315 3500 23.75 3473 3407 3517 24,17 3488 3422 3574 24.17 3541 3475 i22 S 58.24 E 64 S 103 E 156 $ 58,24 E 82 S 132 E 194 S 58.24 E 102 S 165 E 201 S 58,24 E 106 S 171 E 225 S 58,24 E li8 S 191 E 2.5 2,5 2.5 2.5 0,0 SURFACE CASING K-15 UCNU K-12 K-10 3602 24,17 3566 3500 4988 24.17 4831 4765 6139 24.17 5881 5815 7191 24.17 6841 6775 7789 24,17 7386 7320 236 S 58,24 803 -S 58,24 1274 ~ 56.24 1705 S 58,24 1950 S 58.24 124 S 200 423 $ 683 671 $ 1084 898 S 1450 1026 $ 1658 0.0 0.0 0.0 0,0 0,0 K-5 LCU/KIN~AK SAG RIVER SMUBLIK T. IVISHAK SD. TARGET HOT OOWO TD B, IVISHAK SD. 8518 24.17 8051 7985 9323 24.17 8786 8720 9447 24,17 8899 8833 9472 24.17 8922 8856 9553 24.17 8996 8930 9553 24.17 8996 8930 96~6 24.17 9053 8987 9650 24.17 9084 9018 9800 24,17 9221 9155 9556 9490 2248 S 58.24 2578 S 58.24 2629 S 58.24 2639 $ 58.24 2672 S 58.24 2672 S 58.24 E 2698 ~ 58.24 E 2712 $ 58.24 E 2773 S 58,24 E 1183 S 1911 1357 S 2192 1384 S 2235 1389 S 2244 1407 S 2272 1407 S 2272 E 1420 S 2294 E 1427 S 2306 E 1460 $ 2358 E 0,0 0,0 0.0 0.0 0,0 0.0 0.0 0.0 0.0 (I~LI~D (¢)9~ 0517'18P B1.35 §:14 AN I) FROM:GREAT LAND DIR.DRILL~ TO: 90? 564 5193 --OCT 1, 1992 B:48AM PoOl PRUDHOE BAY ..... '-i,- '- ~s'- ' -~" ii' ....... 1, ~ ---- H ~ .... :---4-; " ....... ~ .,Ti ........... k- ,..~: ..... .i..-:--.~..=~.--L: ....... .!,_!t ~ I i!~ _.t !i' i I I ' I- I-' ~ .................... '-1 i' X .~.:-: .::--:I. :: 7:!.-".' "7: ._-t--i ' ' ' I , "q-T,' i .......... .t ,. I .'~. ! .I- ......... i--'~'.. ::-i.'~ *---?; 7. 3.-1. -i--t , i i-- ~ -._-E'--: ............... ':r...! .t ti..-t-~d-~--!- i i: q-j-'-r-'~',--lq"~, * t ...... _i__ ; --,_i; t ! , i "'k'-Ti'--~-t'-! ................... /I-! , ,1., '-,"-m F~.J_.! i j i ~{ I . - ........... t ..... I.. -"{-.l ...... .... "'1 ~ ~ ~'~' ~'~ "' '~ '"'; ~'~'" :'.'~ -"-rl!i t'-i, ill i! i j \' -- ~-'~ ..... '!. ..... : ~L~"' 'L'"_'.'i_-1_~7_ _. _~_-:'..' ..'..u?._i ~t ~",,-- -.-'-~.x.---, ..... :'i, ..... J-U .... . · = . :,..... 12 :-) ' ' ' iq Ii i-J'-q t I iI ii,, 'ii 'uli,! 'q ~;~,~'-- - r--, .... .-r-.,-F !' . .... -i .... l"i ......... '-J- - ' ~" ' ............... ~ ~ , -i ,_-7..... ! ..... 1 ............... - i-. . ........ \J I .............. .J - .t-T_ "" ;'! .-.'-Fi Iiii I- - ..11!1 .] , " il .... I~1 ..... ~ ....... i4 j ": i-':\i _.-4-1 .... .~.'i i,:,, i ..-m---t ..... u.u -~¢¢k.,ti ........... 11'"' I ~ ' ! i ....... 1 ..... "1 I .- 1-713"1 ........ ~- I ! i I I ',~' ~r~r " *- '" 3L'. _'_ :-. IE.. "'_I'- ' ~_--_ .................. I'''!'-'-I . ! ' ' ~ ---i- 'l-'-.:j_,.---7.~ i 'i ' ---.----2 J I I / "'X- ~ [___ "r ' , : :1- q:.::::':."!,. ........... t ........ ,, .~..., .~_,_;. ~ ,,...~ ...., _.!_ ~..,,.. ~...,:, o 600 l~oo 1Boo ~400 3000 3600 Section uep8p~ u).'~,.~_ . .... {.3',_DD jo)g2 DS~.71.B~ BI ,~5 O: 82 AH t) DRT. LLT. NG i l! i, .......... DS 7-18i (pi) VERTZCAL SECTZON VZEN ,.., ,, ,,, _ ,_ j ................. ~j_~ .. , ......... t ; Section at' S 58,24 E TVD Scale,' ~ ~nch : 1200 feet Dep ScaIe.' J ~nch : 1200 feet Drawn ' ~0/01/92 great Land DirectJona! Drilling Mocker Identification ND BKB SECTN INCLN ~) KB 0 0 0 0,00 B) KOP BU]LO 2,50/100 8550 2550 0 0.00 C) ENO OF 2.50 BUILD 3517 3488 201 E4.t7 D) SURFACE CASING 3602 3566 236 24.17 E) TARGET 9553 8996 2072 24.t7 F) TD 9800 9221 2773 24,~7 FROM:GREAT LAND DIR.DRILLT .... TO: 90? 564 51S~ ..... OCT 1, 1992 B:49AM P.04 ......... PRUDHOE iii ii ii A} ~8 0 0 N B) KOP BUILD 2.50/~00 2550 0 N C) END OF 2.50 BUILD 35]7 lOG ~ O) SURFACE CAS]NG 3602 ~24 S E) ~ARGET 9553 1407 S F) TO gBO0 ~450 S B- Y DRILLING DS E/W 200 ~ 2272 E 235B E CLOSURE ..... : DECLINATION.: SCALE ....... DRAWN ....... ; 17- 8i PLAN VlE~ ........... ~ . _~- .... :"':.';'% .r&.'._: _~ .:'. ? 2773 ft at $ 58.24 E 30.20 E ~ ~nch = 500 feet ~0/0~/92 SPear Land DJrectiona] DrJllJng 250 0 250 <- ~EST ' EAST -> 500 FROM:GREAT LAND DIR.DRILL!~ TO: 90? 5B4 5193 .... OCT 1, 1992 B:50AM P.05 Great Land Directional Drilling, Inc. Collision Avoidance Analysis Planned Well: DS1718P Pad: D$17 Field: NSLOPE 09/30/92 08:20:49 Closest Approach Existing Sep Depth Well min ft TVD ft MD ft D$1716P 239 0 0 D$1715P 119 66 66 DS1717P 538 0 0 DS1719P 529 0 0 DSl?20P 622 0 0 DS1701G 541 2595 2595 DS1702G 507 2595 2595 DS1703G 511 2471 2471 DSi704G 529 2594 2594 DSl705G 567 2586 2586 DS1706G 645 2594 2594 DE1708G 160 2570 2570 DS1710G 51 2897 2898 DS1711G 135 3345 3362 DSI712G 159 1796 1796 DS1713G 297 3540 3574 DS1714G 143 3699 3748 100ft [MD'SI 25ft Warning band Serious band ~ta~t End Start End 19 3210 started: 08:20:49 ended: 08:24:27 MUD PROGRAI~I The mud program for this well shall follow the new Mud Policy. The following are mud parameters identified for the surface and intermediate hole sections. MUD SPECIFICATIONS- SURFACE HOLE Surface: Casino point: Mud Weight: ppg 8.5- 9.5 8.5 - 9.0 Funnel Viscosity sec/qt ~300 <100 YP Ibs/100ft2 40 - 60 20 - 40 10 sec Gel lbs/100ft2 30 - 60 15 - 20 10 rain Gel Ibs/100ft2 60 - 80 20 - 30 pH - 8.5 - 10 8.5 - 10 APl Fluid loss mi/30 min 15- 25 15- 25 Hardness mg/I < 200 <200 MUD SPECIFICATIONS- INTERMEDIATE/PRODUCTION HOLE Surface casing shoe to Top 'K' shale (~6000 - 7000'): Top 'K' Mud Weight ppg 9.5 - 10.0 Yield Point lbs/100ft2 10 - 15 10 sec Gel lbs/10Oft2 5 - 10 10 min Gel lbs/100ft2 10 - 20 APl Fluid Loss mi/30 rain <15 pH -- 9.5 - 10.0 Hardness mg/I < 200 shale to Section TD. Mud Weight ppg 9.5 - 10.5 Yield Point lbs/100ft2 10 - 20 10 sec Gel lbs/100ft2 5 - 10 10 rain Gel Ibs/100ft2 15 - 25 APl Fluid loss mi/30 rain 6.0 - 8.0 pH -- 9.5 - 10.0 Hardness mg/Itr < 200 Gar; Cons. Cormnission Pilot test the addition of 1% KCL into mud prior to drilling production interval. If rheology remains adequate and excessive use of dispersants is not required, add KCL to system. If pilot test results are marginal or poor, do not add KCL to active mud system. The KCL is intended to reduce formation damage problems. However, thinners and dispersants will increase the potential for damage. For more detailed information refer to the Prudhoe Bay Drilling Mud Policy that resides in DRILLING VOLUME #1 (file server) under the MUD POLICY folder. CIRC. TEMP 40°F 10-3/4" SURFACE CASING CEMENT PROGRAM - DOWELL SPACER: 75 bbls fresh water ahead of lead slurry. LEAD CEMENT TYPE: ASIII ADDITIVES: retarder WEIGHT: 12.1 ppg APPROX #SACKS: 1150 YIELD: 1.94 ft 3/sx THICKENING TIME: 4:30 hrs MIX WATER: 11.11 gps TAIL CEMENT TYPE: CLASS G ADDITIVES: 2% S- 1 (CaCL) WEIGHT: 15.8 ppg gps APPROX #SACKS: 350 YIELD:1.16 ft 3/sx THICKENING TIME: 4 hrs MIX WATER: 5.0 TOP JOB CEMENT TYPE: ASII ADDITIVES: retarder WEIGHT: 15.0 ppg YIELD:O. 936 ft 3/sx gps MIX WATER: 3.89 APPROX #SACKS: 250 CENTRALIZER PLACEMENT: 1. Run one bow type centralizer & stop collar per joint for the first 20 joints. 2. Place the centralizers in the middle of each joint with a stop collar. 3. Run two bow springs inside the conductor pipe on stop collars. CEMENT VOLUME: 1. Lead slurry to surface w/100% excess. Z. Tail slurry volume 350 sx 3. Top job(if required ) volume 250 sxs ASII. DS 17-181 Casing Design Specifications Production Casing / Liner 7-5/8", 29.7#,NT-95HS,NSCC Casing GRADE BURST COLLAPSE NT-95HS 81 80 71 50 PBYS (#) 811000 TJYS (#) 841000 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. 2.39 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 8800 0.1 3788 Collapse S.F. 1.89 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 29.7 9800 PBYS Tension S.F. 3.30 Mud Wt. 10.2 TJYS 3.42 String Wt. (#) 245684 ,Ar~chora(',8 DS 17-181 Casing Design Specifications Production Casing / Liner 7-5/8", 29.7#,NT-95HS,NSCC Casing GRADE BURST COLLAPSE NT-95HS 8180 7150 PBYS (#) 811000 TJYS (#) 841000 Burst Pressure Calculation Burst rating based on have a tubing leak on top of full column of fluid Worst case will be at tile surface, which has no back up gradient. SffP 3420 Burst S.F. 2.39 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 8800 0.1 3788 Collapse S.F. 1.89 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 29.7 9800 PBYS Tension S.F. 3.30 Mud Wt. 10.2 TJYS 3.42 String Wt. (#) 245684 PRODUCTION CASING / LONGSTRING - 7-5/8" CEMENT PROGRAM- DOWELL CIRC. TEMP 140 o F SPACER: 50 bbls Dowell MUPUSH-XT LEAD CEMENT TYPE: CLASS G ADDITIVES: 0.35% D156 + 0.2_% D65 + 0.15% D800 + 0.05GPS D47 WEIGHT: 15.8ppg YIELD: 1.16ft 3/sx gps APPROX #SACKS: 243 THICKENING TIME: 4 hrs TAIL CEMENT TYPE: CLASS G ADDITIVES: 1.0 gps D600 + 0.25% D65 + 0.1 gps D135 + 0.05 gps D47 + D800 as required WEIGHT: 15.8ppg gps APPROX #SACKS: YIELD: 1.16ft 3/sx MIX WATER: 5.07 125 THICKENING TIME: 4 hrs MIX WATER: 5.07 CENTRALIZER PLACEMENT: 2 Turbulator centralizers ( 7-3/4" x 9-3/8" ) per joint on the bottom 500' of 7-5/8" casing (25 required). 1 turbulator ( 7-3/4" x 9-3/8" ) on the next 500' of 7-5/8" casing(12 required) Run one turbolator or solid type centralizer (7-3/4" x 9-3/8") in the middle of the first two joints of 7-5/8" inside the surface shoe. OTHER CONSIDERATIONS: Perform lab tests and ensure compatibility prior to pumping adequate relative to pumping job requirement. cement - perform fluid loss test. on mixed cement/spacer/mud program job. Ensure thickening times are Displace at 12 bpm. Batch mix tail RECIPROCATION: Make every attempt to reciprocate pipe while circulating. Casing should be on bottom when cement rounds the shoe. Resume reciprocation once cement starts up annulus. A poor or inadequate cement job is far more costly than setting emergency equipment, CEMENT VOLUME: 1. Lead G neat slurry to 1000' above top of Sag River w/30% excess. 2_. Tail G slurry from TD to top of Sag River formation w/30% excess. 2.80' md 7-5/8", 29.6# capacity for float joints. NOTE: There is no requirement to isolate the intermediate casing string from the Cretaceous interval. OL~- 13I'7 ~,m i r-,q ,:YSTEM Two lines venting gO deg. apart in directions that ensure sate down wind venting, and ex- tending to ~ point at least 100' Irom any polenti~l~''' source of ignition. 10' Full Opening Valves 35' or as required '"- I Dresser Sleeve 1. All pipe connections 150¢ ANSI Manges or welded connections · ~nd sec:tired to prevent movemenL 2_ Manua[ 10" full opening valves mechp, nicslly c.~nnec"'~,ed to ensure that one vslve is fail-safe open at sll limes. 10' Dive.der Line 3. All tums sre gO deg. and targeted. 10' Full opening ball valve w/Hydraulic Actuator Cellar 20' D(verter Spool w/10' Side Oullet M E M 1 f3/D 0 NABORS 18 E 13 5/8" 5,000 psi Stack 1.50 4.75 4.73 3.98 3.66 1.4g 2.37 2.21 0.55 :: ..~ GROUND LEVEL ! HYDRIL PIPE RAM BLIND RAM KR TQ RF RI(~ FI tO©R 11.41 15.66 17.93 MUD CROSS PIPE RAM 22.96 26.45 I MUD CROSS ~ , ,, I 1 ETBG SPOOL I ! '~ASE FLG/ 28.25 30.25 Ctiaska~ 0JJ ° cx uas Cons, ComraissJon C3 - Choke Manifold - Poor Boy Degasser . - Brandt Vacuum.-Type Degasser - Brand t Dual Tandem Shale Shaker - Pioneer Mud Cleaners - Pioneer MKI Centrifuge TO STA~D TRIP TA~K Da-GA 55ER TAN K I'~0 88~ TYPE ~ 0o Muo Cz,EANE~ ~ ," MUD RI~TION DIT'C ~IUD co~. CZEAA/E,~ ~,sc~t P/O, AIEEA (-~ 'FO PI]- 1 - RecOrding drilling fluid, pit 'level indicator with both visual and audio warning de~ices at driller's console 1 - Trip Tank (75 BBL.) 1 - Drilling fluid flow sensor with readout at driller's console 11 - 5 Hp Agitators 4A 6A "TA 'f OA '"Fop 0 0 0 0 0 0. ken gth I....b s Cirad ~!~ "i'" h r~.'..> ad Lb s I:: ....... ,':.~.:~ ?/+ ~,"' ,9773 29,7 INT'951""IS INSC::C; 0 0 0 0 0 0 0 0 0 0 (:.1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C! 0 0 CI 0 0 0 0 413 1' 0!3 I'vtud Wiegi~t 9.5 'f O. 5 0,0 0.0 0.0 0.0 O. 0 0.0 O. 0 I....!'.y d. r o lyti o l::~si/ft 0.4.9,4. 0.54,6 0,000 0.0(%) 0.000 0.000 0.000 0.000 psi 3330 0 0 0 0 0 0 0 0 '~ ..6 ~.,., .~.~ fl- I1::~,I1'~,,~#~:~!! "Fer'~sio r'-~ , I,(/i....b s 4 .~ 6~. (.3'~ '7 .~;.;:~...). ~ ..... 0 0 0 0 0 0 0 I;QtLb s 04.0 8'f 'f 0 0 0 0 0 0 .() C, o ll a.p s :.:, F::~,esist. 8't 30 "7'~ 50 0 0 0 0 0 0 0 0 I:::~age '1' ET'Oe. = 9800' - CHECK LIST FOR NEW WELL PERMITS I TEMI APP.ROVE DATE [2 ~h~u 8~ (3) Admi n. [9t hru 13']' ' [ 10 & 1'3] (4) Cas .cj. [14 thru 22] [23 thru 28] 2. 3. 4. 5. 6. 7 8 . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. [29 thru 3:~'] 30. (7) Contact 32. (8) Addl ~ /~-~-~ 33. geo 1 ogy' DWJ~ R P eng i ne,_er lng' MTM ~-~ RAD-~ BEW dD~?//¥ · rev 08/18/92 jo/6.011 Company,, YES Is permit fee attached ............................................... Is well to be located in a defined pool ................... · .......... Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... ¢]] _ Is sufficient undedicated acreage available in this pool ............. · , Is well to be deviated & is wellbore plat included ................... Is operator the only affected party .................................. Can permit be approved before 15-day wait · Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease ncrnber 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 ...... Will 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 wellbore 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 ~'~psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... 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 ...... Lease & Well # ~~ ,,~. ~'~/ .~ ~L~ NO REMARKS Additional requ i rements INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE