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Home My WebLink About186-088Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. J .~ _~- ~ ~ (~ Well History File Identifier Organization {done) RESCAN Color items: Grayscale items: [] Poor Quality Originals: Other: DIGITAL DATA [] Diskettes, No. Other, No/Type TOTAL PAGES: )5 NOTES: ORGANIZED BY: (~~~REN VINCENT SHERYL MARIA LOWELL Project Proofing OVERSIZED (Scannable) [] Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds [] Other By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /s/ PAGES: ~ 5 (at the time of scanning) · VINCENT SHERYL MARIA LOWELL SCANNED BY; REN. DATE: ReScanned (done) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ General Notes or Comments about this file: PAGES: Quality Checked (done) RevlNOTScanned.wpd MICROFILMED 9/11/00 DO NO-/- PLACE ANY NEW M~TERiA£ I$ PAGE Memorandum 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 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 reddlls and or multilaterais 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 ddll. The APl 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 (weilbore segment) Drilling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. e McMains ' ~ Statistical Technician i~iay 2, 1986 Mr. T. P. Oostermeyer Regional Drilling Engineer ARCO Alaska, inc. P. O. Box 100360 A~chorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: Prudhoe Bay Unit DS 1-27 ARCO Alaska, Inc. Permit No. 86-88 Sur. Loc. 84l'F~, 1474'~;~, Sec. 8, T10N, R15E, U!~. Btmhote Loc. 2826'FSL, 220'FWL, Sec. 4, T10N, R15E, UM. Dear Mr. Oostermeyer: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify, you from the probable need to o~tain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commenCing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. ~/(/.trRl~y~urs,//~ C, V. Cha~e~to~ Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF ~HE COmmISSION jo Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery - STATE OF ALASKA ALASKA C._ AND GAS CONSERVATION CO. .... vllSSlON PERMIT TO DRILL 20 AAC 25.005 la. Typeof work Drill .~ Redrill []1 lb. Type of well. Exploratory D StratigraphicTest ~./Development Oil Re-Entry ~ Deepen'~1 Service Fq Developement Gas ~ Single Zone/~,, Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 70', PAD 39.5' feet Prudhoe Bay Field 3. Address 6. Property Designation Prudhoe Bay Oi 1 Pool P.O. Box 100360 Anchorage, AK 99510 ADL28329/ALK2327(TARGE'I)& ADL28328/ALK2326(BH 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 841'FNL, 1474'FWL, Sec.8, TION~ R15E, UM Prudhoe Bay Unit Statewide At top of productive interval 8. Well nu ,mber Number 2640'FSL, 0'FEL, Sec.5, T10N, R15E, UN 1-27 #8088-26-27 At total depth 9. Approximate spud date Amount 2826'FSL, 220'FWL, Sec.4, T10N, R15E, UM 05/15/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 11 , 1 20 ' MD O' (~ tarqet feet 1-7 60'@ surface feet 2560 (9154'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 le)(2)) Kickoff depth2~00 feet Maximum hole angle z~ 2 0 Maximum surface 281 7 psig At total depth (TVD) 3 800 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) L-80 12-1/4':9-5/8" 47.0# L-80 NSCC/BT'10295 27' 27' 10322 8.560' .500 S,~ Class 8-1/2" 7" 29.0# L-80 BTC 998' 10122 8411' 11120 9154' 300 sx Class O 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 F~- Fr' Surface ~k. !TCEiV~D Intermediate Production /'~PR-'~' (' Perforation depth: measured Anchorage true vertical 20. Attachments Fili, n,g fee .~ Property platm ~ ~ Diverter~ Dril BOP Sketch 'r Sketch/~ ling program Drilling fluid program ,~, Time vs depth plot [] Refraction analysis _.3, Seabed report ~% 20AAC 25.050 requirements 21. I hereby certify that th~foregoing is true and correct to the best of my knowledge Signed ~~ ~// Title Regional Drilling Engineer Date~ccf¢ ~/ Commission Use Only (SLM) PD/PD254 I API number I Appro~l/¢o~ I See cover letter Permit Number ,~L--.- ~ ~ 50-- :-' ~'-)'- ~/.~9 / /86 for other requirements Conditions of approval Samples required [] Yes ,~No Mud log required ,_~ Yes .~ No Hydrogen sulfide measures ~ Yes ~ No Directional survey required .~Yes ~ No working ressur fo PE [] ; 3M; ,~5M; ~ 10M; C 15M Required ~~~_~/ ~,~ Other: " by order of Approved b Commissioner the commission Dat 1 Form 10-401 F , , , in triplicate DS 1-27 DRILLING PROGRAM I. Set 20" conductor and poleset in place. 2. MIRU drilling rig. NU and function test 20" 2000 psi diverter (see Diverter Program). 3. Drill 17-1/2" hole to 2200'MD. 4. Set 13-3/8" casing and cement to surface. Test casing to 2000 psi. 5. Install 13-5/8", 5000 psi, I~SRRA BOP stack. Test BOP stack to 5000 psi. Test BOP stack weekly. Drill 10' new hole then perform leakoff test. 6. Drill to 2300' (KOP) . Build 2.5°/100' oriented N40°20'E to 42° Drill directional hole to 10,322'MD (8560'TVD). 7. Set 9-5/8" casing and cement. Test casing to 3000 psi . Perform leakoff test. 8. Drill 8-1/2" hole to 11,120'MD (9154'TVD). 9. Run open hole logs. 10. Run and cement 7" liner. 11 . C1 ean out 1 i ner. Test 1 i ner to 3000 psi . Di spl ace wi th 9.4 ppg bri ne and 400' diesel cap. 12. Secure well and release rig. 13. Run cased hole logs. 14. MIRU completion rig. 15. Run 5-1/2", 17.0#, L-80, AB-MOD tubing string with packer, gas lift mandrels, and provisions for subsurface safety equipment. Set packer above Sadlerochit. 16. NU tree and test to 5000 psi. 17. Secure wel 1 and release completion rig. 18. Perforate and stimulate well. Install subsurface safety valve. NOTES: a. Reserve pit fluids will be disposed of down the 9-5/8" x 13-3/8" annulus. The annulus will be left with a non-freezing fluid during any extended interruption in the disposal process. The annulus will be sealed with 300 sx of cement followed by Arctic Pack upon the completion of the fluid disposal process. b. The drilling fluid program and fluid surface system will conform to the regulations set forth in 20 AAC 25.033. c. Maximum surface pressure is based upon recent BHP surveys and a full column gas to TD (0.11 psi/ft). d. Well 1-27 will pass 101' from well 1-6 at 2823'MD (2819'TVD). e. Well 1-27 will pass 151' from well 1-5 at 3500'MD (3446'TVD). f. The closest well to 1-27 will be well 1-7. This will occur at the surface, which will be 60'. PD/PD254a:tw 04/24/86 DS 1-27 DRILLING FLUID PROGRAM Plas Density Vi sc. Depth (TVD) #/gal (CP) Surf 8.8 Funnel to to 100- 13-3/8" 9.2 250 Csg Poi nt Yield Point #/1 O0 ft2 40-60 13-3/8" Csg Shoe 8.8 Minimum 2 to to Possible to K-lO 9.4 4 Initial 1OM FL % % pH and Gel Gel CC/30M Oil Solids Type of Mud Gel-Benex 30+ 50+ 25 0 8 Spud Mud 2 5 25 3.5 Low Sol ids to to to 0 to Non-di spersed 4 10 10 6.5 K-lO 9.2 10 6 to to to to 9-5/8"Csg. Pt. 9.8 20 10 4 8 15 4 pH 9-10 to to to 0 to Low Sol ids/ 8 12 10 8 Non-dispersed 9-5/8" Csg. Shoe 9.2 10 6 4 8 to to to to to to TD 9.8 20 10 8 12 DS 1-27 EQUIPMENT - DRILLING FLUID sySTEM 10 4 Low Solids/ to 0 to Non-Dispersed 5 8 1. Degasser 2. Shakers Pit level indicator (with both visual and audio warning devices) 4. Drilling fluid flow sensor 5. Trip tank 6. Agitators 7. Mud cleaner (desilter) PD/PD254c: tw Trip Tanks DS 1-27 Typical Mud Pit ~ematic Sandtrap (30 bbls) Shaker Degasser (83 bbls) Desilter (97 bbls) Shaker Shaker (97 bbls) Pill Pit (36 bbls) Desander ( 36 bbls) Suction Pit (448 bbls) Mix Pit (122 bbls) Drawing not to scale. NOTE: System is equipped with a drilling fluid pit level indicator with both visual and audio warning devices and a fluid flow sensor located in the immediate area of the driller's console. SURFACE HOLE D TVERTER SYSTEM ARCO ALASKA 1NC'o SCHEMATIC . IO" HYD. OPR. BALL VALVE WELL BORE (SEE DETAIL) IO',' HY~D. OPR. BALL VALVE ' CUSH'[ON~,,.~ '~..L/~''''~ I NO____~_~: FLOWLINE I Only one of the hydraulic ball valves I will open when the annular preventer _ ~ is closed. The other will remain closed and used only as a backup in case of emergency. RESERVE PIT AREA DRILLING RISER F ! ., 20" 2000 PSI V~ ANNULAR PREVENTOR ~0~"10" D IVERTER L 20" CONDUCTOR PIPE "DETAIL" 2026010203 RNNULRt;I -PREVENTOA PIPE RRMS BLIND -~DRILLIN~ SPOOL PI-PE RRMS 13~5/8'' BOP STACK DIAGRAM A~cumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with charging pump off. 4. Record on IADC report. (The acceptable lower limit is 45 second~ closing time and 1200 psi remaining pressure. 13-5/8" BOP Stack Test 1. Fill BOP stack and manifold with a non-freezing liquid. 2. Check that all hold down screws are fully retracted. Mark running joint with predetemined plug seazing depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 3. Close annular preventer and upstream valves. 4. Functionally test chokes. -5. -In each of the following tests, first hold a 250 psi low pressure test for a minimum of 3 minutes, then test at the high pre~ 6. Increase pressure to~3~000 ps_~and hold for a mimimum of 3 minutes. Bleed pressure to zero. 7. Open annular preventer and clo~ set of pipe rams. Increase pressure t~s~ and hold for at least 3 minutes. Bleed press~r-~--t~ zero. 8. Close valves directly upstream of chokes and open chokes.. Increase pressure to 5000 psi and hold for at least 3 minutes. Bleed pressure to zero. 9. Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to $000 psi below the bottom set of pipe r~ms and hold for at least 3 min- utes. Test reamining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. Bleed pressure to zero. Open bottom set of pipe Back off rmnaning joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 mir~tes. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full of non- freezing liquid and all valves are set in drilling position. Test standpipe valves to 5000 psi. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. Check operation of Degasser. Record test information on blowout preventer test form. Sign and Send to Drilling Supervisor. Perfom complete BOPE test once a week and func- tionally operate BOPE daily. 10. 11. 12. 13. 14. 15. 16. 17. 18. Revised 2/21/84 081-27 0 101]0 IQ 3000 4000 Sr , 6OOO ~ :~0' CASING T"D" 108" ARC13 AL,a,SKA, INC. I~CALF_ I IN = leal1 FT. ~,, , [3.3/8- CASING TVD -- 2200 SHL: 841' (OP TVD = ~DO 2-5 SEC 8, TION, R15E, UI~ 7.5 12.5 THL: 264')' FSL, O' FEI,, 17.5 SFC ~: T~I~N. ~!RF~ Ul~ 5 27.5 ~1.8 EOC TVD-- 3828 MD -- 3973 DEP = 584 , N 47 D~:G 20 MINE 5168 FT(TO TARGET) AVERA; E ANGLE _ ~1 O~4,B MIN ~ 0 TVD -- 7180 MD -- 8484 DI~P ~ 3582 K-5 TVt -- 7840 MD ~ 9366 DEP - 4 174 L=U TVD - 840 ) MD - 10108 DEP -- 4675 SAG RIVER TVD -- 84~15 MD - 10196 DEP - 4733 - SHUBLIK TVO = 85( 0 MD = 1024~]DEP = 4764 9-5/8' CAI~ING TVD -- 8E 50 MD - 1032~ DEP ~4818 TOP SADLEROCHIT TVD -- 81,70 MD -- 103~,6 DEP 4827 G/O Cl)NTAGT TVD · 8806 MD_- 1, )661_DEp~ 5037 . BASE S~DLEflOCHIT T /D -- 8080 ME ~ 11020 DEP = 5283 TD FVD - 9154 M!~ = 11120 DEP = 5349 1000 2000 3000 4000 5000 6000 7000 8O0O 9000 10000 11000 0 7000 0 1000 2000 3000 4000 SO00 6OO0 7000 8OOO 9000 10000 11000 1000 2000 3000 4000 S(lO0 8000 7000 VERT I CFIL SECT I ON F. - N O00RDTNF~?F.S 0 -1000 0 1000 2000 3000 4000 5000 6000 .~HI' R41' ;N , 1474' FWI SEC 8, T' 011, R15E, UM THL: 2841 ' ISL, O' FEL, SEC 5, T' O~ I, R15E, UM 3S1-27 tO ~z~0 T.a RGET j "" TV ~) -- 8940' cDrY ~ N 3481 cD E 3808 - 1000 0 ! 000 2000 3000 ~000 5000 8000 E - N COOROINF~F,S W R - N O00RDINB~£,~ o - 1000 0 1000 2000 3000 4000 5000 6000 0 DS 1 I U U",=,~ ~ ~ I I I I I I I i i I I I I I I t 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 I I I I i i i i I I i i i 351-27 , DS -6 - OS ~ ~'36 - 1000 0 1000 2000 3000 ~000 5000 6000 - N COOROINBTES F: - IN COORDINt:tTES - 1 O0 0 ! O0 200 300 ~00 500 600 DS /~6~9 /~408 051-27 i 675 357 7'3 , ~5 1-5 3189 ~ 'e' '~. ] ~ i i ] v i , i [ , i , t i ] i i i [ i [ i i i v ~ i ! 1 ] i i Il e I I I I I ] I I I [ I I I I i V I [ I I I I [ 1 ] Y , I OK CZ) I I OS - i O0 0 1 O0 200 300 '~00 500 600 E - N O00ROINBTES CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2~ thru 8) 3. 4. 5. 6. 7. 8. (3) Admin (~/L~ .~r 'P[~ 9. (9 thru 13) 10. (10 and 13)/ 12. 13. (4) Casg ~~ ~- ,-gg (14 thru 22) (23 thru 28) Company ~zTqY~-g~-~ Lease & Well No. YES NO Is the 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 and is wellbore plat included ................ Is operator the only affected party ...... .......................... Can permit be approved before ten-day wait .......................... Z~~' " Does operator have a bond in force ................................... Is a conservation order needed ...................................... ' Is administrative approval needed ................................... Is the lease number appropriate eleeeeeeeeeeeeeeeee,eee~eaeeeee-eeee. Does the well have a unique name and number ......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known p~oductive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 23. 24. 25. 26 27. 28. Is a diverter system required ....................................... Is the drilling fluid program, schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~OOO psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable (6) OTHER :/~.~, (29 thru 31) (6) Add: For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones ............ 31. If an offshore loc., are survey results of seabed conditions presented 32. Additional requirements ............................................. R~S o ~ 0 Geo lo gy: Engi~r~eering: LCS ~ BE-~ rev: 04/03/86 6.011 POOL INITIAL CLASS STATUS GEO. AREA UNIT NO. ON/OFF SHORE Additional Remarks: