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Home My WebLink About195-127XHVZE 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. File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beverly Diann~athan Lowell Is~ [] TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Is~ Ol' ggFO W Memorandum State of Alaska Oil and Gas Conservation Commission Re: Cancelled or Expired Permit Action EXAMPLE' Point McIn~re P2-36AXX API# 029-22801-95 This memo will remain at the front of the subject well ~e. 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 i' the treatment of these kinds of applications for permit to ddll. Operators have asked us to adopt formal procedures for this class of permit application in order to prevent future database disparities. If a permit expires or is cancelled by an operator, the permit number of the subject permit will remair unchanged. The APl number and in some instances the well name reflect the number of preexistin! redfills 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 ddil. The AP! number for this cancelled or expired permit is modified so the eleven and twelfth digits is 9",. The well name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the AP! numbering methods descnbed in AOGCC staff memor'anaum "Multi-lateral (wellbore segment) Ddiling Permit Procedures. revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 5, 1995 Tim Billingsley Stewart Petroleum Company 2550 Denali St., Ste 1300 Anchorage, AK 99503 Re: West McArthur River Unit No. 4 Stewart Petroleum Company Permit No 95-127 Surf Loc 2026'FSL, 1974'FWL, Sec. 16, T08N, R14W, SM Btmhole Loc ~1088'FNL, 200'FWL, Sec. 22, T08N, R14W, SM Dear Mr. Biilingsley: 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 ma. de. Your application for a waiver of the diverter requirements of 20 AAC 25.035(b)(1) and a waiver for the open hole wireline logging required by 20 AAC 25.071 at the surface casing point of 2205' TVD and at the intermediate casing point of 5200' TVD is hereby approved. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the B©PE 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 at 279-1433. Chairman BY ORDER OF THE COMMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl Stewart P e. ' oleum Company Denali ~'owers North, Sui~ 1300 2550 Denali Stre'~t, Anchorage, Alaska 99503 (907) 277.4004 · FAX (907) 274-0424 August 23, 1995 Alaska Oil and Gas Conservation Commission 3001 Porcupine Ddve Anchorage, Alaska 99501 Re: Application for Permit to Drill (Form 10-401) West McArthur River Unit #.4 Gentlemen: Enclosed is the Application for Permit to Ddll the West McArthur River Unit ~4 including two copies. The proposed well will be directionaily drilled from an onshore surface location to BHL offshore. The main target is the Lower Tyonek ,gas sands which are productive in the West Forelands Well No. 1 operated by Phillips Petroleum and located about 3500' to the south of the proposed WMRU #.4. A secondary target is the Hemlock oil formation approximately 800' below the Lower Tyonek target. A spacing exception is required due to the anticipated productive gas perforations in WMRU ~4 will be within 1500' of a section line and potential oil perforations will be within 500' of a quarter section line. A separate correspondence is being delivered to you requesting the spacing exception. A waiver is requested to drill the surface hole without a diverter. A waiver is also requested to eliminate the open hole logging runs at the surface casing point and at the intermediate casing point. If there are any questions, please contact me at 277-4004. Tim Billing§ldy~ Petroleum Engineer Stewart Petroleum Company CC: William R. Stewart, President- Stewart Petroleum Company Paul D. White, Operations Manager- Stewart Petroleum Company STATE OF ALASKA ALASKA ~ _ AND GAS CONSERVATION CC MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill .%~ Redrill __-[ lb. Type of well. Exploratory ~ Stratigraphic Test ~ Development Oil ~ Re-Entry -- Deepen"%1 Service - Developement Gas ~ Single Zone - Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Stewart Petroleum Company 140' KB feet West Foreland Field West Foreland Pool 3. Address 2550 Denali St., Suite 1300 Anchoraqe, Ak 99503 4. Location of well at surface 2026' FSL, 1974' FWL, Sec. 16, T8N, R14W, SM At top of productive interval 700' FNL, 200' FWL, Sec. 22, T8N, R14W, SM At total depth 1088' FNL, 200' FWL, Sec. 22, T8N, R14W,SM 12. Distance to nearest ! 13. Distance to nearest well property line IWest Forelands #1 1550' feet i 3424' feet 16. To be completed for deviated wells Kickoff depth 800 feet Maximum hole angle 300 18. Casing program size Hole Casing Driven 20" 18-1/2" 16" 13-1/2" 10-3/4" 9-7/8" 7-5/8" 6-3/4" 5-1/2" 6. Property Designation ADL 359112 7. Unit or property Name West McArthur River Uni 8. Well number No. 4 9. Approximate spud date Ju_ne 1, 1996 11. Type Bond (see 20 AAC 25.025) h~ Blanket Number 1278657 Amwest Surety Ins. Amount $200,000 14. Numberofacresin property Lease 2155 acres Unit 6330 acres 15. Proposed10,475'll'728'depth(MDandTVD)tMD TVD feet 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 3479 psig At total depth ('rVD) 4684 psig I Setting Depth Specifications Weight [ Grade/Coup'ing ] Length ~33 1~-89 BT~C Iz~.o 7~ I~:-Ss/ B~C !*-300 45.51 L-80/ BT&C J5770 I m- 0/ 17 I L-80/ FL4S I 1928 Top Bottom I I 1 S~r~. I I ~.0 I ~.0' Surf.I 123°° I 2205' Surf. I I5770 I 5200' 9800 18684 1117281 10475' Quantity of cement (include stage data) Driven 2160 cuft to surf. 420 ~uf~ (1000' f/shoe ' 2b0 cuf't (IUUU' f/'sho'~ 185 cuft 19. To be completed for Redrill, Re-entry, and Deepen O!)erations. 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 Structural Conductor Surface Intermediate Production AU O 2,~ 1995 Liner &ia_ $[~. u,i & Gas Cons, .C_qmmissi~.n Perforation depth: measured true vertical Measured depth True Vertical depth 20. Attachments Filing fee ~ Property plat i~ 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 certify that the foregoing is true and correct to the best of my knowledge Signed ,7-¢~'~ Permit Number ?~- /,z Title Petroleum Engr., Stewart Pet. Co. Date Commission USe Only APl number I Approval date' 5o-/.~,~ - .2__0 See cover letter for other requirements Conditions of approval Samples required i-] Yes ~ No Mud log required L-] Yes ~ No Hydrogen sulfide.measures F~ Yes ~ No Directional survey required ~Yes [] No Required working pressure for BOPE E]2M; [] 3M; [] 5M; [] 10M; [] 15M Other: Original Signed By by order of Approved by David W. Johnston Commissioner the commission Form 10-401 Rev. 12-1-85 West McArthur River Unit No. 4 Request for Diverter Waiver Stewart Petroleum Company requests that the diverter requirements in 20 AAC 25.035 be waived for West McArthur River Unit No. 4 because West McArthur River Unit No. 1, No. 2, No. 3, No. D-1 and West Forelands Unit No. 2 were all ddlled from the same general surface location without encountering any shallow gas. Previous waivers were granted for WMRU No. 2, No. 3 and No. D-1. Mud weights planned for the surface interval are 8.5 ppg at spud building to 9.4 ppg at 2216' TVD due to ddlled solids. These mud densities are consistent with the 3 pdor wells. Request to Eliminate Logging Runs at Surface and Intermediate Casing Points Stewart Petroleum Company requests a waiver for the open hole wireline logging required by 20 AAC 25.071 at the surface casing point of 2205' TVD and at the intermediate casing point of 5200' TVD. West Mc, Arthur River Unit Wells No. 1, No. 2, No. D-1 and West Forelands Unit No. 2 have previously logged these intervals and it does not seem necessary to incur the added expense for more logs in this area over these shallow intervals. Previous waivers for the surface and intermediate hole logging requirements were granted 'for West McArthur River Unit No. 3. West McArthur River Unit Unit Boundary Plat Proposed WMRU No. 4 T8N, R14W, Seward Meridian ' W Unit ADL 17602 Unocal u ~ i 4 3 2 :1 \ i WMRU-3 8 ~, 9 10 11 12 ' su~...~~iw~1 ~...~. ............... Proposed , Stewart Pet. Co. ""iii ADL 359112 I 20 ~ 21 22 23 24 -- -"-'*: SPC i ~ Phillips ADL 381012 ~L~..~:~:~t:.-~-:.~:~:~;~:.~it'.-~'.it~'~::.~~ ........ 32 ' 33 34 ~ 35 3~ , I 1': 1 mile West McArthur River Unit No. 4 Proposed Well Path of WMRU #4 Section 16 Section 21 West Foreland #1 880' FSL, 671' FEL IIi I 1 I l West Foreland Unit #2 Section 22 Proposed TD of WMRU #4 @ 1088' FNL, 200' FWL 1" = 1000' Section 15 Top of Gas Target @ 700' FNL, 200' FWL West McArthur River Unit No. 4 Proposed Location Section 9 / / / / / / / / Section 10 · VV~RU #3 WMRU #1 / / / / / / 0// 4 WMRU #2A / I / ! / Section 15 .....;(~_WF U #2 WMRU ~4 Proposed Top Perf WMRU #4 Proposed TD West Foreland#1 e 21 Section 22 1" = 2000' . , , , . . . . . 10. 11. 12. McArthur River Unit ~ Drilling Progi'arn Rig up Nabors Rig #!60. Drive 20" conductor to 130' RKB. Directionaiiy drill 18-i/2" hole to su.~ace casing point @ 2300' MD. Note: A waiver is being requested to eliminate the diverter on the surface hole section. Note: A waiver is being reque~ed to eliminate a logging run at the surface casing point. Run and cement !6" casing to surface. If slurry will not circulate to surface, pump top job. Cut off !6" casing, install !6=3/4" 3000 psi SOW casinghead and 16-3/4" 3000 psi x 20-3/4" 3000 psi adapter. NU 20-3/4" 3000 psi BOP stack. Notify AOGCC representative 24 hours in advance to witness BOPE test. Drill cement and t0' of new formation ~th 13~1/2" bit. Perform pressure integrity formation pressure test to 11.5 ppg EtvlW. Dd!! I3-I/2" hole to intermediate casing point @ 5700' MD. Note: A waiver is being requested to eliminate a logging run at the intermediate casing point. Run and cement 10-3/4" casing. Land casing in 16-3/4" casing head. Install 11" 5000 psi tubinghead and 11" 5000 x 13-5/8" 5000 psi adapter. NU and test i 3-5/8" 5000 psi BOPE. Drill cement and 10' of r~ew formation with 9-7/8" bi~, Perform leak-off pressure test. Dril! 9-7/8" hole to drilling liner depth @ 10,000' [VID. .Run wire!ina logs: Run #1 = D!L/CNULDT Run #2 = FMS 13. Run and cement 7-5/8" liner. 14. Drill 6-3/4" hole to TD @ 11,728' MD. West McA~ur River Uni Drilling Program ell #4 15. Run wireline logs: Run #1 = DIL~CNLILDT Run #2 = FMS 16. Run and cement 5-1/2" liner dependent on log resu~s. ,.,,.TI,.,BT 17. Run cased hole logs as rc------quir~: 18. Run completion equipme,~. Completion equipment wilt be contingent on logs. Anadril 1 Schlumber~er Alaska District 1111 East 80th AYenue Anchorage, AK 9951,8 -(907) 349-'~'5tt "Fax-34'9-*2487 DIRECTIONAL WELL PLAN for STEWART PETROLEUM COMPANY .x-.~i~ld ............ : ..West- McArthur River..-Unit .... · ........... Computation,,: MINI~ ~VAT~E -. Units ........ ~ .. ~ Sur. Kac~._ Lat ....... : ..... ~0..3.82439 lt_..N .......................................... "'~urface Lon~.: 151.74657679 W LO~TIONS - ~AS~ Zone: L~al DescriPtion" X- Coord Y-Coord Surface ........ : 2026 FSL 33.06 FEb. $i6 T08N R1,4W.SM 18~8.77..81 2~82Q72.31. ' Tar.~eg ....... : 4580 FSL 5080 FEL $22 T08~ ,R14W SB~ 191314.53 2479254,]5 B~L .......... : ~192 FSL 508~ F~L S22 T08N RI~W SM 191304..22 2478866.53 ANADRILL C°nvergenc~A-DP~i FEASIBILITY PLAN NOT ^PPROVED .FOR EXECUTION Prepared ..... : 08/03/95 Sectiorl,-..at.-.-... t25-...4'2 '-. "' ' 'KB ele.vatio~,: 140.00 .ft.. Magnetic Dcln.: 22,483 E :447726 STATION IDENTI FI CAT ION MEAS INCLN D IRECTI ON VERT- DE PTHS SECT RELATIVE- COORDINATES DEPTH ANGLE AZIMUTH BKI3 S~-S DIST FROM- T[~E - WE LLHEAD .... I(OP'-BLTI'L-D' 2':5/1'00 · EIb3 OF 2.5/100 BUILD · ...0 ....... 0....00 ..... 0..~.0 ............ 0 ....... 140 ........... O ........... 0 30'0 0.00 0.00 800 6¢0 0 0 900 2.50 125,42 900 760 2 1 ~OOO 5.00 125.42 1000 860 9 5 ll0O 7.50 125,42 1099 959 20 :l . . 1200 t0..00 125_,42 ~198 105.8 3.5 20 1:00 12.50 125.42 1296 1156 54 31 1400 15.00 125.42 1393 1253 78 45 1500 17.50 125.42 1489. 1349 106 61 1600 20'.00 125.~2 1584 1444 138 80 1700 22.50 125.42 1677 1537 174 1800 25.00 125.42 ].769 1629 215 124 1900 27.50 125.42 1858 1718 25·9 150 2.000 30.00 .i25.42 1946 i806 307 . 177 2013 30,32 125,42 1957 1817 31.3 181 ,. 00-N ....... 0.-,-0 O--E .00 lq 0.00 E .26 $ 1,78 E .05 S 7. ll E .36 S 15.98 E .18 S 28.17 E .48 9 44.27 E .26 9 63,64 E ,%7 S 86.44 E ~10 S 112.64 E · 10 S 142.17 .44 S 174.99 .07 S 211.03 .94 S 250.,23 .02 S 255,40 STATE- PLANE TOOL DL/ X. Y FACE 100 ................... === == 18~8~-'7v8~-'-~'4~07~';~'1 ' "0':00-' - 187677'.81 24820'7~.31 HS 0'."00 187879.55 2482071,00 HS 2.50 187884.78 2482067,07 HS 2.50 187893.48 2482060.5~ ~S 2.5.0 18790.5.64 24.82051.38 HS 2:50 187921.23 2482039,66 HS 2.50 187940.23 2482025.38 HS 2.50 187962.59 2482008,56 HS 2,50 187988.28 2481989.24 HS 2.50 189017.24 2481967.46 HS 2,50 188049.43 2481943.26 ~$ 2.50 1880~4,78 2481516.68 ~S 2.50 18'81Z3,22 24.81887.77 HS 2,50 188128.29 2481883.96 2.50 ~4RU~4 08/03/95 Page 2 S TAT I ON IDENTI FI CATION 'START 3/100 CURVE E: S~ T( B( TOP TARGET~ 2 TD PROPOSED WELL PROFILE · . MtL%-S I'NCLN -D't-KSCTIO~ vt~RT-DEPTHS S'E~T DEPTH ANGLE AZIMI)~rt BKB SUB-S ~IST 9471 30,32 125,42 8396 ~296 4078 9500 29,'9~ 126.99 8420 8280 4093 9600 28,94 132,72 8508 8368 4142 9700, .28,~6 .138 , 3~ 859.5' 84,55 4-1.89' 9800 27.66 145,11 8684 8544 4233 RE.Ii~TTvE- COORD FROM-THE-WELLHRAD 2363.46 $ 3323.54 E 2371.99 S 3335,19 E 2403.44 S 3372,93 E · 24'3.7,63, S 3406,,25 E 2474. ,42 S 3435,09 1~ STATE-PLANE TOOL DL/ X Y PACE 191137.33 2479621,25 1],4R 0,00 191148.75 2479612.41 ll3R ~ '00 1911,85,63 2479579,97 1OSR 3,00 191-2t~,04' '2~7954'4,91 10'2R':" ~','00 191245,89 2~79507.36 97R 3,00 .......... ~900 ..... 29,,t6 .......... 151.,58 ........... 87-~2 ..... 8632 ........ t216 XOOGO 27,$6 158.08 8861 8721 ~316 101O0 27.96 164,46 8950 8910 4354 10200 28.64 170.63 9038 8898 4389 I030,0 2~.59 . 176,~8 9125 8985 4421 2555.50 S 2599,56 S 2645,80 S 269%,10 S ...... 3,4 -~ 9-.- .3 4.- -E ..... 1.-9-1: 2,69. ;-09 --24 '-7-946 ?", '~9 ....... 9 3478.96 E 191287,59 2479425,.13 85R 3493.88 E 1913~1.33 2479380.70 8UR 3,'00 3504.06 E 191310.28 2479334..20 74R 3.00 3509~48 E .191314~41 24792~,,5.~ 69R 3'.00 10363 30.32 1.80,00 9t80 9040 4440 10363 30.32 180,09 9~80 9040 4440 10363 30.32 180.00 9180 90____q~_Qv 4440 10400 29.58 180.00 9212 9072 4451 10500 27,58 180.00 9300 9160 4~79 2725,71 2725.71 272.5.71 2744.00 2791.84 3510.44 3510.44 3510,44 3510,4t 3510.t4 191314.53 2479254.15 L$ 3,00 191314.53 2479254,15 L$ 3.00 191314.53 2479254.15 LS 3.00 191314.04 2~79235.$7 LS 2,08 191312.77 2479188.~5 LS ~.00 L0590 25,76 180,00 9380 9240 ~502 ~0600 25.58 180,00 9389 9249 4505 ~0700,,. 23...58 ...... I$0,0~ .94~0 ...9~40. -.4529 1'0~00 21.5~ 1~0,00 9572' 9432 ~551 10900 19,5~ 180.00 9666 9526 4571 2832,27 S 2~36.5~ g 2951.74 S 3510.44 E 3510.44 E .... 35t. 0-..44- E 35I'0', 44 Em 2.510.44 E ].91311,70 2499147,63 LS 2.00 1913~1.5a 24791~3.31 .LS 2,00 19~310-,-%~--2479~0~;~3' LS' 2.0'0' ~91309.45 24~9063.34 LS 2"]~0 191308.52 2t79028.20 LS 2.00 11000 17.58 180,00 9761 9621 4590 . . Lll00 t5.5.8. 180,.00 9856 9716. 4606 .11197- 13.65 180,.OO-. 9950.- 9.8.10. ~62,1 ]]200 13.58 lg0,00 995~ 9~13 4621 11300 11.58 lS0,00 10051 9911 4634 2963.60 · 3012.14 - 3036-,,54 3037,32 3059,10 $ 3510,44 S 3530,44 S- 35t0.44- S 3510,44 S 3510,44 191307.67 2478996,34 LS 2.00 193306.91 2478967.82 LS 2,-00 191.306,26 247-8-943-~3 LS 2-,'00 191306.2t 2478942.65 LS 2.00 191305,66 2478920,87 LS 2.00 11400 9.58 180.00 10149 '10009 4644 11500 7,58' !80,00 102%$ 10108 4653 11600 5.'5B 180.00 10347 ~0207 4660 11700 3.58 180,00 10447 10307 4664 1172~ 3,02 180.00 10475 10335 46~5 . . . 3077,47 3092.39 3103,86 3111.84 31~3,46 3510.44 E 3510',44 E .. 351.0.44 E 3510.44 E 3510.4'4 E' 191305.17 2478902,51 LS 2.00 ,!91304.79 2478~gT.S9 LS 2,00 91~04 47 2.t7~876 13 LS 2 00 191304.26 2478868,L5 L$ 2,00 191304.22 2478966.53 2.00 . c I c~ i..4 I 15:54 ~ROM ANADRI LL P,,, TROLE ii1!!. JM · .__ f,800 ~0~ ]000 3600 ', SeCt i~Dn Departure , .. TO P740424 ~, 84 · COiqPANY ---- , _ ~,j~ , ! ...... .._ -illl':-- ~ .__ VERTICAL 'SECTION VIEW s,ctioH ~t: 125.42 IVD Scale' 1 ~nc.q ~ ~200 feet De~ Sc'~]e · t inch-- ~200 feet Orawn..i.. ' 08/03/95 T ....- .._.: ! ,- --.: ~: .... ; 0 0 0 B) KOP 8~!tO ~.5/~00 890 800 0 C) END OE 2.5/100 BUILD 2013 1957 El START!3/100 CURv~ §47~ 8396 4078 E) END OE 3/100 CraVE 10363 9:80 4440 F] SIA~T!2/IO00ROP 10363 g~80 4440 G) TOP T~RGEI#~ ~0363 g~80 4440 HI B0ffO~ TARGET#I t05gO 9380 I) TOP T~RGET#2 11~g7 gg50 462! J} TO 1~788 ~0~75 4885 O.00 o.~o 30.~2 30.32 30.32 30.32 30.32 ~5,~8 ~3,65 3.02 E IBILtT' . ; pLAN 4200 ~ZBOO · i ' · .. , : AUG 5400 6000 6600 7200 78C0 i! ii .~1 AUG-03-1995 15:55 ~ROM ANADR!LL TO 2740424 ~. 05 . ~ .:~'-- - i - .2-- ~ ~ -.JJ~ iij__ ' ................. , i ....... · .. 0 800. 20~3 947~, '!0~3 'I0363' '10590 1'97 c] E] H) N/S £/W ~82, 255 2383 3324 2726 ~0 2726 ' 2726 : 2832 ! 3550 3037 : 35¢0 CLOSURE. ! .... : DECLINaTiON.' SCALE...' ' DRAKN...! .... : 08/0:3/95 .... '?' :J ----ii ii :Anadri l ], Schlumberge~ -- LL I-- .-; --m L__ WMRU#.4 PLAN '-~ ~ ...... ~t.' .... 4692 feet at' Azimuth ~.3~ ,.57. 22.4:83: E I inch--60'0 feet o-- , ~ .~- ....... ..~...~,k A', ~ ~! [ FEAStBILIW ,~ . ~ ,' NO~ APPROX~ED FOR : 0---. i ..... -~- , .... ~ , , ~ ~EXECUT" ~ ......... ~ i ........... L .. ! ; , .~ -'-~. t ~ ' ~' .~,..., ........ ... ~ I - ,. ',. ~ · ,, ~ ...... · '"~ }' ~ ~ ~ .... I ..... ~ ; ..... :j ; : , i . i ...... i ........ ~-~ , r ..... ., ...... ~ ~ .' I ' ' J' I : I F ' )q 0 3~ 600 900 i~O0: i50O ~BO0 ~100 ;2400 2t00 3000 3300 3(]00 3~(:0 .I IJ ~ J. u_' . ~ . ; ~)!~_~'~-~'z~'~ ........ ~' ' : · i:: ',':. ~-., .... ' ...': , ,,~ ---: I TOTqL F:'. 35 West McArthur River Unit #4 Pressure Information The fo!!owi.;ng presents data used for calculation of anticipated su.rface presures (ASP) dudng drilling of the West McAdhur River Unit #4. The pore pressure gradient information was obtained from the bottom hole pressure surveys and RFT surveys on West Mc.Arthur River Unit. #I, #2A, #3, West Forelands Unit No. 2 and West Forelands No. I The fracture ~,-=,4~,-,~ ~,,~,,,.~,,i,-,,, wa- obtained from formation integrity tests below casing points on the West McArthur River Unit # ! ,#2A, and #3. Casing Pore Casing Setting Fract-,ure Pressure Pore ASP Size Depth Gradient Gradient Pressure Drilling ('in.) ~ ~ ~ (psi) (psi) 20 120 8.4 52 18 2300 11.5 8.4 1005 10=3/4 5200 15.0 8.6 2325 7-5/8 8861 14.5 8.6 3963 5-1/2 10475 8.6* 4684 1065 3458 3479 * West Forelands #1, P= 4164 psi @ 9336' TVD from a BHP survey on 3/84 after the iast time that the well was flow tested. Procedure for Caiculatinq A_n_ticipated Surface Pressure ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point !ess a gas gradient to the surface as follows: 1) ASP = ((FG x .052) - 0.115) x D where: ASP = Anticipated Surface Pressure in psi FG = Fracture Gradient at the casing seat in lb/gal 0.052 = Conversion from lb/gal to psi/ff 0.115 = gas gradient in psi/ft D = true vertical Depth of casing seat in ft RKB OR 2) ASP = FPP - (0.115 x D) where: FPP = Formation Pore Pressure at the next casing point which is tied back to surface or at TD (total depth) West Mc.&~thur River Unit · Press~ar¢ Information ASP Calculations . Dfitting _betc~,, surface casing (16') = ~ .052)-0.115) x D ASP ~FG x = ((11.5 x .052) - 0.115) x 2205' = 1065 psi OR ASP =FPP-(0.115xD) = 2325 - (0.115 x 5200) = 1727 ps~ Dd!!ing below intermediate casing (10-314') ASP = ttr,.> x .052)-0.115) x D = ((15.0 x .052) - 0.1 !5) x 5200 = 3458 OR ASP = FPP - (0.115 x D) = 4739 - (0.115 x !0475) = 3534 psi Ddiling below liner (7-5!8") ASP = ((FG x.,,,,,./-,~.~,~'~ n ," 15) x D = ((14.5 x .052) - 0.115) x 8861 = 5662 ps~ OR ASP =FPP '"' D) - ~,,.115 x = 4684 - (0.115 x 10475) = 3479 ps~ . STATE OF ALASKA ALASKA ,JIL AND GAS CONSERVATION C,,.,,vIMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL m OTHER 1 2. Name of Operator 7. Permit No. Amoco Production Company 3. Address 8. APl Number P. O, Box 100779, ^nchorage, Alaska 99510 so- 133-10028 4. Location of Well 879.5' R14W, S.M. FSL, 670.5' FEL, Sec. 21, T8N, t 6 . Lease Designation and Serial No. A-035017 9. Unit or Lease Name West Forelond 10. Well Number 1 5. Elevation in feet (indicate KB, DF, etc.) 78' MSL 12. 1 1. Field and Pool West Foreland No, Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing" [] Perforations [] Altering Casing Stimulate [-1 Abandon [-] Stimulation [] Abandonment Reoair Well [] Change Plans I--] Reoairs Made [] Other Pull Tubing [] Other r"] Pulling Tubing [] Tes t i n g {Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 170 AAC 25.105-170). Approximately 52.8 MMscf were flowed during the period 2/22/84 - 3/20/84 from West Foreland No. 1. Several problems due to hydrate formation were encountered during the initial portion of the test. When these problems were resolved, 7.7 MMscf per day were flowed through a 22/64 choke at 2,675 psi. After the flow test was completed, a Lynes pressure bomb was run in the hole. The static pressure was 4,164 psi at 9,336' At the conclusion of the test, a CAMCO 2½" sub-surface sa~ ~T~-"W~-S~-~et ~t 9,253' and the well was returned to a shut-in status. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .... Titlel gis~.~ct ,U. anager The sDace below for Comm,ssion use _~,x,~,,~ ~" ' Conditions of Approval, if any: By Order pi Approved by COMMISSIONER the Commission Da~e Form 10-403 Submm! "lnlent~ons" ~n Tr~plmcate and "Subsequent Reporls" mn DUpllcale Blowout Prevention Equipment Nabors Rig No. t60 13-5/8" BOP Eauipment 3 ea 13-5/8" x 5000 psi wp ram type preventers (Hyddl) ! ea 13-518' x 5000 psi wp annular preventer (Hyddl) Iea !3-5/8~ x 5000 psi wp drilling spool with 2 ea 4'~ side outlets (choke and kill), HCR and manual valves on both choke and kill lines. 20-3t4" BOP Equipment Iea 20-3/4' x 2000 psi annular preventer (Hydril) Iea 20-3/4" x 3000 psi double ram preventer (Cameron) 1 ea 20-3/4" × 3000 psi wp ddliing spool with 2 ea 4" side outlets (choke and L4.~ HCR and manual valves on h~,m choke and.~.~'-:" lines 1%111/~ ~,fV~I I · Iea Iea I lot BOP accumulator, Vaivcon, 300 psi w/12 bottles, 180 gallons, and (1) 80 gallon Vaivcon accumulator. Accumulator pump, Gardner-Denver Triplex, Model PQ 172, air pump Model G7E. 8 bottles nitrogen backup. Valvcon, 6 station, remote control panel Thomhiil Craver, automatic choke 3"- 10,000 psi with control choke panel Hydraulic pipe and firings from manifold to BOP stack. Nabors Rig #160 13-5/8" 5000 psi BOP Stack 3-1/8" Kill Line I = HCR Valve 2 = Gate Valve 5000 psi Annular Preventer ! I 5000 psi Pipe Rams 5000 psi Blind Rams Drilling Spool 5000 psi Pipe Rams 3-5/8"x 11" 11" 5M Casing / 4-1116" Choke Line Nabors Rig #160 20-3/4" BOP Stack 2000 psi Annular Preventer 3000 psi Pipe Rams I ! I Rams DSA 4~1/16" x 3~i/8" 5K 3000 psi Blind Drilling ~ 3~1/8" 5K Kill - Spool . 4-1/16" Choke Line Line 20-3/4"x 16-3/4" I = HCR Valve ~ 2 = Gate Valve ~ 16-3!4" 3M Wellhead 16" Casing W~t McArthur River Unit #4 Cementing Program 20" Conductor- Driven 16"' Surface Casing 18.5" hole at 2300' MD 2300' x 0,4704 cu~'ft (i8.5~ x 16~) x 2,0 (t00% excess) = 2160 cuff Cement = 520 cuff Ciass G w/CaCI @ I5,7 ppg 1640 cuff Class G w/2% gel @ 12.5 ppg If no returns to surface after pumping !00% excess, perform top job. 10-3/4" Intermediate Casing 13.5" hole @ 5770' MD Cement volume for !000' of fill-up above shoe: 1000' x 0.3637 cuft/ft (12-1/4" x I0-3/4") x 1.15 excess = 420 cuff Cement = 15.8 ppg Class G ~ ~ 7-5/8' Ddlling Liner 9-7/8" hole @ 10,000' MD, top of liner at 5570' MD Cement volume for liner based on 1000' of fill-up above shoe: 1000' x 0.2148 cuf'dft (9-7/8" x 7-5/8") x 1.15 excess = 250 cuff Cement = 15.8 ppg Class G 5-1/2" Ddlting Liner 6-3/4" hole @ 11,728' MD, top of liner at 9800' MD Cement volume for liner based on c, aliper hole volume plus 15% and liner lap, e~imated volume is: 1728' (!1,728' - 10,000') x 0.0835 cuftJff (6-3/4" x 5-1t2") x 1.15 = 165 cuff plus 200' liner !ap @ 0.0928 cufftft x 200' = 20 cuff 165 + 20 = !85 cuff Class G cement "-' AUG 23 1995 · ancliora£e C°m[ni$$ion Drilling Fluid System Description Nabors Rig No. I60 Mud Pumps 2 ea Continental Emsco F-i300 tdplex mud pumps 7' x I2", 1300 HP with (2) C-E pulsation dampeners, Model M822, each pump equipped with (2) 752 GE traction motors, cooled with ambient air. Each pump charged by a 5 × 6 Mission Magnum I with 50 HP AC motor. Mud Tank System (i035 Total Volume) Tank #! (shaker tank) appx, 270 bb!s. Three compartments which include desander, desi,~er suction compartment and cu~ing trap compartment equipped with shale shakers, degasser, poor boy degasser, and mud guns in top skidded section. Tank #2 (volume tank) appx. 460 bbls. One compartment equipped with desander, desi!ter, mud cieaner, mud guns and mud agitators in top skidded section. Tank #3~..,~...,..,r~-,';~,.,., tank) appx.,.,...~n~ bb!s. -r~,..,~, ,,,,.,. compartments, ~,vo of which are pill pits, t thru 65 bbls; one 55 bbl equipped with mud guns, mud agitators, mud mixing hopper, and chemical barrel in top skidded section. Mud System Equipment Iea Iea Iea 1 ea 4 ea 4 ea Iea 6 ea Derdck dual tandem shale shaker Drilco degasser Picenco 16 cone desilter Pioneer sidewinder mud mixer Brandt 7-t/2 HP mud agitators Mission Magnum pumps, 5' x 6' centrifugal with 50 HP GE Electric Motors Pioneer desander, 2 cone, Model S-2-12 Dahiory 3" mud guns McArthur River Unit #4 DHlling Fluid Program Surface Hole Spud - 2300' Hole size = 18-1/2" Casing Size = 16' Mud type = Spud Mud Mud Parameters: Weight: 8.5-9.4 ppg Viscosity: 90-150 sec/qt pH: 8.5-9.5 PV: 14-24 YP: 25-50 Fluid Loss: <30 cct30 min The surface interval will be drilled with a bentonite/acrylic polymer surface mud. Fill pits with fresh water. Treat excessive hardness with soda ash (1/2 to 3/4 ppb) until 40 ppm hardness remains. Prior to spud, mix the sudace system to maximum capacity, adding bentonite (20- 25 ppb) to yield a viscosity of 90 sec/qt. Maintain viscosity while drilling ahead at 120-150 sec/qt through any gravel sections. Keep mud weights as Iow as possible with water additions and solids control equipment. Keep sand content below I%. Acrylic polymer (Ben-Ex) may be added at a 5:1 ratio with bentonite as a bentonite e~ender. West McA~hur River Unit _ ,ell Drilling Fluid Program Intermediate Hole 2300' - 5770' MD or 2205' - 5200' TVD Hole size = 13-1/2" Casing Size = 10-314" Mud type = LSND Mud Parameters: Weight: 8.8-9.4 ppg Viscosity: 50-90 sec/qt pH: 8.5-9.5 PV: 8-18 YP: 15-25 Fluid Loss: <12 cc/30 min The intermediate interval wilt co_ntinue with a !ow solids, non-dispersed mud system. Before drilling out cement, evaluate the spud mud from the previous interval for low gravity solids and active bentonitic clays. If the mud is clean, the 16" shoe can be drilled with the old mud and this would eliminate building a new mud system from scratch, if the iow gravity solids are too high, dump and dilute with fresh water to bring LGS into line. Prior to drilling new formation, increase the yield point to ensure good hole cleaning. Because this well has a high angle, cuttings bed formation could be a problem. Therefore, keep the yield point high (20-25) and initial gel strenghts at I0-15. Rheotogicai propeCJes can be regula~d using Sodium Pyrophosphate (SAPP) in small quantities. If it is necessaw to redu~ the fluid loss to the 6-8 cc range, Ddspac can be used at Iow concentrations. Keep mud weight as iow as possible with water additions and solids control equipment. Keep sand content below 1%. West McArthur River Unit ~ ,ell #-4 Drilling Fluid Program Dd!ling Liner Hole -~'-~ ,., .... on 5770'-10,000' MD or 5200'-8861' TVD Hole size = 9-7!8" Casing Size = 7-5!8" Mud type = PHPA polymer Mud P~. am~e, s. Weight: 9.4-9.6 ppg Viscosity: 42-50 seciqt pH: 8.0-9.0 PV: i0-20 YP: 12-25 Fluid Loss: <6 cc/30 rain Bump the plug on the 10-3i4" casing with the old mud, then build the new PHPA polymer system. Fill one suction pit v~h flesh water for ddll out of the cement. Avoid drilling cement with the new PHPA system. Clean the remaining pits and fill with fresh water. Treat the fresh water with Soda Ash as required for hardness. Add 10-12 ppb bentonite and allow to properly hydrate. Add 0.75 ppb PHPA and do not add barite at this time. After drilling the cement, discard as much of the old mud as possible. Continue PHPA additions until the complete system is treated with 0.75 ppb PHPA. Add su~cient polymer (0.5 ppb) until the Clapper Polymer test on the whole mud yields 0.4-0.6 ppb of available polymer. Because of potential cuttings bed problems, 10 minute get stegths should be at 15-22 and 30 minute gels should ~ 25-30 which will indicate nomprogressive gel structure. There may be siginificant viscosity increases as the polymer reacts initially with ,h,, native solids but additions should continue until you are over the hump". Slight additions of Desto or Ligco will reduce the viscosity somewhat. Inspect the drill cuttings to help determine the proper polymer concentration. Sticky or visibly hydrated cuttings indicate iow polymer concentration. The Clapper Polymer Test is the most accurate method to determine proper polymer concentration and should ~ ru-n at least every, 2 days. If more viscosity is desired to clean the hole, Biozan can supplement the system. Utilize low viscosity-high viscosity sweeps to reduce cuPdngs bed formation. West McA~ur River Unit. ,ell Drilling Fluid Program To reduce fluid loss, add starch at 3-4 ppb while adding PAC polymer at 1-1.5 ppb. This will assist the benton~e and native days in suspending solids when not circulating. Monitor the HTHP filtration for an indication of cake formation and compressibility. Adding an acrylamide and alkali salt will help stabilize the APl filtrate and improve the HTHP values to tess than !2 cci30 min. Supplementing the PHPA polymer with a 4 ppb blend of Bore-Plate will provide maximum shale stabilization especially as the Cook Inlet coal intervals are encountered. To smooth out rheologicai properties, add a low moecutar weight polyacrylate thinner works which wilt not disperse the solids. Mud weights should be kept Iow by running all solids control equipment to their maximum efficiency. Run a minimum of 200 mesh screens on the mud cleaners to give maximum cut. A iow gravity solids of !ess than 7% is required for optimum performance of this system. Dilution or complete displacement should be considered if higher LGS contents persist. VVest McA,~ur River Un,. Cell #4 Drilling F~uid Program Prc, duction Liner Hole S~ion 10,000'-11,728' MD or 8861'~10,475' TVD Hole size = 6~3/4' Casing Size = 5-1/2" Mud type = PHPA polymer Mud Parameters: Weight: 9.4-9.6 ppg Viscosity: 42~50 seclqt pH: 8.0-9.0 PV: 10-20 YP: 12-25 Fluid Loss: <6 cc/30 min Bump the plug on the 7-5i8" liner with the PHPA mud treated with Bicarb to offset cement contamination. The fluid system will already be established from the previous hole section. Eliminate the PAC polymer for filtration control and use starch and acrylamide/alkali salt. This will also enhance the iubricity of the fluid along with a glycol lubricant. After drilling out the cement, have the PHPA concentration at .6-.75 ppb and Bore-plate at 4.0 ppg. The APl filtrate should be less than 6.0 cc. The glycol lubricant should be kept at 3% to provide iubricity for the high angle weilbore. Maintain rheoiogica! prope~ies on the high side to prevent particle settlement and pump regular high viscosity/low viscosity sweeps. Keep the mud weight as iow as possible because unnecessa,~! solids have detrimental effects on the polymers. WMR #4 Casing Design 16" 75#, K-55 BT&C 10-314' 45.5#, L.-80 .1~ 7-5/8' 29.04#, L-80 .-~ 5-1t2" 17#, L-S0 2300' MD, 2205' TVD 5770' MD, 5200' TVD ~. @ t0,000' MD, 8861' TVD 11,728' MD, 10,475' TVD West McArthur River Casing Design 20" Conductor, t33#, NT-80, BT&C @ 120' MD 16" Surface, 75#,. K-55, BT&C @ 2300'. MD, 2205' TVD Tension = 2300' x 75¢ = 173K Rated = 1178K for body Safety Factor = 6.8 OK Burst = (5200' x .45)- (.115 x 5200') = 1742 psi f/drlg to next csg pt. w/f'dll column of gas Rated = 2630 psi for burst Safety Factor = 1.5 OK Collapse = (2300' x .45) - (. 1 t5 x 2300') = 771 psi for full evacuation Rated = t020 psi Safety Factor = 1.3 OK !0-3/4" Intermediate Casinq, 45.5~, L-80, BT&C @ 5770' MD, 5200' TVD Tension = 5770' x 45.5# = 263K Rated = 1046K for body Safety Factor = 4.0 OK Burst = (10475' x .45) - (.115 x 10475') Rated 5209 psi for burst = 3509 psi f! drlg to TD Safety Factor = 1.4 OK w/full column of gas Collapse = (5200' x .45) - (. ! 15 x 5200') = 1742 psi for full evacuation Rated = 2470 psi Safety Factor = 1.4 OK 7-5/8" 29.0#, L-80, STL liner @ 10,000' MD, 9000' TVD Tension = (10000'-5570') x 29.0# = 128K Rated = 444K for joint Safety Factor = 3.5 OK Burst = (10475' x .45) - (. 115 x I0475') = 3509 psi f/drlg to TD w/full column of gas Rated 6890 psi for burst Safety Factor = 2.0 OK NtA for liner Collapse = (8861' x .45) - (8861' x.115) = 2968' psi for full evacuation rated = 4790 psi Safety Factor = 1.6 OK 5-1/2" 17#, L-80, STL liner @ 11,728' MD, 10,475' TVD Tension = (11728'-9800') x 17#: 33K Rated = 210K for joint Safety Factor = 6.4 OK Burst = (10475' x .-~o) - (. 115 x 10475') = 3509 psi Rated = 7740 psi Safety Factor = 2.2 OK N/A for liner Collapse = (9663' x .45) - (9663' x .115) = 3237 psi Rated = 6280 psi Safety Factor = 1.9 OK AUG 2.3 1995 .... """ ~chorag~ West McArthur River Unit Casing Specifications CSGSPEC4.XLS AL/~- .A OIL AND GAS CONS~RVA?IQk .OMMI681ON · BOND w. ......... .~7.~fAR~,,~I~~:~Z ...... : .................................................................. "~~' *~ ~ST S~TY INS~~ COMPANY for ~ ~, ~1 t~ ~y m ~ m~., ~ ~ ~r=;~ ~ ~ of ~, ~ e~ of our ~., A,~ ~f lturfa~ Wall I.n=~-~ie.. Tw~.. Rr~. ~ MK. ~ .i_iv' . ~ AUG 25 1995 . Any ,nd d! w~l~ drilIRt ,rd opmlrt~ ~ I~ PtInGipal Irl tM ~ af Ai~ P~I~ & Gas Co,s. Commi~!~ ~ ru~. ~u~ ~ ~ ~ ~ ~ OU ~ G~ ~~~ ~~, ~ ~ wl~ ~ AIMkl Oil e~ ~ ~n~ · __.~_~..r..s..t. ....... ~aVO~,. October 1= 93 ~..~.,, ' STEWART PETROLEUM COMPANY 'A~ST S TY I~SU A E COMPANY ....... ........ ,._ .... .,.,... ~ Dianne Hansen, A~torney-tn-F:' ~ ~ow~: ~ OIL AND G~ ~NSERVATION COMM~ION 1~ . ,. . , . · -~. 7.1 ~ , ' . . ~t ~. ~l~. ~ ~ ~ retw- , .v LL PERMIT CHECKLIST ~FPROGRAM: exp~ dev [] redrll [] serv [] /.~ lc) oN/o~ s~o~s ~ , , ADMINISTRATION ENGINEERING REMARKS 1. Permit fee attached .................. ~ N ' 2. Lease number appropriate ............... ~ N 3. Unique well name and number .............. ~ N 4. Well located in a defined pool .............. Y Well located proper distance from drlg unit boundary...Y 6. Well located proper distance from other wells ...... ~ N ,~. ~:~ //~, ~--Z~ 7. Sufficient acreage available in drilling unit ...... ~ N · ~ , 8. If deviated, is wellbore plat included ......... ~ N 9. Operator only affected party .............. '~ 10. Operator has appropriate bond in force ......... ~~ 11. Permit can be issued without conservation order ..... ~' 12. Permitcanbeissuedwithoutadministrativeapproval...Y N /~/~.,~ ~.t". ~,~__.,__..,F..,,~,4~..~,~_ 13o Can permit be approved before 15-day wait ........ Y N ~/ f'~ /, ~ 14. Conductor string provided ............... 15. Surface casing protects all known USDW, ........ ~ N ~,~ /~?-- ~/~. '- ~F~.~w~ 16. CMT vol adequate to circulate on conductor & surf cng.. Y~ N 17. CMT vol adequate to tie-in long string to surf cng . . . Y 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. ......... 23. If diverter required, is it adequate ........... ¥ 2~. Drilling fluid program schematic & equip list adequate oI~ 25. BO?Es adequate ..................... t~ N 26. BOPE press rating adequate; test to ~--~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... ~ 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............. Y GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures. 31. Data presented on potential overpressure zones ..... 32. Seismic analysis 9f shallow gas zones .......... 33. Seabed condition survey (if off-shore) . . . ~.~... Y N 34. 0ontact n=e phone for weekl progress reports .... [exploratory only] ENGINEERING: COMMISSION: Comments/Instructions: H~W/jo - A:%FORMb--Acheklist rev 03/94