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Home My WebLink About185-267Image 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. / ~ 5- ~ ~)/~ Well History File Identifier RESCAN [] Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: TOTAL PAGES: O~ I ORGANIZED BY: ~REN Project Proofing DIGITAL DATA [] Diskettes, No. [] Other, No/Type NOTES: VINCENT SHERYL MARIA LOWELL OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of .various kinds [] Other By: Date: PROOFED BY: E~EVERLY E~REN VINCENT SHERYL MARIA LOWELL DATE: /si PAGES: 2 I (at the time of scanning) SCANNED BY-' BEVERLY BREN VINCEN~ARIA LOWELL ReScanned {done) RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: ! General Notes or Comments about this file:/0//~ ~'/0 Is/ Quality Checked (done) Rev1 NOT~canm~l,wpd Memorandum To: Re: State of Alaska Oil and Gas Conservation Commission A1 BI, Cancelled or Expired Permit Action EXAMPLE: Point Mclntyre P2-36AXX AP1 # 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 APl number and in some instances the well name reflect the number of preexisting reddlls and or muitilaterals 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. McMains ' ~ Statistical Technician ARCO Alaska, Inc. Post Office B,.,.. i'00360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 20, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - L2 Wells 11 & 13 Dear Mr. Chatterton: Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU11/L104 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany LOCATED W~T.~. PROTRACTED SEC. lB, LEGEND. / ,N,OTE_S TWP. II N., RGE. 15 E., UMIAT MER., AK. · CONDUCTOR AS'BUILT 0 FUTURE WELLS · EXIST. WELL DES. d. B. CHK. J. B. DATE 9-10-B5 _ JOB NO. 36O O35 34O 32O 0~,1 300- 029 280 - 027 260 025 023 220 021 200 0~9 18® 017 16e 015 140 ·11 I0e 09 8· O7 6e 05 40 03 OI '7 ~,) ,.~. ~' I II BASIS OF LOCATION IS MON'S. L-I AND L-2 PER ER. BELL ASSOC · ALL COORDINATES SHOWN ARE A.S.R ZONE 4. BASIS OF ELEVATION .IS MON. L-2 SO. PER F.R.BELL & AS SOC. LZ-II cgP' Ooy 25 $0 VICINITY MAP Y= 5,963,328.55 L AT.-'70° 18' 15.4'06' X: 69~,8 IT. 16 LONG.=I48°26'I6.5 $ I*' CELLAR BOX EL.= 1~..7 Y= 5,963,386.42 LAT=7001 ~' 15.978" X: $9Z,803.06 LDNG.=I4.8°;g~E'tE,.89 · CELLAR BOX EL.~.12:.5 1ll9' EW.L. ~3z' ~.S.L. It06' F.W.L. 149 I' F.S.L. I D.S.L-2 CONDUCTORS AS'BUILT SHEET I ARCO Alaska, Inc. 4> Submidiory of Atlontic Richfield Compony NORTH SLOPE DRILLING-PRUDHOE BAY · I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND .. .~.:.~'. SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS AN AS-BUILT SURVEY MADE BY ME, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT, AS OF: SEPT. 10,198~ October 31, 1985 Mr. Don E. Breeden Sr. Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Prudhoe Bay Unit L2-11 ARCO Alaska, Inc. Permit No. 85-267 Sur. Loc. !432'FSL, lll9'FWL, Sec. 18, TI~.N, R15E, Btmhole Loc. 957'FSL, 978'F~, Sec. 24, TllN, R14E, UM. Dear Mr. Breeden: 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 obtain 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, k~nere 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. Ve~. trulY yours, ./~/ ? 7.,/' fi.,. ? C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO~{ISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowe~ ARCO Alaska, Inc. Post Office Bo,, ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 29, 1985 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Lisburne L2-11 Permit to Drill Dear Mr. Chatterton' Enclosed are' An application for Permit to Drill Lisburne L2-11, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore Diagrams showing the proximity to other wells in the area. There are two wells passing within 200' of L2-11, as discussed in the application. A diagram and description of the surface hole diverter system ° A diagram and description of the BOP equipment ° A copy of the certified "As-Built" conductor survey We estimate spudding this well on November 8, 1985. If you have any questions, please call me 263-4963. Sincerely, D. E. Breeden Senior Drilling Engineer DEB/tw PD/L183 Enclosures RECEIVED OCT 2 919B5 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany la. Type of work. /--.--.-... STATE OF ALASKA '--'" ALASKA O,L AND GAS CONSERVATION CO~,,,MISSION PERMIT TO DRILL DRILL REDRILL DEEPEN 20 AAC 25.005 EXPLORATORY [] SERVICE [] STRATIGRA~ DEVELOPMENT OIL E~X SINGLE ZONE-~.~X DEVELOPMENT GAS [] MULTIPLE ZONL~ 9 Unit or lease name - Prudhoe Bay Unit/Lisburn~ lb. Type of well 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1432' FSL, 1119' FWL, Sec.18, T11N, R15E, UM At top of proposed producing interval and Target (8952' TVD): 1320'FSL, 1320' FWL, Sec.24, TllN, R14E, UM At total depth 957' FSL, 978' FWL, Sec.24, TllN, R14E, UM 6. Lease designation and serial no. ADL 28307 ALK 2317 10. Well number L2-11 5. Elevation in feet (indicate KB, DF etc.) RKB 52' PAD 13' 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 11. Field and pool Prudhoe Bay Field Lisburne 0f l Pool 15. Distance to nearest drilling or completed L2-13well 60' ~ surface to 1000'feet 18. Approximate spud date 11108/85 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 7-1/2 mi, N of Deadhorse miles 957' ~ TD feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 12729'ND, 9420' TVD feet 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 1000 feet. MAXIMUM HOLE ANGLE 47 Ol (see 20 AAC 25.035 (c) (2) 3l;2f~ psig@ A0OF Surface 4490 .psig@_~8952_~t. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE Hole Casing 30" 20" 17-1/2" 13-3/8" 17-1/2" 13-3/8" 12-1/4" 9-5/8" 8-1/2" 7" Weight 91.5# 68.0# 72.0# 47. O# 29. O# 22. Describe proposed program: CASING AND LINER Grade Coupling H-40 We 1 K-55 BTC! L-80 BTC! L-80 .BTC L-80 BTC! Length 80' 70' 4704' 11964' 928' SETTING DEPTH MD TOP TVD 39' I 39' I 39' 39' I 109' I 109' I 37' I 37' 11801' I 8785' MD BOTTOM TVD 119' I 119' 109' I 109' 4813' I 4000' 12001' I 8922' 12729' I 9420' QUANTITY OF CEMENT (include stage data) 2000# Pol eset 3000 sx AS III Lead & 400 sx Class G Tail 750"G"/300AS I&ArcPack 275sx65%"G"- 35~Poz ARCO Alaska, Inc., proposes to drill this tisburne development well to approximately 12,729'MD (9420'TVD). is planned as a Wahoo production well. It A surface diverter will be installed and operationally tested prior to spud. A 1~-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 13-3/8" surface pipe. It will be tested to 5000 psi (3000 psi for annular) upon installation and weekly thereafter. We plan to set 9-5/8" casing just above the Wahoo and a 7" liner across the Wahoo production interval. Selected intervals will be logged. A string of 2-7/8", 6.5#, L-80, EUE 8rd tubing, including provisions for subsurface safety equipment, will be run with the packer set above the Wahoo. Selected intervals in the Wahoo will be perforated and reported on subsequent reports. (see attached sheet) 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED ~, ~~_~,~~ TITLE Sr. Drilling Engineer The space below for Commission use Samples required []YES /[~I'N 0 Permit number APPROVED BY Form 10-401 CONDITIONS OF APPROVAL Mud log required Directional Survey required I APl number I-lYES [~0 .[~k-YESoNo 1 - Approval date SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSl ONER DATE by order of the Commission October Submit in triplicate PERMIT TO DRILL L2-11 (cont'd) Non-freezing fluid will be left in all uncemented annuli within the permafrost interval. Reserve pit fluids will be disposed of down the 9-5/8" x 13-3/8" annulus of this well prior to Arctic Pack operations (approx 130 bbls Arctic Pack on top of 300 sx Arctic Set I cement). That annulus will be left with a non-freezing fluid during any extended interruption in the disposal process. The maximum anticipated surface pressure of 3420 psig ~ 40°F was calculated from the Wahoo datum pressure of 4490 psig ~ 8952'TVD and 183°F. it assumes a 300' oil column to 8652'TVD and a gas column from there to surface, gas temperature and compressibility effects considered. A similar calculation, assuming a full gas column and original reservoir pressure in the Put River sand ~ 8102'TVD, yields a maximum surface pressure of 3320 psig ~ 40°F. Such surface pressures could occur only if 9-5/8" casing had been set. With 13-3/8" casing set ~ 4000'TVD, the maximum anticipated surface pressure is 2440 psig, based on a 13.7 ppg EMW pump-in gradient at the shoe and a gas column to surface. Our formation leak-off test history, for surface pipe set at similar depth, shows a 11.5 to 13.7 ppg EMW pump-in gradient just below the casing shoe. Well L2-11 will pass within 200' of wells L2-13 and L2-3. Wells L2-11 and L2-13 are 60' apart from surface to 1000', L2-11's KOP, below which the paths separate. L2-13 was kicked-off at 2710'. Well L2-3 is 240' away at surface. L2-11 will pass L2-3 at a calculated minimum distance of 195' at 1789'MD (1773'TVD). There are no other wells within 200' of L2-11. £C£1vEb OCT2 9 9[t5 lllaska oil Chora~e .,.,~S/on STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL I-~X REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [~X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [~(X .~ 2. Name of operator ARCO Alaska, Inc. 9. Unit or lease name .~ Prudhoe Bay UnitfE~B~oe ,5~ 10 Well number ~:~ L2-11 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1432r FSL, 1119' FWL, Sec.18, TllN, R15E, UN At top of proposed producing interval and Target (8952'TVD): 1320'FSL, 1320' FWL, Sec.24, TllN, R14E, UM At total depth 957' FSL, 978' FWL, Sec.24, T11N, R14E, UR 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 52', PAD 13' I ADL 28307 ALK 2317 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 7-1/2 mi. N of Deadhorse miles 957' @ TD feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 12729'ND, 9420' TVD feet 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 1000 feet. MAXIMUM HOLE ANGLE 47 Ol (see 20 AAC 25.035 (c) (2) 11. Field and pool Prudhoe Bay Field Lisburne Oi 1 Pool Amount $500,000 I15. Distance to nearest drilling or completed L2-13well 60' (~ surface to 1000' feet 18. Approximate spud date 11/08/85 psig@___/4d~__ Surface _psig@ 8952 ft. TD (TVD) ' 21 ! Hole 17-1/2" 30" 17-1/2" 12'1/4" ' 8-1/2" SIZE Casing Weight 20" 91.5# 13-3/8" 68.0# 13-3/8" 72.0# 9-5/8" 47.0# 7" 29. O# Proposed Casing, Liner and Cementing Program CASING AND LINER Grade Cou Le H-40 K-55 BTC! 70' L-80 BTC~ 4704' L-80 BTC[ 11964' -80 I .zc/ 928, SE ~¥ING DEPTH MD TOP TVD 39' I 39' I 39' I 39' 109' ~ 109' I 37' I 37' 11801' I 8785 I MD BOTTOM TVD 119' 119' 109' I 109~ 4813' I 4000' 12001' I 8922' 12729' I 9420' QUANTITY OF CEMENT (include stage data) 2000# Poleset 3000 sx AS II! Lead & 400 sx Class G Tail 750"G"/300AS I&ArcPack 275sx65%"G"-35%Poz 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill this Lisburne development well to approximately 12,729'MD (9420'TVD). is planned as a Wahoo production ~ell. It A surface diverter will be installed and operationally tested prior to spud. A 1.3-5/8", 5000 psi, RSRRA DOPE stack will be installed on th~ 13-3/8" surface pipe. It will be tested to 5000 psi (3000 psi for annular) upon installation and weekly thereafter. We plan to set 9-5/8" casing just above the Wahoo and a 7" liner across the Wahoo production interval. Selected intervals will be logged. A string of 2-7/8", 6.5#~ L-80, EUE 8rd tubing, including provisions for subsurface safety equipment, will be run with the packer set above the Wahoo. Selected intervals in the Wahoo will be perforated and reported on subsequent reports. (see attached sheet) 23. I hereby certify that the foregoing is true arid correct to the best of my knowledge SIGNED ~~-~~.C~~_~-- _~_~ TITLE Sr. Dril ling Engineer The space below for Commission use OYES [~AIO CONDITIONS OF APPROVAL Mud Icg required / Directional Survey required I APl nuttier (~YES •NO I 5o- {')?q-2l/,77 . I SEE COVER LETTER FOR OTHER REQUIREMENTS I Octobe~ 31, 1985 ,C~OMMISSl ON ER DATE by order of the Commission Samples required [-)YES [~0 Permit numb~- 85- 267..,,~ ' APPROVEDBY Rev. 7-1-80 Submit in triplicate PERHIT TO DRILL L2-11 (cont'd) Non-freezing fluid will be left in all uncemented annuli within the permafrost interval. Reserve pit fluids will be disposed of down the 9-5/8" x 13-3/8" annulus of this well prior to Arctic Pack operations (approx 130 bbls Arctic Pack on top of 300 sx Arctic Set I cement). That annulus will be left with a non-freezing fluid during any extended interruption in the disposal process. The maximum anticipated surface pressure of 3q20 psig @ ~O°F was calculated from the Wahoo datum pressure of ~90 psig ~ 8952'TVD and 183°F. It assumes a 300' oil column to 8652'TVD and a gas column from there to surface~ gas temperature and compressibility effects considered. A similar calculation~ assuming a full gas co]umn and original reservoir pressure in the Put River sand @ 8102'TVD~ yields a maximum surface pressure of 3320 psig @ ~O°F. Such surface pressures could occur only if 9-5/8" casing had been set. With 13-3/8" casing set ~ ~O00'TVD, the maximum anticipated surface pressure is 2~0 psig~ based on a 13.7 ppg EHW pump-in gradient at the shoe and a gas column to surface. Our formation leak-off test history~ for surface pipe set at similar depth~ shows a 11.5 to 13.7 ppg EMWpump-in gradient just below the casing shoe. Well L2-11 will pass within 200' of wells L2-13 and L2-3. Wells L2-11 and L2-13 are 60' apart from surface to 1000rs L2-11's KOP, below which the paths separate. L2-13 was kicked-off at 2710'. Well L2-3 is 2~0' away at surface. L2-11 will pass L2-3 at a calculated minimum distance of 195' at 1789'ND (1773'TVD). There are no other wells within 200' of L2-11. lO00 2000 ~000 RKB (F..LF_.VATION~ .52') .KOP TVD=I 000 TI'ID=lDO0 .DEP=O 5 10 2O 25 3O ;35 40 45 BUILD 2.5 DEO PER 100 FT ARCO ALASKA. INC. DS L2. WELL NO~ 11 PRUDHOE BAY. NORTH SLOPE. ALASKA EASTMAN WHIPSTOCK. INC. BUR't=ACE LOCAT I ON ~ 14'32' FSI., 1119' FWL b~EC. 18. TI1N, RISE. UM TAROET,LOCAT[Oflt 1320' FSI.. 1320' FWL SEC- 24. T11N. R14.E. UM EOC TVD=2670 TMD=2871 DEP=722 4000 TRUE VERTICAL DEPTH 5000 _ 6000 _ 7000 _ ,8000 9000 _ 10000_ 0 I ~/8' CSg PT TVD=4000 TMD=481~ DEP=21~8 AVERAGE-ANGLE 46 DEG 47~MIN K- !0 TYD~6912_Tt~D~9066_DEP=5237- K-5 TVD,,?502 ;Tt~ID.9927 -DEP~5864 " - PUT RIVER TVD=8102 TMD-t0803 DEP=6505- LC_U TVO_~BL52 A~I~D~] 087_6 DEP_~6556 . SAG RIVER TVD-8187 TMD=t0927 DEP-6593 SHUBL[K TVD=::8227 TMD-10986 DEP-6636 TOP SAD TVD=;8292 TMD=11081 DEP=6?05 KAV I K TVD=BT62 TMD-l-176'/' DEP=7205 9 5/8' CSG PT TVD-8922 TMD-12001 DEP=7376 WAHOO TVD'"8952 TMD-12045 DEP-7407 TARQET '-TVD=8952 'THD='120;45 DEP=7407 ECEiVED- TD - 7' CSG PT TVD-_9420 TUD"12729 DEP=rgo~[aska Oil & Gas Cons, :I 000 2000 :~000 4000 5000 6000 tO00 -ilO00 i I I i I i I I VERTICAL SECTION HO~,.,. ZONTAL PROJECTION SCALE 1 IN. = 1000 FEET ARCO ALASKA, INC. DS L2, WELL NO, 11 PROPOSED PRUDHOE BAY. NORTH SLOPE, ALASKA EASTMAN WHIPSTOCK. INC. 1000 _ 1000 - 2000 3000 400.0 - 5000 _ _.6000 60OO 5000 I ~EST-EAST 4000 3000 2000 I I I 1 000 0 I 8URFAOE LOOAT ! ON ~ 14~2' FSL. 1119' FWL SEC. 18. TllN, R15E. UI"I 1000 S 4 3 -. D E G ..]"7 M IN..14 7407' (TO TARGET) . _ . _ . _ . . . · . . :TARGET ' Tl'ID=12045 SEc. 2-4..TI 1 Il. RI 4E. ~ &?as Cons. Comrn/Ssioo .... 7000 1000 _ ~ 1000 2000 3000 _ 4000 5000 _ 6000 _ 7000 _ 6OOO 6407 5000 5999 5574 5124 NORTH 4000 3000 I I 4'668 6433 6119 5822 5529 5208 81 8762 4220 3789 2 5428 4815 4214 2OO0 1000 I 1000 I / $S89 4OO0 &ooo ~'oo , e.,~o 300 200:~ 1 O0 0 '1 C--' 200 ~00 ! I I I I I I , ~ 4OO 3OO 200 100 100 200 300 400 500 27'00 90,,,,,' 1000 ...... ~_1398 ¢1593 '"17'84 969 / 2146 I ...... WELL 2450 ~2848 5045 &~234 34t9 3596 ' NO~ 6 (STRAIGHT HOLE) _... 400 -1 ......... 300 I .... 2QO ...1_00 . _.0 _ _200 .- _ ..';~00--' I '1 nn n i_ _ I ~0o _ 400 .... 500_ 5OO 500 _ 400 ' 300 . 2OO 100 400 I 3OO NORTH 20O 100 I I 0 100 200 I I 100 200 3OO 400 WELL NO, 6 (STRAIOHT HOLE) 2232 4279 500 ......................... NORTH - 2300 2200 21 O0 2000 1 900 1800 1700 1 600 I I I I I I . 1.800 6?62 1900 6876 ?029 2'00.0 7209 2100 2200 2.300 .2500 - 2600 -48 t 3 ...... 3807' 3882 3648 3729 . . 3956 4101 1600 2300 2200 I i ,. 2100 I NORTH 2000 I 1 900 1800 1700 1 600 I I I , 2562 1700~ 1800 6762 1 9OO 68?6 7029 20O0 72O8 2100 22OO 2.300 2400 2500 ?359 3563 48 t 3 3648 41 4101 ... 3956 3729 417' 424O 7756 · ~ 4430 SURFACE HOLE D IVERTER SYSTEM ARCO ALASKA INC'. SCHEMATZC _,.------IO" HYD. OPR. BALL VALVE .,.~--'-'~LL BORE ISEE DETAIL) f~---- lO" HYD. (3PR. BALL VALVE mALL 90' TURNS ARE "TEE" I CUSHION I" RESERVE PIT AREA NOTE' FLOWL INE DR ILL lNG R I SER 20" 2000 PSI ~ ANNULAR PRE VENTOR ~O~10~ D IVERTER LINE ILL lNG SPOOL Valves on diverter lines open automati- cally when the annular preventer is closed. 20" CONDUCTOR PIPE I O" HYDRAUL lC OPERATED BALL VALVES "DETAIL" 202601020:5 PIPE RRM~ 8LIND ~ DRILLIN8 13-5/8" ~OP STAC~ D~ Accumulator Capacity Test 1. Check arm fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that acomHator pressure is 3000 psi with 1500 psi downstream of the regulator. 5. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with charging pump off. 4J Record on IADC report. (The acceptable lower limit is 45 seconcLs closing time anti 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 predetermined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 5. Close armular preventer and upstream valves. 4. Functionally test chokes. -5. -In each of the following teslm, first hold a Z50 psi low pressure test for a ~ of 5 mimfces, then test at the high 6. Increase pressure t'o~,$00~90 psi~ar~ hold for a mimimum of ~ minutes. Bleed~ to zero. 7. Open ammlar preventer and cl3ose-r~p set of pipe rams. Increase pressure t9/5000 ps~and hold for at least 5 minutes. Bleed pre--zero. 8. Close valves directly upstream of chokes and open chokes. Increase pressure to 5000 psi an~ hold for a: leas: 3 minutes. Bleed pressure to zero. 9. Open top set of pipe rams then close hot:om set of pipe rams. Increase pressure to 5000 psi below the bottom set of pipe rams ar~ hold for at leas: ~ min- utes. Test reamining un:es:ed manifold valves (if any) with 5000 psi ups:ream of valve ar~ zero pressure downstream. Bleed pressure to zero. Open hot:om set of pipe Back off rurming joint and pull out of hole. Close blind rams and test to 5000 psi for at least minutes. Bleed pressure off all equipment, Open blind rams. Make sure manifold and lines are full of non- freezing liqu/d 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 pt~p. Check operation of Degasser. Record test information on blowout preventer test form. Sign ancl send to Drilling Supervisor. Perform complete BOP£ :es: once a week and func- tionally operate BOP£ daily. i0. 11. 12. 14. 15. 16. 17. 18. LOCATED WITHIN PROTRACTED SEC. I TWR il N., RGE. 15 E., UMIAT MER., AK. ~60 34O 300 029 027 26O 025 023 021 200 019 017 160 015 140 120 011 O9 O7 05 40 0:5 ~)1 ,0.?,. LEGEND / NOTES · CONDUCTOR AS- BUILT 0 FUTURE WELLS · EXIST. WELL BASIS OF LOCATION IS MON'S. L-I AND L-2 PER FR. BELL ASSOC · ALL COORDI~IATES SHOWN ARE A.S.P. ZONE 4. BASIS OF ELEVATION .IS MON. b2 SO. PER F.R.BELL B AS SOC. LZ-II L~. 1:5 VICINITY Y= 5,96:5,:528.55 L AT.-=70° lB' 15.406" X= 692,8 IT. 16 LONG.= 148°26'16.5 :~ I" CELLAR BOX EL. · 12.T Y= 5,96:5,:586.42 LAT=70~I ~ 15.97S" X = 692,80:5.06 LONG.~I48e26'I6.89" CELLAR BOX EL.·.12.5 $0 MAP II 19' EW.L.. 1452' F.S.L. It06' F.W.L. 1491' F.S.L. MO I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESEN~:S AN A~BUlLT SURVEY MADE BY ME, AND THAT ALL DIMENSIONS AND OTHER DETAILS CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE Company Lease & Well No. YES NO REMARKS >~ , l~-q,q "" ..... " (2) Loc I" /.,-'~.. ' " · ('2:" thru 8) 3. 4. 5. 6. 7. ~.:X,Z<(,,. /~-~-~:' 8. (8) .... (3) Admin (9 'thru 12) ...'~/~ .,4.,:¥" . (10 and 1~) (4) Casg (13 thru 21) (22 thru 26) e 10. 11. 12. 13. .14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 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 this ................ ''· , ~.'''~' Is sufficient undedicated acreage available in 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 .......................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Is conductor string provided ........................................ 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 productive horizons ..................... Will surface casing protect fresh water zones .............. 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 ............................ Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attac'hed ....... ,d//~/ Does BOPE have sufficient pressure rating - Test to ~~ psig .. ~/,,/,z Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. Additional Remarks: J'~,}~. ~/~_, ~)//} 0 Geo lozv: En~$neer ing: WVA ,~Z~ MTM '~ HJH J~~:,,,';.,~:,1;~.~,~ .... -~ ,, rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE