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187-036
MICROFILMED 9/28/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE PLUGGI~ & LocATION CLEArAnCE Rw, PORT State of Alaska Memcrandum To File: .ALASKA OIL & GAS CONSERVATION COHMISSION -. APi No. Well Name Operator . Location Note casing ~, wt, depth, cmt vol, & procedure.. Review the well file, and' comment on plugging, well head st. atus, and location clearance - p~ovide~oc.2:lear, code. Well head cut off: Marker ~ost or plate: Location Clearance: Conclusions: ~~ - Code Date o o ~ Plugged Back for Sidetrack STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION CuMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG '"~. Status of w~'iJ .................................................. Classification of Service Well .................. [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 87-36 96-118 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21716 4. Location of well at surface 9. Unit or Lease Name 1215' SNL, 802' WEL, SEC. 09, T11N, R13E !~ Prudhoe Bay Unit At top of productive interval 10. Well Number At total depth 11. Field 'and Pool ................ 438' SNL, 18' EWL, SEC. 14, T11N, R13E Prudhoe Bay Field/Prudhoe Bay i5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 78.43 AMSLI ADL 028284 12. Date Spudded 113. Date T.D. Reached 114. Date Comp., Susp., or Aband.115. Water depth, if offshore 116. No. of Completions 04/21/87 I 05/06/87 07/16/96 I N/A MSLI Zero 1'7. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)I19. Directional Surveyl20. Depth where SSSV set~l. Thicknes,s of Permafrost 12250 9131 FTI 12140 9058 FTI []Yes []No I . N/A MD| ..1900 (Approx.) 22. Type Electric or Other Logs Run DIL / SFL, BHCS, CNL / GR-poro ........................ 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" Conductor Surface 110' 8 cu yds Concrete 13-3/8" 72# L-80 / S-95 Surface 2978' 17-1/2" 4127 cu ft Permafrost 9-5/8" ' ................ 2,'7# L-S0 ' "surface 1'.i'150','1'2;'1"/4','~'' ~)'l"~'i'"'cu ff class 'G', 230 cu ft Class 'G' 7" 26# IJ4S 10887' 12250' 8-1/2" 438 cu ft Class 'G' '~;4. Perforations ope~ to Pr~'~'uction (MD+TVD ~f Top and Bottom 25. TUBING RECORD and interval, size and number) SIZE DEPTH SET (MD) PACKER S"-'r'('~'~)'i ................. None N/A 12051' MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11325' EZSV for P&A, 40 Bbls 'G', sqzd at 3500 psi 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etC.) ............................ Not On Production I N/A ... O~'0f'Test Hours Tested PRODUCTION FOR OIL-BBL GA~'rvl(~F ......................... ~VATE~'R-BBL CHOKE SIZE I GAS-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 AUG 3 0 1996 Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Mark,_ ~ 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Sag River 11166' 8393' Shublik A 11211' 8425' Zone 4B 11308' 8491' (Top of Ivishak/Sadlerochit) 3i' List of Attachments ....................... Summary of Daily Drilling Reports 32. I hereby certify that th~o~goin~ true a~r~l correct to the best of my knowledge Signed ~J~~~' Dan Stoltz Title Senior Drilling Engineer Date /'-~ - '~ -" - d...~ Prepared By Name/Number: Terrie Hu ~64-4628 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX ! ARCO WellName: J-20A RigName: Nabors 2ES AFE: 4P0831 Accept Date: 07/09/96 Spud Date: 07/1 8/96 Release Date: 08/1 1/96 Jul 10 1996 (1) Rig moved 100 %. Tested High pressure lines. Held safety meeting. Installed Casing spool. Rigged up Lubricator. Held safety meeting. Circulated at 10755 ft. Circulated at 12122 ft. Circulated at 10775 ft. Held safety meeting. Circulated at 10755 ft. Monitor well pressures. Circulated at 10755 ft. Jul 11 1996 (2) Circulated at 10755 ft. Installed Hanger plug. Removed Xmas tree. Rigged up BOP stack. Tested Well control. Removed Hanger plug. Retrieved Tubing hanger. Circulated at 10755 ft. Laid down 35 ft of Tubing. Installed BOP test plug assembly. Tested All functions. Jul 12 1996 (3) Laid down 10775 ft of Tubing. Tested Kelly cocks. Worked on BOP - Top ram. Tested Top ram. Made up BHA no. 1. Singled in drill pipe to 7000 ft. Jul 13 1996 (4) Singled in drill pipe to 10710 ft. Fished at 10740 ft. Pulled out of hole to 350 ft. Pulled BHA. Laid down fish. Made up BHA no. 2. R.I.H. to 10810 ft. Fished at 10810 ft. Circulated at 10810 ft. Pulled out of hole to 350 ft. Pulled BHA. Made up BHA no. 3. R.I.H. to 2500 ft. Jul 14 1996 (5) R.I.H. to 7000ft. Serviced Block line. R.I.H. to 10792 ft. Fished at 10810 ft. Pulled out of hole to 350 ft. Pulled BHA. Held safety meeting. Made up BHA no. 4. R.I.H. to 10810 ft. Milled Mechanical packer at 10810 ft. Jul 15 1996 (6) Milled Mechanical packer at 10819 ft. Circulated at 10819 ft. Pulled out of hole to 823 ft. Pulled BHA. Made up BHA no. 5. R.I.H. to 3500 ft. Serviced Block line. R.I.H. to 10799 ft. Fished at 10819 ft. Circulated at 10819 ft. Pulled out of hole to 3000 ft. Operations Summary for: ~ jA Jul 16 1996 (7) Pulled out of hole to 850 ft. Pulled BHA. Laid down fish. Conduct braided cable operations - 3/16 size cable. Conduct braided cable operations - 3/16 size cable. Made up BHA no. 5. Pulled BHA. Removed Seal assembly. Installed Seal assembly. Tested Casing. Worked on BOP - Blind ram. Tested Casing. Made up BHA no. 6. R.I.H. to 5000 ft. Jul 17 1996 (8) R.I.H. to 11325 ft. Mixed and pumped slurry - 40 bbl. Displaced slurry - 180 bbl. Circulated at 11324 ft. Serviced Block line. Pulled out of hole to 0 ft. Made up BHA no. 7. R.I.H. to 11265 ft. Set tool face. Jul 18 1996 (9 ) Milled Casing at 11304 ft. Circulated at 11300 ft. Pulled out of hole to 850 ft. Pulled BHA. Tested All functions. Made up BHA no. 8. R.I.H. to 3500 ft. Jul 19 1996 (10) R.I.H. to 8000 ft. Serviced Block line. R.I.H. to 11325 ft. Reamed to 11339 ft. Drilled to 11800 ft. Jul 20 1996 (11) Drilled to 11821 ft. Circulated at 11821 ft. Pulled out of hole to 250 ft. Pulled BHA. Made up BHA no. 9. Fished at 18 ft. Made up BHA no. 9. R.I.H. to 11821 ft. Drilled to 11904 ft. Jul 21 1996 (12) Drilled to 12440 ft. Jul 22 1996 (13) Drilled to 12565 ft. Circulated at 12565 ft. Pulled out of hole to 11326 ft. R.I.H. to 12565 ft. Drilled to 12628 ft. Pulled out of hole to 500 ft. Pulled BHA. Jul 23 1996 (14) Pulled BHA. Made up BHA no. 10. R.I.H. to 4000 ft. Serviced Block line. R.I.H. to 12628 ft. Drilled to 12809 ft. Pulled out of hole to 1000 ft. Jul 24 1996 (15) Pulled out of hole to 200 ft. Pulled BHA. Made up BHA no. 11 . R.I.H. to 12809 ft. Drilled to 13022 ft. Circulated at 13022 ft. Pulled out of hole to 2000 ft. Page 2 JUM OB ~6 OB:~6PM BP E×PLOR~TIOM P.~ ---~ STATE OF ALASKA ALASK ALAND GAS CONSERVATION CON .... {SSION APPLICATION FOR SUNDRY APPROVAL C~ Abandlon [] Suspend 'C~' ~[Ul;iging [] Time Extension [] 1. Type of Request: [] Alter C~ing [] Repair Well [] Pull Tubing [] Vadanoe C~ Other [] Chang~ .App~¥.e_d Pro,Item [] Operation Shutdown r-1 Re-Enter Suspended Well [] S~imulate Plug Back for Sidetrack 2. Name of Operator ! 15. Type of well: 6. Datum Elevation (DF or KBi '" BP Exploration (Alaska) I~c. I [] Development KBE = 78.43 AMSL 3. Address i ... [] Exploratory 7. Unit or Property Name P.O. Box 196612, Anoho;age, Alaska 99519-6612 [] Stratigraphlc Prudhoe Bay Unit [] Service 4. Location of well at surfac 1215' SNL, 802' WEL, At top of productive intm 6' ~NL, 521' WEL, At effective depth 389' SNL, 5~' NWL, SE At total depth 438' SNL, 18' NWL, ~E ~EC. 09, T11N, RI3E vel 15, T11N, R13E 15, T11N, R13E C. 14, T11N, R13E 12. Present well condition Total depth: mess[ 'ed true vel tioal Effective depth: measuFed true vertical ORIGINAL ummary 122.5o feel Plug~ (measured) 9131 feet 12140 feet Junk (measured) 9058 feet Well Number J-20 9. Permit Number 87-36 10. APl Number 50-029-21716 11. Field end Pool Prudhoe Bay Field / Prudhoe Bay Pool fill ~t 12122' MD (02/90) Casing Structural Conductor Surface Intermediate Product[on Liner Perforation depth: me; cured true ~erttcel Tubing (size, grade, an~! measured depth) Length Size 110' 20" 8 cu yda 2942' 13.3/8" 4127 ou ft 111 liS' 9-8/8" 2:371 cuft 1363' 7" 438 cuff Cemented MD TVD 146' 146' 2978' 2748' 11152' 8384' 10887' - 12250' 8199' - 9131' 12025'- 12044', 12069'-12122' subsea 8901'- 8967' 4-1/2", L-80, TD$ to 12,041~ with4-1/2"tailpipe to 12,055' Packers and $88V (tyF 13. Attachments [] Desori 'i6. If propoaat was verbally Name of approver Contact Engineer Narne/J and measured depth) 3lion summary of proposal ~en~ihg operation une 4, 1996 approved Date approved ~urnber: Tim Burns, 564.4315 9.$/8" TIW retrievable packer at 10,815'; 7" TIW permanent packer at 4-1/2" $$SV at 2108' [] Detailed operations program [] BOP sketch 15. Status of well olassiiio~n$ as: [] Oil C] Gas [] Suspended Service Prepared ~y Name/Number Terrie Hubble, 564-4628 [17. I here-by~tii~ that th/e'~)r~)going/js.~tru~ e~yorr~t to the best of my knowledge Signed ................................ r' g"di o. of ~proval: Notify Commission so representative ~' ~ne~ PluS'integrity ~ BOP Test ~ Location clearance I MeChanical Integrity Test __ Approved by order of the Clmmission Form 10-403 Rev. 06/lS/88 t Approved Copy [ Subsequent form required 10._._~ Re.turned Original Signed By _ . ~,/'Y/'~L~,. David W. Johnston UOT..miss. one,, u.,. '~ ~,./~/~C~ I R E 1' llc '{te ~ JUN 0 3 199G Oil & Gas Cons. Commission Anchorage , , . o In SUM OB '~6 03:~?PM BP E×PLOR~TIOM P.3 WELLHEAD: MoE\'OY BF. ELEV = 42.23' ACTUATOR: OTiS P&A 8rv ~ective The objective of the P&A s to effemively aqu~ and isolate the existing pedoration; from 12,o20' to 12,122' After setting an EZSV at ~11,500' MD inside the 7" liner, placement of ~0 bbls of cement below the ~V (21.5 to lowermost ped) should include a ~8.5 bbl squeeze into the pedoratlon~, leaving 21.5 bbls of cement below The EZSV will be located approximately 520' above the uppermost pedomtion. Critical We!l ~~ L 4-~/~", ~.8~, L-80, T~, Tu~ing 7", ~, L-Sg, BTO Li~t I.D. = 3.958" Cep,clIU- 0.0152 bblm I.D.- 6,276' Capacity = 0.0383 bblflt 8S~V Landing Nipple: J 2,108' MD PBTD (7"): 12,140' MD (Retainer) XN-Nipple (3.725" I.D.); 12,050' MD Perforations: 12,020'-12,1~2' MD End of Tubing (WLEG); 12,055' MD P~dTOC: To be P&A'd with rig Max documented hole angle Is 4g~. Angle at the proposed KOP in 7" liner (~11,220' MD) Pre-Ria ~rocedure 1. NotJ~ an AOQCC pmsentative prior to ~mmencing P&A ~eratione. ~, RU sliokline unit a~d pull bottom gas lift valve at ~10,779' MD. / 3, .RU and ,verse ci~pulate the wellbore through the open gas lift mandrel with seawater until returns are clear the well is dead, Emeze prote~l well with diesel to 2,o~'. ~bp~l~n_t~ first full ~oint abo~ the ~W la~~ ~d_~5~emioal cut to D,mote fi~ gperafi~ th~ drilling rig. / 5. Time permitting, RU ~d test the 9-5/8" pack off to 3,800 psi and se~loe Io¢k d~n etude. Notify Representative Immediately of any pressure test or wellhead aondition problems. 6. Bleed any pressure from the tubing, inner and outer annuli to zero 7. Install a BPV and t~st same to 1,000 psi. Remo~ the well house ~d flowlineg. Prepare for the arrival of rig. If necesaa~, I~vel the pad and dig out the cellar. Ri~ .procedure J , MIRU Nabora 28-E Pull 4,1/2" tubing. :1:11,500' MD. Dc reverse out excess TIH and retrieve g-5/8" TIW packei and 4.1/2" tubing down to lower cut. Set an EZSV at · vnsqueeze +30 bbls cement below EZSV (21.5 bbls cement to lowermost perf), PU end e,eat above EZSV. PU tools and mill 11,365' MD (SSD KIck off (__.11,220' horizontal leg is 1, J II Completion operations entail 4-1/2, L-SO solid, cemented, perforated liner. with a permanent I~acker set above 60° inclination. / section in 7" casing from ~11,215'-11,265' MD. Set sidetrack kick-off plug from 1 1,01S'- ecommended practices). MD) and direotionally drill a 6" hole to 13,328' MD (g0° final incllnntion), Estimated total 00' MD in Zone 2 along a planned final azimuth of 359% 4,1/2", L-80 tubing will be run B/gl · IP, EVISED ., 5/3~/g6 Proposed Pre-Rig Status ... III al .... I II .... III _ ][[ , Bp Exploration _ ._ ..,. RECEIVED JUN 0 3 1996 Alaska 011 & 13as Cons. C0mm$si0n Anchorage ~ P.4 SUM 03 ~ 03:17PM BP E×PLOR~TI©M ~.~.- ~,,. - 2.0_~d_P.& A - CAMEROIj KB. ELBV 78,45' WELLHEAD: ~.~/VOY BF, ELEV - 42,23' ACTUAl'OR= i ~oc- ~ ~..o, .~.~, [~~ I L-aO, N,')OO -. , I KOP: SOft 49° 9-s/m, 47#a, , ) ~,~ L. eo, at'RS I 11152 I i . Depth @ +11,240' M~i ~(OTIS ~) (3,813" m.D,) i Proposed To~ of Tubing REF; LO'=: ,,?HOS 5-5-87 .,. ~ ~1~ .sPF J~ ._ I~ER~AL 0P~_ ~ '~ (HBBP)(3.875" I,D.) l-~" I --~" 4 ,~,,=o-,~,o~ sozD ~ ~ ~.5 bbls oement squeezed ' . to pe~or~tion~ ~ EZ-DRILL CMT. RETAINER !12140.~ ..... PBTD ~q ' ~_UDH '~~NIT DATE R , BY COMMENTS II II II 6/2~g0 L~M RWO COMPLETION 8/18/91 ' ~ REVISED ~O1 50'~716 5/~0/96 T~B " Proposed Pre-Rig status ' I ' ' ~~N--',, 11= ~,,, ~ ' ' BP Exploration (Alaska) ~ o~CFI~ ED JUN 0 S 1996 Alaska 0il & Gas Cons. commission Anchorage STATE OF ALASKA it~':~'''~ ?'-'"l-r')lL AND GAS CONSERVATION COMMff'~'';~''-, APPLICA Ii .,JN FOR SUNDRY Al'l-. ,OVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance x Perforate __ Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development X Exploratory __ Stratigraphic Service RECEIVEO 4. Location of well at surface 1215'SNL, 802' WEL, SEC. 09, T1 IN, R13E, UPM FEB 2 2 1995 ntaska Oil & Gas Cons. Commission Anchora. At top of productive interval 6' SNL, 521' WEL, SEC. 15, T11N, R13E, UPM At effective depth 389' SNL, 55' EWL, SEC. 15, T11N, R13E, UMI At total depth 438'SNL, 18'EWL, SEC. 14, T11N, R13E, UPM 6. Datum elevation (DF or KB) KBE = 78.43 AMS/_ 7. Unit or Property name Prudhoe Bay Unit 8. Well number J-20 (41-15-11-13) PBU 9. Permit number 87-36 10. APl number 50- 029-21716 11. Field/Pool Prudhoe Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural -- Conductor 110 Surface 2942 Intermediate 11116 Production -- Liner 1363 Perforation depth: 12250 feet BKB 9131 feet 12140 feet BKB 9058 feet Size 20 13 3/8 9 5/8 7 measured 12025'- 12044~ 12069'- 12122' Plugs (measured) Junk (measured) Cemented 8 c.y. 4127c. f. 2371 c.f. fill at 12122'MD (02/90) Measured depth True verticaldepth BKB 146 146 2978 2748 11152 8384 438 c.~ 1088~12250 8199-9131 true vertical subsea 8901'-8967 Tubing (size, grade, and measured depth) 5 1/2" L-80 surface-2521'; 4 1/2" L-80 2521'-10841' with 4 1/2" tailpipe to 10949' Packers and SSSV (type and measured depth) 9 5/8" TlWpacker at 10841~ 5 1/2" SSSV at 2177' 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation 16. If proposal was verbally approved Oil X Gas ~ Name of approver ~ Date approved Service 17. I here/~~_ th_.a~~oin~ true. and correct to the best of my knowledge. Signet[/ /~)L~-~j Title Supervisor Gravity Drainage f~a ~' FOR COMMISSION USE ONLY Conditions o pproval' Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Mechanical Integrity Test __ Approved by order of the Commission 15. Status of well classification as: Suspended~ Location clearance Subsequent form required 10-~ ORIGINAL SIGNED 8¥ RUSSELL A. DOUGLASS Date"~/~/7 ~ I Approval No. c:~-.-_O Approved Copy Returned G.l. 5- Commissioner Date .~' /' Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Reason for Requesting Variance on Well J-20 Well J-20 is part of gravity drainage area of the Prudhoe Bay Field. For the last several years the GOR has been rising with decreasing oil rate. Long term plans for this well include sidetracking it to a more favorable location. Because of its sidetrack candidate status, an MIT was performed on 12/7/94. The IA failed the pressure test, and subsequent logs have determined that the source of the leak to be the 9-5/8" production packer. The options for this well are to sidetrack immediately or repair the packer leak. Choices for repairing the leak include a cement down squeeze on the packer or a RWO. The variance is needed to flow J-20 until the well is .~ sidetracked or the packer leak repaired. ~o,,~,~ c~~~ ,-,,t,~ ~f t- ~0 LARRY GRANT' Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 16 February 1995 RE: Transmittal of Data Sent by: ANCH.EXPRESS Dear Sir/Madam, Enclosed, please find the data as described below: WELL 90- z-l ~O~O B-02 (32-11-14) DESCRIPTION PLS/STP FINAL BL+RF PFC/PERF FINAL BL+RF CN/GR FINAL BL+RF CN/GR FINAL BL+RF ECC No. Run # 1 4298.03 Run # 1 4544.02 Run # 1 5803.09 Run # 1 5931.07 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please sign and retu~ ~ , .~, ~-- · ~ ~ D~t~ Cente~ Pet.,. or,.~. :~:.~i,.,~..-: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 19 October 1994 RE: Transmittal of Data Sent by: U.S. MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL Y-33 (32-28-11-13) DESCRIPTION 1 PLS FINAL BL 1 PLS FINAL RF SEPIA 1 PLS FINAL BL 1 PL/GASLIFT FINAL BL 1 PLS FINAL RF SEPIA 1 PL/GASLIFT RF SEPIA 1 PL/GASENTRY FINAL BL 1 PL/GASENTRY RF SEPIA 1 PL/GASENTRY FINAL BL 1 PL/GASENTRY RF SEPIA Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 4298.02 4844.03 5609.01 5617.09 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson or "/ STATE OF ALASKA ALAS~,A OIL AND GAS CONSERVATION COl~,v, lSSlL~,,~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Pull tubing x Stimulate Plugging Perforate Alter casing Repair well Other 2. Name of Operator BP Exploration 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development X Exploratory Stratigraphic Service 4. Location of well at surface 1215' SNL, 802' WEL, SEC. 09, T11N, R13E, UPM At top of productive interval 6' SNL, 521' WEL, SEC. 15, T11N, R13E, UPM At effective depth 379' SNL, 55'EWL, SEC. 15, T11N, R13E, UPM At total depth 438°SNL, 18°EWL, SEC. 14, T11N, R13E, UPM 6. Datum elevation (DF or KB) KBE = 78.43 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number J-20 (41-15-11-13) 9. Permit number/approval number 87-36/90-443 10. APl number 50- 029-21716 11. Field/Pool Prudhoe Bay Field/Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12250 feet Plugs (measured) 9131 feet BKB 12122 feet Junk (measured) 9044 feet BKB cement @ 12140'MD (06-90) Casing Structural .Conductor ' Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth BKB 20 8 cu yds 146 146 13-3/8 4127 cu fl 2978 2748 9-5/8 2371 cu fl 11152 8384 110 2942 11116 1363 7 measured 12020'-12044', 12059'-12122' true vertical 8897'-8967' Tubing (size, grade, and measured depth) 4-1/2"L-80 to 12055' 438 cu ft NOV 8 1990 _Al. asK ~0!i & Gas Cons. C0mmtss[0t~ '.Anchorage Packers and SSSV (type and measured depth) 9-5/8" TlW packer at 10816',7"Packer@ 12041', 4-1/2"SSSV@ 2108' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Averaae Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 4 hr test 1180 Subsequent to operation 4 hr test 4731 7040 0 0 12115 207 0 Tubing Pressure 1733 297 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations x 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. (~' Signed~ ~ ~,~/' Title Completion En~ineerin~ Supervisor Form 10-40~4 Rev 06/15~8~' Date//~-~ SUBMIT IN DUPLICATE~ Attachment I Well J-20 Workover Procedure Accepted rig at 1700 hours on 6/13/90. Pulled 5-1/2" x 4-1/2" tubing. Replaced 9-5/8" packoff. Milled and recovered 9-5/8" packer. Fished and recovered 1160' of coiled tubing. Cleaned out to 12150'. Tested 9- 5/8" liner lap to 3000 psi. Pumped 15 bbls acid to perfs. Cement squeezed perfs with 41 bbls Class G cement. Cleaned out to 12140' BKB. Tested squeeze to 1000 psi. Perforated 12,102' - 12,122', 12,082' - 12,102, 12,020'- 12,044' and 12,069'- 12,082'. Ran 4-1/2" completion string. Set packer, tested tubing to 3000 psi. Tested annulus to 2500 psi, ok. Released rig at 0400 hours on 6/28/90. 14.5 Days. RECEIVED NOV i~ 8 1990 Alaska 0il & {~as Cons. CommiSs'tott Anchorage BP EXPLORATION DAILY WORKOVER REPORT: PRUDHOE As of 0600 Hrs. Wednesday, June 13, 1990 WELL: J-20 (41-15-11-13) BAY UNIT RIG: DOYON #16 Day: 0 Expense AFE Number: Expense AFE Amount = 145010 Current Field Cost = Estimated Final Cost = Current Operation' Move rig to J-20. Summary of Last 24 Hours' Move rig to J-20. NOV 2 8 1990 AlasNa Oil.& Gas Cons. Commission Anchorage Reviewed By: ~ BP EXPLORATION DAILY WORKOVER REPORT: As of 0600 Hrs. Thursday, June 14, 1990 WELL: J-20 (41-15-11-13) PRUDHOE BAY UNIT RIG: DOYON #16 Day: 1 Expense AFE Number: Expense AFE Amount = 145010 Current Field Cost = Estimated Final Cost = Current Operation: Pulling 5-1/2" x 4-1/2" tubing. Summary of Last 24 Hours' Accepted rig at 1700 hours on 6/13/90. MIRU. Circulated diesel from well. Set two-way check. ND tree and adapter flange. NU BOP's. Reviewed By' ~.~. BP EXPLORATION DAILY WORKOVER REPORT: As of 0600 Hrs. Friday, June 15, 1990 WELL: J-20 (41-15-11-13) PRUDHOE BAY UNIT RIG: DOYON #16 Day: 2 Expense AFE Number: Expense AFE Amount = 145010 Current Field Cost = Estimated Final Cost = Current Operation: RIH with overshot. Summary of Last 24 Hours: Pulled 5-1/2" x 4-1/2" tubing. Pulled and replaced 9-5/8" packoff. Tested new packoff to 5000 psi. Reviewed By: ~:.¼. BP EXPLORATION DAILY WORKOVER REPORT: As of 0600 Hrs. Monday, June 18, 1990 WELL: J-20 (41-15-11-13) PRUDHOE BAY UNIT RIG: DOYON #16 Day: 5 Expense AFE Number: Expense AFE Amount = 145O10 Current Field Cost = Estimated Final Cost = Current Operation: POH with 3-1/2" driilpipe and overshot. Summary of Last 24 Hours: Recovered slick stick. RIH with packer mill. Milled and recovered packer. RIH with overshot and recovered wireline tools. RIH with overshot and wash down over fish at 10,890'. No fish recovered. RIH with new grapple and overshot. Recovered 1160' of coiled tubing. RIH with overshot and attempted to work over fish at 12,042'. Reviewed By: '¢'.'~-. BP EXPLORATION DAILY WORKOVER REPORT: As of 0600 Hrs. Tuesday, June 19, 1990 WELL: J-20 (41-15-11-13) PRUDHOE BAY UNIT RIG: DOYON #16 Day: 6 Expense AFE Number: Expense AFE Amount = 145010 Current Field Cost = Estimated Final Cost = Current Operation' Wash and mill over coil tubing fish at 12115'. Summary of Last 24 Hours: Change out fishing tools. P/U washover shoe. Tag top of fish at 12042'. Wash over fish to 12102'. Not able to wash down. Breakdown washover shoe. Recovered balled up coil tubing inside shoe. M/U new shoe and fishing tools. Reviewed By: ~k~... BP EXPLORATION DAILY WORKOVER REPORT: PRUDHOE As of 0600 Hrs. Wednesday, June 20, 1990 WELL: J-20 (41-15-11-13) BAY UNIT RIG: DOYON #16 Day: 7 Expense AFE Number: Expense AFE Amount = 145010 Current Field Cost = Estimated Final Cost = Current Operation: RIH with mill. Summary of Last 24 Hours: L/D 10' coiled tubing fish. L/D wash pipe and shoe. Pick up mill and boot baskets. Mill on fish to 12,134'. L/D mill. P/U new mill. Reviewed By: BP EXPLORATION DAILY WORKOVER REPORT: As of 0600 Hrs. Thursday, June 21, 1990 WELL: .J-20 (41-15-11-13) PRUDHOE BAY UNIT RIG: DOYON #16 Day: 8 Expense AFE Number: Expense AFE Amount = 145010 Current Field Cost = Estimated Final Cost = Current Operation' RIH with drillpipe and BHA. Summary of Last 24 Hours: RIH and milled on fish to 12,150'. Changed BHA. Reviewed By: ~:.~,. BP EXPLORATION DAILY WORKOVER REPORT: As of 0600 Hrs. Friday, June 22, 1990 WELL: J-20 (41-15-11-13) PRUDHOE BAY UNIT RIG: DOYON #16 Day: 9 Expense AFE Number: Expense AFE Amount = 145010 Current Field Cost = Estimated Final Cost = Current Operation: POH. Summary of Last 24 Hours: RIHwith mill. Mill 12,141'-12,148'. Stuck at 11:30. Jarring, attempting to free pipe. R/U wireline and Dialog. Perform backoff. R/D wireline. Reviewed By: BP EXPLORATION DAILY WORKOVER REPORT: As of 0600 Hrs. Monday, June 25, 1990 WELL: J-20 (41-15-11-13) PRUDHOE BAY UNIT RIG: DOYON #16 Day: 12 Expense AFE Number: Expense AFE Amount = 145010 Current Field Cost = Estimated Final Cost = Current Operation: POH. Summary of Last 72 Hours: L/D BHA. Sub and boot baskets. P/U RTTS. Test 9-5/8" liner lap to 3000 psi, ok. RIH to 12,037'. Circulate 12 bbls acid. Pump 15 bbls acid to perfs. L/D RTTS. P/U retainer and plug catcher. Tag retainer at 12134'. Pump 41 bbls cement. Squeeze 9 bbls into perfs at 2500 psi. L/D Halliburton head and plug catcher~ P/U 6" bit, jars and 15 collars. Tag cement at 11,122'. Drill cement4..1,122' to 11,959'. Drill to 12,038'. Test top perfs, ok. Ddll to 12140'. Test bottom perfs, ok. P/U 8-1/2" bit and 9-5/8" casing scraper. Reviewed By: BP EXPLORATION DAILY WORKOVER REPORT: As of 0600 Hrs. Tuesday, June 26, 1990 WELL: J-20 (41-15-11-13) PRUDHOE BAY UNIT RIG: DOYON #16 Day: 13 Expense AFE Number: Expense AFE Amount = 145010 Current Field Cost = Estimated Final Cost = Current Operation: POH with wireline guns. Summary of Last 24 Hours' RIH with 6" bit and 7" scraper. RIH with wireline guns and perforated intervals 12,102'- 12,122' and 12,082'- 12,102'. Reviewed By: ..~ ~''~ BP EXPLORATION DAILY WORKOVER REPORT: PRUDHOE As of 0600 Hrs. Wednesday, June 27, 1990 WELL: J-20 (41-15-11-13) BAY UNIT RIG: DOYON #16 Day: 1 4 Expense AFE Number: Expense AFE Amount = 145010 Current Field Cost = Estimated Final Cost = Current Operation: RIH with 4-1/2" tubing. Summary of Last 24 Hours: Perforate intervals 12,020'- 12,044' and 12,069'- 12,082'. 8.5" and 5.95" gauge rings. RIH with Reviewed By: BP EXPLORATION DAILY WORKOVER REPORT: As of 0600 Hrs. Thursday, June 28, 1990 WELL: J-20 (41-15-11-13) PRUDHOE BAY UNIT RIG: DOYON #16 Day: 15 Expense AFE Number: Expense AFE Amount = 145O 10 Current Field Cost = Estimated Final Cost = Current Operation' Moving rig to J-15. Summary of Last 24 Hours: RIH with completion string. Tie-in packers with GR log. Spaced out and landed tubing. ND BOP's and NU tree. Dropped ball and pressured up to 3000 psi to set packers. Tested 4-1/2" x 9-5/8" annulus to 2500 psi, ok. Sheared RP valve and freeze protected well with 140 bbls of diesel. Secured tree and wellhead. Released rig at 0400 hrs on 6/28/90. Reviewed By: ~,9,. /"-~ ~'~' STATE OF ALASKA ~-"~ I AI~....A OIL AND GAS CONSERVATION Ct. ,tiS,. REPORT OF SUNDRY WELL OPERATIONS Stimulate x Alter casing Plugging Repair well 5. Type of Well: Development X Exploratory Stratigraphic REC .lv u 1. Operations performed: Operation shutdown Pull tubing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1215' SNL, 802' WEL, SEC. 09, T11N, R13E, UPM At top of productive interval 6' SNL, 521' WEL, SEC. 15, T11N, R13E, UPM At effective depth 389' SNL, 55' EWL, SEC. 15, T11N, R13E, UMI At total depth 438'SNL, 18'EWL, SEC. 14, T11N, R13E, UPM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Perforate Other NOV - 12250feet Plugs (measured) BKB 9131feet 12140feet Junk (measured) BKB 9058feet 6. Datum elevation (DF or KB) KBE,, 78.43 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number J-20 (41-15-11-13) PBU 9. Permit number/approval number 87-36 / 90-613 10. APl number 50- 029-21716 11. Field/Pool Prudhoe Oil Pool fill at 12122'MD (02/90) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 110 20 8 c.y. 2942 13 3/8 4127 c.f. 11116 9 5/8 2371 c.f. measured 1363 7 438 c.f. 12025'- 12044', 12069'- 12122' Measured depth True vertical depth BKB 146 146 2978 2748 11152 8384 1088~12250 8199-9131 true vertical subsea 8901' - 8967' Tubing (size, grade, and measured depth) 5 1/2" L-80 surface-2521 '; 4 1/2" L-80 2521'-10841' with 4 1/2" tailpipe to 10949' Packers and SSSV (type and measured depth) 95/8" TlW packer at 10841';5 1/2" SSSV at 2177' 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure 14. Reoresentative Daily Averaae Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 860 636 14 Subsequent to operation 0 0 0 15. Attachments I 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X I Oil X Gas Suspended 17. I hereby ~:~Jtify that the foregoing i~rue and correct to the best of my knowledge. Signed c~~{.~_,~ y] ~~/.~_ :orm 10-~,04 Rev 06/1~88 · ° ! 0 252 0 288 Service SUBMIT IN DUPLICATE WELL ,1-20 (14-11-13~ PBU STIMULATION OPERATION A HC1 perforation wash followed by a contingent scale inhibition treatment was done August 21, 1990 on the following perforated interval in Well J-20. 12020-12044' MD BKB 12069-12122' MD BKB Pressure tested lines with 4000 psi. Ran in hole with coiled tubing, opened well to bleed down wellhead pressure to 230 psi. Pumped acid stimulation down hole. Pumped 0.5 bpm filtered seawater down annulus. Tested well and put on production. mr: 10/27/90 TAL~ .~-~.,A STATE OF ALASKA '-'~, OIL AND GAS CONSERVATION C(' REPORT OF SUNDRY WELL.OPERATIONS 1. Operations performed: Operation shutdown Pull tubing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1215' SNI., 802' WEL, SEC. 09, T11N, R13E, UPM At top of productive interval 6' SNI., 521' WEI., SEC. 15, T11N, R13E, UPM At effective depth 389'SNL, 55'EWL, SEC. 15, T11N, R13E, UMI At total depth 438' SNL, 18'EWL, SEC. 14, T11N, R13E, UPM 12. Present well condition summary Total depth: measured true vertical BKB Stimulate x Plugging Alter casing . Repair well 5. Type of Well: Development X Exploratory Stratigraphic Service 12250feet Plugs (measured) 9131 feet Effective depth: measured true vertical 12140feet Junk (measured) BKB 9058feet Perforate Other x 6. Datum elevation (DF or KB) KBE = 78.43 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number J-20 (41-15-11-13) PBU 9. Permit number/approval number 87-36 / 90-713 10. APl number 50- 029.21716 11. Field/Pool Prudhoe Oil Pool fill at 12122'MD (02/90) Casing Structural Conductor Surface Intermediate Production . Liner Perforation depth: Length Size Cemented 110 20 8 c.y. 2942 13 3/8 4127 c.f. 11116 9 5/8 2371 c.f. measured 1363 7 438 c.f. 12025'- 12044', 12069'- 12122' Measured depth True vertical depth BKB 146 146 2978 2748 11152 8384 10887-12250 8199-9131 true vertical subsea 8901' - 8967' Tubing (size, grade, and measured depth) 5 1/2" L-80 surface-2521 '; 4 1/2" L-80 2521'-10841' with 4 1/2" tailpipe to 10949' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary See Intervals treated (measured) 14. 9 5/8"TlWpacker at10841'; 51/2"SSSV at 217R E I V E D Attachment Treatment description including volumes used and final pressure NOV - 6 1990 Alaska 011 & Gas Cons. Commission Anchomoe Reoresentative Daily Averaoe Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 860 636 14 0 Subsequent to operation 5880 2564 207 0 15. Attachments I 16. Status of well classification as: Copies of Logs and Surveys run ~ Daily Report of Well Operations X I Oil X Gas Suspended 17. I hereby (~ify that the fo.r~goi~l is true and correct to the best of my knowledge. Signed' J"~~L./"~ .LJ_¢ .,) (' ~ ~ Title sup~rvl, er (~ravlty brai. age Form 10-~04 Rev 06/1/5/88 ~ Service 252 297 Date SUBMIT IN DUPLICATE WELL .I-20 (41-1~-11-13~ PBU FRACTURE OPERATION _ Hydraulic fracture on well J-20 was performed on September 20, 1990. 1. Unable to set 4-1/2 or 7" treesaver in 4-1/2 tubing or 7x4-1/2" corssover. There were no records of tubing hanger corssover profile lenghs. wing valved leaked. Unable to seal w/grease, had to rebuild wing whcih shouwed damage on the age and seal ring in were rear plate. Injectivity test at 42 bpm/4500 psi was used to redesign, job. Pad engineer based new design on 40 pbm rate. Finished flushing. Tested well. Put on produciton. mr: 10/27/90 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard PO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date :10/03/90 T#:81724 FROM: Information Control Well Records LR2-1 RECEIVED SUBJECT: BP CASED HOLE FINALS OCT ! 0 1990 L~ 011 & ~a~ Cons. Comm~ior~ : u~p Enclosed is your copy of the material listed below. If you have any q lease contact BP Well Records at (907) 564-4445. D-22 G-07 J-15 J-20 K-07 K-11 M-12 M-14 W-03 X-12 Y-03 Prod-F 09/23/90 #1 9080-9370 Camco 5" Prod- F 09/19/90 #1 10980-11315 Camco 5" Prod-F 09/21/90 #1 5090-9940 Camco 5" Prod-F 09/21/90 #1 10000-11510 Camco 5" Leak Detection 09/16/90 #1 10000-12050 Camco 5" Prod-F 09/19/90 #1 9980-10175 Camco 5" CCL 09/22/90 #1 10420-10665 Camco 5" Inj 09/20/90 #1 9690-10175 Camco 5" -' lnj 09/22/90 #1 10160-10725 Camco 5" Prod-F/Jewery 09/18/90 #1 9050-9888 Camco 5" PITS 09/23/90 #1 9850-9400 Camco 5" lnj/PITS 09/24/90 #1 8900-9400 Camco 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES STATE OF ALASKA ...... . A, XA OIL AND GAS CONSERVATION COMMIL ~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon__ Suspend ~ Alter casing ~ Repair well Change approved program 2. Name of Operator 5. Type of Well: 6. BP Exploration (Alaska) Inc. Development x , Exploratory 3. Address Stratigraphic 7, P. O. Box 196612, Anchorage, Alaska 99519-6612 service ~ 4. Location of well at surface 8. 1215' SNL, 802' WEL, SEC. 09, T11N, R13E, UPM At top of productive interval 6' SNL, 521' WEL, SEC. 15, T11N, R13E, UPM At effective depth 389'SNL, 55'EWL, SEC. 15, T11N, R13E, UMI At total depth 438' SNL, 18'EWL, SEC. 14, T11N, R13E, UPM 12. Present well condition summary Total depth: Operation Shutdown ~ Plugging Time extension ~ Pull tubing ~ Variance ~erforate ~ Re-enter suspended well Stimulate Other X, Datum elevation (DF or KB) KBE- 78.43 AMSL feet Unit or Property name Prudhoe Bay Unit Well number Effective depth: J-20 (41-15-11-13) PBU Permit number 87-36 10. APl number 50- 029-21716 11. Field/Pool Prudhoe Oil Pool measured 12250 feet Plugs (measured) true vertical BKB 9131 feet measured 12140 feet Junk (measured) true vertical BKB 9058 feet fill at 12122'MD (02/90) Casing Length Size Cemented Measured depth True vertical depth Structural -- BKB Conductor 110 20 8 c.y. 146 146 Surface 2942 13 3/8 4127 c.f. 2978 2748 Intermediate 11116 9 5/8 2371 c.f. 11152 8384 Production -- Liner 1363 7 438 c.f. 10887-12250 8199-9131 Perforation depth: measured 12025'. 12044', 12069'- 12122' true vertical subsea 8901'- 8967' Tubing (size, grade, and measured depth) 5 1/2" L-80 surface-2521 '; 4 1/2" L-80 2521'-I0841' with 4 1/2" tailpipe to 10949' Packers and SSSV (type and measured depth) 9 5/8" TIWpacker at 10841'; 5 1/2" SSSV at 2177' 13. Attachments Description summary of proposal X 14. Estimated date for commencing operation September 1990 16. If proposal was verbally approved Date approved Detailed operations program __ BOP sketch X 15. Status of well classificatiolr~sb ~ ~ I V r. ~/ Name of ~prover f~~ 17. I hereby~.e~ify that the fq~g.¢i'~ is true and correct to the best of my knowledge. Signed ~ ~~ TitleSupervisorGravityDraina~le " _ / ' I ' FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test Location clearance Mechanical Integrity Test~ Su----bsequent form required 10- ~ q Oil X Gas~ ~,~nde~ 1,990 Service ~,,,,,,,,,, mi z C~_~ Cons. Anchorage IApproval ~ .- ,~/ No. / f Approved by order of the Commission Commissioner Date -'orm 10-403 Rev 06/15/88 ORIGINAL SIGNED ~-~' LONNIE C. SMITH Approved Copy R~tur ed SUBMIT IN TRIPLICATE WELL J-20 (41-15-11.13) PBIJ FRACTURE PROPOSAL · 3. 4. 5. 6. Slickline work: a)Gauge run with 3-3/8" DG and TEL. Last TD was 12140' MD on 6/28/90 (top of EZ-Drill CMT. Retainer). Bottom perf is at 12122' MD. b)Dummy off GLMs (at NSPE°s discretion), c)Ensure sliding sleeve is closed. Service tree. Pressure test inner annulus to 3000 psi (if possible). Perform frac. %000 gal 15% HCl spearhead. Cleanout as necessary. PBGL or nitrogen lift as necessary. 5 GLMs in well. mr:8/31/90 S E P - Alaska Oil A Gas Cons. Anchorage F- INJEGTOF~ HEAD PACK OFF BOP STACK IF,-.- QUICK UNION BLIND SHEARS BLIND SHEARS WHP SENSOR PIPE SLIPS · ~ . PIPE" RAMS ......... KILL LINE CONNECTION FLANGED CONNECTION SWAB VALVE TYPICAL CTU STACK ECEiV D S E P -' ~ 1990 0il & Gas Cons. 6om¢~ssi0r~ Anchorage FORM 1481 5110/89 , STATE OF ALASKA ~ AL,, ,A OIL AND GAS CONSERVATION COMMIS,.. ~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well~ Alter casing ~ Repair well __ Plugging ~ Time extension ~ Stimulate x Change approved program ~ Pull tubing ~ Variance ~ Perforate ~ Other ~ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address Po 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1215' SNL, 802' WEL, SEC. 09, T11N, R13E, UPM At top of productive interval 6'SNL, 521'WEL, SEC. 15, T11N, R13E, UPM At effective depth 418SNL, 19EWL, SEC. 15, T11N, R13E, UMI At total depth 438'SNL, 18'EWL, SEC. 14, 'T11N, R13E, UPM 12. Present well condition summary Total depth: measured true vertical BKB 5. Type of Well: Development Exploratory S~'atigraphic Service 6. Datum elevation (DF or KB) KBE = 78.43 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number J-20 (41-15-11-13) PBU 9. Permit number 87-36 10. APl number 50- 029-21716 11. Field/Pool Prudhoe 0il POol 12250 feet Plugs (measured) 9131 feet Effective depth: measured 12203 feet true vertical BKB 9100 feet Junk (measured) fill at 12122'MD (02/90) Casing Length Size Cemented Measured depth True vertical depth Structural -- BKB Conductor 110 20 8 c.y. 146 146 S u rface 2942 13 3/8 4127 c.f. 2978 2748 Intermediate 11116 9 5/8 2371 c.f. 11152 8384 Production -- Liner 1363 7 438 c.f. 10887-12250 8199-9131 Perforation depth: measured 12020-12044', 12069-12122' RECEIVED true vertical subsea 8976-9O45 Tubing (size, grade, and measured depth) 4 1/2" L-80 2108'- 12055' Alaska ni~,& Packers and SSSV (type and measured depth) 9 5/8" TIW packer at 10816~ 7' TIW Perm Packer at 12041 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation August 1990 16. if proposal was ve_r~ approved ~/~.~) Oil X Gas__ Name of approv~)t/~~ Date approved Service 17. ! hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY 15. Status of well classification as: Suspended __ Date Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test~ Subsequent form required 10- ORIGINAL SIGNED BY Approved by order of the Commission I ~INNIE (~, SMITH Form' 10-403 Rev 06/15/88 I Appr°va' Approved Copy c~- Returned ~ato ~)--~.-- ~) SUBMIT IN TRIPLICATE A ",wing perforatedh fOllowed by a contingent interval in Well 1-20. SCale inhibition treatment is proposed for 12020-12044, MD BKB 12069.12122, MD BKB The acid wash Will be PumPed via coiled a) 1500 gal. 15% tubing as follows: b) 1500 gal'. dies ttC1/25% Xylene With additives c) Displace to to;l w/ '10% mutual SOlvent perfs W/diesel · The Well Will be returned to Production immediately following the acid treatment. RECEIVED AUG 08 1990 Oil & Gas Cons. C_Omllljs8[O~' '.., 8nchorag~' ' rar:8/6/90 BOP STACK [ ,,- IF--- INJECTOR HE.AD ! >L~ PAC;,< .. QUICK UNION BLIND SHEARS ,~--- BLIND SHEARS WHP SENSOR KILL LINE CONNECTION FLANG~ CONNECTION ,~ WAI3 VALVE TYPICAL CTU STACK FORM .148I BP EXPLORATION BP Exploration (AlasKa) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date: 07/06/90 T#:81328 FROM: SUBJECT: Information Control Well Records LR2-1 BP CASED HOLE FINALS Enclosed is your copy of the matedal listed below. If you have. any questions, please contact BP Well Records at (907) 564-4445. B-10" TUBING CUTTER 06/27/90 #1 9060-9415 SCH 5" E-26/ CNL/GR 06/29/90 #1 9050-9721 SCH 5" H-16- PACKER RECORD 06/30/90 #1 9800-10155 SCH 5" J-20- TUB/PKR POSIT REC 06/27/90 #1 10732-12025 SCH 5" J-20 ~ PERF 06/26/90 #1 10710-12120 SCH 5" M-06 ,' PROD-L 06/30/90 #1 11000-11703 SCH 5" M-19 -' CCL 07/03/90 #1 9463-10479 ATLAS 5" W-06- PFC 07/04/90 #i 12850-13290 ATLAS 5" X-15 - PROD-L 06/26/90 #1 9400-10041 SCH 5" Di~;tribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES REC I. ED Alaska Oil & Gas Cons. Commission - Anchorage BP EXPLORATION BP Exoloration (Alaska) Inc. 900 East Benson Boulevara P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date :06/08/90 T#:81259 FROM: Information Control Well Records LR2-1 SUBJECT: DP CASED HOLE FINALS Enclosed is your copy of the matedai listed below. If you have any questions, please contact BP Well Records at (907) 564-d'!.d5. E-09 CCI 06/06/90 #1 10790-19898 Atlas 5" J-20 CCL 06/05/90 #1 10700-10884 Atlas 5" S-06 CCL 06/05/90 #1 9396-9677 Atals 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS ARCHIVES eECEIVEb 1 8 1990 41aska O# ~, (~as COns. COmmission Anchorage f~"~'" ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COI~..,,ISSIL,,, APPLICATION FOR SUNDRY 1. Type of Request: Abandon__ Suspend ~ Operation Shutdown ~ Re-enter suspended well~ Alter casing __ Repair well ~ Plugging __ Time extension ~ Stimulate ~ Change approved program ~ Pull tubing x Variance__ Perforate x Other 2. Name of Operator 5. Type of Well: 6. 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. 1215' SNL, 802' WEL, SEC. 09, T11N, R13E, UPM At top of productive interval 9. 6' SNL, 521' WEL, SEC. 15, T11N, R13E, UPM At effective depth 10. 379'SNL, 55'EWL, SEC. 15, T11N, R13E, UPM At total depth 11. 438'SNL, 18'EWL, SEC. 14, T11N, R13E, UPM 1'2. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12250 feet Plugs (measured) 9131 feet BKB 12122 feet Junk (measured) 9044 feet BKB Length Size Cemented Casing Structural Conductor Surface Intermediate Production ~,Liner Perforation depth: Datum elevation (DF or KB) KBE = 78.43 feet Unit or Property name Prudhoe Bay Unit Well number J-20(41-15-11-13) Permit number 87-36 APl number 50- 029-21716 Field/Pool Prudhoe Bay Field/Oil Pool 110 20 8 cu yds 2942 13-3/8 4127 cu ft 11116 9-5/8 2371 cu ft RECEIVED 1363 7 measured 12025'-12044', 12059'-12122' fill@ 12122'MD (02-90) JUN 1 ! 199!) ,.,~i'~slm 0ii & Gas Cons. Com. mi~ Measured depth .' .Tr, ' epth ' ~ ~JJl~J~J~J~BKB true vertical 8901'-8967' 146 146 2978 2748 11152 8384 438 cu ft 10887-12250 8199-9131 Tubing (size, grade, and measured depth) 5-1/2" L-80 surface-2521', 4-1/2" L-80 2521'-10821'with 4-1/2" tailpipe to 10949' Packers and SSSV (type and measured depth) 9-5/8" TlW packer at 10841', 5-1/2" SSSV@ 2177' 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation June 10, 1990 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 certify that the foregoing is true and correct to the best of my knowledge. Signed Title Completion Engineering Supervisor ~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness plUg integrity ~ BOP Test ~ Location clearance ~ Mechanical Integrity Test~ Subsequent form required 10- Approved by order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY , Commissioner Approvea Returned /.~ h Date ~:~//cL-~/~ SUBMIT IN TRIPLICATE , 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. ATTACHMENT I WELL ~1-20 WORKOVER OUTLINE PROCEDURE: Pull SSSV. Kill well with sea water. Set plug in tailpipe. Pull valve from the GLM. Circulate well & freeze protect to 2000' with diesel. Set BPV. MIRU workover rig. Pull BPV. Circulate diesel from well. Install two-way check valve. ND tree. NU & test BOP's to 5000 psi. Pull 5-1/2" and 4-1/2" tubing string. Test the 9-5/8" packoff. Mill and recover packer and tailpipe assembly. RIH and recover wireline tool string and stuck coil. RIH with test packer Test 9-5/8" casing to 3000 psi. Cement sqeeze all remaining perforations. RIH with 6" bit and clean hole to a TD of 12180.' Run 9-5/8" casing scraper. Run 7" casing scraper reverse circulate. Change over to filtered inhibited brine. RIH with drillpipe conveyed guns and perforate. 12020' - 12044' 4SPF 12069' - 12122' 4SPF RIH with 8.5" gagering/junkbaskets. RIH with 5.95" gage ri ng/ju n kbaskets. RIH with straddle packer assembly with sliding sleeve, 4-1/2" tubing, and GLMs. Log assembly into place and set packers. Land tubing. Set two-way check valve. ND BOP's. NU & test tree to 5000 psi. Test annulus to 2500 psi. Shear valve in the GLM. Displace annulus to filtered and treated brine + 140 bbls diesel. U-tube diesel to tubing. Set BPV. Release rig. Gas Cons. commisslor~ - Anchorag~ BOP STACK CONFIGURATION ATTACHMENT II 13 5/8", 5000 PSI WP TRIPLE RAM STACK WORKO VER RISER ANNULAR PREVENTER 2" KILL LINE MANUAL HYDRAULIC GATE GATE I i PI PE RAMS I I I I PI PE RAMS I DRILLING SPOOL BLIND RAMS 4" CHOKE LINE HYDRAULIC MANUAL GATE GATE BP EXPLORATION BP Exploration (Alasi<a) Inc. 900 East Benson Boulevard 13.O. Box 196612 'Anchorage, Alas}<~ 99519-6612 · (907) 561-5111 ';," ,, ., · T~. D IS TRIB UTION D a t e: 04 / 30 / 90 T#:81087 FROM: SUBJECT: Information Control Well Records LR2-1 BP CASED HOLE FINALS Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. B-II Leak Det 04/23/90 # 1 10850-11184 Sch 5" J-20 OZL 02/23/90 # 1 10502-12138 Atlas 5" G-26 TDT-P 0~./21/90 # 1 9650-10558 Sch .5" M-26 Perf 0~/23/90 # 1 10490-11504 Sch 5" R-20 Perf 04/24/90 # 1 10727-11850 Sch 5" Distribution' ARCO CHEVRON EXXON GEOSCTENCES MOBIL PHILLIPS ARCHIVES RECEIVED 011 & Gas Cons. BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 April 11, 1990 Alaska Oil & Gas Conservation Commi:~ion 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well J-20 (41-15-11-13) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to perform remedial/capacity sustainment work on the well. Yours~ery~ ~t%~,~ R. B. Fra~ier Supervisor Gravity Drainage RBF: JAM Enclosures (9) cc: L. Burke (MB12-1) Well File ,..,KA OIL AND GAS CONSERVATION COMb, ...... ~1 :: ! APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Alter casing ~ Repair well Change approved program ~ 2, Name of Operator BP Exploration (Alaska)/nc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1215' SNL, 802' WEL, SEC. 09, T11N, R13E, UPM At top of productive interval 6'SNI., 521' WEL, SEC,. 15, T11N, R13E, UPM At effective depth 379'SNL, 55'EWL, SEC. 15, T11N, R13E, UPM At total depth 438'SNL, 18'EWL, SEC. 14, T11N, R13E, UPM 12. Present well condition summary Total depth: measured true vertical 12250 feet BKB 9131 feet Operation Shutdown ~ Plugging ~ Pull tubing ~ Variance ~ 5. Type of Well: Development X Exploratory ~ Stratigraphic Service Re-enter suspended well~ Time extension Stimulate Perforate ~ Other X 6. Datum elevation (DF or KB) KBE. 78.43 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number J-20 (41-15-11-13) PBU 9. Permit number 87-36 10. APl number 50- 029-21716 11. Field/Pool Prudhoe Oil Pool Plugs (measured) Effective depth: measured 12122 feet true vertical BKB 9044 feet Junk (measured) fill at 12122'MD (02/90) Casing Length Size Structural -- Conductor 110 20 S u rface 2942 13 3/8 Intermediate 11116 9 5/8 Production -- Liner 1363 7 Perforation depth: measured 12025'- 12044', 12059'- 12122' Cemented Measured depth True vertical depth BKB 8 c.y. 146 146 4127 c.f. 2978 2748 2371 c.f. 11152 8384 438 c.f. 10887-12250 8199-9131 true vertical subsea 8901' - 8967' Tubing (size, grade, and measured depth) 5 1/2" L-80 surface-2521'; 4 1/2" L-80 2521'-10841' with 4 1/2" tailpipe to 10949' Peckers and SSSV (type and measured depth) 9 5/8" TIWpacker at 10841'; 5 I/2" SSSV at 2177' 13. Attachments Description summary of proposal 14. Estimated date for commencing operation April 1990 16. If proposal was verbally approved Oil X Gas ~ Name of ap~rover /I A Date approved Service Signed .~'~ .~,,,J ./~~~ Title Supervisor Gravity Draina~te ' ! ~' 0 FOR COMMISSION USE ONLY Conditions of approve: Notify Commission so representative may witness Plug integrity BOP Test~ Location clearance ~ Mechanical Integrity Test Detailed operations program ~ BOP sketch x 15. Status of well classification a's~,. _ ~.,~. ~, ~ '~ .... Approved by order of the Commission Form 10-403 Rev 06/15/88 Subsequent form required 10- ~" Z/ ORIGINAL SIGNED BY I, ONN~E C, SMITH J Approval No. ~), ,2~,,~ Approved CoPY / Returnect SUBMIT IN TRIPLICATE WELL J-20 (41.15.11-13~ PBU CTU CEMENT SOUEEZE PROPOSAL A coiled tubing cement squeeze of existing perforations is proposed as follows: 1. Perform pre-workover surveillance. Cleanout well w/CTU to establish a deeper 2. Rig up CTU and support equipment and pressure test BOP's to 4000 psi. 3. Perform perforation acid wash. 4. Pump cement and squeeze existing perforations. 5. Reverse out cement after squeeze is obtained. Wait overnight, then test squeeze by performing inflow test. If squeeze fails, immediately resqueeze. 6. If squeeze is successful, reperforate the following intervals: 12030' - 12044' MD BKB 12069'- 12122' MD BKB All depths are referenced to BHCS 5/5/87. Return well to production and test. If well will not flow, a nitrogen lift and/or perforation acid wash will be performed. e jam 4/11/90 Coiled Tubing Blow-Out-Preventers Coiled Tubing Pack-Off Blind Rams Cutter Rams Chicksan (Kill Line) Slips Pipe Rams Pump-In Sub (C irc ula te/R e turns) W ell Head Swab Valve · BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To: Distribution Date: 02/26/90 Transmittal: 80923 From: Information Control Well Records LR2-1 Subject: BP CASED HOLE FINAL LOGS Enclosed is your copy of the material listed below. If questions, please contact BP Well Records at (907) 564-4445. J-20 TDT-P 02/21/90 #1 M-26 CBT 02/17/90 #1 M-26 CET 02/17/90 #1 M-27 PERF 02/20/90 #1 you have any 11150-12115 SCH 5" 10568-11658 SCH 5" 10568-11664 SCH 5" 10865-12020 SCH 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR ARCHIVES RE¢ IVIED FEB 8 ]99o Alaska Oil & Gas ~ns. Commlssl~ An~or~e Standard Alaska Production Company 900 East Benson Boulev~-,~ P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION January 31, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well J-20 (41-15-11-13) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of stimulating the well. Yours very truly, JAB:JAM Enclosures (4) cc' L. Burke (MB12-1) Well Records (LR2-1) w/10 Well File ~nager Production Engineering A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALAoKA OIL AND GAS CONSERVATION COMMIS~. ,4 REPORT OF SUNDRY WELL OPERATIONS 1, Operations performed: Operation shutdown Pull tubing Alter casing 2. Name of Operator Standard Alaska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1215' SNL, 802' WEL, SEC. 09, T11N, R13E, UPM At top of productive interval 6' SNL, 521' WEL, SEC. 15, T11N, R13E, UPM At effective depth 406' SNL, 22'EWL, SEC. 15, T11N, R13E, UPM At total depth 438'SNL, 18'EWL, SEC. 14, T11N, R13E, UPM 12. Present well condition summary Total depth: measured true vertical Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length .. 12250 feet BKB 9131feet 12181 feet BKB 9084feet Size 2O 13 3/8 9 5/8 Stimulate X Plugging Perforate Repair well Other 6. Datum elevation (DF or KB) KBE = 78.43 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 5. Type of Well: Development X Exploratory Stratigraphic Service 8. Well number J-20 (41-15-11-13) PBU 9. Permit number/approval number 87-36 / 8-958, 8-948 10. APl number 50- 029-21716 11. Field/Pool Prudhoe Oil Pool Plugs (measured) Junk (measured) fill at 12181'MD (12/88) 110 2942 11116 .. 1363 7 438 c.f. measured 12025'- 12044', 12059'- 12122' Cemented Measured depth True vertical depth BKB 8 c.y. 146 146 4127 c.f. 2978 2748 2371 c.f. 11152 8384 10887-12250 8199-9131 true vertical subsea 8901'- 8967' Tubing (size, grade, and measured depth) 5 1/2" L-80 surface-2521 '; 4 1/2" L-80 2521'-10841' with 4 1/2" tailpipe to 10949' Packers and SSSV (type and measured depth) 9 5/8" TIWpacker at 10841'; 5 1/2" SSS Vat 2177' 13. Stimulation or cement squeeze summary see attachment Intervals treated (measured) Treatment description including volumes used and final pressure ~ka.OJl & Gas Cons. '.- ,.. Anch0rag~ 14. Reoresentative Daily Avera(3e Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 860 · 636 14 0 252 Subsequent to operation 3530 4483 84 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 1~-/4/04 Rev 06/15/88 ' ~/~/ 0 288 Service Manager Production Engineering Date / ,~/ SUBMIT IN DU~LIC~O~ WELL J-20 (41-15-11-13} PBU STIMULATION OPERATIONS A perf breakdown and scale inhibition treatment were performed on the following perforated intervals in Well J-20. 12025' - 12044' MD BKB 12059' - 12122' MD BKB Prior to the breakdown job a bullheaded 36-bbl. HCl/xylene tubing wash was performed. The breakdown was pumped as follows: a) b) c) d) 40 bbls. 15% HC1/20% xylene 135 bbls. 15% HC1/20% xylene w/588 5/8"OD 1.1 SG ballsealers dropped evenly throughout this stage 50 bbls. diesel displacement to top of perfs 111 bbls. hot crude containing 444 scl/bbl. N2 The 'well was then returned to prOduction and tested. jm 1/26/89 ~,,~,z~ Oil & Gas Cons. Anchorage Standard Alaska . Production. Company 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION December 16, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well J-20 (41-15-11-13) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to stimulate the well. Yours very truly, JAB:JAM Enclosures (6) cc: L. Burke (MB12-1) J-20 Well File A. Bragg ~ duction Engineering A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend __ Operation Shutdown ~ Re-enter suspended well ~ Alter casing __ Repair well ~ Plugging ~ Time extension __ Stimulate X Change approved program ~ Pull tubing ~ Variance ~ Perforate ~ Other __ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Standard Alaska Production Company Development x KBE = 78.43 AMSL feet Exploratory __ 3. Address StratJgraphic. 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 Service Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1215'SNL, 802'WEL, SEC. 09, T11N, R13E, UPM At top of productive interval 6'SNL, 521' WEL, SEC. 15, T11N, R13E, UPM At effective depth 414'SNL, 12'EWL, SEC. 14, T11N, R13E, UPM At total depth 438'SNL, 18'EWL, SEC. 14, T11N, R13E, UPM J-20 (41-15-11-13) PBU 9. Permit number 87-36 10. APl number 50- 029-21716 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural -- Conductor 110 Surface 2942 Intermediate 11116 Production -- Liner 1363 'Perforation depth: 12250 feet BKB 9131 feet 12197 feet BKB 9089 feet Plugs (measured) Junk (measured) fill at 12197'MD (06/88) Size Cemented Measured depth True vertical depth BKB 20 8 c.y. 146 146 13 3/8 4127 c.f. 2978 2748 9 5/8 2371 c.f. 11152 8384 7 438 c.f. measured 12025'- 12044; 12059'- 12122' 10887-12250 8199-9131 true vertical subsea 8901'- 8967' Tubing (size, grade, and measured depth) 5 1/2"L-80 surface-2521;' 4 1/2" L-80 2521'-10841'with 4 1/2" tailpipe to 10949' Packers and SSSV (type and measured depth) 9 5/8" TIWpacker at 10841'; 5 1/2" SSSV at 2177' 13. Attachments Description summary of proposal × Detailed operations program __ BOP sketch ___ 14. Estimated date for commencing operation December 1988 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas ~ SUsPended Service 7. I hereby certify that the foregoing is true and correct to the best of my knowledge, i~i~¢,-,;,;. ; :'~:~ ~:~ Signed Title Manager Production Eng/neering Date // ' ' ~' ~J FOR COMMISSION USE ONLY Conditi~f¢~ of approval: Notify Commission SO representative may witness I Approval No. 0~;~ Plug integrity_ BOP Test__ Location clearance __ Mechanical Integrity Test__ Subsequent form required 10- "~¢; ~' Approved by order of the Commission ~:~INAL SIGNED 8Y LOHNIE C. SMITH Form 10-403 Rev 06/15/88 Commissioner Date SUBMIT IN TRIPLICATE J-20 PERF BREAKDOWN PROCEDURE: 1) 2) 3) 4) 5) 6) 7) 8) 9) Perform a Maximum Rate Well Test. Clean out existing paraffin/asphaltene by: a) Pump 200 bbls of produced water heated to 190 deg F through flow lines. b) Pump 100 bbls of hot dead crude at 2 BPM into tubing and immediately flow the crude back. Perform a Tubing Wash as per the attached Tubing Wash Procedure. Make a wireline drift/TD tag with TEL. If a 3.5" drift will not pass through the tubing because of scale/asphaltene problems, redo tubing wash to insure tubing is clear. Pressure test annulus to 2000 psi. Remedy any situation that would allow acid placement in the annulus. Obtain a sample of crude from this well or an offset for emulsion testing using APl RP 42 testing procedure. Adjust additives as required. Filter fluids to 3 microns. MIRU service company. RU 5/8" ball injector. DO NOT USE A 7/8" BALL INJECTOR TO DROP 5/8" BALLS. The 7/8" ball injector will cut the 5/8" balls. Rig up ball catcher. Bullhead the Perf Breakdown stage into the formation at a rate of 10 - 12 BPM and a maxmum injection pressure in the range of 4500 to 5000 psi. Hold 2,000 psi on the annulus. AFTER THE JOB IS STARTED DO NOT SHUT DOWN FOR ANY REASON EXCEPT AN EMERGENCY. THE SUCCESS OF THIS JOB DEPENDS ON AN 10 - 12 BPM RATE BEING MAINTAINED TO SEAT THE BALLS. NOTE: IF BALLOUT OCCURS PRIOR TO FINISHING THE 15% HCl/20% XYLENE, SD AND WAIT A FEW MINUTES THEN CONTINUE THE DISPLACEMENT. Make a chart recording of both rate and pressure pen recording and send this to Ric Crawford at Anchorage Production Engineering. Pump the job as follows INTO THE FORMATION: a) 40 bbls 15% HCI/20% xylene. b) 150 bbls 15% HCI/20% Xylene with 600 - 5/8 "OD, 1.1 SG ballsealers dropped evenly throughout this stage. c) 50 bbls diesel buffer to be flushed to the perfs. d) flush with hot crude containing 300-500 scf/bbl of N2. RD, POP. Monitor the well. CAUTION: Some balls may return to sudace. Allow production to stabilize, pedorm a Maximum Rate Well Test. RDC/November 22, 1988 ~ Standard Alaska Production Company 900'E~st Benson Boulevord P.O. Box 196612 Anchorage, Alaska 99519-661 (907) 561-5111 STANDARD ALASKA PRODUCTION December 12, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well J-20 (41-15-11-13) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to stimulate the well. Yours very truly, JAB:JkM Enclosures (6) cc: L. Burke (MB12-1) J-20 Well File A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown. Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate x Change approved program __ Pull tubing __ Variance __ Perforate Other 2. Name of Operator Standard Alaska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1215' SNL, 802' WEL, SEC. 09, T11N, R13E, UPM At top of productive interval 6'SNL, 521'WEL, SEC. 15, T11N, R13E, UPM At effective depth 414'SNL, 12'EWL, SEC. 14, T11N, R13E, UPM At total depth 438'SNL, 18'EWL, SEC. 14, T11N, R13E, UPM 5. Type of Well: Development x Exploratory __ Stradgraphic __ Service 6. Datum elevation (DF or KB) KBE = 78.43 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number J-20 (41-15-11-13) PBU 9. Permit number 87-36 10. APl number 50- 029-21716 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural -- Conductor 110 Surface 2942 Intermediate 11116 Production -- Liner 1363 Perforation depth: 12250 feet BKB 9131 feet 12197 feet BKB 9089 feet Plugs (measured) Junk (measured) fill at 12197'MD (06/88) Size Cemented Measured depth True vertical depth BKB 20 8 c.y. 146 146 13 3/8 4127 c.f. 2978 2748 9 5/8 2371 c.f. 11152 8384 7 438 c.f. measured 12025'- 12044', 12059'- 12122' 10887-12250 8199-9131 true vertical subsea 89O 1' - 8967' Tubing (size, grade, and measured depth) 5 1/2"L-80 surface-2521'; 4 1/2" L-80 2521'-10841' with 4 1/2" tailpipe to 10949' Packers and SSSV (type and measured depth) 9 5/8" TIW packer at 108417 5 1/2" SSS V at 2177' 13. Attachments Description summary of proposal X · Detailed operations program __ BOP sketch~_..,_ 14. Estimated date for commencing operation December 1988 16. if proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Service Gas . 7. I hereby certify that the foregoing is true and correct to the best of my knowledge. .Signed ~¢¢¢~/'J/~..~ ~'~"'.~~ Title ManagerPrOduction Engineering // ~,/ FOR COMMISSION USE ONLY Condt[~rbns of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance __ Mechanical Integrity Test__ Subsequent form required lO-~ni~'~-~ed Copy -' -Returned,. ORIGINAL SIGNED BY Approved by order of the Commission LONNIE C. SMITH · . ,.,o,-n,-~issioner Form 10-403 Rev 06/15/88 *'* ~ "'~i ~ ~,-J i Approval No. oO.. ~, :~,z',cJ:~ Date /.,..~?...-) c /_// SUBMIT IN TRIPLICATE PROCEDURE: 1) 2) 3) 4) 5) 6) J-20 PERF BREAKDOWN 7) 8) 9) Perform a Maximum Rate Well Test. Clean out existing paraffin/asphaitene by: a) Pump 200 bbls of produced water heated to 190 deg F through flow lines. b) Pump 100 bbls of hot dead crude at 2 BPM into tubing and immediately flow the crude back. Perform a Tubing Wash as per the attached Tubing Wash Procedure. Make a wireline drift/rD tag with TEL. If a 3.5" drift will not pass through the tubing because of scale/asphaltene problems, redo tubing wash to insure tubing is clear. Pressure test annulus to 2000 psi. Remedy any situation that would allow acid placement in the annulus. Obtain a sample of crude from this well or an offset for emulsion testing using APl RP 42 testing procedure. Adjust additives as required. Filter fluids to 3 microns. MIRU service company. RU 5/8" ball injector. DO NOT USE A 7/8" BALL INJECTOR TO DROP 5/8" BALLS. The 7/8" ball injector will cut the 5/8" balls. Rig up ball catcher. Bullhead the Perf Breakdown stage into the formation at a rate of 10 - 12 BPM and a maximum injection pressure in the range of 4500 to 5000 psi. Hold 2,000 psi on the annulus. AFTER THE JOB IS STARTED DO NOT SHUT DOWN FOR ANY REASON EXCEPT AN EMERGENCY. THE SUCCESS OF THIS JOB DEPENDS ON AN 10 - 12 BPM RATE BEING MAINTAINED TO SEAT THE BALLS. NOTE: IF BALLOUT OCCURS PRIOR TO FINISHING THE 15% HCl/20% XYLENE, SD AND WAIT A FEW MINUTES THEN CONTINUE THE DISPLACEMENT. Make a chart recording of both rate and pressure pen recording and send this to Ric Crawford at Anchorage Production Engineering. Pump the job as follows INTO THE FORMATION: a) 40 bbls 15% HCI/20% xylene. b) 150 bbls 15% HCI/20% Xylene with 600 - 5/8" OD, 1.1 SG ballsealers dropped evenly throughout this stage. c) 50 bbis diesel buffer to be flushed to the perfs. d) flush with hot crude containing 300-500 scf/bbl of N2. RD, POP. Monitor the well. CAUTION: Some balls may return to surface. Allow production to stabilize, perform a Maximum Rate Well Test. RDC/November 22, 1988 Slandard Alaska Pro~uctlofl Company ~0 ~o,,I 8efta, on ~ulevo~u P.O. ~, 196617 Ancho, oge. AlonZo 1~7~ ~64-~ I ! I INDEXED DALLAS ARCO CHEVRON EXXON Date: 06/13/88 TEXACO 78950 TO: Tt: MOBIL PHILLIPS STATE OF ALASKA ARCHIVES STANDARD ALASKA PRODUCTION REFERENCE: ~APC FINAL DATA - PRESSURE SURVEY DATA The following materlal Is being submitted herewith. Please acknowledge receipt by signing a copy of thls letn~er and returning It to thls office: D-23 · J-20 J-25 M-7 M-20 N-10 U-7 Static Survey - 06/01/88 Gearhart Static Gradient 06/05/88 Camco Static Gradient 06/05/88 Camco Static Survey 05/23/88 Gearhart Static Gradient 06/06/88 Camco Static Gradient '06/06/88 Camco Static Survey 05/23/88 Gearhart Race i ved Date ~"- -' INFGRI~T I ON CONTROL Wel I Records LR2-1 Slondard Alaska Production Compo 900 Eo$! 8en$on flo~. ,~,d P.O. Bo~, 196612 An¢ borage, AIos&o 99519-66 f907~ 564-.511 I DALLAS ARCO INDEXED CHEVRON EXXON TEXACO Date: 10/21/87 ID: MOBIL I#: 78247 PHILLIPS STATE OF ALASKA GEOSCIENCES STANDARD Al. A,SF~, PRODIJC flC)N REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of thls letter and returning It to this office: E-3 F-9 J-2 J-20 J-26 J-27 M-13 Production Profile T emp / Flowme t er Perf. Record Production Profile Perf. Record Production Profile Injection Profile 10/02/87 #1 12250-12675 Camco 5" 09/27/87 #1' 9700-10220 Camco 5" 10/11/87 #1 9071-10274 Sch 5" 10/01/87 #1 11900-12170 Camco 5" 10/14/87 #1 9400-10647 Sch 5" 10/03/87 #1 9400-9550 Camco 5" 10/01/87 #1 9300-9633 Camco 5" Rece 1 ved Date 2 1961''''~ Alaska Oil & Gas cons. Co.-i.]]$~]ori Vic toria Aldrtdge Anchorage I NFORHAT I ON CONTROL Wel I Records LR?-I A u-,) el ,he o~,g,nol STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status o! Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Standard Alaska Production Company 87-36 3. Address B. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 50- 029-21716 4. Location of well at surface 9. Unit or Lease Name 1215' SNL, 802' WEL, Sec. 9, T11N, R13E Prudhoe Bay Unit At Top Producing Interval 10. Well Number 6'SNL, 521' WEL, Sec. 15, T11N, R13E J-20 (41-15-11-13) 11. Field and Pool At Total Depth Prudhoe Bay Field 438' SNL, 5262' WEL, Sec. 14, T11N, R13E Prudhoe Bay Pool 5. Elevation in feet (indicate KB, DF, etc.) J6. Lease Designation and Serial No. KBE = 78.43 feet I ADL 28284 12. Date Spudded' 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 4-21-87 5-6-87 10-11-87I N/A feet USE I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost I 12250'MD/9131'TVD 12203'MD/9099'TVD YES [] NO [] 2177'feet MD 12139' 22. Type Electric or Other Logs Run DIL/SFL, BHCS, CNL/GR-poro to State 5-14-87 23. CASING, LINER AND CEMENTING RB3OF~ SETTING DEPTH MD CASING SIZE VVT. PER FT. GRADE TOP BO'I'rOM HOLE SIZE CEMI~iTING R~D AMOUNT PULLED 20" Conductor Surface 110' 8 cu yds concrete 13-3/8" 72# L-80 Surface 2005' 17-1/2" 13-3/8" 72# S-95 2005' 29 78' 17-1/2" 4127 cu ft Permafrost 9-5/8" 47# L-8O NSCC Surface 5253' 12-1/4" 2141 cu fl Class G lead slurry followed by 230 cu ft "9-5~'8"' 47# L-80 Butt 5253' 11150' 12-1/4" Class G tail slurry 7" 26# IJ4S 10887' 12250' 8-1/2" 438 cu ft Class G 24. Perforations open to Production (MD+TVD of TOP and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" 12. 6# 10949' 10842'MD Perforations 4 spf: L-80 Mod. Butt. 12025' - 12044' MD BKB (8901' - 8914' TVDss) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12059' - 12122' MD BKB (8924' - 8967' TVDss) DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See attached Initial Perforation Data 13-3/8"x9-5/8" Inject 13-3/8"x 9-5/8" annulus with 100 bbls Brine followed by 18 bbls diesel 27. PRODUCTION TEST Dale First Production IMethod of Operation (Flowing, gas lift, etc.) 10-11-87 I Flowing Date of Test Hours Tested PRODUCTION FOR OlL-BBL GAS-MCF ~ATER-BBL CHOKE SIZE ]GAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED..~ OIL-BBL GAS-MCF ~/ATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE Z8. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. RECEIVED Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. '~ 30. i : .... FO. ,,,,~TION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sag 11166' 8393' Shublik A 11211' 8425' Zone 4 11308' 8491' IvisT°p hak/Sadlerochit) 31. LIST OF ATTACHMENTS 32, I hereby certify that the foregoing is true and correct to the best of my knowledge 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 INITIAL PERFORATING DATA - Well J-20 09/01/87 Pressure tested tubing and inner annulus. 09/16/87 Installed and tested lubricator to 3500 psi. Rigged up Schlumberger and perforated the following intervals for initial production using 3 3/8" carrier guns at 4 spf: 12025' - 12044' MD BKB (8901' - 8914' TVDss) 12059' - 12122' MD BKB (8924' - 8967' TVDss) Ail depths are referenced to BHCS/GR, 5/5/87. Put well on production and tested. 09/25/87 Shut in well to prepare for initial static pressure survey. 09/27/87 Ran static pressure/temperature survey at 8800' TVDss. 10/11/87 Set initial SSSV in ball valve nipple at 2177'. Well on production. ~!aska Oil & Sas Cons. ~mchom~o 0755Z 6REAT LAND DIRECTIONAL DRILLIN8 INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY STANDARD OIL PRODUCTION CORPANY COMPANY J PAD WELL .... ~ ..........# .,.....,, .. WELL NAME AL487DlO MWD & SS 5-4-87 JOB., NUMS,[':F;~ TYPE SURVEY DATE LYNN HENSLEY DIRECTIONAL SUPERVISOR~"~,,~ NAME T I l'L.E S I GNATURE 424 FT FROM DEF'TH INTERVAL 4-18-87 5-3-87 DAI'E SURVEY TAKEN FROM TO THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULD'YOU SO DESIRE, ALL COPIES OF THE SURVEY REPORT WILL BE FORWARDED TO YOU ON WRITTEN REQUEST. ALL SURVEYS ARE KEPT IN A LOCKED FILE AND ARE HELD IN STRICTEST GREAT LAND DIRECTIONAL DRILLING,INC 5-4 -87 Cltent .............. : STANDARD ALASKA PRODUCTION CO. Well ................ : J PAD WELL ~20 Closu=e Dt=ectton...: S S2.02 E Mognettc Decltnot~on: 31 deg 30 m~n E Doto ftle nome ...... : B:PB-J2OD.DAT RECORD OF SURVEY (Well ossumed ve=ttcol to Computotton: RADIUS OF CURVATURE' Su=vey dote: 5-4-87 Method ..... : MWD & SS RKB Hetght.: 78.0 ft 424.0 ) MEAS DRIFT TRUVERT SUBSEA SECTION DEPTH DG MN DEPTH DEPTH DIST DIRECTION RELATIVE COORDINATES ANGLE FROM WELL-HEAD 424 0 0 424.00 346.00 771 0 12 771.00 693.00 930 6 18 929.67 851.67 1111 8 42 1109.11 1031.11 1291 12 18 1286.06 1208.06 0.00 N 0.00 E -0.25 S 62.80 W 3.91 S 53.90 E 27.38 S 62.00 E 59.68 S 62.00 E 0.00 N 0.00 E 0.28 S 0.54 W 7.79 S 1.12 W 20.31 S 18.88 E 35.71 S 47.84 E CLOSURE DISTANCE DG MN S 0.00 N 0 0 0 E 0.61 S 62 47 60 W 7.87 S 8 12 29 W 27.73 S 42 54 50 E 59.70 S 53 lB 46 E DOG LE( 0.001 O. OS~ 3. 3: 1.33~ 2.001 1475 16 24 1464.28 1386.28 1569 18 30 1553.95 1475.95 1724 .20 18 1700.15 1622.15 1914 22 42 1876.91 1798.91 2102 26 30 2047.82 1969.82 104.51 S 63.10 E 132.23 S 61.70 E 183.11 S S9.90 E 252.41 S SS.O0 E 330.52 S SS.70 E 56.73 S 88.30 E 69.78 S 113.28 E 94.90 S 158.22 E 132.35 S 216.89 E 176.84 S 281.26 E 104.95 S 57 16 59 E 133.05 S S8 21 S6 E 184.50 S 59 2 41 E. 254.09 S S8 36 28 E 332.23 S S7 SO 28 E 2. 2. 1.17~ 1.32~ 2. 021 2286 29 30 2210.26 2132.26 2474 34 36 2369.56 2291.56 2660 39 36 2517.86 2439.86 2847 43 0 2658.33 2580.33 2930 45 12 2717.93 2639.93 416.82 S S2.90 E S16.40 S S7.00 E 628.16 S S6.70 E 750.89 S 59.20 E 808.07 S 61.00 E 227.24 S 284 .SO S 345.83 S 411.31 S 440.10 S 351.40 E 433.02 E 526.93 E 631.52 E 681.58 E 418.47 S S7 6 38 E S18.12 S S6 41 42 E 630.28 S S6 43 21E 753.65 S S6 SS 25 E 811.32 S S7 8 58 E 1.67; 2.80; 2. 3108 46 0 2842.47 2764.47 933.98 S 59.20 E S03.49 S 791.83 E 3328 46 48 2994.18 2916.18 1092.17 S 58.50 E 585.90 S 928.17 E 3701 45 30 3252.58 3174.58 1359.87 S 56.70 E 730.03 S 1155.27 E 3977 45 24 3446.20 3368.20 1555.79 S 57.40 E 837.01S 1320.32 E 4457 45 18 3783.53 3705.53 1896.42 S 54.60 E 1027.94 S 1603.39 E 938.35 S 57 32 57 E 1097.63 S S7 44 17 E 1366.60 S S7 42 39 E 1563.28 S 57 37 40 E 1904.61 S 57 20 9 E O. 0.40 O. 0.13, 0. 4741 46 6 3981.88 3903.88 209~.33 S S6.00 E 1143.65 S 1770.49 E 5115 46 42 4239.80 4161.80 2369.79 S 54.00 E 1298.9~ S 1992.34 E 5582 46 18 4561.26 4483.26 2708.35 S 53.90 E 1498.34 S 2266.22 E S9S4 46 6 4818.74 4740.74 2976.76 S S2.90 E 1658.42 S 2481.77 E 6331 46 S4 5078.24 5000.24 3250.22 S S1.80 E 1825.46 S 2698.28 E 2107.74 S S7 8 23 E 2378.40 S 56 S3 46 E 2716.76 S S6 31 44 E 2984.88 S 56 14 S1 E 3257.76 S SS SS 14 E O. 38 O. 32 0.08 O. 1S O. 26 PAD WELL ~20 RECORD OF SURVEY MEAS DRIFT TRUVERT SUBSEA SECTION DIRECTION RELATIVE COORDINATES DEPTH DG MN DEPTH DEPTH DIST ANGLE FROM WELL-HEAD -- 6802 45 54 5403.05 5325.05 3591.30 S 51.80 E 2036.38 S 2966.32 E 7179 46 12 S664.70 SS88.70 3862.71 S S1.SO E 2204.79 S 3179.18 E 7556 47 30 S922.53 S844.53 4137.73 S 51.10 E 2378.76 S 3393.83 E 7932 48 24 6179.20 6101.20 ~412.44 S 50.80 E 2549.86 S 3607.21 E 8307 45 24 6440.16 6362.16 4681.69 S S1.10 E 2719.51S 3816.34 E 8497 46 54 6571.78 6493.78 ~818.67 S S0.40 E 2806.20 S 3922.44 E 8686 48 36 6698.86 6620.86 4958.51 S S0.40 E 2895.37 S 4030.24 E 9155 47 0 7013.88 6935.88 S305.73 S 49.70 E 3118.46 S 4296.57 E 9531 ~S 24 7274.12 7196.12 5576.97 S 50.80 E 3291.98 S 4505.21 E 9802 45 30 7464.23 7386.23 5770.05 S 50.80 E 3414.04 S 4654.87 E 10187 46 6 7732.84 7654.6~ 6046.04 S 52.20 E 3585.86 S 4870.87 E 10657 ~6 42 8058.76 7978.76 6386.'37 S 53.20 E 3792.11 S S141.62 E 10967 45 42 8271.32 8]93.32 6610.09 S S2.S0 E 3927.23 S S319.95 E 11092 45 2~ 8358.86 8280.86 6699.31 S S0.10 E 3983.02 S 5389.59 E CLOSURE DISTANCE DG MN S 3598.05 S SS 31 49 E 3888.89 S SS 1S 30 E 4143.31 S S4 S9 45 E ' 4417.43 S 54 44 40 E 4686.17 S 54 31 35 E 4822.90 S S4 25 9 E 4962.46 S S4 18 22 E S308.99 S S4 1 40 E SS79.79 S S3 SO 39 E 5??2.65 S 53 44 33 E 6048.46 S 53 38 24 E 6388.77 S '53 35,24 E 6612.49 S S3 33 S4 E 6701.65 S 53 32 S E DOG LE( deg/lO( 0.21~ 0.09( "]35( 0.27( 0.81~ 0.89~ 0.35( 0.45: 0.03~ 0.24~ O. 17( 0.3,4: 1.00,. J PAD WELL ~20 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEP?H s-4-87 MEAS. TRU VERT DEPTH DEPTH 78 78 178 178 278 278 378 378 478 478 SUB SEA MD-TVD VERTICAL DEPTH DIFF. CORRECT 0 0 0 100 0 0 200 0 0 300 0 0 400 0 0 578 578 500 0 0 678 678 600 0 0 778 778 700 0 0 878 878 800 '0 0 979 978 900 I 1 1080 1078 1181 1178 1283 1278 1386 1378 1489 1~+78 1594 1578 1701 1678 1808 1778 1915 1878 2025 1978 2136 2078 2249 2178 2366 2278 2485 2378 2610 2478 2740 2578 2874 2678 3016 2778 3160 2878 3305 2978 1000 2 1 '1100 3 1 1200 5 2 1300 8 3 1400 11 3 1SO0 16 5 1600 23 7 1700 30 7 1800 37 7 1900 47 10 2000 58 11 2100 71 13 2200 88 17 2300 107 19 2400 132 25 2500 162 30 2600 196 34 2700 238 42 2800 282 44 2900 327 45 RELATIVE COORDINATES FROM WELL-HEAD -- 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.01N 0.00 W 0.07 N 0.09 W 0.02 N 0.32 W 0.30 S 0.57 W 3.85 S 2.09 W 11.01S 3.48 E 18.05 S 14.84 E 25.68 S 28.99 E 34.89 S 46.31 E 45.91 S 67.25 E 58.57 S 91.96 E 73.63 S 120.47 E 89.84 S 1Sl.?S E 109.33 S 184.23 E 132.62 S 217.27 E 157.98 S 253.78 E 185.46 S 214.35 S 251.27 S 287.78 S 328.35 S 294.02 E 338.63'E 384.21E 438.09 E 500.83 E 373.87 S 420.86 S 469.33 S 522.46 S S75.65 S 570.50 E 647.72 E 735.27 E 823.74 E 914.39 E PAD WELL it20 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH s-4-87 MEAS. TRU VERT SUB SEA MD-TVD VERTICAL DEPTH DEPTH DEPTH DIFF. CORRECT 3449 3078 3000 371 44 3593 3178 3100 415 44 3737 3278 3200 459 44 3880 3378 3300 502 43 4022 3478 34 O0 544 42 4165 3578 3500 587 43 4307 3678 3600 629 42 4449 3778 3700 671 42 4592 3878 3800 714 43 4735 3978 3900 757 43 4880 4078 4000 802 45 5025 4178 4100 847 45 5170 4278 4200 892 45 5316 4378 4300 938 46 S461 4478 4400 983 45 S606 4578 4500 1028 45 5751 4678 4600 1073 45 5895 4778 4700 1117 44 6040 4878 4800 1162 45 6185 4978 4900 1207 45 6331 5078 5000 1253 46 6476 5178 5100 1298 45 6621 5278 5200 1343 45 6766 5378 5300 1388 45 6910 5478 5400 1432 44 7054 S578 SSO0 1476 44 7198 S678 5600 1520 44 7345 5778 S700 1567 47 7491 S878 5800 1613 46 7637 5978 5900 1659 46 RELATIVE COORDINATES FROM WELL-HEAD 631.45 S 684.36 S 744.20 S 799.58 S 854.30 S 1003.35 E 1092.95 E 1176.88 E 1262.07 E 1347. SO E 907.85 S 960.12 S 1011.10 S 1083.36 S 1141.41 S 1433.46 E 1520.14 E 1607. S3 E 1682.34 E 1767.17 E 1199.37 S 1256.40 S 1322.71S 1384.70 S 1446.52 S 1854.27 E 1942.53 E 2025.01 E 2110.42 E 2195.68 E 1508.63 S 1569.74 S 1630.19 S 1695.79 S 1758.61S 2280.35 E 2364.95 E 2449.86 E 2531.41E 2615.88 E 1821.12 S 1890.61S 1955.59 S 2020.24 S 2084.33 S 2701.24 E 2781.08'E 2863.66 E 2945.81E 3027.35 E 2148.27 S 2213.53 S 2279.44 S 2345.66 S 2414.28 S 3109.02 E 3190.17 E 3273.32 E 3357.34 E 3440.39 E J PAD WELL ~20 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH s-4-87 MEAS. TRU VERT DEPTH DEPTtt 7784 6078 7930 6178 8074 6278 8218 6378 8362 6478 8506 6578 8655 6678 8804 6778 8953 6878 9102 8978 9248 7078 9392 7178 9537 7278 9879 7378 9822 7478 9965 7578 10109 7678 10253 7778 10398 7878 10543 7978 10688 8078 10832 8178 10977 8278 SUB SEA MD-TVD VERTICAL DEPTH DIFF. CORRECT 6000 1708 47 6100 1752 46 8200 1796 44 6300 1840 44 6400 1884 44 6500 1928 44 6600 1977 49 6700 2028 49 8800 2075 49 6900 2124 49 7000 2170 46 7100 2214 44 7200 2259 45 7300 2301 42 7400 2344 43 7500 2387 43 7600 2431 44 7700 2475 44 7800 2520 45 7900 2565 45 8000 2810 45 8100 2854 44 82OO 2699 45 RELATIVE COORDINATES FROM WELL-HEAD 2481.43 S 2547.94 S 2614.56 S 2679.46 S 2743.97 S 3523.98 E 3607.12 E 3686.70 E 3766.77 E 3846.76 E 2810.S1S 2880.57 S 2951.43 S 3021.46 S 3090.60 S 3927.65 E 4012.35 E 4098.21E 4183.74 E 4268.84 E 3162.02 S 3228.90 S' 3294.47 S 3358.65 S 3422.94 S 4348.18 E 4428.41 E 4508.26 E 4586.96 E 4665.80 E 3487.30 S 3551.17 5' 3614.88 S 3678.69 S 3742.24 S 4745.65 E 4826.38 E 4908.38 E 4991.52 E 5075.25 E 3805.47 S 3867.77 S 3931.37 S 5159.49 E 5243.48 E 5325.37 E J PAD WELL ~20 DATA INTERPOLATED FOR EVEN 1000 FEET OF MEASURED DEPTH s- -s7 MEAS. TRU VERT SUB SEA DEPTH DEPTH DEPTH -- 1000 999 921 2000 1955 1878 SO00 2757 2589 4000 3452 3384 5000 ~151 4083 5000 ~851 4773 7000 5541 5453 8000 6225 5148 9000 6909 6831 10000 7603 7525 11000 8294 8215 RELATIVE COORDINATES FROM WELL-HEAD 12.45 S 5.57 E 152.00 S 245.12 E 453.98 S 725.29 E 845.81S 1334.13 E 1245.48 S 1927.00 E 1578.40 S 2124.28 S 2380.91S 3043.52 S 3502.85 S 2508.25 E 3078.33 E 3545.33 E 4210.82 E 4755.16 E 3941.49 S S338.75 E /V {{w~' I~nti~icstio~ HORIZONTAL VIEW STANDARD ALASKA PRODUCTION CO. d PAD NELL #20 CLOSURE 6702 ft S 53.5 E DECLZNATZOI~ 3t.50 deg E SCALE: !tnch = tO00 feet BRAWN: 5-4-87 5OO t500 ~000 2.5OO 3000 35OO 4000 45OO 5O00 6OOO 6frO0 ,500 0 ,500 t000 iffO0 2000 ZqO0 3000 3500 4000 4500 5000 5500 75O 225O 3OOO 375O 45O0 525O T 8ooo D 6750 7500 8250 go00 t0,~)0 1125O t2000 t2750 i3500 -750 VERTICAL SECTION STAND~ ALASKA PRODUCTION CO. J PAD NELL #20 , SECTION AT S 52.02 E , _ TVD SCALE: ! inch - t500 feet DEP SCALE: ! inch - t500 feet , DRANN · 5-4-87 14arker Identification ID ~ DEFRT , x~X .... ,.,, , , ~ , , . , , , , ,, . ~ .. , ,, , . , , , , , ,, ,,, , ,. , ,, , , ...... ,., , , .,, o 7,0 i.oo ~ ~000 37.o ~0 ,;,0 6000 67so 7,o0 e250 Departure ~1 TELE/~71 Teleco Oilfield S(' 's of Alaska Inc. 61 16 Nielson Way Anchorage, AK 99502 (907) 562-2646 May 6, 1987 STANDARD ALASKA PRODUCTION CO. WELL J-20 PRUDHOE BAY RIG AUD #2 JOB #572 Dear Sir, Please find attached a copy of the computer calculated MWD directional surveys for the above mentioned well. We at Teleco appreciate this opportunity to provide service to Standard Alaska Production Company. Teleco is committed to providing the highest quality of service and we would welcome any comments or questions concerning these surveys or any of our other services. Sincerely, Pat Havard Field Service Supervisor PH/el Enclosures A ,~',~!~'1' COMPANY TELECO OILFIELD SERVIVES JOB 572 SURVEY CALCULATIONS Date Page 04/21/87 Company: S.A.P.C. Well: J-20 Location: PRUDHOE Rig: AUD #2 BAY TELECO Job # 572 TAK Grid Correction: Magnetic Declination: Total Correction: Proposed Direction: 0.00 degrees 31.50 degrees 31.50 degrees 127.98 degrees RADIUS OF CURVATURE CALCULATION MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' **************************************************************************************************** TIE IN TO VERTICAL 771.00 0.2 242.8 S 62 48 W 770.99 -0.25 0.27S 0.53W 0.60 S 62.800W 0.058 930.00 6.3 126.1 S 53 54 E 929.66 3.90 7.78S 1.12W 7.86 S 8.201W 4.020 1111.00 8.7 118.0 S 62 00 E 1109.10 27.38 20.31S 18.88E 27.73 S 42.916E 1.446 1291.00 12.3 118.0 S 62 00 E 1286.06 59.68 35.72S 47.83E 59.70 S 53.247E 2.000 1475.00 16.4 116.9 S 63 06 E 1464.28 104.51 56.74S 88.29E 104.95 S 57.274E 2.233 424.00 0.0 127.9 S 52 06 E 424.00 0.00 0.00N 0.00E 0.00 N 90.000E 0.000 TELECO MWD sURVEYS TELECO Job # 572 TAK 04/21/87 Page 2 . ~ MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' **************************************************************************************************** 1569.00 18.5 118.3 S 61 42 E 1553.95 132.23 69.80S 113.27E 133.05 S 58.358E 2.278 1724.00 20.3 120.1 S 59 54 E 1700.14 183.11 94.91S 158.21E 184.49 S 59.039E 1.224 1914.00 22.7 125.0 S 55 00 E 1876.91 252.41 132.36S 216.88E 254.08 S 58.604E 1.577 2102.00 26.5 124.3 S 55 42 E 2047.81 330.52 176.85S 281.25E 332.23 S 57.838E 2.027 2286.00 29.5 127.1 S 52 54 E 2210.26 416.82 227.25S 351.39E 418.47 S 57.108E 1.780 2474.00 34.6 122.9 S 57 06 E 2369.55 516.39 284.44S 433.06E 518.12 S 56.703E 2.959 2660.00 39.6 123.3 S 56 42 E 2517.86 628.15 345.69S 527.03E 630.29 S 56.738E 2.691 2847.00 43.0 120.8 S 59 12 E 2658.32 750.88 411.17S 631.61E 753.65 S 56.936E 2.021 2930.00 45.2 119.0 S 61 00 E 2717.92 808.06 439.96S 681.68E 811.33 S 57.161E 3.050 3108.00 46.0 120.8 S 59 12 E 2842.46 933.97 503.36S 791.92E 938.35 S 57.559E 0.851 3328.00 46.8 121.5 S 58 30 E 2994.18 1092.16 585.77S 928.27E 1097.63 S 57.747E 0.430 3701.00 45.5 123.3 S 56 42 E 3252.58 1359.86 729.89S 1155.37E 1366.61 S 57.718E 0.492 3977.00 45.4 122.6 S 57 24 E 3446.21 1555.78 836.87S 1320.42E 1563.28 S 57.634E 0.185 4457.00 45.3 125.4 S 54 36 E 3783.53 1896.40 1027.80S 1603.48E 1904.60 S 57.341E 0.416 4741.00 46.1 124.0 S 56 00 E 3981.88 2099.31 1143.50S 1770.57E 2107.73 S 57.144E 0.451 5115.00 46.7 126.0 S 54 00 E 4239.79 2369.77 1298.85S 1992.42E 2378.39 S 56.900E 0.419 5582.00 46.3 126.1 S 53 54 E 4561.26 2708.35 1498.21S 2266.32E 2716.77 S 56.532E 0.087 TELECO Job # 572 TAK 04/21/87 Page 3 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' **************************************************************************************************** 5954.00 46.1 127.1 S 52 54 E 4818.73 2976.77 1658.29S 2481.87E 2984.90 S 56.251E 0.202 6331.00 46.9 128.2 S 51 48 E 5078.24 3250.22 1825.33S 2698.38E 3257.78 S 55.923E 0.300 6802.00 45.9 128.2 S 51 48 E 5403.05 3591.29 2036.40S 2966.31E 3598.04 S 55.530E 0.213 7179.00 46.2 128.5 S 51 30 E 5664.70 3862.72 2204.81S 3179.18E 3868.90 S 55.258E 0.098 7556.00 47.5 128.9 S 51 06 E 5922.53 4137.73 2376.77S 3393.82E 4143.32 S 54.996E 0.353 7932.00 46.4 129.2 S 50 48 E 6179.20 4412.45 2549.88S 3607.20E 4417.44 S 54.744E 0.298 8307.00 45.4 128.9 S 51 06 E 6440.16 4681.71 2719.54S 3816.35E 4686.19 S 54.526E 0.273 8686.00 48.6 129.6 S 50 24 E 6698.61 4958.79 2894.89S 4030.96E 4962.77 S 54.315E 0.855 9155.00 47.0 130.3 S 49 42 E 7013.64 5306.01 3117.98S 4297.30E 5309.30 S 54.037E 0.359 9531.00 45.4 129.2 S 50 48 E 7273.87 5577.25 3291.51S 9802.00 45.5 129.2 S 50 48 E 7464.00 5770.33 3413.65S 4505.94E 5580.11 4655.54E 5772.96 S 53.853E 0.475 S 53.750E 0.041 10187.00 46.1 127.8 S 52 12 E 7732.40 6046.32 3585.46S 4871.54E 6048.76 S 53.647E 0.304 10657.00 46.7 126.8 S 53 12 E 8056.52 6386.65 3791.72S 5142.28E 6389.07 S 53.596E 0.200 10967.00 45.7 127.5 S 52 30 E 8271.09 6610.37 3926.84S 5320.62E 6612.80 S 53.571E 0.361 11092.00 45.4 129.9 S 50 06 E 8358.62 6699.59 3982.63S 5390.26E 6701.95 S 53.541E 1.391 TLLECO 0 ~; i ,~ i a i d Ser-v ices p~ ~_AN ViEW 1600 0 1600 B;).O0 4800 6400 8000 0 r' ,-T--"~~r, ~'~ .... -r---~--T--]----F--3----m----T---'r---~--'t---T =~ 'X , -- ~-T'-~ k--¢-.-./.~-..[~~~[~..~ -~.-.[-.~ ....... L~_~_J__L.~_.L .~ ~--? ....... P -%, ~-~-"~'--~'~-~ ~-z~ ..... , ~--~ ............... , ~" ~'~ .... t'--- ~ .... ~ .... ~ r' ...... ~" ~-'-" ..... ~- --4 __:__ ........ ..... . ............... ..... r-~ ....~-~--+~.-'t ...... ~ .......... ~--~ ....... i eoo _: i ~ L I ~ } 1 ,, ~;~,,,~ 4--:=' ...... ...... .... 2._, ....... ,, ...... ..... , ,__J ..... .... : L~-~ .... i_L.I_L..L~._~ .... ~ .... =.4 ....... ~ .... ~-~..-' ....... ~': [ :'/ · ~ l'/ ,:/, :i / : ~' :~ " ~ '/ i : ': t' __~_.~ ..... .._~_?.l.+_., .... ~__.__~ ......... ] : ~ I ~ : ~ I ~ , , i : ~ ~ I I . , I ~eOO ......... ' 8400 i i __~=_. . -. -4-4 ...... I 8000 ~ ~ ~--T ....... ! ...... ~" ~ i ~ ~ ~ : " ' ....... ~ ....... >--t-.~ g60o ~ ~ ~ ~ .~-~ ........ ~ .... ~ .......... ~. ~ ..... ~ ~ ~ ~ r .... ~ ...... ~-..~ ~.---~ ~---~...~ ......... ~---~ ..... ~ ......... ~ .... ~ ~ ..... ~ ...........~ ....Z....~.._~ ............ ~_~ .... ~_.~ ........ ~ .......... ~ .... ~..-.~ _.=-_~ ..... ~_.4 ........ ~___~_..~ .................. : .... ~ ...... ~ _., ~ ~ .... ~ ......... ~.._~ .... ~ .... . ..... ; .... ~ .... ~ ....... : ....... f ..... ~ : ~ ; : ~ · ]i '. R' ' f- r---- , --., ........ +-~-~ ....... ,---~ ...... +.--.~ ........... ~--.,--~-4.~ .... EAST cLECO 0 i ] £ ~ ~ 1 d Sarv ~ cas VERTICAL PRO~TECTION 2000 ~000 6000 8000 10000 12000 14000 16000 18000 - 1000 1000 BO00 5000 7000 9000 11000 VERTICAL SECTION (~t) Standard Alaska Produ¢lion CompanY0 900 Eo$1 Ben~on Boulevv~'d P.O. Bo~ 1966t? Anchoroge. Alosko 99519-6612 1907) 564-51 I I TO: DALLAS ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS STATE ~OF ALASKA INDEXED STANDARD ALASKA PRODUCTION Date: t0/t2/87 TI: 78229 REFERENCE: SA]PC FINAL DATA - PRESSURE SURVEY DATA The following material is belng submitted herewith. Please acknowledge receipt by slgnlng a copy of this letter and returning It ~o this office: J-20 J-23 J-25 Static Survey 09/27/87 GO Static Survey 09/27/87 GO Multi-rate & PBU 09/17/87 GO Anchorage Rece I ved Da-re A ,,,,;t ol lhe ,.,(i,nOI 5~o,~¢lo,(! O,I Victoria Aldridge INFORMATION CONTROL Well Records LR2-1 $landa~d Alaska Production Compony ~00 [o~t Ben~o,~ Boulevo,d P 0 Bo. 1966 I 2 An( ho~ oge. AIo~ o 99519 66 I 2 ,907~ 564 5l I I I)AIJ,AS ARCO CHEVRON I£ XXON TEXACO TO: MOBIl. PHILLIPS STATE OF ALASKA CEOSCIENCES INDEXED STANDARD ,",1,/", ~',1. :', ' '[.'~..!( Dote: 10/01/87 T#: 78205 REFERENCE: SAPC CASED HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: B-17 D-1 D-1 D-6 E-29 F-1 F-27 F-28 F-29 F-31 G-16 }t-3 J-20 J-27 M-6 H-21 M-14 N-23 S-13 Production Profile GR Collar Temp./Flowmeter CBT Completion Record Production Profile Production Profile Production profile Production Profile Spinner/Temp Collar Perf. Record Pref. Record 09/11/87 #1 10700-11050 Camco 5" 08/23/87 H1 8800-9882 Dress 5" 08/23/87 #1 9200-9867 Dres 5" 09/27/87 H1 9050-9400 Camco 5" 09/23/87 H1 10730-12500 Sch 5" 09/24/87 #1 7686-8138 Sch 5" 09/23/87 H1 10375-10575 Camco 5" 09/23/87 H1 9100-9300 Camco 5" 09/24/87 #1 10000-10175 Camco 5" 09/24/87 #1 9300-9475 Camco 5" 09/27/87 #1 9300-9700 Sch 5" 09/26/87 H1 9500-10097 Camco 5" 09/16/87 H1 10850-12173 Sch 5" 09/15/87 #1 8700-9544 Sch 5" 26/87 H1 10900-11305 Camco 5" #1 9750-10150 Camco 5" H1 10200-10540 Camco 5" H1 10100-10798 Camco 5" #I 3000-11250 Camco 5" Flowmeter/Temp/Capacitance 09/ Injection Profile 09/12/87 Injection Profile 09/11/87 Injection Profile 09/08/87 Temp. 09/12/87 Victoria Aldridge INFORMAT ION CONTROL Wel I Records LR2-1 STATE OF ALASKA ~"~' ALA;. .~ OIL AND GAS CONSERVATION COM..SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown E~ Re-enter suspended well [] Alter casing E] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate Il Other 2. Name of Operator 3. Address P. O. Box 196612, Anchorac~e, Alaska 99519-6612 _ 4. Location of well at surface 1215' SNL, 802 WEL, Sec. 9, TllN, R13E At top of productive interval 6' SNL, 521 WEL, Sec. 15, TllN, R13E At effective depth At total depth 438' SNL, 5262 WEL, Sec. 14, TllN, R13E 11. Present well condition summary Total depth: measured true vertical 12250 feet 9131 feet Effective depth: measured feet true vertical feet Casing Structural Conductor Surface Intermediate Production Liner 1363 ' Perforation depth: measured true vertical Length Size 20" 2934' 13-3/8" 11112 ' 9-5/8" 5. Datum elevation (DF or KB) FBE - 78_43 6. Unit or Property name Prur~hoe Bay Unit 7. Well number J-Z0 (41-15-11-13) 8. Permit number 87-36 9. APl number 50-029-21716 10. Pool Prudhoe Bay Pool Plugs (measured) Junk (measured) Cemented Measured depth feet ~.~ 8 cu.yds, concrete 4172 cu.ft. Permafrost 2371 cu.ft. Class G 7" 438 cu.ft. Class G True Vertical depth 110' 110' 2978' 2978' 11150' 8383' 12250' 9131' Tubing (size, grade and measured depth) 4-1/2" 12.6# L-80 Mod Butt 10949' MD Packer @ 10842' MD Packers and SSSV (type and measured depth) SSSV @ 2189' MD 12.Attachments Description summary of proposal ~ Detailed operations prog ~(DlJCsl~l~ L-] 13. Estimated date for commencing operation 14. If proposal was verbally approved Alaska 0il & %- Anch0r~ge Date approved Name of approver 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~. 9. ~ Title Division Drillinq Enqineer Conditions of approval Commission Use Only NO. Approved by Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI Commissioner by order of the commission Date~-- f,~--o¢,-~ Form 10-403 Rev 12-1-85 1818D Submit in triplicate PBU WELL J-20 (41-15-11-13) Permit Number: 87-36 Approval Date: 4-3-87 Well Status Well operations were shut down after running ~. 4-1/2" tubing, nippling down BOPE, and installing the tree. A DIL/BHCS/CNL has been run in the 8-1/2" hole and a gyroscopic survey has been run from PBTD to surface. The 13-3/8" x 9-5/8" annulus has been freeze protected for future annular disposal. Remaining Drilling Operations The well will be completed by perforating underbalanced with wireline conveyed guns. Perforations to be consistent to current development strategy. Flow well for simple cleanup. Install sub surface safety valve in ball valve nipple. MAW/kb/1818D SAPC DailX Drilling Report --- PBIJ April 21, 1987 at 0600 hours Rig- AUDI #2 Well' J-20 (41-15-Il-13) AFE # 120572 API 50-029-21716 0600 Depth' 424' Day' -1 24-Hour Ftg: 314' Water Used' lO00 Current Operation' Drilling. NU and test 20" diverter. Spud J-20 at 0300 hrs. 4/21/87. Drilling at 424'. MUD TYPE-Non-Disp. WT'9.2 VIS'160 PV-lO YP'30 FL'25 SOLIDS:6.5 TEMP'°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1 586h' SAPC Daily Drilling Report -- PBIJ April 22. 1987 at 0600 hours Rig' AUDI #2 Well- J-20 /41-15-11-13) AFE # 120572 API 50-029-21716 0600 Depth' 1635' Day' ~ 24-Hour Ftg' 1211' Water Used' 1400 Current Operation- Drilling w/ max. torquej Drill and survey to 785'~ Trip for bit and BHA. Kick off and drill to 1583" Trip for bit and BHA. Drilling at 1635'. MUD TYPE-Non-DISP WT'9'8 VIS-130 PV:20 YP'28 FL-gj6 SOLIDS:Il TEMP'72°F SURVEY MD ANGLE DIRECTION TVD SECTION 'COORDINATES DLS 2 771 ,2 S62j8E 771 0 0 1 3 930 6j3 S53JgE 930 5 9 1.4.0 4 llll 8j7 S62E 1109 28 21 19 5 1291 12j3 S62E 1286 60 37 48 6 1475 16,4 S63.1 1464 105 58 88 7 1 569 18.5 S61.7E 1554 133 71 ll3 1.5 2.0 2.2 2.7 1586h- SAPC Daily Drilling Report -- PBU April 23, 1987 at 0600 hours Rig: AUDI #2 Well: J-20 (41-15-11-13) AFE # 120572 API 50-029-21716 0600 Depth: 3000' Day: 2 24-Hour Ftg: 1365' Water Used: Current Operation: Chg. BHA and RIH f/Wiper trip. Drill to 2262'. Trip for BHA. Repair top drive. Drill to 3000'. POH. LD mud motor. RIH for wiper trip. MUD TYPE-Non-DISP WT:gj7 VIS:130 PV:18 YP:20 FL:9.6 SOLIDS:lO TEMP:°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 9 1914 22.7 S55E 1877 253 134 217 1.6 11 2286 29.5 S52.9E 2210 418 229 351 1.8 13 2660 39.6 S56.9E 2518 629 347 527 2.7 15 2930 45.2 S61E 2718 809 441 682 3.0 1586h: SAPC Daily Drilling Report -- PBU April 24, 1987 at 0600 hours Rig' AUDI //2 Well' J-20 (41-15-Il-13) AFE # 120572 API 50-029-21716 0600 Depth' 3000' Day' 3 24-Hour Ftg' ' Water Used' 1800 Current Operation- Nipple up BOPE. Made wiper trip, Ran 13-3/8" casing to 2978' and cemented with 4438 sks Permafrost. Had cement returns at surface of 65 bbls. ND diverter. NU wellhead and BOPE. MUD TYPE-Non-DISP WT:IOj2 VIS:60 PV:14 YP:22 FL-8.8 SOLIDS:13.5 TEMP:68°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES ,DLS 1 586h- SAPC Daily Drilling Report -.- PBU April 25, 1987 at 0600 hours Rig: AUDI #2 Well' J-20 141-15-Il-13) AFE # 120572 API 50-029-21716 0600 Depth' 3150' Day: 4 24-Hour Ftg' 150' Water Used: 1500 Current Operation' POH F/ BHA. NU and test BOPE. RIH and drill cement to 2933'. Test casing to 3000 psi. Drill shoe and new hole to 3010'. Ran FIT to .6 psi/ft/ Trip for bit. / MUD TYPE-Non-DISP WT'9 0 VIS:31 PV-3 YP-4 FL-20 SOLIDS'5 TEMP'66°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS .... 1586h- SAPC Daily Drilling Report -- PBU April 26, 1987 at 0600 hours Rig' AUDI #2 Well' J-20 (41-15-11-13) AFE # 120572 API 50-029-21716 Current Operation' Drilling. Drill to 4275'. 0600 Depth' 5362' Day- 5 24-Hour Ftg' 2212' Water Used' 700 Trip for bit. Drilling at 5362'. MUD TYPE-Non-DISP WT'9.4 VIS:33 PV'4 YP'8 FL'20 SOLIDS'8 TEMP'68°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 17 3328 46.8 S58.5E 2994 1093 587 928 . 4 18 3701 45.5 S56.7E 3253 1361 731 1155 .5 19 4076 40. l S56.7E 3519 1624 876 1376 . 4 20 4551 44.6 S55.7E 3358 1925 1061 1652 . 2 21 4927 44.2 S56.7E 4127 2217 1 201 1871 .2 · 1 586h' SAPC Daily Drilling Report -- PBI~ April 27, 1987 at 0600 hours Rig' AUDI #2 Well' J-20 (41-15-Il-13) AFE # 120572 API 50-029-21716 0600 Depth' 5266' Day' 6 24-Hour Ftg' ' Water Used' 800 Current Operation' POH F/ BHA. Drill to 5922'. Trip for bit and BHA. Ream from 3183 to 3993'. Sidetracked hole. Drill new hole to 5266'. POH for bit. MUD TYPE-DISP WT'9.5 VIS:40 PV'6 YP'IO FL:9 SOLIDS'8-1/2 TEMP'67°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 22 5396 42.9 S55E 4467 2540 1380 2138 23 5862 43.9 S53.9E 4806 2360 1575 2399 18 3701 45.5 S56.7E 3253 1361 731 1155 19 3977 4554 S57.4E 3447 1556 838 1320 20 4457 45.3 S54.6E 3784 1897 ~ 1029 1603 21 4741 46.1 S56E 3982 2100 1145 1770 22 5115 46.7 S54E 4240 2370 1300 1992 DLS .... .4 .3 .2 .4 .4 .4 1586h' SAPC Daily Dril 1 ing Report -- PBU April 28, 1987 at 0600 hours Rig' AUDI #2 Well' J-20 ~41-15-11-13) AFE # 120572 AP! 50-029-21716 0600 Depth' 7000' Day: 7 24-Hour Ftg: 1734' Water Used: 500 Current Operation' Drilling. Trip for bit and BHA. Drill to 6579'. 7000'. Trip for bit. Drilling at MUD TYPE-DISP WT:9.7 VIS'38 PV-11 YP-9 FL'7.4 SOLIDS'lO TEMP'67'~F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 23 5552 46.3 S53.9E 4562 2709 1500 2265 24 5954 46.1 S52.9E 4819 2977 1661 2481 25 6331 46.9 SS1 , 8E 5079 3251 1825 2697 26 6802 45.9 S51.8E 5401 3592 2040 2965 DLS -1 .1 .3 .2 1586h- SAPC Daily Drilling Report -- PBIJ April 29, 1987 at 0600 hours Rig' AUDI #2 Well- J-20 (41-15-Il-13) AFE # 120572 API 50-029-21716 Current Operation: Drilling. Drill to 7342'. 0600 Depth' 8300' Day' 8 24-Hour Ftg' 1300' Water Used' 500 Trip for bit. Drilling at 8300' MUD TYPE-DISP WT:IO VIS-43 PV-12 YP-12 FL'7 SOLIDS'13.4 TEMP:86°F SURVEY MD ANGLE D I RECTI ON TVD SECTI ON COORDINATES DLS 27 '~ 7179 46:2 S51E 5665 3863 28 7556 47.5 S51E 5923 4138 29 7932 46.4 S50.8E 6180 4413 2207 2379 2552 3178 .1 3393 .3 3606 .3 1586h' SAPC Daily Prilling Report -- PBU April 30, 1987 at 0600 hours Rig' AUDI #2 Well' J-20 141-15-11-13) AFE # 120572 AP! 50-029-21716 0600 Depth' 9000' Day' 9 24-Hour Ftg' 700' Water Used' 560 Current Operation' Drilling. Drill to 8376'. Trip for bit and BHA. change. Drilling at 9000'. Drill to 8745'. Trip for BNA MUD TYPE-DISP WT'IO. 1 VIS'44 PV'12 YP:ll FL'6 SOLIDS:13.4 TEMP'78°F SURVEY MD ANGLE DIRECTION l~D SECTION COORDINATES DLS 30 8307 45.4 SS1. IE 644l 4682 2722 38l 5 . 3 3l 8497 46.9 S50.4E 6572 4819 2808 3921 28 32 8686 48.6 S50.4E 6699 4959 2897 4029 '9 1586h: SAPC Daily Drilling Report -- PDU May 1, 1987 at 0600 hours Rig: AUDI #2 Well: J-20 (41-15-11-13) AFE # 120572 API 50-029-21716 0600 Depth: lO,O00' Day: l0 24-Hour Ftg: 1000' Water Used: 500 Current Operation- Drilling. Drill to 9862'. Trip for bit. Test BOPE. Drilling at lO,O00'. MUD TYPE-DISP WT:lOJl VIS:39 PV:ll YP:7 FL:5.8 SOLIDS:13.4 TEMP: °F SURVEY MD ANGLE DIRECTION 'TVD SECTION COORDINATES DLS ~... .33 ..... 9155 47 . S49,7E 7014 5306 3121 4295 34 9531 45j 4 S50.8E 7274 5577 3294 4304 35 9802 45.5 S50.8E 7465 5770 3416 4654 .4 .5 .0 1586h: Rig: AUDI #2 Well: J-20 (41-15-Il-13) SAPC ~aily Drilling Report -- PBU May 2, 1987 at 0600 hours AFE # 120572 API 50-029-21716 0600 Depth: 10,900' Day: ll 24-Hour Ftg: 900' Water Used: 500 Current Operation: Drilling. Drill to 10,717, Trip for bit. Drilling at 10,900'. MUD TYPE-DISP WT:lO~l VIS:39 PV:ll YP:ll FL:6 SOLIDS:14 TEMP: °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 36 10187 46.1 S52,2E 7733 6046 3588 4870 37 10657 46.7 S53j2E 8057 6387 3794 5140 1586h: DLS j3 J2 SAPC Daily Drilling Report -- PBU May 3. 1987 at 0600 hours Rig' AUDI #2 Well' J-20 (41-15-11-13) AFE # 120572 API 50-029-21716 0600 Depth' 11.157' Day' 12 24-Hour Ftg' 257' Water Used: 500 Current Operation' Running 9-5/8" casing. Drill to 11~157j Short trip. POH. Running 9-5/8" casing, MUD TYPE-DISP WT:IO,2 VIS'39 PV'll YP'll FL'6 SOLIDS:14 TEMP' °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1 586h: SAPC Daily Drilling Report -- PBU May 4, 1987 at 0600 hours Rig: AUDI //2 Well- J-20 (41-15-11-13) AFE // 120572 API 50-029-21716 0600 Depth: 11,167' Day: 13 24-Hour Ftg: lO' Water Used: 500 Current Operation' Drilling. Ran 9-5/8" casing to 11,152'. Cemented with 1133 sks Class G with 8% gel followed by 200 sks Class G. Test BOPE. RIH to llj0201 Test casing to 3000 psi. Drill cement and float equipment. Test casing to 3000 psi. Drilling at 11,157'. MUD TYPE-DISP WT:9.2 VIS:31 PV-2 YP:3 FL'21.2 SOLIDS'5 TEMP:74:F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES' DLS 1586h' Rig: AUDI #2 Well: J-20 (41-15-11-13) SAPC Daily Drilling Report -- PF~U May 5, 1987 at 0600 hours AFE # 120572 API 50-029-21716 0600 Depth: 12,160' Day: 14 ~4-Hour Ftg: 993' Water Used: 50 Current Operation: Drilling. Drilling 8-1/2" hole at 12,160'. MUD TYPE-DISP WT:9-1 VISi38 PV:ll YP:7 FL:8.2 SOLIDS:5.8 TEMP:86°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1586h: SAPC Daily Drilling Report -- PBU May 6. 1987 at 0600 hours Rig- AUDI #2 Well: J-20 (41-15-11-13) AFE # 120572 API 50-029-21716 0600 Depth.' 12,250' Day: 15 24-Hour Ftg: 90' Water Used: 500 Current Operation' Circ' f/liner. Drill to 12,250'. Short trip, CBU. POH. Ran open hole logs. Mak(ng wiper trip. MUD TYPE-DISP WT:gjl VIS:40 PV:12 YP:7 FL:6.4 SOLIDS:6 TEMP:88°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS .... 1586h: Rig: AUDI #2 Well: J-20 141-15-Il-13) SAPC Daily Drilling Report -- PBU May 7, 1987 at 0600 hours AFE # 120572 API 50-029-21716 0600 Depth.' 12,250' Day: 16 24-Hour Ftg: ' Water Used: 500 Current Operation- RIH with bit. Ran 7" liner to 12,250' and cemented with 370 sks Class G. POH. RIH with bit. MUD TYPE-DISP WT:9.1 VIS:42 PV:13 YP:8 FL:6.2 SOLIDS:6 TEMP:79°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1586h: SAPC Daily Drilling Report -- PBU May 8, 1987 at 0600 hours Rig: AUDI #2 Well: J-20 141-15-Il-13) AFE # 120572 API 50-029-21716 0600 Depth: 12,203' Day: 17 24-Hour Ftg: ' Water Used: 700 Current Operation: Cqean pits and inject mud. Drill cement to TOL. CBU. Trip for 6" bit. Test liner lap to 3000 psi. Clean out liner to 12,203'. Test liner to 3000 psi. Inject mud in annul us. MUD TYPE-DISP WT:9jO VIS:45 PV:17 YP:IO FL:12.0 SOLIDS:6 TEMP:76°F SURVEY MD ANGLE DIRECTION TVD' SECTION COORDINATES DLS 1586h: SAPC Daily Drilling Report -- PBU May 9, 1987 at 0600 hours Rig' AUDI #2 Well' J-20 141-15-Il-13) AFE # 120572 API 50-029-21716 0600 Depth' Day' 24-Hour Ftg' Water Used' 12,203' 18 ! 1000 Current Operation' Nippled/BOP. Inject waste mud Displace well to NaC1. Ran 5-1/2" x 4-1/2" tubing with 5 GLM's. Test liner to 3000 psi. MUD TYPE-NaC1 Brine WT- VIS' PV' YP' FL' SOLIDS: TEMP'°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1586h' SAPC Daily Drilling Report -- PBU May 10, 1987 at 0600 hours Rig: AUDI #2 Well: J-20 (41-15-Il-13) AFE # 120572 API 50-029-21716 0600 Depth: 12,203' Day: 19 24-Hour Ftg: ' Water Used: 300 Current Operation: Moving Rig. ND BOPE. NU and test tree to 5000 psi. Set packer and test to 3500 psi~ Freeze protect annulus. Released rig at 1800 hrs. 5/9/87. MUD TYPE-NaC1 Brine WT: VIS' PV' YP' FL' SOLIDS' TEMP'°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1586h: Standard Alaska Production Coml~zny 900 Eo$I Benson Boule, P.O. ~x 19~12 Anchoroge, Alosko DALLAS. ARCO ,. CHEVRON EXXON TEXACO INDEXED STANDARD ALASKA PRODUCi ION Date: 06/02/87 TO: MOBIL Tt: 77936 PHILLIPS STATE OF ALASKA GEOSCIENCES REFERENCE: SAPC CASED HOLE FINAL LOGS .' The following material Is being submlYted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this office: A-16 Water Injection Survey 05/15/87 al 10600-11434 Sch 5" c-28 Production 05/21/87 #1 10450-10950 Sch 5" D-1 Completion Record 05/22/87 al 9659-9860 Sch 5" D-5 Reperf. Record 05/16/87 al 9550-10682 Sch 5" D-16 Completion Record 05/19/87 al 9600-10050 Sch 5" D-19 Completion Record 05/22/87 al 9120-9460 Sch 5" J-1 Completion Record 05/23/87 #1 8070-9100 Sch 5" J-20 CBT 05/20/87 al 10600-12200 Sch 5" Race i ved -~ff Victoria Aldridge I NFORMAT I ON CONTROL Date Wel I Records LR2-1 A unit of the o,iginol Stondo,d Oil Compon¥ Founded in Clevelond. Ohio. in 1870 Standard Alaska Production Compa 900 Eost Benson Bob PO Box 196612 Anchorage, Alaska 99,519-6612 (907! 564-,51 I1 AP. CO STANDARD Al. ASKA f)k!(-)l')/.;(~ 1 I(.)N EXXON Date: 05/13/87 PHILLIPS TO: T~: PDBY Systems (Transmittal Only) 77885 SYSTEMS .(Transmittal & Tape) ARCHIVES SAPC MAGNETIC LIS TAPES & LISTINGS Tne following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: * J-20 OH EDIT LIS Mag tape 05/05/87 ~/1 Sch ~/72295 1988-12284 1600 bpi Open Hole + GR Casing Tape Pos. f/05242 * EXXON: An Asterisk (*) next to a listing above means you should have received the Tape(s) and Listing(sp directly from the respective service company. Please confiKm this Received i'.ji./?i: i~ (} ~.~,0 Victoria Aldridge INFORMATION ~L ~[SS~- u,, ~~- ,,.~-:,~--,~ ........ Well R~rds ~2-1 ~ un~l Ot the O,,9inOI Stondord ~1 Co,npon~ Founded ,n Cle*elond. ~,o, ~n 1870 Stondard Aloska Production Company 900 Eost Benson Boul, PO Box 196612 Anchoroge. Alosko 995 ~9-66 (907) 564-511 ! INDEXED DALLAS ARCO CHEVRON EXXON TO: TEXACO MARATHON MOBIL PHILLIPS STATE OF ALASKA GEOSC IENCES REFERENCE: STANDARD ALASKA PRODLJCI'tC)N Date: 05/11/87 Ti: 77879 SAPC OPEN HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this office: DAL./UNIT/STATE: 3-20 J-20 J-20 DIL/SFL 05/05/87 #1 11155-12258 Sch 5" & 2" BHCS 05/05/87 #1 11155-12228 Sch 5" & 2" CNL/GR-poro 05/05/87 #1 11155-12209 Sch 5" & 2" STATE ONLY: //~ ~ECTIOI~I~LL SURV~Y-~ax Magnetic Single Shot ~irec~ion~S.~]~7~te: -~-7 //~/~obft: Gyroscopic Dir ec t iona~ S~~a t e~~(~ob~/: Date aska Oil & Gas ~3ons. Cum,n,~ ..... n ~f}G~K)y<;dr~e We I I Records LR2- I A um, of the o~,gmol Slon(~d ~1 [o,n~ MEMORAMOUM TO: C.V. Chilton Chairman~V'-----~ THRU: Lonnie C Smith Commissioner FROM: Edgar W. Sipple, Jr. Petroleum Inspector Stat' of Alaska CONSERVATION CO~ISSION DATE: May 6, 1987 FILE NO.: D.EWS. 42 TELEPHONE NO.: SUBJECT: BOP Test SAPC PBU J-20 Permit No. 87-36 Prudhoe Oil Pool ~hursday, April 23, 1987: I traveled this date from ARCO's Kuparuk, 's~ubjec~'' of another report, to Standard Alaska Production Company J-20, Alaska United Rig 2, to witness a BOP test. The drilling contractor was in the process of cementing the casing. Friday~ April 24, 1987: The BOP test commenced at 11:15 a.m. and was C~clUdeda~ I2:30 p.m. There were no failures . I filled out an AOGCC BOP inspection report which is attached. In summary, i witnessed the BOP test on SAPC PBU J-20, Alaska United Rig 2. Attachment 02-001 A ( Rev 10-84) 5/s4 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Operator Well ~-2. o Location: Sec ~ T!/d R[)6~.M Drilling Contractor ~/4'~ ~/~ Ri Location, General ~Ri Well Sign General Housekeeping ~ Rig ~/~.. Reserve Pit ~ Visual Audio Date ~/~ 4-- ~ 7 Well Representative Permit # ~--~ / Y~Cas lng Set Mud Systems Trip Tank ~([ Pit Gauge ~ Flow Monitor O~.~ Gas Detectors Representative ACCUMULATOR SYSTEM Full Charge Pressure Pressure After Closure Pump incr. clos. pres. 200 psig psig ~o psig ] ~ ~ 0 mi~ a7sec. BOPE S t ac]~,~ Pipe Rams B l~i~d Rams 7,~ / ,,~.<, ' Choke ~ine Check V.~ve Test Pressure Test Results: Failures Full Charge Pr~ssure.~kttained: ~l~'min_~_~sec. N2.~Ooa ~/na ~Z~5/Z~zZooo --p--sxg. Controls: Master Remote~ Blinds switch cove='~ Kelly and Floor Safety Valves Upper Kelly.~Test Pressure Lower Kelly ~-"~Test Pressure Ball Type/~--~Test Pressure, Inside BOP~"'_~Test Pressure Choke Manifold ~ ' Test~Pressure No. Valves No. flanges ~ Adjustable Chokes ~/C_ ,, Hydrauically operated 'choke Repair or Replacement of failed equipment to be made within ~/~ days and InsPector/ Commission office notified. Remarks: Distribution orig. - A0&GCC cc - Operator cc - Supervisor MEMORANqUM TO: THRU: FROM: Stat of Alaska ALASKA o~L A/{D GAS CONSERVATION COba.~SSION C. ~.~~ er~ on Lonnie C, Smith Commissioner Bobby Foster Petroleum Inspector DATE: FI LE NO.' TELEPHONE NO.: SUBJECT: April 27, 1987 D.BDF.29 Diverter Inspection SAPC PBU J-20 Permit #87-36 Prudhoe Bay Field .Mt~day,.. April.20, .1987: I inspected and witnessed the function st of the divert'er system on Standard Alaska Production Company's well J-20 being drilled by Alaska United Drilling Company's Rig #2. The system met all AOGCC regulations. 02-001 A ( Rev 10-84) ..... STATE OF ALASKA ALASr,,~ OIL AND GAS CONSERVATION COM,,.,$SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well U3 Alter casing Iq Time extension [] Change approved program X3 Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate I;l Other [] 2. ~ameof O~ator. 5. Datum elevation(DF or KB) b~anoaro A±as~a Production Company KBE = 78' 3. Address 6. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 Prudhoe Bay Unit 4. Location of wellatsurface 1215' SNL, 802' WEL, Sec. 9, TllN, R13E 7. Wellnumber J-20 (41-15-11-13) Attop ofproductiveinterval 450' SNL, 300' WEL, At effective depth Sec. 15, TllN, R13E Sec. 15, TllN, R13E 8. Permit number 87-36 9. APl number 50_029-21716 10. Pool P~udhoe Bay Unit 11. Present well condition summary Total depth: measured true vertical feet Plugs (measured) feet Effective depth: measured true vertical feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size 80' 30" Cemented Measured depth True Vertical depth 8 cu.yds. 110' 110 ' · Replace 9-5/8" cement of 575 cu. ft. with: true vertical 2371 cu. ft. of cement Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) Estimated T.O.C. is 3794' MD Also add installation of 20" Diverter 12.Attachments Description summary of proposal~{~ !~ ~,,,gt~il~e~/~e~9~tions 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver program E3 BOP sketch APR 2 o 1987 Alaska 0ii & Bas Cons. Commission Anchoraqe Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~:~..~--~. (/'~~ TitleDivision Drilling Engineer Commission Use Only Date Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearancel ~7- ~ ~'~' Approved by Form 10-403 Rev 1~'2f-1-85/ ~ -/ ; the commission Date Submit in t p feet .April 3, 1987 Mr. R. S. Allan Division Drilling Engineer Standard Alaska Production Company P.O. Box 196612 Anchorage, Alaska 99519-6612 Telecopy: (907) 276-7542 Prudhoe Bay Unit Unit J-20 Standard Alaska-Production Company Permit No. 87-36 Sur. Loc. 1215'SNL, 802'WEL, Sec. 9, TllN, R13E, UM. Btmhole Loc. 599'SNL, 109'WEL, Sec. 15, TllN, R13E, UM. Dear Mr. Allan: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where'a diverter~system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. C. V. ChatteYtdn Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION dlf 'Enclosure cC: Department of Fish & Game, Habitat Section w/o encl. Department ~of Environmental Conservation w/o encl. Mr. Doug L, Lowery STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.OO5 la. Type of work Drill [~: Redrill ~1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil ~ Re-Entry [] Deepen~ Service [] Developement Gas [] Single Zone,t~ Multiple Zone E] '2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Standard Alaska Production Company 78' KBE feet Prudhoe Bay Field '3. Address 6. Property Designation Prudhoe Bay Pool P.O. Box 196612 Anchorage, Alaska ADL 28284 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1215' SNL 802' WEL Sec 9 TllN Pl3E Prudhoe Bay Unit At top of productive interval 8. Well nu ,mber Number 450' SNL 300' WEL Sec 15 TllN R13E J-20 (41-15-11-13) KO0683449-G-14 At total depth 9. Approximate spud date Amount 599' SNL 109' WEL Sec 15 TllN R13E April ~, 1987 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number_of_aqre_s. in property 15. Proposed depth(Ma aod TVD) property tine 1 2 2 59 ' MD ADL 28285 300 feet 33' from. J-9 feet 2560 9095' TVD feet 16. To be completed for deviated wells 4 5 ,, 6 5 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 800 feet Maximum hole angle 0 Maximumsurface3330 psig At total depth C'VD) 8800 4390~sig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement , Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" Co~ducto~ 80' Surface 110 110. 8 cu. yds concrete 17!~'' 13-3/8 72# L-80 Butt 2126" Surface 2156 2078 '17!~'' 13-3/8 72# S-95 Butt 815' 2156 2078 2971 2680 4.127cu.ft.Permafro '12¼" 9-5/8' 47# L-80 NSCC 55_45 Surface 5575 4500 i2¼" 9-5/8' 47# L-80 Butt 5630 5575 4500 11205 8436' 575 cu.ft.Class G 8-1/2" 7" 26# L-80 't-J4S 1304 10955 8261 12259 9173 426 cu.ft.Class G Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor ;,,i~ ,;:-., Surface._ ~." ~' ~ ' Intermediate ~,.-..~ ii~{ 0 1~ Production ," Liner ,1 '~ Perforation depth: measured ~-~.S~.~ 0i~ & '''~' true vertical 20. Attachments Filing fee ~: Property plat '~ BOP Sketch [] Diverter Sketch E-~ Drilling Drilling fluid program ~ Time vsdepth plot [] Refraction analysis E3 Seabed report ~ 20AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed 2,. %., ~~.~_ TitleDivisi°n DrillingEngineer Date~///~ Commission Use Only Permit Number,¢. 7_. ~g 50--0¢-¢] '-~-I 7//¢ 04/03/87 for other requirements Conditions of approval Samples required [] Yes '1~ No Mud log required L~] Yes r~ No Hydrogen sulfide measures [] Yes [] No Directional survey required ~ Yes [] No Required working p.,~sure~o~,~2M,~ []/3M; X~ 5M; [] 10M; [] 15M Other: J /'~// ~'/~~ / ~ by order of 7 Approved by ( j,./ L ~/~/~/~//~'~ Commissioner tho commission Date PROPOSED DRILLING AND COMPLETION PROGRAM WELL J-20 [41-15-11-13] PBU Install and cement 80' of 20" conductor to surface. The drilling fluid program will consist of an 8.5-9.5 ppg spud mud in the 17-1/2" hole, a 9.0-9.7 ppg water base mud in the 12-1/4" hole and a 9.2 ppg water base mud in the 8-1/2" hole. Drill 17 1/2" hole to 2991' and cement 13 3/8" L-80/S-95 Buttress casing to surface. Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based on original resevoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Directionally drill 12 1/4" hole to the 9-5/8" casing point above the Sadlerochit Sandstone. Run 9 5/8" 47# L-80 mixed string of Buttress and NSCC to within 5' of 12 1/4" TD and cement in two stages: First stage using Class G cement around the 9 5/8" shoe. The second stage to be downsqueezed in.the 13 3/8" x 9 5/8" annulus followed bynonfreezing fluid. Directionally drill 8 1/2" hole to TD. Run 7" liner from TD to 250' inside 9 5/8" casing shoe and cement using Class G cement. Clean out to 7" float equipment. Change over to 9.6 ppg. NaCl completion fluid. Test casing and lap to 3000 psi. Run 9 5/8" production packer on internal plastic coated tubing with gas lift mandrels and a sliding sleeve. Set packer 50' above top of liner. A subsurface safety valve with dual control lines will be placed 50' below base of permafrost. Install and test xmas tree. Displace tubing to diesel. Set and test packer. Shut down rig operations for perforating subsequent to rig release. The well will be perforated in accordance with normal practices. Tubing Size: 4 1/2", 12.6~, L-80, A/B Mod, BUTT, IPC tubing w/6 GLM's Tailpipe Size: 4 1/2", 12.6#, L-80, BUTT tailpipe JWB:20-MAR-87 PROPOSED DONNHOLE DIAGRAM WELL J-20 [41-15-11-13] PBU PROPOSED DEPTH BKB 20" Conductor 110 Ball Valve 2189 13 3/8" Casing Shoe 17 1/2" Open Hole 2971 2991 4 1/2", 12.6#, L-80, A/B Mod, BtriT, IPC tubing w/6 GLM's 9 5/8" Packer 7" Tieback Assembly 9 5/8" Casing Shoe 12 1/4" Hole 10905 10955 11210 7" PBTD 7" Liner Shoe 8 1/2" Open Hole 12219 12259 12259 JWB: S-MAR-87 §.O.P. STACK CONFIGURATION 1 ~3-5/8 IN. TRIPLE RAH STACK SO00 PSI WP DRILLING I ANNULAR PREVENTER 2 IN. KILL LINE CHECK GATE GATE I 1 I i PIPE RAMS I 1 I I BLIND RAMS I 1, DRILLING SPOOL I I PIPE RAMS I ] 4 IN. CHOKE LINE GATE GATE r (Actual 04 (Ach 02 05 04 ~(Actua ) 547' -J-'- b 2o ~o 4o ' "~o % ! J-7 ,~ f d -24 El !~00 .~'{~cfual ~5.,(Proposed 2~00~ ~ 850 ~ J-19 4 J -22 ~{Proposed) (Proposed) (ACtuOl) -0:, J -21 (Proposed) - 2580' ~eoo' J- 23 '~-- '~,f(Proposed) ~L, 5387' (Actual) J-6 Lat. : 70019'~78 Long.= 148° 50'08.9 ×: 643,547 ¥= 5,970,605 [Actual~ $ t0 SECTION $,4,9,10 T. II N.,R.13E. SCALE I"= I/2 MILE ~ 3C0 CERTIFICATE OF StJRVEYOR I hereby certify that I am properly registered to practice land surveying in .the State of Alaska and that this plat represents a location survey of the wet lpad shown and the wel~s thereon. This survey was made by me or under my supervision and alt dimensions and other details are correct. Bottom ho!e locations are furnished by others. , . Date Surveyor NOTE: All bottom holes ore 8800' sub sea. ADDED PROPOSED BOTTOM HOLE d-20 ADDED PROPOSED BOTTOM HOLE J-25 ADDED PROPOSED BOTTOM HOLE d- 2 I ADDED PROPOSED BOTTOM HOLE J-22 REVISED BOTTOM HOLE PROPOSED J-19~-' ADDED PROPOSED 80TTOM HOLE J-24 ADDED PROPOSED BOTTOM HOLE J-t9 REDREW PLAT-CERTIFICATE REVISION ONLY 3/5 t / 87 3/f7/87 2/26/87 2 / 3 /87 ~/22187 I/7/87 7/10,/86 7/10/86 . '32-O3- J -:,3 ) 0 --e.- 5 -% PAD t-- .-:to' DETAIL FCALE : 3 )S P~AT 2 OF b PAD "J" EXTENSION t'..co ted - Su~, e~,ed for STANDARD ALASKA PRODUCTION COMPANY Sd-va,-ed by OCEAN TECHNOLO6Y, LTD. LAND ~ Hr'ERC. GRAPHIC ~dR'/EYC RS Anchorage q :s-,: $1$DUA10:[DRAN017]J20 CLOSAP SHORT.LIS;5 Search Radius= 200 COURSE LINE For proposed well: J-20 [41-15-11-13] Location = W-E S-N TVD(SBS) Top 643560.00 5970139.00 -78.00 Bottom 649624.73 5965595.09 9094.70 Note: All depths in feet Below Kelly Bushing (BKB) 25-MAR-1987 --- Closest Approach Analysis --- Date: 25-MAR-87 Time: 15:19:59 15:20 Page Closest Approach WELL IDENT /PROPOSED% /NEARBY~ TVD DEPART TVD DEPART A029-2002300 J-2 900.0 2.2 902.6 52.0 A029-2013500 F-8 A029-2025100 J-9 A029-2026500 J-8 A029-2032200 Q-3 A029-2033300 Q-2 A029-2034000 Q-4 A029-2034400 A029-2034600 Q-6 A029-2035200 Q-7 A029-2049700 3-13 A029-2095500 J-14 A029-2096100 J-15 A029-2096700 J-16 A029-2096900 J-17 A029-2098600 J-18 7891.4 1116 5 800 0 5140 5 3819 4 4885 5 8171 0 6781 7 8936 0 800 0 1489 2 1583 9 1296 0 1198 0 1393 2 6267.4 22.3 0.0 3453.4 2102.0 3192 5 6553 4 5132 3 7336 0 0 0 106 1 138.2 54.3 34.8 78.1 CLOSEST DISTANCE S U M_W~AR Y The well which comes closest to A029-2025100 J-9 415.5 8450.0 4899.9 4058.6 1112.5 5.1 31.7 789.4 7.6 59.1 5058.6 890.3 3404.9 3297.0 34.9 3826.1 5495.0 481.1 3413.6 8777.3 3915.4 1910.6 7145.0 4155.2 605.3 8096.3 6021.2 1482.4 792.3 9.9 156.1 1735.8 625.6 1025.7 1845.2 613.1 868.4 1470.3 265.4 992.8 1353.0 255.0 890.7 1562.0 442.2 657.3 the proposed well is: Vertical /PROPOSED% TVD DEPART Intersection /NEARBY% TVD DEPART VERTICAL DISTANCE 2329.4 585.5 4373.1 1031.8 2064.3 5036.2 3346.7 8410.6 3783.1 3395.1 6581.1 4927.1 7553.9 4501.7 981.1 8104.6 2393.4 5137.0 Closest approach distance = KICK OFF for this run = 31.7 feet 800.0 feet $1$DUA10:[DRAN017]J20 CLOSAP SHORT7.LIS;3 15:21 Page I Search Radius= 200 7 DEGREE LEAD LINE For proposed well: 3-20 [41-15-11-13] Location = W-E S-N TVD(SBS) Top 643560.00 5970139.00 -78.00 Bottom 650133.55 5966368.53 9094.70 25-MAR-1987 --- Closest Approach Analysis --- Date: 25-MAR-87 Time: 15:20:35 Note: All depths in feet Below Kelly Bushing (BKB) WELL IDENT Closest Approach /PROPOSED% /NEARBY% TVD DEPART TVD DEPART A029-2002300 J-2 900 A029-2013500 F-8 7891 A029-2025100 3-9 4 A029-2026500 3-8 800 A029-2034000 Q-4 3557 A029-2034600 Q-6 7338 A029-2049700 3-13 800 A029-2095500 3-14 1393 A029-2096100 J-15 1489 A029-2096700 J-16 1296 A029-2096900 J-17 1198 A029-2098600 3-18 1393 2.2 6267.4 0.0 0.0 1833 .9 5701 8 0 0 78 1 106 1 54 3 34 8 78 1 CLOSEST DISTANCE 902 .6 52.0 415.6 8450 .0 4899.9 3412.5 0 .0 0.0 33.6 789.4 7.6 59.1 3769.8 301.5 3662.9 7929.2 4865.4 895.5 792.3 9.9 156.1 1641.4 591.5 1032.3 1750.6 581.7 873.9 1470.7 265.5 994.2 1353.4 255.1 891.2 1562.9 442.5 657.5 Vertical /PROPOSED% TVD DEPART Intersection /NEARBY% TVD DEPART VERTICAL DISTANCE 7027.0 5383.2 8353.9 5278.9 1335.4 2616.4 871.3 7338.6 2052.5 4723.6 S UM3LARY Th. well which comes closest to A029-2025100 J-9 Closest approach distance = KICK OFF for this run = the proposed well is: 33.6 feet 800.0 feet S tJC T~O,',J SUCT~O,',J ~,~ ~L 1 - Brandt Dual Tandem Shale Shaker 1 - Demco 6-12" Cone Shale Desander 1- Demco 416H w/16 cones & (1) 48H w/16 cones (Desilter) 1 - Drilco Atmospheric Mud Degasser r~t 3 5'0 B6L 1 - 200 gpm Operating Capacity. Centrifuge 15 - Brandt MA5 Mud Mix Agitators 1- 150 bbl. Trip. Tank 1 - Rmoording drilling fluid pit level indicator with both visual and audio warning devices at driller's console - TA~I~ Z 70 1 - Drilling fluid flc~ s. ansor with readout at drill%~.'0s console CHECK LIST FOR NE%; W~.I, PERMITS Company 3~~. & ~-f~a. ~,~+~ C~ Lease & Well No. ITEM APPROVE DATE YES NO (1) Fee ~ ~-~-F~,, 1. Is the permit fee attached .......................................... (2) hoc (2 thru 8) (8) (3) Admin. ~ ~'- 2-F~ 9. (9 thru 13) ~ 10. ';" ii. 13. (4> Casg ,~.,I'~.~ (14 thru 22) (23 thru 28) 2. Is well to be located in a defined pool ............................. ~ 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. ~.. Is a conservation order needed ...................................... Is administrative approval-needed ................................... Is the lease number appropriate ............................. ~ Does the well have a unique nanm ~'~~' 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cemant tie in surface and intermediate or production strings ... Will c~m~nt cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonnmnt procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~Oo psig .. Does the choke manifold comply w/AP1 RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (6) OTHER (29 thru 31) For 29. 30. 31. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones .... _/7 If an offshore loc., are survey results of seabed conditions ~~d--~' F 32 Additional requiremm~ts Geology: Engineering: WWB 'w~ LCS~"' BEW~ 'ev: 01/28/87 '~1 INITIAL GEO. UNIT DN/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX~ No special'effort has been made to chronologically organize this category of information. .o '~ *:0-029-2t7iA ~ 50-02S-21716 ',--,' F I L E i"1 E A D :: R ,";", ;',-' FiLE i"~A:"I;'.: :EDZ I .uOl SERVICE NAME : V'ERS i:CN ~ : uAT~ : MAXIMUM LENG!'ii : lc) 2~ FiLE TYPE : PkEViOUS FiLE : -,--,. l i', r: Ci R M .A f T '3 N R ": C '"" -~ ~C S ;:~ M N E M C 0 N T E ,,'.J 1 S TYPE C&TE SiZE CO.CE CF,, T C w ;'~ .SC: CT C 2 ~J STAT ETRY : ST,~NDAi.:U ALASKA PACSUCT'C:N : J-gO (-i-15-11-!3) : : 1 1N : hS~Tm SLC~]i : &L~SKA USA 3 d 0 .'20,3 030 0 E .5 000 OOC 018 06.5 ,300 OOJ 012 065 000 000 003 065 000 CCJ 003 OE5 OOO GOO OOl 065 00,~ OOC 0t2 065 '" ,,- OCO nO~,~ ,-. 065 0 C 0 O 00 003 065 'rYp= C&TE SIZE COC'E ;:, b N ~ .ti., G .&. T !:: L .S. ~S G E D = 0 ) - ?,' ~:',, Y - :~. 7 _DP: RICK KRUHELL 3ASING DRiLLE?; = S,623'~ ~,~, 11152' i'"fPs FLUID = ;')iSP:?.PSF:D LiGNO L..'",ENSiiY = '~.i LS/G ViSCOSiTY = 38 S P M = g.. · 0 4.76 J 6~ DF 3.79 ~ 68 DF '3.67' ~ 68 :IF 2.017 G 170 FLUiE; LCSS = ~;.:!i! C2 LCF 'fiATRiX SAi:'4DSTOF'.iE .,..,.-,-.,.-,- TifiiS ,..,,,,::, T ,~,: ' He, S,. f',; 0 T ;~' ~;: ;:: f',j,.. DEPTH, S~ T 'F:t' =' ''':.,. ,.. - ..n VERLAY q.... FIELD PRINTS ......... -,- -,--,. -,-" ..... -,- , DATuk,I $?f:CiP,ICATiO'q i::,L[2CK3 !~',N~N ,S~T~v'.T. CE S~:J:iViC~ UNiT AP1 API AFl ~.Pi FIL.~ SEE::{ SPL RE?~ PftCCESS lO 0~'21:.2 ~' LCG TYPE CLASS MOD i~C. CUOE (OCTAL) 0 E. P'T FT C,O 000 O0 0 0 4 I ~8 O000030OO00CO0 SFLU OIL Oh~v:'i JO 22C O! 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