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Home My WebLink About193-081PLuG=iA'= = LOC3.TION CLEnCh. REPORT ,:err i~--=arvais - to_us: Review =he wel__~ ~___=~ ~ =, and' c~-~.~U cn plugging, well head suaUus, and !oca=icn clearance - urmvide loc. clear. Well head =a: o~f: .. Harkar pos= or pla=m: Locanlon · PERMIT 93'-081 93-081 93-081 AOGCC Indi'v'¥dual Wel"l Geological Nater'~ials Inventor'y DATA T DATA_F' L U S /+O7 DAIL. Y WELL OF', $ IJ R V E Y ¢~EOMP DATE:7'-16-93 k.~6~29 .... 93 TO 7-16 .... 9,3 . L~GREATLAND DRILLING Page D a t e R U iq 'i DATE RECVD 08/06/'1993 08/06,/199~ 08/06/1993 Ar'e dr'y ',:,/as the APe we1 I '¢1e11 'i s C 0 N M E N T S d~'tch samples r'equ~r'ed? yes ,_~__~,r,d r'ece~ved?/~es we]l cor'ed? yes ~},,Analys'fs & descr~4._p~ r'ece~ved? tests r'equ"~r'ed?]~(. es ~ Received? ..... ~ no n compliance~ti'a~'~ I n I"1 0 y e S n 0 AbASKA OIL AND GAS · CONSERVATION CO~IMISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 30, 1994 Jerry Bixby/Steve Farris Wireline/Completion Supervisors BP Exploration (Alaska), Inc P O Box 196612 Anchorage, AK 99519-6612 Re: No-Flow Verification 15 BPX PBU Wells Dear Mr. Bixby/Farris: Our inspectors witnessed no-flow tests on and recommended no-flow status for the 15 BPX PBU wells listed below. The wells were open to an atmospheric tank to determine fluid production and monitored through a gas meter to determine gas production rates. The inspectors recommended "no-flow" status for the wells listed below. Well No. ?TD No. Test Date Inspector Fld Rate Gas Rate S - 29 92-099 12/08/94 Grimaldi 0 30 scf/hr P - 04 91-076 12/18/94 Foster 0 0 scf/hr P - 12 91-017 12/18/94 Foster 0 0 scf/hr P - 15 90-176 12/18/94 Foster 0 0 scf/hr P - 16 90-163 12/18/94 Foster 0 0 scf/hr X - 21 93-111 12/18/94 Foster 0 0 scf/hr X - 25 84-034 12/18/94 Foster 0 0 scf/hr R - 08 81-001 12/19/94 Foster 0 0 scf/hr R - 17 81-164 12/19/94 Foster 0 90 scf/hr ~!!~U~?~, llA 91~0~81~ 12/19/94 Foster 0 135 scf/hr U - 12 85-182 12/19/94 Foster 0 180 scf/hr U - 13 78-101 12/19/94 Foster 0 120 scf/hr Y - 02 79-066 12/19/94 Foster 0 120 scf/hr Y - 13 81-112 12/19/94 Foster 0 0 scf/hr Y - 33 91-030 12/19/94' Foster 0 200 scf/hr The above wells meet the criteria of a "no-flow" performance test and as such are considered incapable of flowing, unassisted, to the surface. Under the authority of Conservation Order 341, Rule 5, these wells are not required to have fail-safe automatic SSSVs. However, the LPSs and SSVs must be maintained in good condition and, if for any reason, the wells again become capable of unassisted flow of hydrocarbons, the SSSVs must be reinstalled and maintained in good working condition. Sincerely, Blair E. Won~F~ell PI Supervisor cc: Bobby Foster hew/bp 15wl $ 4 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation ~)'mmission TO: THRU: FROM' David John~~, Chairmeh~ DATE: BlairWondzell, ~ FILE NO: P. I. Supervisor Bobby Fost SUBJECT: Petroleum Inspector December 19,20 & 21, 1994 1191LSBD.doc No Flow Test BPX - PBU - R,Y & U Pads Prudhoe Bay Field Monday, December 19, 1994: I met with Jeff Eckstein, BPX P.E., and continued No Flow test. The wells were tested using the American 425 gas measurement meter used previously in the field. There were 5 wells to be tested, but only 2 were tested. Wells R-9, 21, and~would not bleed down, so only wells R-8 and 17 were tested. The crew began bleeding the wells on R pad down in the afternoon of 12-18-94. The bleed down of the Y pad wells began in the afternoon of 12-19-94. The bleed down on the X pad wells began on the after noon of 12-20-94. The gas meter was tied into tubing at the swab cap on each well and a reading was taken approximately every hour for 3 hours with the following results: WELL R - 08 Casing pressure - 240 psig Tubing pressQre -0 psig Water Cut -65.2% Test # 1 - 6 sd/hr. Test # 2 - 5 sd/hr. Test # 3 - 0 sd/hr WELL R-17 Casing pressure -435 psig Tubing pressure - 0 psig Water Cut - 75.9% Test # 1 - 120 scf/hr. Test # 2 - 90 scf/hr. Test # 3 - 90 scf/hr. WELL Y-02 Casing pressure - 290 psig Tubing pressure -0 psig Water Cut - 66.9% Test # 1 - 120 scf/hr. Test # 2 - 120 sd/hr. Test # 3- 120 scf/hr. WELL Y - 13 at -~ ~' z. Casing pressure - 200 psig Test # 1 - 40 sd/hr. Test # 2 - 0 sd/hr. Page 2/2 Tubing pressure -0 psig Water Cut - 71.0% Test # 3 - 0 scf/hr. · . WELLY-33 ~t-o3~ Casing Pressure - 200 psig Tubing pressure -0 psig Water Cut - 64.2 % Test # 1- 550 scf/hr. Test # 2 - 210 sd/hr. Test #.3 - 200 scf/hr. WELL U-1 lA ',) ~' -,~ Casing pressure - 520 psig Tubing pressure, 0 psig Water Cut - 97.4% Test # 1 - 150 sd/hr. Test # 2 - 135 sd/hr. Test # 3- 135 scf/hr. WELL U-12 ~'~-- ~a z Casing presssure - 520 psig Tubing pressure - 0 psig Water Cut - 69.6% Test # 1 - 540 sd/hr. Test # 2 - 190 sd/hr. Test # 3 - 180 scl/hr. WELL U-13 --z ¢-~_0 ¢ Casing pressure - 250 psig Tubing pressure - 0 psig Water Cut - 60.0% Test # 1 - 120 scf/hr. Test # 2 - 180 sd/hr. Test # 3 - 120 scf/hr. All of the above listed wells met the requirements set forth by the AOGCC concerning wells with a NO FLOW status. -+¢~.y ~,,~¢/e /tc~ ~,.,.,',~ E¢,-¢,,~ ;~/~ ~ Summary_.: I witnessed the acceptible NO FLOW test on the above listed BPX- PBU wells. -, Attachment: NONE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well , OIL [] GAS [] SUSI=ENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BPExpl°rati°nn IGIiV4L 3. Address U ~ \ 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21420-01 4. Location of well at surface 9. Unit or Lease Name 69' NSL, 1685' WEL, SEC. 18, T11N, R13E tU3C,~~ Prudhoe Bay Unit At Top Producing Interval1I, ~1~1.1~ 10. Well Number t~~~ U-11A(32-20-11-13) N/A 11. Field and Pool At Total Depth :~ Prudhoe Bay Field/Prudhoe Bay Pool 4261' NSL, 2269' WEL, SEC. 20, T11N, R13E 5. Elevation in feet (indicate KB, DF, etc.) J6. Lease Designation and Serial No. KBE = 76.51' I ADL 28283 12'. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. o~ Aband. 115. Water Depth, if offshore J16. No. of Completions 7/5/93 7/10/93 7/16/93I N/A feet MSL I Zero 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey ~20. Depth where SSSV set J2.1. Thickness of Permafrost 10384' MD/8859' TVD 8538' MD/7457' TVD YES [] NO []! N/A feet MD ! 1900' (Approx.) 22. Type Electric or Other Logs Run MWD 23. CASING, LINER AND CEMENTING RECOI:~ SE'I'rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ... 20"X 30" Insulated conductor Surface 110' 36" 8 cu yds Concrete 13-3/8" 72# L-80 Surface 2835' 17-1/2" 4648 cu ft CS II 9-5/8" 4 7# L-80 Surface 8700' 12-1/4" 230 cu ft Class "G" 24. Perforations open to Production (.~M~D+? ~D-of'?op and Bottom and 25. TUBING RECORD interval, size and number) " j ~ ~._..~?__ No perfo,.rations ~j." SIZE DEPTH SET (MD) PACKER SET (MD) -- None None ~ ' '~"'"~ -" '" J' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10063'-10371' 253 CUft Class "G" 8538'-8850' 197 cuft Class "G" 27. j PRODUCTION TEST Date Firs~..Production IMethod of Operation (Flowing, gas lift, etc.) Not on production J N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED..~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. RECEIVED AU G - 6 199;5 Alaska 0il & Gas Cons, Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ' 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea Sag River 10222' 8659' Top Zone 4 10344' 8750' R£C£1V£D ALI6 - 6 1993 Alaska Oil & Gas Cons. Commission Anchorage 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~-~~ Title SeniorDrillinoEn_oineer Date ~)/~/(~-~ - / / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP/AA! SHARED SERVICE DAILY OPERATIONS PAGE: I WELL: U-1 lA BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: APl: 50- PERMIT: APPROVAL: ACCEPT: 06/30/93 12:00 SPUD: 07/06/93 06:00 RELEASE: OPERATION: DRLG RIG: NABORS 18E WO/C RIG: NABORS 18E 06/29/93 (1) Move in -Rig up Lay derrick over @ 0330 HRS 06/30/93 Moving to U-Pad · o 07/01/93 R/U rig floor, r/u ds maint, pull BPV thru tree w/lubricator. N/U BOPE, displaced diesel, circ bdne. N/U BOPE & test. .. .. 07/02/93 pull 2-way ck valve, pull 4-1/2" tubing, chg top & btm rams to 5", set bop test plug, test hydril. RIH w/F_.Z drill BP. 07/03/93 set BP @ 9050' MD, test 9-5/8" csg w/3500 psi-ok. POH. Strap section mill -RIH & tag BP @ 9050', displace seawater to milling fluid; circ & cond. pull up to 8700' & began cutting window, will cut f/8700'-8750'. 07/O4/93 contd milling window, poh 11 stds. pump hi'lo vis sweeps, poh to 6743'-saw excessive drag again, pump hi-lo vis sweep, poh slowly, I/d bha p/u mule shoe & RIH. 07/05/93 wash f/8642'-8850', pump sweep, poh to 7500', pump 54 bbls cmt-pedormed hesitation squeeze to 2000 psi, stap & mu KO BHA, rih to 8150', wash f/8150'-8318'. 07/06/93 drig cmt f/8615'-8705', controlled ddg to ko from cement plug f/8705'-8760', KO plug f/8715'-8760', chg mud over to KCL mud system, hole packed off on btm, stuck for 10-15 mins. worked pipe & jarred up several times, pulled pipe free, resumed drlg. to 9100' 07/07/93 drid f/9100'-9437', short trip to 9-5/8" shoe, drlg ahead. 07/08/93 drig to 10157', pump hi-lo vis sweep, drop survey, dry job, poh, tstd BOPE, p/u logging tools. EC IVE ) Alaska. 0ii & Gas Cons. Anchorage 07/09/93 RIH w/teleco tools, break circ @ 9917', pull to 9-5/8" shoe, & attempt to unplug bit, poh, RIH & break circ 2 times, attempt to log w/teleco- packing off, wash & ream f/9950'-1 10157', logging tools not working, directional tools working ok, drlg w/bit #2. 07/10/93 drlg to 10292'-losing mud, circ & build vol. ddg to 10336'-losing 60 bbl p/hr, circ & build vol. spot pill, chg stab. sleeve & RIH, cut & slip drlg line 105', RIH slow & fill every 10 stds. 07/11/93 CBU @ shoe, rih to 10247', wash & ream to btm @ 10236', drlg to 10384' (lost all returns), fill @ annulus & pump LCM in dp, no rtns, pumping thru dp, hole getting sticky, spot pill, rih w/open ended bal. plug to suspend well. circ @ shoe - no mud lost. RIH to 10371', attempt to wash to TD. Lost 180 bbls to hole last 24 hrs. Pump 45 bbl Bal. plug f/10371'-9723', poh to 9-5/8" shoe. CBU, I/d 18 jts dp, circ & WOC. 07/12/93 RIH to 9774'-no cmt, POH to 905/8" shoe, woc, rih & tag cmt @ 10063', poh to shoe & circ, RIH & pumped 29 bb117# bal. plug f/8900' ClP, pull 15 stds, & circ, woc, rih to 8900'-no cmt. 07/13/93 Circ. @ 8900', spot hi-vis pill f/9300'-8800', pump 36 bb117# bal. plug f/8900',, poh to 7509' & woc, RIH - did not tag cmt until plug #1 @ 10058', circ, -packing off, work up to 9993' & slowly increase circ rate to 10 bpm & rig up to pump 44 bb115.7 bal. plug. 07/14/93 R/U BJ; test lines, pumP 13 bbls water, hole packing off @ 10058', poh to 9-5/8" shoe, attempted to circ dp, dp plugged. RIH w/cmt retainer, set @ 8650' (50' above top of window), w/dp still in retainer, broke down formation (Kingak) w/2500 psi surface & e established a rate of 6.5 bpm @ 2400 psi, unstung f/retainer, pump 25 bbls of class "G" cmt, stung into retainer, pumped 18 bbls cmt below retainer, unstung f/retainer. POH & I/d running tool. m/u mule shoe. clean floor, RIH to 7983', circ while woc, rib & tagged cmt @ 8632', circ & cond mud. 07/15/93 Circ & cond mud f/2nd plug above retainer w/DP @ 8632' (18' cmt above ret set @ 8650'), pump 10 bbls cmt, broke off circ. head, fluid level right @ dp collar and not flowing.POH 15 stds, est. toc @ 8496', or 154' above ret. circ down dp & woc, RIH w/dp & tagged actual toc @ 8538', circ, set 15-30k on toc, poh to 8518', tested plug/9-5/8" csg to 3000# for 10 mins-ok, POH displace well to diesel w/dp @ 2000' for freeze protection (145 bbls) contd, poh, I/d dp, r/u csg tongs, RIH w/1 jt cr tbg, 2 pups & tbg hgr, [/d csg tongs, installed 2-way ck valve into tbg hgr, n/d BOPE. 07/16/93 N/Y adaptor flange & tree, tested flange to 5000 psi for 15 mins-ok, tested tree to 5000 psi -ok, removed 2-way ck valve, cleaned up pits. Released rig @ 0900 hrs 7/15/93. RECEIVED AU G - 2 199 Alaska Oil & Gas Cons. Anchorage GREAT LAND DIRECTIONAL DRILLIlqG, Client .... : PRUDHOE BAY DRILLING Field ..... : PRUDHOE BAY U- PAD Well ...... : U-11A Section at: 134,40 Engineer..: DON LEJEUNE Units ..... : FEET INC. Computation...: Survey Date...: KB Elevation..: Reference. .... : AL0793D31/AFE~P0467 Magnetic Dcln.: 29.763 E 07/30/93 CU VATUR 77.71 ft MEAS ' INCLN DIRECTION DEPTH AN~LE AZIMUTH 2 0,00 0.00 102 0.12 160,31 202 0.27 161.31 302 0,25 146.31 402 0.85 91.90 7 502 2.90 74.60 7 602 4.52 76.19 7 702 5.88 81,19 7 802 7.58 83.60 7 902 8.82 79.60 7 1002 10.48 75.60 7 1102 11.42 80.30 7 1202 12.43 83.30 7 1302 13.42 85.00 7 1402 14.70 92.31 7 1502 16.12 91.70 7 1602 16.68 89.19 7 1702 17.25 88.19 7 1802 17.92 93.61 7 1902 18.72 94.31 *Station Types: 7/GYRO ~(GLDD (c) 93 [311,% ~1.49 ~:,~:1 Al4 2) RECORD OF SURVEY (Well assumed vertical to 2 MD) VERTICAL-DEPTHS SECTION BKB 'SUB-SEA DISTNCE 2,0 -75,7 0.0 102.0 2&.3 0.1 202.0 124.3 0.4 302.0 2243 0.8 402,0 324.3 '1.6 coo r c .oso FROM-WELL-/rEAD DISTNC¢. aZImUTH /100 501.9 424.2 3.4 601.7 524.0 6.8 701.3 '623 · 6 11.9 800.6 722.9 19.1 899.6 821.9 27.7 0.0N 0,0 E 0.1 S 0.0 E 0.4 S 0.1 E O.8 $ O.3 E 1.0 S 1.2 E 998.1 920 . 4 36.9 1096.3 1018.6 47.4 1194.2 1116.5 59.9 1291.6 1213.9 74.2 1388.6 1310.9 91.2 1485.0 1407.3 110.8 1581.0 1503.3 131.1 1676.6 1598.9 151.5 1772.0 1694 . 2 173.4 1866 . 9 1789 . 2 197,3 0.0 0.00 0.00- 0.1 160.31 0.12 0.4 160.84 0.15 0.9 157.45 0.07 1.6 130.56 0.73 0.4 $ 4.4 E 4,4 95.00 1.2 N 10.7 E 10.7 83.42 3,0 N 19.5 E 19.8 81.40 4.5 N 31.2 E 31.5 81.83 6.6 lq 45.3 E 45.7 81.71 10.2 N 61.6 E 14.2 N 80.2 E 17.1 lq 100.6 E 19.4 N 122.9 E 19.9 N 147.1 E 2.10 1.62 1.43 1.72 1.36 62.4 80 . 56 1.79 81.4 79.98 1.30 102.1 80.36 1.18 124.4 81.05 1.06 148.4 82.31 2,19 18.9 N 173.7 E 174.7 83.78 18.7 N 201.9 E 202.8 84.70 19.4 N 231.1 E 231.9 85.20 18.9 N 261.2 E 261.9 85.86 16.7 N 292.6 E 293.1 86.73 MIC OI:iLMED Date,, ~ .......... 1.43 0.90 0.64 1.77 0.83 ]] 0 m iD --I r- 3) z o m z -7- m m U-llA (P3) MEAS INCLN DIRECT ION DEPTH ANGLE AZ IMUTH 2002 19.92 92.40 2102 22,95 90.40 2202 26.40 90.61 2302 27.88 90.81 2402 30.12 90.20 7 2502 31.15 7 2602 30.38 7 2702 29.87 7 2802 29.25 7 2902 29.93 7 3002 30.55 7 3102 31.18 7 3202 32.27 7 3302 33.38 7 3402 34.85 7 3502 35.67 7 3602 36.10 7 3702 36.22 7 3802 36.10 7 3902 36.12 7 4002 35.77 7 4102 35.85 7 4202 35.55 7 4302 35.27 7 4402 35.20 7 4502 35.25 7 4602 35.35 7 4702 35.28 ^Station Types: RECORD OF SURVEY (Well assumed vertical to 2 MD) VERTICAL-DEPTHS BKB SUB-SEA 1961.3 1883.5 2054.3 1976.6 2145.2 2067.5 2234.2 2156.5 2321.6 2243.9 90.31 2407.7 2330.0 91.61 2493.6 2415.9 92.61 2580.1 2502.4 92.61 2667.1 2589.4 92.70 2754.0 2676.3 92.90 2840.4 2762.7 93.40 2926.3 2848.6 93.81 3011.3 2933.6 93.40 3095.4 3017.6 91.90 3178.1 3100.4 7/GYRO 91.70 91.70 91.70 92.00 92.00 92.20 92.40 92.81 93.40 94.20 94.70 95.00 95.50 SECTION DISTNCE 222.3 249.0 279.1 312.0 347.0 RELATIVE-COORDINATES FROM-WELL-HEAD 14.8 N 325.6 E 14.0 N 362.1 E 13.6 N 403.9 E 13.0 1~ 449.5 E 12.6 N' 498.0 E 383. 420. 457. 494. 531. 5 7 8 6 4. PaGe 2 07/30/93 569. 607. 647. 688. 730. CLOSURE DI STNCE AZ IMUTH 3259.8 3340.8 3421.6 3502.3 3583.1 3182.1 3263.1 3343.8 3424.6 3505.4' 772 . 815. 859. 902. 946. 326.0 362.4 ~04.1 449.7 438.1 3664.0 3745.1 3826.3 3907.8 3989.5 3586.3 3667.4 3748.6 3830.1 3911.8 989. 1033. 1076. 1120. 1163. 12 . 4 N 548 . 9 E 549.1 1t. 5 N 600.1 E 600.2 9.7 N 650.2 E 650.3 7.4 N 699.5 ,.E 699.5 5.1 N 748.8 E 748.8 4071.2 4152.8 4234.4 3993.5 4075.1 4156.7 1208. 1252. 1297. 2.7 N 799.1 E 799.1 0.1 S 850.4 E' 850.4 3.5 S 902.8 E 902.8 6.9 S 956.9 E 957.0 9.4 S 1013.0 E 1013.0 11.2 S 1070.7 ,E 1070.7 13.0 S 1129.2 E 1129.3 14.7 S 1188.2 E 1188.3 16.6 S 1247.2 E 1247.3 18.7 S 1306.1 E 1306.2 20.8 S 1364.8 E 1364,9 23.2 S 1'423.2 E 1423.4 25.8 S 1481.5 E 1481.7 29.D S 1539.4 E 1539.6 32.8 S 1596.9 E 1597.3 37.3 S 1654.4 E 1654.9 42.2 S 1712.0 E 1712.5 47.5 S 1769.6 E 1770,2 DL /lOO 87.40 1.36 87.79 3.12 88.07 3 .45 88.34 1.48 88.55 2.26: 88.71 1.03 88.90 1.02 89 15 0 72 89.61 0.68 89.81 0.63 90.01 0.68 90.22 1.11 90.41 1.13 90.53 1.69 90.60 90.66 90.71 90.76 90.82 90.88 90.93 91.00 ' 91.08 91.18 91.29 91.41 91.54 0.83 0.43 0.12 0.02 0.37 0.14 0.38 0.44 0.47 0.29 0.20 0.30 [(;LI,D {.r]93 UllA P3.49 9:41 U-11A (P3) S MEAS INCLN C DEPTH ANGLE 7 4802 3560 7 4902 35.60 7 5002 35.55 7 5102 35.75 7 5202 35.63 7 5302 36,02 7 5402 36,52 7 5502 36f43 7 5602 36.50 7 5702 36.42 7 5802 36.67 7 5902 36.58 7' 6002 36.30 7 6102 36.70 7 6202 36.37 7 6302 36.25 7 6402 36.02 7 6502 35.88 7 6602 35.37 7 6702 34.93 7 6802 34,38 7 6902 34.15 7 7002 33.50 7 7102 32.72 7 7202 31,75 7 7302 30.98 7 7402 30,18 7 7502 28,95 ~Station Types: DIRECTION AZ I MUTH 95,81 96,50 96,81 97.00 97.31 97,70 97.81 97.81 97,70 98.00 98.00 98.11 98.11 98.11 98.11 98.11 98.11 98,00 98.11 98.4O 98.50 98.81 99.31 99.40 99,81 1.00.20 100.70 101.81 7/GYRO RECORD OF SURVEY (Well assumed vertical to 2 MD) VERTICAL-DEPTHS SECTION BKB SUB-SEA DISTNCE 4315.9 4238,2 ' 1342 , 7 4397.2 4319.5 1388.5 4478 . 5 4400.8 1434 . 5 4559 . 8 4482 . 1 14 80 . 7 4641.0 4563.3 1527.2 RELATIVE-COORDINATES FROM-WELL-HEAD 53.2 S 59.4 S 66.2 S 73.2 S 80,4 S 1827.3 E 1885.2 E 1942.9 E 2000.8 E 2058,7 .E 4722.1 4644.4 1574.0 88,1 S 2116.7 E 4802.7 4725,0 1621.4 96.1 S 2175,3 E 4883,1 4805,4 1669.2 104.1 S 2234.2 E 4963.6 4885.9 1716.8 112,2 S 2293.1 E 5044.0 4966.3 1764.6 120.3 S 2352,0 E 5124.3 5046.6 1812.5 5204,6 5126,9 1860.6 5285.0 5207.3 1908,4 5365.4 5287,7 1956.4 5445.8 5368.1 ~ 2004.4 128.6 S 136.9 S 145.3 S 153,7 S 162,1 S 2411,0 E 2470,0 E 2528.,8 E' 2587,7 E 2646.7 E 5526,3 5448.6 2052,1 5607.1 5529.4 2099.6 5688.1 5610.4 2146.9 5769.3 5691,6 2193.8 5851,1 5773.4 2240.3 170.4 178,8 187.0 195.2 203.4 2705,3 E 2763.7 E 2821.8 E ' 2879.5 E 2936.4 E 5933.4 5855,7 2286.4 211.8 S 2992.7 E 6016,0 5938.3 2332,0 220.2 S 3048.3 E 6099.1 6021,4 2377,5 229,0 S 3103~3 E 6182,9 610.5,1 2422.2 237.9 ~ 3157.2 E 6267.4 6189.7 2466.0 246.8 S 3209,8 E 6352,8 6275.1 2508,9 255.8 S 3261,1 E 6438.9 6361,2 2551.1 265.0 S 3311.1 E 6525.9 6448.2 2592.4 274.7 S 3359.5 E Page 3 07/30/93 CLOSURE DISTNCE AZIMUTH 1828,1 91,67 1886.1 91.81 1944.1 91.95 2002,1 92.09 2060.3 92.24 2118.5 92.38 2177.5 92,53 2236.'7 92,67 2295.9 92.80 2355.1 92.93 2414.4 93.05 2473.8 93.17 2533,0 93.29 2592.3 93,40 2651.6 93.50 2710.6 93.61 2769,4 93,70 2828.0 93.79 2886.1 93.88 2943.5 93.96 3000,2 94,05 3056,3 94.13 3111,7 94,22 3166.2 94.31 3219.3 94.40 3271.1 94.49 3321,7 94.58 3370.7 94.67 DL /loo 0.37 0.40 0.19 0.23 0,22 0.45 0.50 0. O'9 0,10 0,20 0,2.5 0.11 0.28 0.40 0.33 0,12 0.23 0,15 0,51 0.47 0.55 0,29 0.71 0.78 D .99 0.80 0.84 1.35 ~] m -H F ]) Z m z u-") i--,i Z m m U-llA (P3) S MEA~ INCLI~ C DEPTH ANGLE 7 7602 28.17 7 7702 27.08 7 7802 26.40 7 7902 25.37 7 7992 24.13 7 8052 23.88 7 8102 24.67 7 8202 25.18 7 8302 25.25 7 8402 25.77 8502 26.63 8602 27.42 8700 28.30 8922 31.60 9018 34.50 911t 37.70 9205 41.00 9299 44.20 9394 46.40 9487 46.00 9581 46.60 9674 46.60 9769 48.30 9863 47.00 9957 45.40 ~ 10051 43.40 ~ 10245 41.60 ~[ 10384 41.60 · ~Station Types: RECORD OF SURVEY (Well assumed vertical to 2 DIRECTION VERTICAL-DEPTHS SECTION AZIMUTH BKB SUB-SEA DISTNCE 102.61 66i3.7 6536.0 2632.9 284.8 S 103.70 6702.3 6624.6 2672.5 295.3 S 104.61 6791.6 6713.9 2711.4 306.3 S 105.90 6881.6 6803.9 2749.5 317.8 S 101.50, 6963.3 6885.6 2781.9 326.7 S RELATIVE-COORDINATES FROM-WELL-HEAD 3406.2 E 3451.4 E 3495.0 E 3537.1 E 3573.7 E 94.70 7018.2- 6940 .~ 2801.5 92.20 7063.7 6986.0 2817.1 92.31 7154.4 7076.7 28~8.3 93.31 7244 . 9 7167.2 2880.2 94.90 7335.1 7257.4 2913.0 330.2 S 331.4 S 333.1 S 335.2 S 338.3 S 3597.8 E 3618.3 E 3660.4 E 3703.0 E 3745.9 E 97.70 7424 . 9 7347 . 2 2947.8 100 . 31 751~ . 0. 7436 . 2 2984.8 101 . 31 7600 . 6 7522 . 9 3023.0 12~. 00 7793 . 6 7715.9 3124.6 128.20 7874.0 7796.3 3176.4 343.1 S 350.2 S 358· 8 S ~01.8 S 432.7 S 3789.8 E 3834.7 E 3879.7 E 3979.8 E ~022.1 E 131.70 '7949.2 7871.5 3231 135.20 8021.9 7944.2 3290 135.90 8091.1 8013.3 3354 135.90 8157.9 8080.2 3421 137.30 8222.2 8144.5 3488 .0 467.9 S {064.0 E .6 509.0 S 4107.2 E .2 554.4 S 4151.7 E .7 602.9 S 4198.7 E .8 651.6 S 4244.9 E .7 700.9 S 4291.7 E .2 748.3 S 4339.8 E .0 793.8 S 4392.9 E .8 835.4 S 4448.6 E .3 877.6 S 4501.6 E .0 922.1 S {550.0 E .9 1016.9 S 4640.3 E .9 1086.7 S 4700.8 E 135.60 8287.2 8209,5 3556 133.50 8351 . 1 8273 . 4 3624 127.80 8415.4 8337.7 3694 125.70 8{78.7 8401.0 . 3762 131.40 8543.8 8466.1 3830 133.80 8610.9 8533 . 2 3896 139.10 8754.0 8676 . 3 4026 139.10 8858.0 8780 . 2 4118 3/~rWD 7/GYRO N/INTERPOLATED Page 4 07/30/93 CLOSURE DISTNCE AZIMUTH 3418.1 94.78 3464.0 94.89 3508.4 95.01 3551.3 95.13 3588.6 95.22 3612.9 95.24 3633.5 95.23 3675.5 95·20 3718.1 95.17 3761.2 95.16 3805·3 95.17 3850.6 95.22 3896.2 95.28 4000.1 95.77 4045.3 96.14 4090.9 96.57 4138.6 97.06 4188.6 97.61 4241·8 98.17 429~.6 98.73 4348.5 99.28 4403.9 99.78 4464.1 100.24 4526.3 100.64 4586.3 101,.03 46~2.5 101,46 4750.4 102·36 4824.7 103.02 /lOO 0.87 1·20 0.79 1 17 - 4:.63 2.59 o. 1 0 43 - 0.86 1.51 1.42 1.02 .5.28 3.85 4.09 4.23 3.44 2 .32 1.17 i.45 1.64 4.77 2.15 4.69 2.78 2.07 0.00 ~[.DO (C,~93 DllA BI..19 9:41 k%1 2~ Baker Hughes INTEQ Anchorage, Alaska Well Name Date Surveyed Client Survey Performed By : U-11A : : : : 7/12/93 : BP Exploration : Rodney St. Pierre MICROFILMED SEP - 9 199~ Alaska Oil & Gas Cons. Anchorage This survey is correct to the best of my knowledge and is supported by actual field data. .... COMPANY REPRESENTATIVE Client : Well Name : U-11A : : : No Interpolation Baker Hughes INTEQ Date 7/12/93 Filename : 1237 Plane of Vertical Section : 134.4° Latitude & Departure relate to : WELLSITE CENTER Vertical Section Originates at : WELLSITE CENTER Slot Coordinates : Lat 0.00Oft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+29.76°WELLSITE North Grid convergence : +0.0000° U-11A Prudhoe Bay +0 ° 0' 0'' (T) Client : Well Name : U-11A : : : No Interpolation Baker Hughes INTEQ MD C~L INC DIR TVD VS LAT ft ft deg deg ft ft ft 8700 0 28.0 101.3 7601 3024 -359 8922 222 31.6 124.0 7794 3125 -402 9018 96 34.5 128.2 7874 3177 -433 9111 93 37.7 131.7 7949 3231 -468 9205 94 41.0 135.2 8022 3291 -509 9299 94 44.2 135.9 8091 3354 -554 9394 95 46.4 135.9 8158 3422 -603 9487 93 46.0 137.3 8222 3489 -652 9581 94 46.6 135.6 8287 3557 -701 9674 93 46.6 133.5 8351 3624 -748 9769 95 48.3 127.8 8415 3694 -794 9863 94 47.0 125.7 8479 3763 -835 9957 94 45.4 131.4 8544 3830 -878 10051 94 43.4 133.8 8611 3896 -922 10147 96 41.1 135.9 8682 3961 -968 10245 98 41.6 139.1 8756 4025 -1015 Page 1 of 1 Date 7/12/93 Filename : 1237 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 3880 0.0 0.0 0.0 3980 5.3 1.6 10.2 4022 3.8 3.0 4.4 4064 4.1 3.4 3.8 4107 4.2 3.5 3.7 4152 3.4 3.4 0.7 4199 2.3 2.3 0.0 4245 1.2 -0.4 1.5 4292 1.5 0.6 -1.8 4340 1.6 0.0 -2.3 4393 4.8 1.8 -6.0 4449 2.2 -1.4 -2.2 4502 4.7 -1.7 6.1 4550 2.8 -2.1 2.6 4596 2.8 -2.4 2.2 4640 2.2 0.5 3.3 Origin of Bottom Hole Closure WELLSITE CENTRE Bottom Hole Closure 4750 ft 102.3° ~? STATE OF ALASKA ~~ OIL AND GAS CONSERVATION COMMISSlUh REPORT OF SUNDRY WELL OPERATIONS Stimulate . Plugging Alter casing 1. Operations performed: Operation shutdown Pull tubing Repair well 5. Type of Well: Development x Exploratory Stratigraphic Service 2. Name of Operator BP Exploration 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 69' NSL, 1685' WEL, SEC. 18, T11N, R13E At top of productive interval N/A At effective depth 5001' NSL, 2121' WEL, SEC. 20, T11N, R13E At total depth 4261' NSL, 2269' WEL, SEC. 20, T11N, R13E 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10384 8859 8538 7457 Perforate Other x Plugged back for redrill 6. Datum elevation (DF or KB) KBE = 76.51 7. Unit or Property name Prudhoe Bay Unit 8. Well number U- 11 A(32-20-11-13) 9. Permit number/approval number 93.81/93-188 10. APl number 50- 029-21420-01 11. Field/Pool Prudhoe Bay Field~Oil Pool feet feet feet feet Plugs (measured) Junk (measured) Cement plug 10063'-10371'-264 cuft Class "G" 8538'-8650'- 140 cu ft Class "G" Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 110' 2812' 8677' measured None Size 13-3/8" 9-5/8" Cemented Measured depth True vertical depth 8 cu yds concrete 133' 133' 4648 cu ft CS II 2835' 2696' 2364 cuft Class "G" 8700' 7600' true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary None RECEIVED d U L 0 199 ) Ali~ska Oil & Gas Cons. C0mm'tss~O~ ;Anchorage Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run x Daily Report of,,.~ell Operations 7z._ Oil x Gas Suspended 17.1 hereby ce~ t~tthe foregoin~ is true and~correct to the best of my knowledge. Signed ~,-~'~~.~~'~"~" Title Drilling Engineer Supervisor Form 10-404 Rev 06/15/88 ','~, 14, Service SUBMIT IN D~PLIC~TE BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: U-1 lA BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: APl: 50- PERMIT: APPROVAL: ACCEPT: 06/30/93 12:00 SPUD: 07/06/93 06:00 RELEASE: OPERATION: DRLG RIG: NABORS 18E WO/C RIG: NABORS 18E 06/29/93 (1) Move in -Rig up Lay derrick over @ 0330 HRS 06/30/93 Moving to U-Pad 07/01/93 R/U rig floor, r/u ds maint, pull BPV thru tree w/lubricator. N/U BOPE, displaced diesel, circ brine. N/U BOPE & test. 07/02/93 pull 2-way ck valve, pull 4-1/2" tubing, chg top & btm rams to 5", set bop test plug, test hydril. RIH w/EZ drill BP. 07/03/93 set BP @ 9050' MD, test 9-5/8" csg w/3500 psi-ok. POH. Strap section mill -RIH & tag BP @ 9050', displace seawater to milling fluid; circ & cond. pull up to 8700' & began cutting window, will cut f/8700'-8750'. 07/04/93 contd milling window, poh 11 stds. pump hi-lo vis sweeps, poh to 6743'-saw excessive drag again, pump hi-lo vis sweep, poh slowly, I/d bha p/u mule shoe & RIH. 07/05/93 wash f/8642'-8850', pump sweep, poh to 7500', pump 54 bbls cmt-performed hesitation squeeze to 2000 psi, stap & mu KO BHA, rih to 8150', wash f/8150'-8318'. 07/06/93 drlg cmt f/8615'-8705', controlled drlg to ko from cement plug f/8705'-8760', KO plug f/8715'-8760', chg mud over to KCL mud system, hole packed off on btm, stuck for 10-15 mins. worked pipe & jarred up several times, pulled pipe free, resumed drlg. to 9100' 07/07/93 drld F9100'-9437', short trip to 9-5/8" shoe, drlg ahead. 07/08/93 drlg to 10157', pump hi-lo vis sweep, drop survey, dry job, poh, tstd BOPE, p/u logging tools. RE( EIVED J U L 3 0 199; Alaska 0il & Gas Cons. Commissio~ Anchorage 07/09/93 RIH w/teleco tools, break circ @ 9917', pull to 9-5/8" shoe, & attempt to unplug bit, poh, RIH & break circ 2 times, attempt to log w/teleco- packing off, wash & ream f/9950'-1 10157', logging tools not working, directional tools working ok, drlg w/bit ~. 07/10/93 drlg to 10292'-losing mud, circ & build vol. drlg to 10336'-losing 60 bbl p/hr, circ & build vol. spot pill, chg stab. sleeve & RIH, cut & slip drlg line 105', RIH slow & fill every 10 stds. 07/11/93 CBU @ shoe, rih to 10247', wash & ream to btm @ 10236', drlg to 10384' (lost all returns), fill @ annulus & pump LCM in dp, no rtns, pumping thru dp, hole getting sticky, spot pill, rih w/open ended bal. plug to suspend well. circ @ shoe - no mud lost. RIH to 10371', attempt to wash to TD. Lost 180 bbls to hole last 24 hrs. Pump 45 bbl Bal. plug f/10371'-9723', poh to 9-5/8" shoe. CBU, I/d 18 jts dp, circ & WOC. 07/12/93 RIH to 9774'-no cmt, POH to 905/8" shoe, woc, rih & tag cmt @ 10063', poh to shoe & circ, RIH & pumped 29 bbl 17# bal. plug f/8900' CIP, pull 15 stds, & circ, woc, rih to 8900'-no cmt. 07/13/93 Circ. @ 8900', spot hi-vis pill f/9300'-8800', pump 36 bbl 17# bal. plug f/8900',, poh to 7509' & woc, RIH - did not tag cmt until plug #1 @ 10058', circ, -packing off, work up to 9993' & slowly increase circ rate to 10 bpm & rig up to pump 44 bbl 15.7 bal. plug. 07/14/93 R/U BJ; test lines, pump 13 bbls water, hole packing off @ 10058', poh to 9-5/8" shoe, attempted to circ dp, dp plugged. RIH w/cmt retainer, set @ 8650' (50' above top of window), w/dp still in retainer, broke down formation (Kingak) w/2500 psi surface & e established a rate of 6.5 bpm @ 2400 psi, unstung f/retainer, pump 25 bbls of class "G" cmt, stung into retainer, pumped 18 bbls cmt below retainer, unstung f/retainer. POH & I/d running tool. m/u mule shoe. clean floor, RIH to 7983', circ while woc, rih & tagged cmt @ 8632', circ & cond mud. 07/15/93 Circ & cond mud f/2nd plug above retainer w/DP @ 8632' (18' cmt above ret set @ 8650'), pump 10 bbls cmt, broke off circ. head, fluid level right @ dp collar and not flowing. POH 15 stds, est. toc @ 8496', or 154' above ret. circ down dp & woc, RIH w/dp & tagged actual toc @ 8538', circ, set 15-30k on toc, poh to 8518', tested plug ~9-5/8" csg to 3000# for 10 rains-ok, POH displace well to diesel w/dp @ 2000' for freeze protection (145 bbls) contd, poh, I/d dp, r/u csg tongs, RIH w/1 jt cr tbg, 2 pups & tbg hgr, I/d csg tongs, installed 2-way ck valve into tbg hgr, n/d BOPE. 07/16/93 N/Y adaptor flange & tree, tested flange to 5000 psi for 15 mins-ok, tested tree to 5000 psi -ok, removed 2-way ck valve, cleaned up pits. Released rig @ 0900 hrs 7/15/93. RECEIVED J U L 3 0 Alaska 0il & Gas Cons. Commission Anchorage MEMORANDUM S TA TE Or ALASKA a, s coss r os co t 4 ss o TO: David JOhnst .~,~''''~ Chairma~ DA TE: July 14 1993 FILE NO: CINJGNAB.DOC THRU: Blair Wondzell ~'~ P.I. Supervisor FROM: Lou Grimaldi ~'~.~ Petroleum Inspector PHONE NO.: 279-1433 SUBJECT: Wellbore plug @ casing shoe BPX well #U-1 lA Prudhoe Bay Field ~D# 93-81 WEDNESDAY JULY 14 1993 I verified the placement of the plug at the casing shoe in BPX well # U-1 lA in the Prudhoe Bay Field. Nabors rig #18-E was on the well and had expierienced some problems with thier first attempt at placing this plug. When I arrived the rig had already circulated out the old contaminated cement and laid a new batch in place over the retainer. The rig was standing by for cure time to tag the plug. We tripped in the hole and tagged the top of cement at 8538' with the retainer reportedly set at 8650'. The rig then set down 25,000 pounds on the plug, which appeared firm and did not move. the fluid was then changed out from 10.1 mud to 8.6 seawater and the casing and plug was then pressure tested to 3000 PSI for 15 minutes with no loss observed SUMMARY; I witnessed verification of the placement of a casing shoe plug in BPX well U-1 lA in the prudhoe bay field Attachment ' CINJGNAB.XLS Operator: Operator Rep.: Lease No.: Drive Pipe: Conductor: Intermediate: STATE OF ALASKA ALASKA OIL AND GAS CONSER VA TION COMMISSION Plug And Abandonment Report BPX CRAIG HURST Well No.: U-11A Sec. T-R Total Depth: 10,384 Date: 7/14/93 Well Name: U-1 lA PTD No.: 93-81 S 18, T 11N, R 13E, U Meridian: U MIAT Elevation: Mud Wt.: 10.1 ppg. CASING DATA: O.D." Set @: O.D." Set @: O.D." Set @: ft. With ft. Surface: ft. Prodctn: Penetration O.D." Set @: O.D." Set @: PLUGGING DATA: 1. Open Hole Plugs: 2. Open Hole Isolation Plugs: 3. Perforation Plugs: 4. Annulus Plugs: Retainer @ 8650, Top of cement at 8538 5. Casing Stub Plugs: 6. Surface Plug: Casing Removal: REMARKS: " Casing Cut @ Feet " Casing Cut @ Feet " Casing Cut @ Feet " Casing Cut @ Feet Tagged top of cement at 8538' 25000# set down. Pressure tested plug and casing to 3000 PSI "OK" Distribution: orig - Well File c - Operator c - DNR/DOG c - Database c - Rpt File c - Inspector Inspector (s): Louis R. Grimaldi FI-000 (Rev. 6/93) CINJGNAB.XLS 2& L , ........ ? .......... :. ...... / z ~7'- j r-ooo~z ~ouo 0 / i~, STATE OF ALASKA ' ~'"-~ ~,; "'~ OIL AND GAS CONSERVATION COMMI~ )N APPLICATION FOR SUNDRY APPROVALS Abandon Suspend X..~_ Operation Shutdown Re-enter suspended ~mel' ,aXt. ~1~. Alter casin-'-g ~ Repair well Plugging Time extension S' u Change approved program Pull tubing ,.. Variance . Perforate_ __ Other , 5. Type of Well: 6. Datum elevation (DF or KB) 1. Type of Request: 2. Name of Operator BP Exploration Development x Exploratory 3. Address Stratigraphic 7. P. O. Box 196612, Anchorage, Alaska 99519-6612 service 4. Location of well at surface 8. 69' NSL, 1685' WEL, SEC. 18, T11N, R13E At top of productive interval N/A At effective depth At total depth 4261' NSL, 2269' WEL, SEC. 20, T11N, R13E 10. 11. KBE= 76.51 feet Unit or Property name Prudhoe Bay Unit Well number U-11 A(32.20-11-13) Permit number 93-81 APl number 50- 029-21420-01 Field/Pool Prudhoe Bay Field/Oil Pool , ~ , 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor ' 110' Surface 2812' Intermediate 8677' Production Liner Perforation depth: measured None 10384 8859 Size 2O" X 3O" 13-3/8" 9-5/8" true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None feet feet feet feet Plugs (measured) Junk (measured) Cernent plug 10063'-10371'-264 cu ft Class "G" Cemented 8 cu yds concrete 4648 cuft CS II 2364 cu ft Class "G" ,, Measured depth 133' 2835' 8700' True vertical depth 133' 2696' 7600' RECEIVED d U L 1 3 1995 Alaska 0il & Gas Cons, Comm'tssiot~ ;Anchorage 13. Attachments Description summary of proposal ~ Detailed operations program BOP sketch 14. Estimated date for commencing operation 7/12/93 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas Suspended __ Service 17. i hereby/~rtify that the ~correct to the best of my knowledge. Signed ~ Title Drilling Engineer Supervisor ~ FOR COMMISSION USE ONLY Plug integrity ~ BOP Test __ Mechanical Integrity Test Conditions of approval: Notify Commission so representative may witness Location clearance Subsequent form required 10- ~o 7 Original Signed By Approved by order of the Commission David W. Johnston J Approval No_. ~:~ ..? Returnea Commissioner SUBMIY IN 'I'I~IPLICATE Form 10-403 Rev 06/15/88 A,-,Co Alaska, BP EXPLORATION To: AOGCC Commissioner Date: July 13, 1993 From: Ding Hsu Tel: 564-5061 Subject: Plugginq for Temporarily Suspension for U-11A Sidetrack well U-1 lA will be temporarily suspended due to severe loss circulation problem in the Shublik formation. Severe lost circulation and 25' of missing Shublik indicate that we crossed a fault at or near the top of the Ivishak. That being the case, it was not desirable having a Zone 4 frac'd producer so close to a fault. The rig (Nabors 18E) will move to drill new well U-14 and sidetrack U-04Ai, which will give us time to evaluate the new bottom hole location to redrill. The following is a proposed plugging program to meet the requirements of AOGCC regulation 20 AAC 25.105. In addition, we like to request for an exception to 20 AAC 25.105 (c) to waive the requirement of setting a surface plug for U-1 lA temporarily suspension.. Recommended Pluaaina and Suspension Proaram: (1) Contact AOGCC representative to discuss and witness the program for temporary suspending well U-1 lA. (2) RIH with 5" open-ended drilipipe to TD. Break circulation and condition the mud before going into open hole. (3) Circulate and condition mud at TD (10,384'MD) until hole stabilized. (4) Lay a 47 bbls of balance cement plug from TD (10,384'MD) to 500'MD above top of Sag River formation (9719'MD). Pump 50 bbls of water ahead of cement plug and appropriate water spacer behind to balance the cement plug. (5) POOH into the 9-5/8" shoe. Circulate at Iow flow rate and wait on cement for minimum 12 hours. RIH and tag the cement top with State Representative witnessing the process. POOH. (6) RIH with 9-5/8" cement retainer (Halliburton) on 5" drillpipe. CBU if needed to condition the hole. Set the cement retainer at 8650'MD (50' above the casing window). R E C E IV F. D J U L 1 199; Alaska 0il & Gas Cons. commissio[~ ;Anchorage July 13, 1993 Page 2 (7) (8) (9) (10) (11) (12) (13) (14) (15) (16) (17) (18) Function test cement retainer by un-stinging from and stinging into the retainer as per service hand recommendation. With drillpipe engaged with the retainer, inject mud down through drillpipe to establish a feasible injection rate (3-5 bpm) before start pumping cement. Pump 5 bbls of water as spacer, follow by 22 bbls of 15.8 ppg Class G cement slurry and 5 bbls of water spacer behind. Cement volume calculation is based on 200' of cement below and 100' of cement above the retainer. Displace cement with rig pump until squeezing 15 bbls cement below the retainer. Unsting from the retainer and displace the remaining 7 bbls of cement above the retainer. Pull sufficient distance above the cement plug. Circulate and condition the polymer mud for suspension. WOC while circulating for minimum of 9 hrs. RIH and tag the cement plug Wffh State Representative witnessing the process. POOH and lay down drillpip~ to 2000'MD, circulate and displace with 150 bbls of diesel for freeze protection. Continue to POOH and lay down drillpipe. Run 1 joint of 4-1/2" tubing below tubing hanger and land the same. N/D BOPE and N/U tree and test the same to 5000 psi. Complete end of well reports and hand over forms. Complete rig move notification form to move to well U-14. CC: Kirk White Bill Kirton Russ Strickland RECEIVED d U L 1 Alaska 0il .& Gas Cons. C0mmissior~ Anchorage 'u'- IIA I · ,.. i' .. ,, , ... "2¢ [. Alaska Oil & Gas Cons. CommisSion .. Anchorage - 'TO ..... ~- iplOl,,l~l?. ~ ! / - Choke Manifold - Poor Boy Degasser · - Brand t Vacuum.-Type Degasser - Brand t Dual Tandem Shale Shaker - Pioneer Mud Cleaners - Pioneer MKI Centrifuge I0O ~Bk ".' I~0 88L.. HUD DISTRIGUTION O/TC / ... / ./ " TYF~ 1 - Rec'ording drilling fluid, pit 'level indicator with both visual and audio warning devices at driller's console ,. 1 - Trip Tank (75 BBL.) 1 - Drilling fluid flow sensor with readou~ at driller's console 11 - 5 Hp Agitatbrs NABORS 1 8 E 13 5/8" 5,000 psi Stack 1.5O 4.75 4.73 3.98 3.66 1 1.49 2.37 1 2.21 I O.55 GROUND LEVEL KR TO RF 11.41 HYDRIL PIPE RAM BLIND'.RAM" MUD CROSS PIPE RAM i EMUD CROSS I TBG SPOOL 15.66 17.93 22.96 RECEIVED J u L 1 ;~ 199;~ 26.45 Alaska 0il & Gas Cons. Commission Anchorage 28.25 , 3O.25 ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 June 11, 1993 Bill Kirton Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re .. Prudhoe Bay Unit U-11A BP Exploration (Alaska), Inc. Permit No. 93-81 Sur. Loc. 69'NSL, 1685'WEL, Sec. 18, TllN, R13E, UM Btmnhole Loc. 4059'NSL, 2020'WEL, Sec. 20, TllN, R13E, UM Dear Mr. Kirton: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum.field inspe6tor on the North Slope pager at 659-3607. Sincerely, Russell A. Doug~ Commissioner BX ORDE~ OF T~E CC~ISSIO~ dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS : ,IL AND GAS CONSERVATION C MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redriii •]l lb. Type of well. E xPloratoryr"l Stratigraphic Test I"1 Development Oil [] Re-Entry [] DeepenDI Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE ,, 76.21 feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraae. Alaska 99519-6612 ADL 28283 4. Location of well at surf-ace 7. Unit or property Name 11. Type Bond(-a 20 69' NSL, 1685' WEL, SEC. 18, T11N, R13E Prudhoe Bay Unit At top of productive interval 8. Well number Number 4254' NSL, 2219' WEL, SEC. 20, T11N, R 13E U- 1 lA (32-20-11-13) 2S 100302630-277 At total depth 9. Approximate spud date Amount 4059' NSL, 2020' WEL, SEC. 20, T11N, R13E 7/15/93 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MD andTVD) property line ADL 28284-2020' feet No close approach feet 2560 10840' MD/9182' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (eee :,o sc 2s.oas Kickoff depth ~7oo, feet Maximum hole angle44.~ o Maximum satiate 3330 pslg At total depth ('rVD) ~O0'/~0 pslg 18. Casing program Settin~ Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD M D TVD (include stage data) 8-1/2" '7" 29#-- L-80 NSCC 1069' 8550, 9919' 8-1/2" 7" 29# 13CR NSCC 921' 9919' 10840' 9182' 503 cu ft Class "G" · , I.. ~;, IL, I v MAY 4 19. To be completed for Redrill, Re-entry, and Deepen Operations. Alaska 0il & Gas Cons. C0mmissio~ Present well condition summary Total depth: measured 10490 feet Plugs (measured) Anchorage true vertical BKB9207 feet Effective depth: measured 10200 feet Junk (measured) fill@ 10200'MD (9/90) true vertical BKB 8946 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 110' 20"x30" 8 cu yd concrete 133' 133' Surface 2812' 13-3/8" 4648 cu ft CS II 2835' 2835' I nte rmediate 10002' 9-5/8" 2364 cuft Class "G" 10025' ' 8787' Production 630' 5" 264 cu # cass 'G' 9698'-10328' Liner 745' 7" 256 cu # cass 'G" 9745'-10490" 8536'-9207' Perforation depth: measured 10000'-10028', 10095'-10187' true vertical 8690'-8715; 8775'-8858' 20. Attachments · Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch I~1' Drilling program[] Drilling fluid program [] Time vs depth pict [] Refraction analysis [] Seabed report• 20 AAC 25.050 requirementsr"l 21. , hereby,~-~/-/~--~::;~;'~ce~fy-th'a~g is true and correct to the best of my knowledge _,c-',~--~//'~'j~ Signed Title Drilling Engineer Supervisor Date Commission Use Only Permit Number IAPI number JApproval dat0 ISee cover letter ~',.~-~'/ J50-o..~, ~- .~,/~.2. C) ~ I. I ~"~//"' ~ Ifor other requirements Conditions of approval Samples required [] Yes J~ No Mud Icg requir6~-- !-i Yes ~ No Hydrogen sulfide measures i-! Yes J~ No Directional survey requ~recl ,~ Yes [] No Required working pressure for BOPE 1-12M; 1-13M; ~5M; I-I10M; !-115M; Other: Approved by ~i~. :, :'iAL SIGN•0 BY by order of ,: ,:-- ~. A,. OOUGLASS Commissioner ~ne commission Date ~'""// · Form 10-401 Rev. 12-1-85 . Submit in triplicate '=~'.~ILLIN(~ PERMIT ApPL!¢ATI~ . U-11A SIDETRACK WELL: U-11 A PBU WOA APl NO.: 50-029-21420 (on the original U-11 well) LOCATION: Surface: 69' FSL, 1685' FEL, Sec. 18, T11N, R13E, UM Tie-in: 4990' FSL, 3086' FEL, Sec. 20, T11N, R13E, UM @ 8700' MD Target: 4254' FSL, 2219' FEL, Sec. 20, T11N, R13E, UM @ 8826' ss BHL: 4059' FSL, 2020' FEL, Sec. 20, T11N, R13E, UM @ 9106' ss EST. KBE: 75.74' AMSL ESTIMATED START: MID July, 1993 OPR. DAYS TO COMPLETE: 18days CONTRACTOR: NaborsRig18E DIRECTIONAL: Kickoff at -.. 8700' MD with a 4°/100' constant curvature build / turn from 28.03° to 44.81 o inclination and from S78.7°E to S45.6°E direction. Max angle is 44.81° atTD. No close approaches for this sidetrack well. WELLBORE: Item KOP TOP SAG RIVER TOP SHUBLIK TOP SADLEROCHIT (4/4B) TARGET ZONE 4A/X-RAY POWC TOP HOT ZONE 3 OOWC ZONE 2/2C TOTAL DEPTH LOGGING PROGRAM' TVD(BKB) MD(BKB) Mud Wt. 7601' 8700' 9.8-10.0 8742' 10219' 9.8-10.0 8768' 10256' 9.8-10.0 8836' 10352' 9.8-10.0 8902' 10445' 9.8-10.0 8931' 10486' 9.8-10.0 8985' 10562' 9.8-10.0 9029' 10624' 9.8-10.0 9029' 10624' 9.8-10.0 9076' 10690' 9.8-10.0 9095' 10717' 9.8-10.0 9182' 10840' 9.8-10.0 8-1/2" Open Hole: Case Hole: GR / DIL / CNL / BHCS by electric line (DLL if needed due to salinity) Cement bond Icg and possible Gyro if BHL in question after released rig. RECEIVED k4 AY 2 4 199;~ Alaska 0il & Gas Cons. CommiSsio~ Anchorage '~--~RILLING PERMIT APPLICATt,,.,~ U-11A SIDETRACK .MUD PROGRAM: The milling / drilling fluid program will consist of a 9.8- 10.0 ppg Biozan polymer / KCI water based mud in the 8-1/2" hole. DEPTH DENSITY PV YP INT 10MIN FL OIL SOLIDS MUD (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30rnin (%! ~%~ TYPE KOP' 9.8 10 10 5 7 8 0 5 Water to to to to to to to to to Base TD' 10.0 16 18 10 15 5 0 7 Mud MUD WEIGHT CALCULATIONS ! WELL CONTROL' Est. Pore Press. Sag River: Est. Pore Press. Sadlerochit: 3750 psi/8700' ss TVD. 3575 psi/8800' ss TVD. Mud Wt.: 8-1/2" Hole = 10 ppg. Overbalance Sag River: 774 psi. Overbalance Top Sadlerochit: 1001 psi Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling "worst case" situations as follows: Maximum possible bottom hole pressure is 4115 psi at 8740'TVDss based upon original reservoir pressure. Maximum possible surface pressure is 3400 psi based upon a gas column to surface from 8740' TVDss with no oil column. Fluids incidental to the drilling of a well will be removed by truck and disposed down CC-2A. LINER DETAILS: CASING DEPTH BURST COLLAPSE TENSILE 7" 29# 13CR NSCC 7" 29# L-80 NSCC ~ 10840'-9919' MD ~9919'-8550' MD CEMENT CALCULATIONS' 8160 psi 7020 psi 676 klbs 8160 psi 7020 psi 676 klbs RECEIVED 7" LINER: Measured Depth: Basis: 8550'MD (Hanger)- 10840'MD (Shoe) MAY 2 4 1993 Alaska Oil & Gas Cons. (;ommissiof~ Anchorage 60% open hole excess, 40' shoe joint, 150' liner lap and 150' excess above liner with DP. Total Cement Vol: 503 cuft or 419 sx of Class G blend @ 1.2 Cu ft/Sk ..TUBING DETAILS' 4-1/2" 12.6# 13CR-80 NSCT (Surface- 10069' MD) '.~RILLING PERMIT APPLIGATI~.,, U-11A SIDETRACK OBJECTIVE: The primary objective of the U-11 sidetrack is to return the well to Iow watercut, high oil rate production by drilling a new hole to a location in an upthrown block about 800' southeast of the original bottom hole location. This sidetrack wellbore will be drilling through majority of Kingak shale section and may cross a small fault (25'-50') in the lower Jurassic interval. Drilling may encounter loss circulation and/or hole stability problem in the Kingak interval. Well U-11 is currently producing at 470 BOPD at a 1500 GOR and 90% watercut. The current well is fault-cut in the Shublik and has suffered from high watercut production for much of its life. Post-sidetrack production rates are estimated at 1200 BOPD at 20% WC and 1000 GOR pre-frac, with a post frac rate of 3000 BOPD, 25% WC and 1000 GOR. The well will be completed with 4.5" 13Cr tubing and 7" 13er/L-80 liner. The well will be fracture stimulated, therefore, a good primary liner cement job and an anchor type of tubing packer are required for this well. SCOPE: The original wellbore will be plugged and abandoned prior to the sidetrack using coiled tubing, and the wellbore will be pre-cut using a chemical cutter. Pull the existing 4-1/2" 12.6# L-80 BTC tubing completion. Mill a section in the 9-5/8" casing and lay a cement plug below and across the section. Kick-off and drill a new 8- I/2" hole to TD of 150' MD below the prognosed top of HOT Run wireline conveyed open hole logs. Cement in a 7" 29# L-80/13Cr liner. Recomplete with 4-1/2" 13Cr tubing with approximately 5 gas lift mandrels. TIMING: This U-1 lA sidetrack is presently scheduled for Nabors Rig 18E upon completion of activity on U-7A sidetrack program in Mid July, 1993. The sidetrack should take approximately 18 days. R'ECEIVED MAY 2 4 1995 Alaska Oil & Gas Cons. Oommission Anchorage ~filLLING PERMIT APPLICATI~., .U-11A SIDETRACK SU,,MMARY, PROCEDURE; · o. , , , 5. 6. 7. 7a. 10. 11. 12. 13. 14. 15. 16. 17. 18, 19. 20. 21. 22. 23. 24. 25. Pre-rig work: Kill well. Lay cement plug across perforations to at least 100' MD above top perforation. Cut 4-1/2" tubing just above the packer SBR. Freeze protect and set a BPV. Test intermediate casing pack-off to 3500 psi. Move in drilling rig. Test 9-5/8" intermediate casing pack-off if not done during pre- rig work. Pull BPV. Circulate diesel freeze protection cap from well and recover for future use if feasible. Set a BPV and remove the production tree. Install BOP's and test to 5000 psi. Remove the BPV. Pull and lay down the existing 4-1/2" tubing. Run 9-5/8" casing corrosion Icg (Schlumberger USIT) only if intermediate casing integrity is suspect. Set a 9-5/8" bridge at 9050'MD (300' below the bottom of section window). Replace the 9-5/8" casing pack-off as needed. Spot a 18 ppg pill on bottom and cut a 50' section in the 9-5/8" casing from about 8700' to 8750' MD. Spot a balanced cement kick-off plug (165 cubic feet minimum) from 100' below the base of the section to 200' above the top of the section. Run in with an 8-1/2" steerable drilling assembly and dress the cement to 5' below the section top. Kickoff and directionally drill to align well with target. Follow with an 8-1/2" packed hole assembly and drill to the target at 150' MD below the HOT of- 10840'MD/9106q'VDss (see directional plan for more details). Run wireline conveyed open hole (GR/DIL/BHCS/CNL) logs. If a DLL is used in place of the DIL, a micro-resistivity Icg will be required. Run a 7" 29 # L-80 / 13Cr liner assembly to bottom in the 8-1/2" hole. Space the liner hanger and top isolation packer about 150' up inside the 9-5/8" casing. The top of 7" liner is at 8550'MD). Cement the liner in place with the total cement volume based upon 60 % open- hole enlargement plus the shoe volume, lap volume and 150' excess on top of the liner with drillpipe in the hole. Re-test the 9-5/8" casing pack-off and replace as needed. Clean out the liner to the landing collar and test to 3500 psi. Displace well to filtered and inhibited seawater. Run a 4-1/2" 13CR completion string and 7" packer. Space out, land tubing hanger and set packer. The packer should be set at about 10069'MD (150' above Sag River) with the tubing tail above any future objective. Test tubing to 4000 psi. Test tubing by casing annulus to 3500 psi. Set two-way check valve. Remove BOP's. Install and test the production tree to 5000 psi with diesel. Pull the two-way check valve. Shear RP valve in the upper GLM and freeze protect the well. Set a BPV. Release workover rig. Complete appropriate documentation and hand-over to Production for pedoration. Run cement bond Icg and possible Gyro if BHL in question after released the rig. Anticipated BHP: 7.8 ppg equiv. Drilling Fluid: 10 ppg Completion Fluid: 8.5 ppg. REEEIVED MAY 2 4 1993 Alaska Oil & Gas Cons. Commission An~hnr~n. ~RILLING PERMIT APPLICATI~.,,,' U-11A SIDETRACK NABOR.S RIG NO. 18E MUD $O,L,,ID$ CONTROL EQUIPMENT 2 - Continental Emsco Fl000 Mud Pumps 2 - Derrick FIoLine Cleaner Shale Shakem 1 - Derrick Mud Cleaner 1 - Swaco Centrifuge 1 - DRECOGas Buster 2 - Pioneer Sidewinder Mud Hopper 2 - 5 HP Flash Mixer Agitator 3 - Abcor 10 HP Agitators 1 - 50 bbl. Trip Tank 1 - Recording frilling fluid pit level indicator with both visual and audio warning devices at driller's console. 1 - Drilling fluid flow sensor with readout at driller's console R'ECEIVED MAY 2 4 199;~ ^Jaska Oil & Gas Cons. Commissio" Anchorage t ?" L,;,,e~, L- 8 o',, 27#. · R [ C E ! VflE~''~t'.-~.°''' ~ MAY 2 4 1993 ..... Alaska Oil & Gas Cons. 6omrnissio~ Anchorage DiPuECTIONAL WELL pku/~ for PRUDHOE BAY DRILLING ;ell ......... : U-11A (P3) · ~ield ........ : PRUDHOE BAY U-PAD io~,pu:acion..: MI~';I!~u24 CUP. VA~F.E /nits ........ : FEET Prepared ..... : Sectio~ at...: ~ elevation.: 05/0{/'93 134.40 75.74 ft LEGAL DESCF{IPT!ON ~urface ...... : 69 FSL ~o85 FEL S18 TiiN R13E L~I "i~-in ...... , 4990 FSL 3086 FEL S20 TiI?,i RJ..~P, T_~! 2ar~et ....... : 4254 FSL 2219 FEL S20 TiiN RI3E U/,[ 9HL .......... : 4059 FSL 2020 FEL S20 TI!I{ R!3E LTM, X ASP 50~'~ 4 Y 642217,00 ~10~.84 5960366.46 637086,00 5959646.00 637~88 48 =9594=~ 78 WELL PROFILE STATION :'~AS iNCLlq VERT-DEPTHS IDEk:TiPICA'£ZON DEP~q ~2$GLE BK~ TiE-iN SECT 8700 28.03 7601 7525 3024 8B00 29.99 7688 7612 206~ 8900 32.28 . 77~4 7698 3113 9000 34.86 7~£7 77~I 3166 9100 37.66 7935 7g62 !224 DIRECTIO1J D"' AZIMUTH FRO£~-WELLH~ I00 101.3~ !59 S 3550 i08.52 372 S 3927 E 4.0 !14.~5 391 S 3975 E 4.0 120.39 43.~ S 4024 E 4. 125.23 %48 S 4074 E 4.0 END O? CDq~.~JE SAG RIVER (Oi'~,/~'=~,~ ~ ) SHI/SLIK 9200 40.63 ~015 7939 9300 43.73 8089 S014 9334 44.81 S!13 S03g LO219 44.~I ~742 8666 10256 44.~i ~76E S~9'2 3287 3354 3377 4027 129.46 487 $ -!124 E 4.0 134 23 £31 $ ~."7~ ~-' .... ~ -- 4.0 !34.~0 548 S 4!9: E 4.0 134.40 984 $ 4637 E 0.0 134,40 1002 S 4655 E 0.0 TSAD z4/4B / T.~GET ZONE TOP HOT 20352 44.8~ ~$36 8760 10562 44 . Ei ~9S.5 ~909 _0o== ~ ~.~ .- 0953 4095 4160 4189 4287 134.40 i050 S 4704 E 0.0 134.40 1095 S 4750 E 0.0 134.40 1!16 S 4771 E 0.0 134.40 1153 S 4~69 ~ 0,0 134.40 '1184 c 4R4. A E 0.0 Z OI,TE 3 . ZONE_ 2/2C TD 10624 44.R! 9029 6953 10690 44.~I 9076 9000 10717 44.8! 9095 9019 i0840 44.8i 9182 9106 4287' 4333 4352 4439 134.40 1184 S &~4! E 0.C. 134.40 12!6 S 487& E 0.0 134,40 1230 $ 6887 E C.0 134.40 1290 S 4'250 E 0.C RECEIVED MAY 4 199; ,Alaska Oil & Gas Cons. Commissio~ Anchorage "PRUDHOP' Marker iOentif~ca~ion RD N/$ A] TIE-iN $7~0 359 S BI ENO OF CURVE 9334 S4& s £) TARGET 10445 log5 S BAY DRILLING E/w _~0 £ ~750 E 4¢50 E U-I:LA (P3) PLAN VIEW CLOSURE · 5115 feet at. Azimuth ~04 61 DECL]NAT!OH.' 20.1BO E SCALE ' 1 il'iCh = 200 feet DHAHN ' 0b/04/93 Great Land Directional Drilling 40.0.. 600 200 · 500 ......... ' t 3900 ~O00 1 EAST -> I · r.',~GFT P~q FT .q$. TII.S. I i .-J. -1 ! I MAY 2 4 19~ Alask1 Oil & Gas Cons. Anchorage I i 'J' 4800 ,~,OO 500[ ,3. ;ommissio~ l T:Z:TP:L F'. !.':-, PLAN VIEW CLOSUFIE ' 5115 leer at Aziau[i~ 104.61 DECLINATION.' 29.80 E SCALE'. ' i ~nch = 600 feet DRAt~N '05/04/93 PRUDHOE BAY DRILLING Marker I[ient~ f ica[ inn MD N/S E/VI A) fIE-IN 870t} 359 S 3880 E B) EftD OF CraVE 933,1 5,f8 ~" 4t9! E C) f.,',flOEl 10445 ]095. S 4750 E D) fO 10846 J290' S 4950 E 1<,3 i 300 I { got} 12OO 1[,00 1800 ;_' 1 O0 ?(10 300(I 3300 36OO 3qoD O Fl .: 4800 .510 r{ ! , ," '- .... ¢~RUDHOE ~-3AY DRILLING ~900 3730 A) I6-1N 87e9U60~. '~ ~* ~ ~,~ :~ ~:~'~'~ ~'~ ~:~ ~: ~"~ VE~T I CAL SECT I "' Sect:on at: ~3~.a0 TV0 Sco]e · 1 inch = 300 feet Dep Sc~]~.' J i~l~ = 300 75oo]-- -- ~ Dnawn ' 05/04/93 / ~850~ A 7~so .............. 7x~ ~ -.~ ............. ~ ........... ~oo .... : x i~% ~250' ' : ' ~ r~ ' '~ ..... ~.~ I ' ~ I i 855~ ....... ~ .............. , , . i ( :' ......... -~,~-~----~ -'- ~-~--I -' ' N-~ ...... i T - ~r -I ' ' -%'- .... ..~. ..... , -~.~ · -X~ ~,~[ - ~ ~ ..... . ..... 's°-! .... ~ ' ' ~ ',, ~ o~ I ,, ~O0 ' ,. t ~50 " : , RECEIVED ~ I . ' ' Y 2 4 19~ ........... ~oo , M A / i · Alask~ Oil & Gas Cons Commission · ~ ....... ~ ; ~ I Anchorage ~ , . 2850 330( 3i50 ~_~"" 2456 3600 3750 3900 ~050 4200 4350 ~500 Section Oepar, ture ...... VIEW [?£ J ] ].i n 9 Marker Identification VIE-IN It'n'.~ OF CURVE ID ~200 2400- 3000- 3500[ PRUDHOE BAY DRILLING MD BKB SECTN 8700 760~ 3094 28.03 933~ 81!3 3377 108,10 g:E2 4439 ~,1.8~ U-1 ~tA (P3) VERTICAL SECTION 1 I I ' I · 95C0 ' VIEW Section a[: ~3~1.40 TVD Scale.: I inch : :1200 feet Dep Sca]e.: 1 inch - ~200 feet Drawn ..... : 05/0q/93 Land Directional Drilling '~ ~ [ ... 5-100 ""-'-~ ', , I i 6000 I : J ,~ ,, R CEIVE J ' 78oo .--- ,. ........ ~'0o-. Anch;.ag;--'r 8 600 1200 ~?~00 2~I00 3000 3600 4200 4890 5400 600( -~, $=.~ ion Departure __ i 6500 7800 i~ABORS 18 E 13 518" 5,000 psi Stack 1.5O 4.75 4.73 't 3.98 3.66 I 1.4@ 2.37 2.21 RKB 1 HYDRIL PIPE RAM BLIND RAM 1 MUD CROSS PIPE RAM _ , KB TO RF · RIG FI (')OR 11.41 ..,./ 15.66 17.93 I ! I MUD ~ CROSS ,,.I ...... .'1 TBG SPOOL ~ I GROUND LEVEL 22.96 ,f 26.45 RECEIVED MAy ~ 4 199~ Alaska Oil & 6as Cons. Cornm'tss'~o~ 'Anchoraqe 28.25 3O.25 PILL Vo~. H~ ~/sr4c'-nod - Choke Manifold - Poor Boy Degasser · - Brand t Vacuum.-Type Degasser - Brand t Dual Tandem Shale Shaker - Pioneer Mud Cleaners - Pioneer MKI Centrifuge · 1 - Recording drilling fluid, pit 'level indicator with both visual and audio warning devices at driller's console ' · 1 - Trip Tank (75 BBL.) 1 - Drilling fluid flow sensor with readout at driller's console 11 - 5 Hp Agitators U-11ACNT~LS State: Well: Field: State Permit It A/a~,~ Engineer. ~/u'Jxlsr u-'~ '~ A Wo& Sheet C-~ V~ ~,~m~ Prudho® B Date: 5¢28/~¢3 93-81 C~lng T~,e c~s~ Casing Length Hole Diamete -Ii Cement- Sacks Cement- Y'~4d Cement- Cul:ic tt Cemer~ - Cubic ti Cemenl - Sacks - Cemen~ - ¥~cl Cement- ~ It Cement - Cubic It Cerrent - Sacks Cement- Y'~4d Cement- ~It Cement- Cubic tt Cement - Cubic It/' Cement- Fill Facto Condu~or Su~Iace i.iner -I 0.000 0.000 7.000 · F 0.000 0.000 1,990.000 0.000 0.000 8.500 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 §03.OO0 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 113 0.000 113 0.000 113 0.000 113 0.000 0.000 0.000 503.000 ItDIV/O! :I:I:DIWO!1.993 ~ T~ ~ermediate 11~ermed~e 11 ~ Size -i 0.000 0.000 Ce.~aDep~h . ~ o. ooo o. ooo Hob Diamete~ -h 0.000 0.000 Cent- Sacks 0.00 0.00 Cemen~ - Yield 0.00 0.00 Cement- Cubic It 0.00 0.00 Cement- Cubic tt 0.00 0.00 Cement- Sack~ 0.00 0.00 Cement-Yield 0.00 0.00 Cement - Cubic It 0.00 0.00 Cement- Cubic ft 0.00 0.00 Cement-Sacks 0.00 0.00 Cement- Yield 0.00 0.00 Cement- Cubic It 0.00 0.00 Cemeni - Cubic tt 0.00 0.00 Cement- Cubic ft/' 0.00 0.00 Cement-Interval fi 11DIV/O! 11DIV/O! Top o~ Cement- F~ItOIV/O! IiOIV/O! I~oduction 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11DIV/OI ItOIVIO! )asured Depth ;";" CHECK LIST FOR NEW WELL PERMITS :";" ITEM APPROVE DATE Fee Loc '[2 thru 8] - (3) Adm ~.~.13] [10 & 13] [14 thru 22] C5) BOPE -~.~.~'-::~: -~,~ [23 thru 28] . 2. 3. 4. 5. 6. 7. 8. Se 10. 11. 12. 13. 14. 15. 16. 17. 18. !.9. 20. 21. 22. 23. 24. 25. 26. 27. 28. 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 ........................................ ! s adm i n i st rat i ve approval needed .................................... Is lease nuWoer appropriate .......................................... ~ . Does well 'have a unique name & n~nber ................................ Is conductor st r lng 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 wel 1 bore separat ion proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of ~Z~__~---"'~. ~ 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 ....................................... Lease & Well ~zg/_ NO REMARKS 4 w/z) , (]6) Other [29 thru 31] (7) Contact [32] geology' cng i neer i rig' DWJ MTM~ RAD RP~ BEW dDH~_~! rev 12/92 3o/6.011 29. 30. 31. 32. 33. FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone nunber of contact to supply weekly progress data ...... / / Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Additional remarks' UM ~tERIDTAhJ: SM ,,, TYPE: Exp/Dev Redrill Inj Rev o