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182-053
• • ~~Q~~ 0~ Q1~Q~~{Q /~....~..~a~w.~. John McMullen Engineering Team Leader ,. ~p~,/, , ~ f~ , ry f~ ej ~~ BP Exploration (Alaska), Inc. ~ ~ .• Q P.O. Box 196612 ~ ~' Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 13-21 Sundry Number: 310-150 Dear Mr. McMullen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this day of May, 2010. Encl. ,1~ STATE OF ALASKA yeti ALASI(~L AND GAS CONSERVATION COMMIS~N APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 r ~ -/~'/a MAY ~ o Z01~ 1. Type of Request: A1tGht3f«~'' ^ Abandon ®Plug for Redrill . ^ Perforate New Pool ^ Repair Well ^ Change Approved Program ^ Suspend ^ Plug Pen`orations ^ Perforate ^ Pull Tubing ^ Time Extension ^ Operations Shutdown ^ Re-Enter Suspended Well ^ Stimulate ^ Alter Casing ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 182-053 3. Address: ®Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20789-00-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 13-21 - Spacing Exception Required? ^ Yes ®No 9. Property Designation: ~ 10. Field /Pool(s): , AOL 028315 & 028330 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13420' ~ 9212' - 13323' 9164' None 13309' Casin Len Size MD TVD Bust Colla Structural Conductor 7 ' 7 ' 7 Surface 251 1 -3/ " 2 1 24 4 30 2670 Intermediate 12 7' 9-5/8" 1 579' 7 7 476 Production Liner 11 7" 1 9 ' - 13404' 04' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12559' - 13084' 8754' - 9043' S-1/2", 17# x 4-1/2", 12.6# L-80 / N-80 12320' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker packer Packers and SSSV 12204' / 8540' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ^ Development ®Service ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: May 15, 2010 ^ Oil ^ Gas ^ WDSPL ^ GSTOR ^ Abandoned 16. Verbal Approval: /~ Date: S-~C•!a ^ WIND ^ GINJ 'WAG ^ Plugged ^ SPLUG Commission Representative: 4? Scl1W~z- L/ ,~ / 17. I hereby certify that the foregoing is a and correct to the best of my knowledge. Contact Amanda Suddreth 564-5543 Printed Name John MC ul n Title Engineering Team Leader /~ ~ ,~ ~> /~ / ~ Prepared By Name/Number Signature ,,.~'`"~ Phone 564-4711 Date !/ I Terrie Hubble, 564-4628 `' Commission Use Onl Conditions~'approval: N9tify Commission so that a representative may witness 2 ~ ~~~ S d N b um un ry er: J ^ Plug Integrity ~ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ,~ 35~o p~~ ,~P e s~- Other: ~.~ ~ ,f C~-~`> Z SOv p J9rin . ~~, Subsequent Form Required: / ~- !~/ p `7 APPROVED BY ~ ~' Approved By: COMMISSIONER THE COMMISSION Date Form 10-403 Revised 12/2009 R8DN1~ MAY ~, / Submit In Duplicate 27 GRIGINAL ~=,Y_~o • • To: Alaska Oil & Gas Conservation Commission h From: Amanda Suddreth "~ p CTD Engineer Date: April 12, 2010 Re: 13-21 Sundry Approval Sundry approval is requested for well 13-21. Well 13-21 was drilled in 1982 as a long step-out WAG injector. No problems were reported while drilling and completing, and initial PITS didn't indicate any channelling of injected fluids. A workover in Jan 83 repaired a leaky packer, followed by an acid wash that opened three intervals. First indications of a thief zone were discovered in Jan 84; the zone is at 12,882'-12,922'. This thief zone is likely due to a fault, although no drilling problems were indicated while in this zone. There was good indication that the injection zones below the thief had also seen water, so the four zones below the thief had an acid stim job in Jan 85, with little effectiveness. Injection percentages in these zones tapered to nothing within 2 years. New perforations were added in Dec 85, but within a year, it was clear that they were not taking injection. In March 87, an injection profile indicated that the thief zone was taking 100% injection; three sand matrix profile mods were attempted (March-May) but deteriorated within a month. A two-stage acid job was performed in Dec 87, but the infectivity index returned to normal values within two weeks. An injection profile following the acid job showed the intervals below the thief cooling, most likely due to previous SWI injection. It was concluded that injection was primarily entering the thief zone, and most of the water was travelling down to Z3, with a small amount (<10%) entering lower 46P. REASON FOR SIDETRACK Since injection for 13-21 is being lost to afault-related thief zone, and is thereby ineffective, this well is a good candidate for a coil sidetrack. The proposed sidetrack will replace 13-21's central injection location, avoiding the fault that was encountered in the parent wellbore. The proposed plan for 13-21A is to drill athrough-tubing sidetrack with the SLB/Nordic 2 Coiled Tubing Drilling rig on or around June 28, 2010. The existing perforations will be isolated by a cement downsqueeze after setting the whipstock, as well as the primary cement job. The sidetrack, 13-21A, will exit the existing 4.5" tubing and kick off through 7" casing in the Sag and land in zone Z4. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. ~ Pre-Rig Work: (scheduled to begin May 1, 2010) 1. S Caliper tubing from 13,036' (DONE on 11/23/2009) 2. S Drift well and tag top of fill (DONE on 11/23/2009) 3. O MIT-IA to 3000psi 4. O MIT-OA to 2000psi ' 5. O PPOT-T, function LDS 6. S Drift well with dummy whipstock 7. E RIH w/ through-tubing whipstock (4.5" x 7"); set TOWS @ 12,568' MD ' 8. C Squeeze cement past whipstock to isolate perforations 9. C Mill out XN Nipple @ 12,154' (ELMD) 10. C Freeze protect well and thoroughly wash the tree ' 11. O Post-cement job MIT-T to 1000psi for 30 minutes 12. O Bleed wellhead pressures down to zero 13. O Bleed production flow lines and GL lines down to zero and blind flange , 1- ~ ~~, ~f~5/l~7 • • 14. O Remove wellhouse, level pad Rig Work: (scheduled to begin on June 28th, 2010) ~ ~~ 1. MIRU Nordic Rig 2 2. NU 7-1/16" BOPE; test to 250 si low and 3500 si hi h. _ 3. Mi113.8" window at ~ 12,585' and 10' of rathole. Swap the well to Geo-VIS. 4. Drill Build: 4.25" OH, 200' (35 deg/100 planned) with resistivity ~'(~ 5. Drill Lateral: 4.25" OH, 457' (12 deg/100 planned) with resistivity 6. Run 3-1/2" x 3-3/16 x 2-7/8" solid L-801iner leaving TOL at 12,100' ,~ ~0' Duo 7. Pump primary cement leaving TOC at 12,100', 21 bbls of 15.8 ppg liner cmt planned 8. Cleanout liner and MCNL/GR/CCL log 9. Test liner lap to 2000 psi. 10. Perforate liner per asset instructions (~ 150' ) 11. Freeze protect well, RDMO Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Generic GLV's Amanda Suddreth CTD Engineer 564-5543 CC: Well File Sondra Stewman/Terrie Hubble • • VDL / CBL, 5/23/82 - TREE = FMC 13 ~~ ~ FETY NOTES: ~,NELLHEAD = GRAY ACTUATOR = BAKER C KB. ELEV _ 84' BF. ELEV _ _ KOP _ 2100' Max Angle = 60 @ 13300' Datum MD = 12784' Datum TVD = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ 2513' Minimum ID = 3.725" @ 12308' 4-1/2" OTIS XN NIPPLE 2024' S-1/2" OTIS ROM SSSV NIP, ID = 4.562" "~~'' w / 5-1/2" ROY DSSSV (07/26/08) 12123' ~~5-1/2" OTIS XA SLIDING SLV 12184' ~-~5-1/2"BOTPBRASSY L5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" ~ 12215' TOP OF 4-1 /2" TBG-PC 12215' TOP OF 7" LNR 12295' 14-1/2" TBG-PC, 12.6#, N-80, .0152 bpf, ID = 3.958" I~ 12320' 9-518" CSG, 47#, L-80, ID = 8.681" ~ 12579' PERFORATION SUMMARY REF LOG: BHCS ON 05/18/82 ANGLE AT TOP PERF: 54 @ 12559' Note: Refer to Production DB for historical oerf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 12559-12590 O 12/27/91 3-3/8" 4 12720-12738 O 12/20/85 3-3/8" 4 12744-12764 O 12/20/85 3-3/8" 4 12774-12784 O 12/20/85 3-3/8" 4 12796-12806 O 12/20/85 3-3/8" 4 12815-12835 O 12/20/85 3-3/8" 4 12846-12866 O 12/20/85 3-1/8" 4 12882-12922 0 04/20/83 3-1/8" 4 12928-12958 O 04/20/83 3-1/8" 4 12974-13004 O 04/20/83 3-1/8" 4 13028-13048 O 11/18/82 3-1/8" 3 13064-13084 O 11/18/82 PBTD 13360' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 13404' TD 13420' 12204' -j9-5/8" X 5-1/2" BOT 12215' 5-1/2" X 4-1/2" XO 12308' -14-1/2" OTIS XN NIP, ID = 3.725" 12319' 4-1/2" SHEAROUT SUB 12320' 4-1/2" TUBING TAIL 12261' ELMD TT LOGGED 12/20/85 13309' I-I FISH - 20' MAGNETIC DECENTRALIZER DATE REV BY COMMENTS DATE REV BY COMMENTS 01/25/83 ORIGINAL COMPLETION 08/05/08 RWJ/PJC TREE REPLACEMENT (07/29/08) 01/03/01 SIS-SLT CONVERTEDTOCANVAS 01/30/01 SIS-LG REVISION 10/27/01 RN/TP CORRECTIONS 08/05/08 BSE/JPJC SET DSSSV (07/26/08) PRUDHOE BAY UNff WELL: 13-21 PERMfI' No: 82-053 API No: 50-029-20789-00 SEC 14, TION, R14E 1898.51 FEL 3095.2 FNL BP Exploration (Alaska) i TREE FMC WELLHEAD= GRAY ACTUATOR = BAKER C KB. ELEV = 84' BF. ELEV = ? KOP = 2100' Ndx Angle = 60 ~ 13300' Datum MD = 12784' DatumTVD= 8800'SS 13-3/8' CSG, 72#, L-80, ®= 12.347" 2513' Minimum ID = 3.725" ~ 12308' 4-1/2" OTIS XN NIPPLE 5-1/2° TBG-PC, 17#, L-80, LT8.C 8RD AB MOD, 12215, IPC, 0.0232 bpt, ID = 4.892" TOP OF4-1/2"TBG-PC 12215' 4-1/2' TBG-PC, 12.6#, N-80, 12320' BTC, 0.0152 bpf, ID = 3.958" OF 7' LNR elmd logged 11/23/09 12235' 9-5/8" CSG, 47#, L-SO & S00-95, 12546' ID = 8.681' elmd BRCS PERFORATION SUMMARY REF LOG: BHCS ON 05/18/82 ANGLE AT TOPPERF:54 ~ 12559' Nn}A' RPTPr Tn PrnrT„n}inn r1R fnr hielnrirnl nnrf rT~i~ S¢E SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 12559-12590 O 12/27/91 3-3/8" 4 12720-12738 O 12/20/85 3-3/8" 4 12744-12764 O 12/20/85 3-3/8" 4 12774-12784 O 12/20/85 3-3/8" 4 12796-12806 0 12/20/85 3-3/8" 4 12815-12835 O 12/20/85 3-318° 4 12846-12866 O 12/20/85 3-1/8' 4 12882-12922 O 04/20/83 3-1/8' 4 12928-12958 O 04/20/83 3-1/8° 4 12974-13004 O 04/20/83 3-1/8" 4 13028-13048 O 11/18/82 3-1/8" 3 13064-13084 O 11/18/82 PBTD 13360' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 13404' TD 13420' DATE REV BY COMMENTS DATE REV BY COMMENTS 01/25/83 ORIGINAL COMPLETION 08/05/08 RWJ/PJC TREE REPLACBu1ENT (07/29/08) 01/03/01 SIS-SLT CONVERTEDTOCANVAS 12/11/09 MSE DRLGCORRECTIONS 01/30/01 SIS-LG REVISION 10/27/01 RN/TP CORRECTIONS 08/05/08 BSE/JPJC SET DSSSV (07/26/08) 5-1/2" OTIS XA SLIDING SLV 121$4' -'~5-1/2' BOTPBRASSY I 12204' 9-5/8" X 5-1/2' BOT PKR WffH 7" MOE 12215' S-1/2" x 4-1/2" xo 1230$' -j4-1/2" OTLS XN NIP, ID= 3.725" 12162' ELMD TT LOGGED 1 /6/85 FISH - 20' MAGNETIC DECBVTRALQER I PRUDHOE BAY UNfi WELL: 13-21 PERMIT No: 82-053 API No: 50-029-20789-00 SEC 14, TION, R14E 1898.51 FEL 3095.2 FNL BP Exploration (Alaska) SA FEN NOTES: 13-21 ® 2024' 5-1/2" OTIS ROM SSSV NIP, O = 4.562" w/5-1/2" ROY DSSSV (07/26/08) • TREF = FMC WELLHEAD= GRAY ACTUATOR= BAKERC KB. ELEV = 84' BF. ELEV = ? KOP = 2100' Max Angle = 60 ~ 13300' Datum MD = 12784' Datum TV D = 8800' SS 13-3/8' CSG, 72#, L-80, ID = 12.347" 11 Minimum ID = 2.3" @ 12100' TOL 3-1/2" 5-1/2' TBG-PC, 17#, L-80, LT&C 8RD AB MOD, IPC, 0.0232 bpf, ID = 4.892" 13-21 Ai Proposed CTD Sidetrack • 5-1/2' OTIS ROM SSSV NIP, ID = 4.562" w/5-1/2" ROY DSSSV (07/26/08) ~5-1/2" OTIS XA SLIDING SLV ~ I I 12184' 15-1/2" BOT PBR ASSY I 12046e 9-5/8° X 5-1/2" BOT PKR WITH 7" MOE 12060e 5-1/2" X 4-1/2" XO 50 121 1i13V"Z' D~29BI' 12154e 4-1/2" OTIS XN NIP, ID milled to 3.80' 12166e 4-1/2" SHEAROUTSUB 1216$' ELMDTTLOGGEDI/6/85(corr) 3-1/2" LNR, 9.2#, L-80 STL, .0087 bpf, b = 2.99" 12535' 12535' 3-v2' x 3-3/16° x0 3-3/16" LNR, 6.2#, L-BO TCII, .0076 bpf, ID = 2.80" 12785' 54 12785' 3-3/1s" x 2-7/e• xo 12056e 4-1/2" TBG-PC, 12.6#, N-80, BTC, 0.0152 bpf, ID = 3.958" 12168e TOP OF 7" LNR elmd logged 11 /23/09 12243' 9-5/8" CSG, 47#, L-80 & 500-95, ID = 8.681 " ehnd BHCS 12546' 4 1/2° x 7' w hipstock 12585' PERFORATION SUMMARY REF LOG: BHCS ON 05/18/82 ANGLE AT TOP PEFiF: 54 ~ 12559' Note: Refer to Roduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 65 2-7/8' LNR, 6.4#, L-80 STL, .0058 bpf, ID= 2.44" 13240' T LNR, 29#, L-80, .0371 bpf, ID = 6.184" r-t 13404' DATE REV BY COMMENTS DATE REV BY COMMENTS 01/25/83 ORIGINAL COMPLETION 08/05/08 RWJ/PJC TREE REPLACEMENT (07/29/08) 01/03/01 SIS-SLT CONVERTEDTOCANVAS 12/16/09 MSE PROR~SEDCTDSIDETRACK 01/30/01 SIS-LG REVISION 10/27/01 RN/TP CORRECTIONS 08/05/08 BSE/JPJC SET DSSSV (07/26/08) SAFETY NOTES: PRUDHOE BAY UNfr WELL: 13-21 A PERMrr No: API No: 50-029-20789-01 SCE 14, TION, R14E 1898.51 FEL 3095.2 FNL BP F~cploration (Alaska) f ~. Page 1 of 1 r Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, May 26, 2010 2:48 PM To: 'Hubble, Terrie L' Subject: RE: 13-21 P & A time line? (PTD 182-053) Terrie, You have verbal approval to continue sundry operations on the P & A for DS 13-21. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Hubble, Terrie L [mailto:Terrie.Hubble@bp.com] Sent: Wednesday, May 26, 2010 2:33 PM To: Schwartz, Guy L (DOA) Subject: RE: 13-21 P & A time line? Hi Guy, The Sundry had a start date on it for May 15th... all the pre-rig work has taken place up to the point where the Sundry is required to perform the work. The Slope is just waiting on this approval to finish up the pre-rig work. For us, this one fell through the cracks because we should have followed up with you folks before now. The Slope has the "space" to complete this work now, if it isn't too much trouble, we would like to receive a verbal approval to proceed. Thanks! Terrie From: Schwartz, Guy L (DOA) [maitto:guy.schwartz@alaska.gov] Sent: Wednesday, May 26, 2010 2:28 PM To: Hubble, Terrie L Subject: 13-21 P & A time line? What is the timing exactly. We wilt have commissions to sign tomorrow. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 5/26/2010 MEMORANDUM • State of Alaska • Alaska Oil and Gas Conservation Commission TO: ~ DATE: Tuesday, December I8, 2007 Jim Regg ~ ,~~~ ~ l ~ ~ )j ; f~ SL`BJECT: Mechanical Integrity Tests P.I. Supervisor BP EXPLORATION (ALASKA) INC ] 3-21 FROM: John Crisp PRUDHOE BAY UNIT 13-Z1 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By, P.I. Suprv J=~'"- Comm Well Name: PRUDHOE BAY UNIT 13-21 API Well Number: 50-029-20789-00-00 Inspector Name• John Crisp Insp Num: mitJCr071217100031 permit Number 182-053-0 Inspection Date: IZi16i2007 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 13-21 Type Inj. ~ W I TVD 8540 ,.~~ IA 160 ~ 2510 ~~ 2500 2480 2460 P.T. 1820530 ~TypeTest I SPT i TeSt pSl 2135 °~ I~QA i 60 i 260 - ~ 260 260 i 240 Interval aYRTST p~F ,.I~ f Tubing ~ laoo laoo ~ laoo I laoo ~ laoo Notes• 6 bbPs pumped for test. Pressure not stabilized. Retest required r • ~~yy ~~ ii r~ ~'LJ~D`iS d~~ qq ~j ~~}}g ~ 2 L~UtI Tuesday, December 18, 2007 Page 1 of 1 MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission !I DATE: Tuesday, December 18, 2007 To~ Jim Re P.I. Supervisor ~ ~~~~~ ! ~ ~~ ~ ~0 ~ SUBJECT: Mechanical Intea ity Tests BP EXPLORATION (ALASKA) INC 13-21 FROM: John Crisp PRUDHOE BAY UNIT 13-21 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv J%~n NON-CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT 13-21 API Well Number: so-o2~-20789-00-0o Inspector Name: John Crisp Insp Num' mitJCr071217100510 Permit Number: 182-053-0 Inspection Date: 12/16/2007 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ 13-21 Type In]. ~ W ~~ TVD 840 ~~ IA ~ ?460 I 2510 ~ 2500 ~ ?500 P.T. ~ 1820530 TypeTest ~ SPT ~ 'l'est pSl ~ 2135 / OA '~ 240 ~ 240 ~ 240 ~ 240 Interval 4YRTST p~F P `' Tubing j laoo ~ taoo laoo laoo ~ '-- L NOteS' -1 bbl pumped for retest. ~l~~~1 ~~~~~t ,1C ~ ~ (~ ~V~~' Tuesday, December 18, 2007 Page 1 of I i It ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay I PBU / Drill Site 13 12/21/03 Anna Dube Witnessing declined by John Crisp Packer Depth Pretest Initial 15 Min. 30 Min. Well 13-21 Type Inj. F TVD 8,540' TubinQ 1,300 1,300 1,300 1,300 Interval 4 P.T.D. 1820530 Type test P Test psi 2,135 Casing 360 2,500 2,450 2,430 P/F P Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi CasinQ P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover a = Other (describe in notes) SCA¡~ir\ijEJr} DEC ~ 1 2003 MIT Report Form Revised: 06/19/02 MIT PBU 13-21 12-21-03-1.xls ARCO Ahska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-6-92 REFERENCE: ARCO CASED HOLE ??-- //12-s 1-~ 1-18-92 1-34-92 1-18-92 2-8-92 1-26-92 1-26-92 1-20.92 2-7-92 2-3-92 1-26-92 13-16 13-19 3-9-92 17-1 1-~ Production Profile ~ 1, 5" ~tatie Tempemtur~ RXm 1, InJ Profile Run 1, Lesk Detect Run 1, Leak Detect Run 1, Prod Profile ~ 1, 5" Prod Profile Run 1, 5" InJ profile ~ 1, InJ profile Run 1, Inj Profile ~ 1, Inj Profile Run 1, Prod Profile l~m 1, Prod Profile Run 1, Canlco Camco Camco Camco Camco Camco Please sign and return the attached copy as receipt of data. RECEIVED BY ~___ Have A Nice Day! RECEIVED Sonya Wallace ATO- 1529 /APR 0 1 1992 ~Oll & Gas Cons. Commission APPROVED _.~v, Anchorage Trans# 9205~-I # CENTRAL ~ # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL ' * The Run Date on this_ log is 1-23-92. #PHILLIPS PB WEIJ, FII,ES R&D # BPX # STATE OF ALASKA TEXACO STATE OF ALASKA ALASKA ( AND GAS CONSERVATION CO(' :ISSIONO REPORT OF SUNDRY WELL OPEHATIONS 1. Operations performed: OperatiOnpull tubingShUtd°wn~Aiter casingStimulate RepairPlUggingwell ~ Perforate Xother 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2523' FSL, 106' FEL, Sec. 14, T10N, R14E, UM At top of productive interval 2273' FSL, 2581' FWL, Sec. 18, T10N, R14E, UM At effective depth At total depth 2187' FSL, 3174' FWL, Sec. 18, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic 6. Datum of elevation(DF or KB) 84' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-21 9. Permit number/approval number 82-53 10. APl number 50 - 029-20789 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 13420 feet Plugs(measured) true vertical 9211 feet Effective depth: measured 13350 feet true vertical 9175 feet Junk(measured) None Casing Length Size Cemented Measured depth True vertical depth Conductor 75' 20" 360 sx 75' 75' Surface 2513' 13-3/8" 2500 + 400 sx 2513' 2482.9' Production 12579' 9-5/8" 500 + 300 sx 12579' 8754' Liner 1109' 7" 350 sx 13404' 9193' Perforation depth: measured 12559-12590', 12720-12738, 12744-12764, 12774-12784, 12796-12806, 12815-12835, 12846-12866, 12882-12922, 12928-12958, 12974-13004, 13028-13048, 13064-13084. true vertical 8743-8800, 8836-8846, 8850-8861, 8866-8872, 8879-8884, 8889-8900, 8906-8917, 8925-8946, 8950-8965, 8974-8989, 9002-9012, 9021-9031 Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 PCT @ 12215', 4-1/2", 12.64t, N-80 PCT @ 12320' MD Packers and SSSV (type and measured depth) BeT Packer @ 12204' MD; Otis RQY SSSV @ '~024' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) JAN 2 2 't~9~ Treatment description including volumes used and final pressure J!~15~1 0J| & ~aS ~S. ~~ Reoresentative Daily Averaoe Produ~ion or Ink.ion 0~t~ ~~ OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 22730 1550 Subsequent to operation 22750 1425 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil__ Gas__ Suspended__ Service Water Injection 17. I hereby certify that the forego/j~ is true and correct to the best of my knowledge. Signed ~ (~/Ik"/~//"~ Title Senior Engineer Form 10-404 Rev 06/15/88 cc: S.Wallace/DS Eng Date f~/~o/~ ?.~ SUBMIT/IN DUPLICATE SAG RIVER WELL 13-21 PERFORATING COMPLETED 12/27/91 · · . . Rigged up E-line unit and pressure tested lubricator. RIH with perforating guns and tied in to Reference Log. Perforated the Sag River interval 12559'-12590' (Ref. BHCS 5/18/82) at 4 SPF. RD ELU and returned well to injection. RECEIVED JAN 2 2 1~92 Alaska 0il & Gas Cons. Core. lin 1. ~400 ff~J 3. SO00 FSI 4 4. SO00 ffSl 4 1/6" fLOW TUe[ P~CK-M'f' 2 ': "R E'CE'IV ED JAN 2 2 t~92 Oil & ~as Cons' Anchorage ARCO ALASKA, INC. F'.O. BOX i0e360 ANCHORAGE, ALASKA 995i~ DATE' REFERENCE' ARCO CASED HOLE .FI.I~:_$./ 2-29-9i C..CL/PERF~' ' 2-26-9 t CCL/PERF 2-26-91 CCL./~'~K~ 2-26-9i CUL/PERF ~ / . 2-27-9J 2-28-9 i CCL/F'ERF -- RUN t, 5' ATLAS RUN i, 5' ATLA£ RUN t, 5' ATLAS RUN t, 5' ATLAS RUN t~ 5' A'JL~ RUN i, ~" AIL~$ RUN i, 5' AiLA~ RUN i, 5' ATLA~ RUN t, 5' ATLAS PLEASE SIGN AND RETURN THE ATTACHED COF'Y AS RECEIPT OF DATA. R ECE!VED BY __~_ HAVE A NICE DAY! $ONYA WALLACE AT0-t529 DISTRIBUTION CEIVED AF"F'ROVED',~Jd'.~ '~ JAN 2 1 199~ TRAN$¢ 92j~08 ..... Alaska 011 & Gas Cons. Commission Anchorage CENTRAL'FILES CHEVRON D&M EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS PB WELL F:'ILE~ R & D BF'X STATE OF ALASKA TEXACO * THE CORRECT AP'iS FOR t",R~':~'-~:.'i I~' ALASKA(V_ AND STATE OF ALASKA GAS CONSERVATION APPLICATION FOR SUNDRY APPROVA 1.-':--.~ype of I:~quest:' 2. Name of Operator ARCO Alaska, Inc. Abandon Suspend Opera~on shutdown Re-enter suspended well Alter casing ~ Repair well Plugging .... Time extension SlJmulate Change approved program Pull tubing Variance Perforate X 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2523' FSL, 106' FEL, Sec. 14, T10N, R14E, UM At top of productive interval 2273' FSL, 2581' FWL, Sec. 18, T10N, R14E, UM At effective depth At total depth 2187" FSL, 3174' FWL, Sec. 18 T10N, R15E, UM Other 6. Datum of elevation(DF or KB) RKB 84' feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-21 9. Permit number 82-53 10. APl number 50 - 029-20789 11. Field/Pool Prudhoe Bay Oil Pool 5. Type of Well Development Exploratory Stratigraphic Service 12. Present well condition summary Total depth: measured true vertical 13420 feet Plugs(measured) 9211 feet Effective depth: measured 13350 feet true vertical 9175 feet Junk(measured) None Casing Length Size Cemented Measured depth True vertical depth Structural . Conductor 75' 20" 360 sx 75' 75' Surface 2513' 13-3/8" 2500 + 400 sx 2513' 2482.9' Intermediate . . Production 12579' 9-5/8" 500 + 300 sx 12579' 8765.1' Liner 1145' 7" 350sx 13404' 9203' Pedoration depth: measured 12720-12738,12744-12764,12774-12784,12796-12806,12815-12835,12846-12866, 12882-12922,12928-12958,12974-13004,13028-13048,13064-13084. true vertical 8847-8857,8860-8870,8876-8881,8887-8893,8898-8908,8914-8924,8933-8955, 8958-8974,8982-8998,9011-9021,9030-9041 Tubing(size, grade, and measured de~h) 5-1/2",17#,L-80 PCT@12215';4-1/2",12.6#, N-80 PCT@12320' MD Packers and SSSV (type and measured depth) BeT Packer @ 12204' MD; Otis RQY SSSV @ 2024' MD 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch X ,,,, 14. Estimated date for commencing operation 15. Status of well classification as: December 1991 16. If proposal was verbally approved Oil ..... Gas __ Suspended Name of al)prover Date approved Service Injector 17. I hereby certify that the fore,~lo{ng is true and correct to the best of my knowledge. Signed "~'~~ O,,,~~~Fel ] / Title WellworkCoordinator R COMMI~RION U~l= ONLY Conditions of approval: No fl~ommission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10----- Approved by order of the Commissioner .... · ~' · OfllG)N)J- SIGNED BY LON~,JtE C. SMITH commiSsioner Date Form 10-403 Rev 06/15/88 c: SW SUBMIT IN TRIPLICATE WELL 13-21 PERFORATING PROCEDURE 1. MIRU ELU and test lubricator. 2, 1 Perforate the Sag. River interval 10559'-10583' MD, (Ref. BHCS 5/18/82) at 4 SPF. . RD ELU. 4 2 1. SO00 PSi '/' W[LL~ COFI~CI'OR IrLAhG[ 2. 5000 PSi 4 1/1&". PIPE: RAMS- 3. SO00 PSI 4 1/t"-mORJUJLC SLPS 4. SO00 PSI 4 l/l' SHr.~ RAMS ~,. sooo PSI 4 1ir BLmO K4US S. SO00 PSI 4 1/11" STUFFING BOX 4 2 .]IKL!NE ,,,,BOP 1. SO00 PSI.'" tlKLLH~ COflN[¢10R 2. SO00 PSi WIR[LIN[ RAMS (VARIABL[ 3. SO00 PSi. 4 1/l," LUBRICATOR 4. ~OO PSI 4 l/e- fLOW lull: PACK- TO: THRU: ~ Lonnie C. Smith Commt s s ioner DATE: FILE NO: TELEPHONE NO: · sUBJECT: July 1, 1990 JT.DA.726 Safety Valve Tests AAI PBU Drillsites Prudhoe Oil Pool FROM: Doug Amos. ,~ Petroleum Inspector Tuesday June 19, 1990: I traveled this date from Anchorage to AAI's PBU to stand by for the safety valve retests on the following .drillsites: 2-5,9,11-13,15,17 and Lisburne L1. wednesday June 20 thru Monday June 25, 1990: The testing commenced each morning at 7:00 a.m. and was concluded each evening at 7:00 p.m. I shut in the following wells because of a second failure on equipment that failed on the initial test: DS9-4, 11 and 33, DS 13-21, DS17-4 and 7. All wells shut in with the exception of well 17-4 were repaired and retested by me on 6/23-'and 6/25/90. I checked on well 17-4 before leaving PBU on 6/25/90 and wireline work to replace the SSSV was still in progress. An AOGCC safety valve test report for all dril.lsites retested is attached along with a report for the retests of the shut-in wells. The following is a list of the equipment retested and the resulting failures: " .. Pilots Tested - 18 Pilots Failed - 0 , SSV's Tested - 22 SSV's Failed - 3 $SSV's Tested - 38 SSSV's Failed - 7 In summary, I witnessed the'safety valve retests at AAI PBU Drillsites 2-5,9,11~13,15,17 and Lisburne L1. PAOlg. AOoCC SAFETY VALVE TEST REPORT ...... , ..... ' ,I, ,, Ii , . , I .. . I_1 I .... I . , II I "' I ' ' . I-I I. ~ ........ I_1 I .... II I .... . ....... I _ I .... I_1 'FIELD: OPERATOR: A WELL I PERHIT NUHBER". I NUHBER I REHARK$= INSPECTOR ARCO Alaska, Inc.~ ~" Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager January 18, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 13-21 Permit No. 7-493 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work per- formed on the above-referenced well. Very truly yours, D. F. Scheve DFS/JMV/jp Attachment cc: Standard Alaska Production Company Pi(DS 13-21)W1-3 WELLS/102 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C , STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COM , 31ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] StimulateX Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator A~CO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of wellatsurface 2523' FSL, 106' FEL, Sec. 14, T10N, R14E, UM 5. Datum elevation(DF or KB) 84' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number 13-21 Feet At top of productive interval 2273' FSL, 2581' ~3_,, Sec. At effective depth 18, T10N, R14E, UM At total depth 2187' FSL, 3174' FWL, Sec. 18, T10N, R14E, UM 11. Present well condition summary Total depth: measured 13420' feet true vertical 9211 ' feet 8. Approval number 7-493 9. APInumber 50-- 0?~-?nTRq 10. Pool Prudhoe Bay Oil Pool Plugs (measured) Effective depth: measured 13350 ' feet true vertical feet 9175' Casing Length Size Structural Conductor 75 ' 20" Surface 2513 ' 13-3/8" Intermediate Production 12579 ' 9-5/8" Liner 1145' 7" Junk (measured) Cemented Measured depth True Vertical depth 360 Sx 75' 75' 2500 + 400 Sx 2513' 2482.9' 500 + 300 Sx 12579' 8765.1' 350 Sx 13404' 9203' Perforation depth: measured 12720-12738'; 12744-12764'; 12774-12784'; 12796-12806'; 12882-12922'; 12928-12958'; 12974-13004'; 13028-13048'; true vertical 8837-8846'; 8850-8861'; 8866-8871' ;8878-8883'; 8888-8899'; 8905-8916'; 8925-8946'; 8949.-8964'; 98.73-8988': 9Q02-9.Q12' ' ~UD~ng ~s~ze, graoe anameasurea aeptn} ; 9021-9031 12815-12835'; 12846-12866'; 13064-13084' 5~", 17#, L-80 PCT @ 12215' MD; 4½", 12.6#, N-80 PCT @ 12320' MD Packers and SSSV(type and measured depth) ~T Pnrkpr @ l??~&' Hn~ n~ ~Q¥ RR~v @ 2024' 12. Stimulation orcementsqueeze summary Attached Intervalstreated(measured) 13. Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data.j OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tu bi r)g,.pressure , .:.,. ~.&~ r,~,,,~.~ .... 8500 0 ............. :/.. ~', ...... ~200 Prior to well operation Subsequent to operation 20600 0 1200 14. Attachments Daily Report of Well Operations'~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ Signed Form 10-404 Rev. 12-1-85 WELLS/102 JMV Date/~/n,~''~' '~' Submit u~ate ~ DS 13-211 SELECTIVE STIMULATION ARCO Alaska INC. performed the following stimulation treatment on DS 13-211 on December 13 and 14, 1987: 1. MIRU pump trucks, transports, and CTU. 2. RIH w/inflatable coil tubing packer and set the packer at 12969' CTMD. 3. Stimulated the Interval from 12974' to 13084' MD through CT as follows: A. 1000 gals of xylene B. 2000 gals of 15% HCI C. 3200 gals of 12% HCI/3% HF D. 2000 gals of 7.5% HCl F_ 300 gals of 2% NH4Cl w/400# OSR F. 1500 gals of 15% HCI G 2400 gals of 12% HCl/3% HF H. 1500 gals of 7.5% HCI I. 25 bbls diesel w/10% EGMBE 4. Released inflatable CT packer. POH w/packer. 5. RIH w/inflatable coil tubing packer and set the packer at 12840' CTMD. 6. Stimulated the interval from 12720' to 12835' MD through CT as follows: A. 1000 gals of xylene B. 2500 gals of 15% HCI C. 4000 gals of 12% HCl/3% HF D. 2500 gals of 7.5% HCI E. 400 gals of 2'/0 NH4Cl w/400# OSR F. 2500 gals of 15% HCl G 4000 gals of 12% HCI/3% HF H. 2500 gals of 7.5% HCI I. 25 bbls diesel w/10% EGMBE 7. Released inflatable CT packer. POH w/packer. 8. RD and released equipment. 9. Placed well on water injection. ARCO~ALASKA, INC~ P~O. BOX ANCHORAGE, ALASKA DATE: t-5-88 REFERENCE: ARCO CASED HOLE FINAL 7-i2 t2-28-87 £PINNER TEMPERATURE RUN t2-27-87 ~PINNER TEMPERATLIRE RUN t, 5" t6-7 i2-28-87 PUMP-IN TEMPERATURE RUN Pl..EASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT Of DATA, ,DCH $CH .~CH RECEIVED BY HAVE A NICE DAY! PEGGY BENNETT AT0-t529 TRAN$ ~88GtG APPROVED DISTRIBUTION CENTRAl- FILES CHEVRON D&M EXTEN.~ION EXF'I...ORAT I ON EXXON MARATHON MOBIL° F'HII_I...IP$ PB WELL PIi..EX £AF'C ~TAT~ OF ALASKA TEXACO ........ [ STATE OF ALASKA ALA~.,...A OIL AND GAS CONSERVATION COt[ ~SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown []/ Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] StimulateI~ Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator AECO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2523' FSL, 106' FEL, Sec. 14, T10N, R14E, UM At top of productive interval 2273' FSL, 2581' FWL, Sec. 18, TiON, R14E, UM At effective depth At total depth 2187' FSL, 3174' FWL~ Sec. 18~ T10N~ R14E~ UM 11. Present well condition summary Total depth: measured 13420 ' feet true vertical 9211 ' feet Plugs (measured) 5. Datum elevation (DF or KB) 84 ' REB feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number 13-21 kJ2- 8. Permit number 82-53 9. APInumber 50-- 029-20789 10. Pool Prudhoe Bay Oil Pool Effective depth: measured 13350 ' feet true vertical 9175 ' feet Casing Length Size Structural Conductor 75' Surface 2513 ' Intermediate Production 12579 ' 9-5/8" Liner 1145 ' 7" Perforation depth: measured 12720-13084' (11 intervals) true vertical 8847-9041.4' (11 intervals) Junk (measured) Cemented Measured depth True Vertical depth 20" 360 Sx 75' 75' 13-3/8" 2500 + 400 Sx 2513' 2482.9' 500 + 300 Sx 12579' 8765.1' 350 Sx 13404' 9203' ~bing(size, grade and measured depth) 5½", 17#, L-80 PCT @ 12215'; 4½", 12.6#, N-80 PCT @ 12320' MD Packers and SSSVltvpe,and measured dept~ BOT Packer @ 12204 MD; Otis RQY SSSV @ 2024' MD 12.Attachments Description summary of proposal [] Detailed operations program 13. Estimated date for commencing operation July 1987 Oas C commission Anchorage, 14. If proposal was verbally approved Name of approver Date approved 15. I hereb~ certify Nat the foregoing is true and correct to the best of my knowledge Signed ~/7¢,-~~///4/~~ Title Operations Engineering Manager Date Conditions of approval Approved by Commission Use Only Notify commission~ so representative may witness I ^~o~a, ~o. ~ ~Z/?£ [] Plug integrity [] BOP Test [] Location clearance '~ by order of ~ (:::~ ~l~ Commissioner the commission Bat Form 10-403 Rev 124-85 WELLS/102 TPA Submit in triplicate~ DRILL SITE 13-21i DESCRIPTION OF PROPOSED WORK ARCO Alaska, Inc. intends to perform a stimulation treatment on DS 13-21. The treatment will be performed as follows: le Ensure that the water injection rate and pressures are known prior to the treatments. me MIRU CTU. RIH w/3-3/8" inflatable coiled tubing packer, hydraulic disconnect and tubing tail locator. Correlate to E-line depths. Set packer at 12966' MD. 3. MIRU pump trucks and transports. 4. Pump stimulation fluids through the coiled tubing as follows: 80 g. h. i. 2000 gals of 15% HCl 3200 gals 12% HCl-3% HF 2000 gals 7~% HC1 600 gals of 2% NHAC1 water w/400# of oil soluble resin diverter 1500 gals of 15% HC1 2400 gals of 12% HCl-3% HF 1500 gals of 7½% HC1 25 bbls of diesel 100 bbls of seawater 0 Release inflatable packer. Put an injection at 10,000 BWPD. POH with packer. e RIH 3-3/8" inflatable coiled tubing packer, hydraulic disconnect and tubing tail locator. Correlate to E-line depths. Set packer at 12874' MD. Ye MIRU pump trucks and transports and stimulate down the wellbore as follows: a, g. h. i. 2500 gals of 15% HC1 4000 gals of 12% HCl-3% HF 2500 gals of 7~% HCl 500 gals of 2% NHAC1 with 500# of oil soluble resin d~Si~t[~11~ 2500 gals of 15% HC1 4000 gals of 12% HCl-3% HF ~0G 0 4 lS87 2500 gals of 7~% HC1 25 bbls of diesel '~Bk~0||& ~as~ons. C, ommisslo~ 400 bbls of seawater ~$h0F~ 0 Release inflatable packer, put on injection at 10,000 BWPD. POH with packer. 9. Obtain representative injection rates and pressures. WELLS/102 6 5 4 3 2 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAMS 5. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX CO ! LEDTUB ! NG: UN ! TBOP EQU ! PI, lENT II IIII II! IIIF II ARCO ALaska, Inc. I::'~0. Box tOOS60 Anchor.~ge, A DATE: d t~ L y t 6, t 98? REFERENCE: ARCO Cased Hole Final 3-9 7-t 2-87 CET 5- t ? 5-22-87 Yet t i £ ocj t-.t0 '7-t 3-87 CET 3-2t 7-t~-87 Spinner Profi[e I::'Lea~e .sign and return the at'~ached Ruin t, 5" Run Run t , 5" Run t ,. 5" copy am' receipt of data. $ch Dre~ $ch ..~ c h Received By. HAVE A N ICF DAY! Ro~anne Peek ATO-t 52~ TRAN$ :~87~69 Approvecl ........................................................... ~' D I ,~ T R I B I] T I 0 N Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, In~ Prudhoe B~ Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager June 16, 1~87 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 13-21 Permit No. 7-14 Dear Mr. Chatterton: Attached is the Report of Sundry Well formed on the above-referenced well. Very truly yours, D. F. Scheve DFS/JLB/jp At tachment cc: Standard Alaska Production Company Pi(DS 13-21)W1-3 Operations detailing work per- ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing ~ Other [] 2. Name of Operator ARC. C) A1 ~ ~'1~:~. T'n~. 3. Address P. O. Box 100360, Anchora~;e, AK 99510 4. Location of well at surface 2523' FSL & 106' FEL, Sec. 14, TiON, R14E UM At top of productive interval ' 2273' FSL & 2581' FWSL, Sec. 18, T10N, R14E, UM At effective depth 2201' FSL & 3075' FWL, Sec. 18, T10N, R15E, UM 5. Datum elevation (DF or KB) 84 ' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 13-21 Feet 8. Approval number 7-14 9. APl number 50-- n?q-?.D789 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 13360 feet Plugs (measured) 9170 feet Effective depth: measured true vertical 13253 feet Junk (measured) 9117 feet Casing Length Structural Conductor 75 ' Size Cemented Measured depth True Vertical depth 20" 36 Sx 75'' 75' Surface Intermediate 2513' 13-5/8" 2500 + 400 Sx 2513' 2475' Production 12579' 9-5/8" 500 + 300 Sx 12579' 8754' Liner 1109 ' 7" 350 Sx 13404' 9203' Perforation depth: measured 12720-12738' 12744-12764' 12774-12784' 12706-12806' 12815-12835' 12846-12866' 12882-1292 ' 12928-12958' 12974-1300 ' 13028-1304 ' 13064-13084 ' true vertical 8836-8989 ' Tubing (size, grade and measured depth) 5½", L-80 @ 12320', 4½" Tailpipe, N-80 @ 12320' Packers a_nd SSSV (type and measured depth) BOT 3-H_Permanent Packer @ 12204', Otis RQY SSSV @ 2024' 12. Stimulation or cement squeeze summary Intervals treated (measured) See attachment Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Injection well 10,000 BWIPD 1,800 BWIPD Water-Bbl Casing Pressure ~bing Pressure 1000 psi 500 psi 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-404 Rev. 12-1-85 WELLS/26 J. L. Brady, ATO-1504, 263-4245 Submit in Duplicate DS 13-21 SAND PLACEMENT FOR PROFILE MODIFICATION 3/10/87 3/12/87 3/29/87 4/9/87 4/9/87 4/11/87 4/19/87 5/1/87 2 WELLS/26 Tag PBTD at 13191' with slickline. Ran pre-treatment injection spinner. Indicated 100% of injection entering thief perforations 12881-12922'. Pumped four stages of sand-gelled water slurry. Total sand pumped: 8000 lbs 20/40 mesh sand 600 lbs 100 mesh sand Only minor pressure increases (+300 psi) when sand reached formation. Produced water injection rate before and after treatment was 10,000 BWPD at 1000 psi surface injection pressure. Switched to seawater injection. Slickline tag run indicated PBTD was 13269' indicating all of the sand went into the formation. Pumped second sand treatment down 5~" 2 tubing in three stages. Total sand: 5500 lbs 12/20 mesh sand 5500 lbs 20/40 mesh sand 2200 lbs 100 mesh 5 sx silica flour Second treatment total sand: 13,2000 lbs. Some reduction in injectivity was observed after each stage entered formation. Total reduction was from 9400 BWPD at 750 psi to 3500 BWPD at 750 psi. Injectivity improved within 8 hours to 6400 BWPD at 750 psi and then after 2 days, the well was back to 9000 BWPD at 750 psi. Tagged sand top at 13006'. Left 5900 lbs of sand in rathole and, therefore, placed 7300 lbs of sand into formation. Injection spinner indicated 100% of injection still entering thief at 12882-12922'. Tagged hard PBTD at 12996'. Soft fill at 12903'. Pumped third sand treatment down 5½" tubing. Stages 1 - 3: 1500 lbs 12/20 mesh sand 1500 lbs 20/40 mesh sand 1000 lbs 100 mesh sand 5 sx silica flour 875 lbs bentonite Stage 4: 1500 lbs 12/20 mesh sand 1500 lbs 20/40 mesh sand 1000 lbs 100 mesh sand 5 sx silica flour 1200 lbs bentonite DS 13-21 Sand Placement (Cont.) 5~2~87 Third treatment total sand: 16,000 lbs Some reduction in injectivity was observed as each stage entered the formation. Largest reduction was with 4th stage. Total reduction was from 10,000 BWPD at 750 psi to 1100 BWPD at 750 psi. Tag PBTD at 12787'. Left 4900 lbs of sand in wellbore and placed 11,100 lbs in formation. Total sand pumped in three treatments: 37,800 lbs. Total sand left in wellbore: 10,800 lbs. Total sand placed information: 27,000 lbs or 45 bbl~ or 250 ft- Injectivity has increased some since 3rd treatment. Current injection (6/3/87) is 1800 BWPD at 500 psi on seawater. WELLS/263 ARCO Alazka, Inc. P.O. Box tG0360 Anchorage, Alaska DATE: Hay 13, t787 REFERENCE: ARCO Cazed Hole Final t -28 ~ 4-22-87 2-8 4-t 3-87 3-.5) 4- t 0-8'? .3-22 4-i 5-87 3-22 4-29-87 · 3-25 4- t 5-87 3-25 4-.t 6-.87 4-t7 4-t t-87 6-22 4- t 9-87 <5-23 4-2O-87 9-4 4-22-87 9-6 4-3-8'7 ?..-28 4-t 6-87 t t-t 4-2O-87 t t -t O 4-t '7.-.87 t t-t 5 4-t 8-87 t 3'2t 4-20-87 t:3-2.5 4-25-87 t 3-32 4-t 9-87 t 4-20 4-5-87 t4-35 4-.6-87 t 6-24 4-6-87 t 8-2 - 4-t 2-87 t8-8 4-..-.--8,' F [owmeter/CCL Run Leak Def,/Temp/Ftowme~er Run Leak Dot, Run FLuid I,D,/GR/Temp J~an Ftop, P.L,(CCL/GR/Temp) Run F [owmefer/GR Run Pump in Tamp, ~urvey Run Inj, F'rofi le Run F [op,P,L, (CCL/GR/Temp) Run F [op,F',L, (CCL/GR/'remp) Run Co[Jar Log (~e~ bridge ping) Run Co[tar & F'erf, Log Run CoLLar Log(~e~ AVA &DW pack) Run Prod, Profile/Flow/Fluid :[,D Pull F Lop,P,L, (CCL/GR/I'emp) Run F top,F',L, (CCL/GR/'remp) Run Inj, Profi te/Ftowme~er Run Inj, F'rofi [e/Ftowme~er Run In j, Profi Le/Ftowmeter Run C H C NL R u n CH CNL Run F Lop · P, L, ( CCL/GR/Temp ) Run Ftowaeler/Temp/FLuid I)ensity Run F'[owmeter/Ftuid Density Run F:'l. ease sign and~t~Jm-Jd~e, tt_tached- copy as rece Received By __ ,, '~Y/I' 5 I.( ~ 'FRANS :~87237 ~ gpprov~d ........ DIX'FRIBUTION of data. · Camco C a h! C 0 Ca mc o $ch Camco C a m c o ~ch ~ch Gear Gear Gear Ca mc o ~ch C a mc o Camco Camco Sch Ech Ech Ca mc 0 · "" Cen+.ra L Fi Le.~ ,,'~ Chevron D&M · .'"' Ex 'tension Exploration ~ Exxon Harm thon ~ MOb i L Phi Ltip$ F'B WeLL Fi [es R & D (" ARCO Alaska, Inc. P.O. Box ~00360 Anchorage, Alaska 995~e DATE: March 27 ~987 ~ REFERENCE: ARCO L.'ased Hole Final :~-t4 ~5-t6-87 F'roduction F'rofi Le Run 4-4 ,~-~ ~-87 GR/CCL Run 4--6 ~-~ 6-87 Inj F'rof i Le Run 4-~:3 3-'~ 3-87 Inj. F'rofi te Run 4-"~ 8 3--. ~ 5 -. 8 7 F:' ~ m p I n T e m p, L o g R u n 7-J 3-7-87 Spinner/FLuid Density Rtln 7-2 3-6-87 Spinner/FLuid I)enxi ty Run 7-5 3-8-87 ,S'p inner Run 7-6 ~-9-'8'7 Sp i ~ner/'l'emp. Run 7-9 ;~-6-8'7 Sp inner/Fluid Dens'i fy Run '7 .... ~ ~ 3- 8- 87 ,.pF~ i n n e r / T e m p, R ~ n 7-~7 3-t~-87 F'roducfion F'rofi [e Run '7 .... t8 ~..-.?-8'7 Spinner/Fluid Density R~n ~3--2~ ~-~2-87 In.j,. Profi[e Run 'l 4-4 "-'~'"' ' ' 3 .,., 8~ 'femp/F'Lowme'[er/F[oid I)en~ity Run , ~8--~ ~-~4-87 I_eak Defect./Diff. Temp/F[ow .Run Ca,lie o Ca ~11c o Camco C a ;~!c o Camco Camco Camco Camco Camco C a m c o Camco C a m c o ~ Camco Camco .. Camco Camco l::'l, ease .,;ign and ret'urn 'fhe a+'ta . HAVE: : e":e i,,edA N .......................................... . 3 DA~~ Alaska 011 & Gas Cons. Commisslo~ '" '~ "' F:'e e k Anchorage Rc.$anne .. A "r0 -..I ..:..., ,?,.. o. T F:A ~' '"' q' " N,... .,,,:. 7 ~ 93 A i:) P r o v ecl ....... ~ ..... l) I $ T R I B U'F I 0 N F:'h i I. L il:::' s F'B We L !. i:;: & D · ,- '1' e x a c (3 Fi les ARCO Alaska, Inc.(' Prudhoe Ba~ ,_,~gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager January 6, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 13-21 Permit No. 82-53 Dear Mr. Chatterton: Attached is the "Intention" Sundry Notice detailing work proposed on the above-referenced well. Very truly yours, D. ¥. Scheve DFS/JL~/]p Attachment cc: Standard Alaska ?roduct±on Company PI(DS 13-2)W5-4 gla,~,ka Oi~ & G~s Cons r,~ . JLB2/57 ARCO A~aska, DY'/'~ STATE Of A LAS KA !~(, ALA , OIL AND GAS CONSERVATION COM · dS ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 84' RKB feet Address 6. Unit or Property name 3.p.O. Box 100360, Anchorage, AK 99510 Prudhoe Bay Unit 4. Location of well at surface 2523' FSL & 106' FEL, Sec. 14, TION, R14E, UM 7. Well number DS 13-21 At top of productive interval 2273' FSL & 2581' FWSL, Sec. At effective depth 2201' FSL & 3075' FWL, Sec. At total depth 187' FSE & 3174' FWL, Sec. 18, TION, R14E, UM 18, TION, R15E, UM 18, TION, R15E, UM 8. Permit number 85-53 9. APl number 50-- 029-20789 10. Pool Prudhoe Bay 0il Pool 1. Present well condition summary Total depth: measured true vertical 13360 feet Plugs (measured) 9170 feet Effective depth: measured true vertical 13253 feet Junk (measured) 9117 feet Casing Length Structural Conductor 75' Size Cemented Measured depth True Vertical depth 20" 36 Sx 75' ' 75' Surface Intermediate 2513' 13-5/8" 2500 + 400 Sx 2513' 2475' Production 12579' 9-5/8" 500 + 300 Sx 12579' 8754' Liner 1109' 7" 350 Sx 13404' 9203' Perforation depth: measured 12720-12738', 12744-12764', 12774-12784', 12706-12806', 12815-12835', 12846-12866' 12882-12922' 12928-12958' 12974-13004'.,.l~Q2,8-13048' 13064-13084' truevertica, ' ' ' I~,~ C~ Tubing (size, grade and measured depth) 5½", L-80 @ 12320', 4½" Tailpipe, N-80 @ 12320' ..]i'~'.: ¢ Packers ~nd SSSV (type and measured depth) ~,.,, ~, ~.~,~,n~ ... B0T 3-H Permanent Packer 0 12204', 0t~s ROY SSSV 0 2024'~..*-~a ~ ~ ¢~ v:n~. ~- ...... ...... 12.Attachments Description summary of proposal ~ Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver 2/15/87 Date approved Approved by 15.1 hereby~qertify that/tThe .f~regp~ng is true and correct to the best of my knowledge /I Signed.~//'~~~ ...... ~ Title 0peration~ I~nginPPr'in~ Commission Use Only Conditions of approval Notify commission so representative may witness ~ Approval No. ~ Plug integrity ~ BOP Test Approved ~' - "'"~ by order of ~ L~[ ~* ~1~ Commissioner the commission Date Form 10-403 Rev 12-1-85 WELLS/26 J. L. Brady, AT0-1504, 263-4245 Submit in triplicate DRILL SITE 13-21i (SAND PLUO) PROFILE MODIFICATION AFE #699047 PROPERTY CODE 2182777-13 Procedure 1. Load 150 bbls of warm produced water. 2. MI & RU CUT, pump truck and blender. 3. Reduce the well's injection rate to 3000 BWPD. 4. RIH with CT and TT locator. Tie in with tubing tail locator. Locate CT nozzle at 12870' MD. 5. Mix 130 bbls of sea water with 220 lbs of HEC, (residual free), gel and breaker. 6. Begin pumping gel while adding sand at 1.5 lbs/gal until all 8000 lbs of sand have been pumped. Pump the 7000 lbs of 12-20 sand followed by 1000 lbs of 100 mesh sand. 7. Displace the sand slurry with methanol water. 8. POOH & RD. 9. Monitor injection rate vs pressure and run spinner survey. JLB2/57 6 5 4 3 2 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAMS ,%. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PS! 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX COILED TUB]Ni3 UNIT BOP EI}UIPMENT ARCO (.:ìiaskò¡ Inc. P.O. Box 100360 Anchorage, ALaska DATE: REFEF:ENCE : ~3-16 -...,¡.t. - 9 ~11 -9 ~12-4d """,1 2 - 5 """""---""" ..., -1"':':'- id ~12-;4 ~12-16 ~13-21 ~ 3-22 August 71 ,~1 99510 ARCO Cased Ho~e F¡naL 1986 4-8-85 -"""'4-4-85 7-'")8-0.t. I .:.. u~. t..-1-8t.. 12-12-85 '(",)-;"'7-8C:: I':" '-' oJ 1 "') -" '7 - Co c:- .:.. I...' U...I ;':>-;1:\_0':::: .... oJ '-' ..., -4 '") - " '") -- 8 c:- I':" I.:.. ...I " .., - ") .~ - 8 c:: I.. .. "" oJ 2-9-85 Co L L a ¡- log CCL Perforating Record Spinner Fluid ID DifferentiaL TeMP Pumpin Completion Record Perforating Depth Perforating Depth Perforating Depth Completion Record Perforating Record EPLog t'.' . , ,; " F\' U ¡- ':) L~" , 1.._, R U '" i. c,:" ! I I _.' Contì-o L j' 0 ¡- t 0_"'" l -' I I U Control ~:: . F: un 1 5" F~un 1 5" ¡:;:un 3 5" F~un 1 :::" Run J 5" Run 1 5:. Run 1 5" ;~un 1 5:" PLease sIgn and return the attached copy as receipt of dataA Rec e ¡'led By --------------Mm E HAVE A NICE DAY! Q/~A~ 1986 Linda Hulce p¡ TO-; 529 T 1:' l', ~J {' .II. C l. fl C) ., It.r-II oW 'D'\..'~'" I.o.¡. Alaska Oil & GdS Cons Commisslor. p. nChnraqe Dr ':::,""'r.;'rHII""rfi;..J - '-' I h - - I - I. Centra l F j tes Chevron D ~'C M Extension Exploration Exxon ..I!. ". .a. ,... -II. V .a. T .L ll' Ma'¡""atr,on ì1ob i l .11, '" Phillips F'E: ~:JelL Files F-~ .~'C D .It, 1 " S'oh ¡.J "'""",,~.~t^....tð-- f"'-A't (:"',- ~~.....<O c-...Q .,.;.. d- "-.;:j .II. -J " T e ::: ,:;¡ c c. ':-' - ~, ~'L I; Sch 0-1: ¡::.: G e ,oj r S'ch Sch Seh Sch Seh Sch Seh ARCO Alaska, Inc. p.O'. Box I00360 Anchorage, Alaska 995~8 DATE' March 27, t986 REFERENCE' ARCO Cased Hole Final DS 6-5 2-~2-86 DS 6-5 i-~.°-85 DS 6-5 ~-9-85 DS 6-5 t - ~ ~ -8.5 DS 6-ii - 2-7-85 DS 6-i t 2-7-85 DS 7-8 i2-28-85 DS 9-i 2-i~ oA DS 9-3 3-i-86 DS 9-t6 2-i-86 DS fi-8 2-3-86 DS i 2-!,~ i i-30-84 DS i2-i 6 -2-i 7-86 F'Lea~e_- _.~igll a'nd l-e,urn Ca [ i per I~nspecl i on Run i 5" CCL/Perf. Record Run i 5" CET Ceme~n~ Eva[ Run i 5' CET Run 2 5 ' CCL/Perf~ Record Run 2 5' CET Run 2 5' F'L$ Rur~ i_,~" Gamma Ray RUn i 5" Gamma Ray Run i 5' I~nj. Spinner Run ~, _.~' Co[Jar Run i ~" ! _ TDT Run ~ ~ ' X-Y CaLiF. er Log R,ln i 5' Sp iht, er Run ! 5' Sp i nr~er Run i 5: · Sp inner R un ~, _:-~" Che a¢¢ached copy as receip¢ of data. C8 ;~iC 0 $ch $ch $ch $ch $ch DA C8 f:lC 0 C8 ~c o Go $ch C8 ~i,.z o Received By HAVE A NICE DAY! irma Car[i~ ATO-i429F TRANS ~862i4 DISTRIBUTION Central Fi Les ~ F'hi LLips Chevron F'B WeLL F'i Les D & M F,' & D ExCensior, ExpLora*ion, ~ Sohio ~ S¢afe of Alaska Exxol~ ~ Marathon ~ Texaco ARCO Alaska, Inc.[.~, Prudhoe Bay ,dineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer January 22, 1986 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 13-21 Permit 82-53 Enclosed is the corrected Completion Report for work done on the above-mentioned well. Very truly yours, D. F. Scheve DFS/SKAD/jj Enclosure cc: SOHIO Alaska Petroleum Co. File Pi(DS 13-21)W1-3 RECEIVED J AN 2 7 1986 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ({,_ AND GAS CONSERVATION CA )IlSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL r-] GAS [] SUSPENDED [] ABANDONED [] SERVICE~ Wa§ Injection 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-53 3. Address 8. APl Number Post Office Box 100360, Anchorage, AK 99510 50- 029-20789 4. Location of well at surface 9. Unit or Lease Name 2523' FSL & 106' FEL, Sec.1/+, TION, R1/+E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2273' FSL & 2581' FWL, Sec.18, TiON~ R15E, UM DS 13-21 At Total Depth 11. Field and Pool 2187' FSL & 317/+' FWL~ Sec.18~ T10N~ R15E~ UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 8~' RKBI ADL 28330 12. Date Spudded 13. DateT.D. Reached 14. Date Comp., Susp. orAband. 115. Water Depth, ifoffshore ,16. No. of Comp,etions /+/25/82 5/19/82 5/2/+/82I JN/Afeet MSL 1 1'/. Total Depth {MD+TVD} 18. PI.ug Back Depth {MD+'TYDI 10. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 13/+20'MD~9211'TVD 13350'MD,9175'TVD YES ~[ NO FR 202/+ feet MD 1750' (aomrox.) 22. Type Electric or Other Logs Run ' ' D~./SP/~HCS/¢R, ~DC/C~/~, CSL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PERFT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" gl .5~ ~-/~O .m,~face 75' 30" 360 _~z AS II 13-3/8' 72.O4~ I,-RO R,r~mn, 9~] q! 17%,! -9500_~x Fend,_, & %00 sx Pa: ~_fro_~t C 9-5/8" &7.05~ L-RO R111"~:,qni~ q957q' 19_~" 500 eY P.~ooo "C" ~- 300 SM Permafrc~_t C - $00-96 7" 29.0# L-80 12295' 13/+0/+' 8]5" t~m .~w C]~ss C 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) 12720-12738 'MD 12815-12835 'MD ";~" 12320' 12209' 127/+/+-1276/+ 'MD 128/+6-12866 'MD 1277/+-1278/+'MD 12882-12922'MD "26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ,,, 12796-12806'MD 12928-12958'MD _.DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 1297/+'1300/+ 'MD N/A 8836-8989 'TVD 13028-130/+8 'MD 1306/+-1308/+'MD All (/+ spf) I~4:. RT4t"~ ~.1 ~-o'~ 27. PRODUCTION TEST Date First Production Meth°d of Operation (Flowing, gas lift, etc.) Wag Injection N/A Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OI L RATIO N/A TEST PERIOD' J~ Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE alF 28. CDR E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED N/A JAN 2 7 1986 ~ 0il & Gas Cons, C0mmissi01 Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit irt duplicate 29. NAME Top Sadlerochit O/W Contact Base Sadlerochit MEAS: DEPTH 12718' 13183' Not Reached TRUE VERT. DEPTH 88z~6 ' 9092' - :FORMATION TESTS ' ' Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt .water disposal, water supply for injection, observation, injection for in-situ combustion. Item'5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, a,nd 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. lng 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, Shi~t-in, Other-explain. _ Item 28' If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc.( Prudhoe Ba~~,-.,gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer January 20, 1986 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 13-21 Permit No. 82-53 DS 13-19 Permit No. 81-180 Enclosed are the "Subsequent" Sundry Notices detailing work completed the above-mentioned wells. Very truly yours, D. F. Scheve DFS/SKAD/jj Enclosure CC: SOHIO Alaska Petroleum Co. File Pi(DS 13-21)Wl-3 File P1 (DS 13-19)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA (~ ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well Surface: 2523' FSL & 106' FEL, Sec. 14, T10N, R14E, UM At Top Producing Interval: 2273' FSL & 2581' FWL, Sec. 18, T10N, R15E, UM At Total Depth: 2187' FSL, 3174' FWL, Sec. 18, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 84' RKB 6. Lease Designation and Serial No. ADL 28330 7. Permit No. 82-53 8. APl Number 5O-- 029-20789 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 13-21 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [~[X Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation on 12-20-85. RU perforating unit and pressure tested equipment. RIH w/gun #1, shot interval 12846-12866' MD (4 spf), flowed well to clean up. Shut-in well, POOH, all shots fired. RIH with gun 92, shot interval 12815-12835' MD (4 spf), flowed well to clean up. Shut-in well, POOH, all shots fired. RIH with gun #3A and gun 93B shot interval 12796-12806' MD (4 spf)and shot interval 12774-12784' MD (4 spf), flowed well to clean up. Shut-in well, POOH, all shots fired. RIH with gun 94, shot interval 12744-12764' MD (4 spf), flowed well to clean up. Shut-in well, POOH, all shots fired. RIH with gun 95, shot interval 12720-12738' MD (4 spf), flowed well to clean up. Shut-in well, POOH, all shots fired. Ran SSSV, Secured well, all shots fired. ~RD. Ref: BHCS 5-18-82 RECEIVFD JAN 2 1986 AlasKa 0il & u~ Cons. ~ui~mJssioll Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Date q~ ~)/~g ,, The space below for Commission use /' / Conditions of APproval, if any: ~'" By Order of Approved by COMMISSIONER the Commission Date Form 10-403 c~_~'~ Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA ~'-AND GAS CONSERVATION Ca /IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERV:~I~E [] Wag Injection 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-53 3. Address 8. APl Number Post Office Box 100360, Anchorage, AK 99510 50- . 029-20789 4. Location of well at surface 9. Unit or Lease Name 2523' FSL & 106' FEL, Sec.1/+, T10N, R1/+E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2273' FSL & 2581' FWL, Sec.18, TiON, R15E, UM DS 13-21 At Total Depth 11. Field and Pool 2187' FSL & 317/+' FWL, Sec.18~ TION~ R15E~ UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0il Pool 8~' RKBI ADL 28330 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions /+/25/82 5/19/82 5/2/+/82I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back'Depth (MD+'FVD) 19. Directional Survey 20. Depth Where SSSV set 21. Thickness of Permafrost 13/+20'MD,9211'TVD 13350'MD~9175'TVD YES ~ NO [] 202/+ feet MD 1750' (approx,) 22. Type Electric or Other Logs Run DIL/SP/~CS/OR, ~C/C~/CR, 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT..PIER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD .AMOUNT PULLED . · 13-3/8' 72.0~ L-80 Sur~mm~_ 9-5/8" Z~7.0# L-80 ,~ur~mc~_ 800-96 7" 29.0t/~ , ~ L-80 12295' 13404' 8~" 350 .~ 24. Perforations open to 'Production (MD+TVD of ToP and'Bottdrh'a6d 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 12720-12738 'MD 12815-12835 'MD 5%" 1~3~0' 12209 ' 127/+/+-1276/+ 'MD 128/+6-12866 'MD 1274/+-1278/+'MD 12882-12922'MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12796-12806'MD' 12928-12958'MD DEPTH .INTERVAL (MD) AMOUNT & KIND OF MAT,ERI.AL USED 8836-8989'TVD 1297/+-1300/+'MD N/A 13028-130/+8 'MD 13064-13084'MD Ail (4 spf) 27. PRODUCTION TEST Date First Production Method of Operation {Flowing, gas lift, etc.} Wag Injection J N/A ' Date .ofN/ATeSt Hours Tested TEsTPRODUCTIONpERIOD ~FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE I] GAS-OI L RATIO Flow Tubing Casing Pressure CALCULATEDai~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of l ithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A R£CEIVFD Alaska 0il & 6as Coa. s. Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE G EC: LOG iC MAR KiER. S " ~ {.;;·. ;..:.~,. ,-i !)f'.4 'i' ESTS ' · NAME Include interval tested, pressure data, all fluids recovered and gravity MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase· ........ Top Sadlerochit 12718' 8846' N/A O/W Contact 13183' 9092' Base Sadlerochit Not Reached 31. LIST OF ATTACHMENTS None ;32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed, ./~Z~ Title Oper.Engr.MgT. Date, Y~¢)/°~¢' 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 on-ly 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 ARCO Alaska, Inc. [' Post OfficeI~ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 5, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 13-15 Permit No. 82-157 13-19 81-180 13-20 82-09 13-21 82-53 13-23A 82-23 13-24 82-65 13-25 82-91 13-32 82-123 Attached are the "Intention" Sundry Notices detailing work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS:JEB:dp Attachment cc: SOHIO Alaska Petroleum Co. File Pi(DS 13-15)W1-3 PI(DS 13-19)W1-3 Pi(DS 13-20) Wl-3 PI(DS 13-21)W1-3 Pi(DS 13-23A)Wl-3 P1 (DS 13-24) Wl-3 Pi(DS 13-25)W1-3 P1 (DS 13-32) W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanflcRIchfleldCompany STATE Of ALASKA o(~M ALASKA OIL AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~X OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-53 3. Address 8. APl Number P.Oo BOX 100360, Anchorage, Alaska 99510 50- 029-20789 4. Location of Well 2523' FSL, 106' FEL, Sec. 14, T10N, R14E, UM (surf) 9. Unit or Lease Name Prudhoe Bay Unit 2273' FSL, 2581' FWL, Sec. 18, T10N, R15E, UM (Top Prod) 2187' FSL, 3174' FWL, Sec.18, T10N, R14E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) 84' RKB 6. Lease Designation and Serial No. ADL 28330 10. Well Number DS 13-21 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. (Submit in Triplicate) Perforate ~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Arco Alaska, Inc. proposes to perforate well 13-21 at selected intervals within the Sadlerochit sand of the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator tested to 1.5 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Ref: Proposed Perforation Intervals: 12720-12738'MD 12815-12835'MD 12744-12764'MD 12846-12866'MD 12774-12784'MD 12928-12958'MD (reperf) 12796-12806'MD 12974-13004'MD (reperf) 13028-13048'MD (reperf) BHCS 5-18-82 I ECEIVED Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby I~,rtify that ttlff foregoing is true and correct to the best of my knowledge. Signed ' Title Operations ~.ng±neor±ng M~jr. The space be~ow for Commission use Date Conditions of APproval, if any: gRIGIIiAL SIJlI[ll .BY LI)J,]HT[ C. SMITH Approved Copy Ileturn~d .. By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Im{'~' Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: February 18, 1985 Reference: ARCO CH Final /'9-16 Injection Profile Survey 1-12-85 Run 1 5" GO j13-21 Injection Profile Survey 1-14-85 Run 1 5" GO J15-7 Gamma Ray Log /,15-8 Gamma Ray Log /15-9 Gamma Ray Log 15-16 Collar Log 15-20 Gamma Ray Log >~14-29 Spinner f14-30 Spinner 1-27-85 Run 1 5" Camco 1-28-85 Run 1 5" Camco 2-4-85 Run 1 5" Camco 1-10-85 Run 1 5" GO 1-25-85 Run 2 5" Camco 2-2-85 Run 1 5" Camco 1-30-85 Run 2 5" Camco P~~lease sign and return the attached copy as receipt of data, Received by Pam Lambert ATO 1429C Trans ~)~ Chevron D & M Expl. Services Ext. Exploration Exxon Marathon Mobil Mobil E & P Phillips PB Well Files R & D Sohio State of Alaska Texaco ARCO A I.a_'-;ka, Inc. P..O. Box t(~OS60 Anchorage, ALa:~ka ...... / t.., F;,' E F E F;,' E N C L':-. ' A R C 0 C a :ii: e d HoLe F inal. s' Received By. .................................... KeLLy M,.-:F:'a~"Land A'T' 0 ..... i..;- '''~ 2'il;' F:' Alaska "l'* l"t A :** I ,II. ;; .' ~ F". l"i t'X JiJ.; 'ii' ;.' . --. D I S "i" R I B U T I 0 C ...?1 iii C] C) [-; 0 I..~. i.j . C a m ,::: (3 DA D A D A D A '::'..;." G. 0 C ,am ,": (::, C a n',. (:: o t::; '] [; 0 [:; ;", [; 0 ;:"; c h [:; 0 (:; 0 ,....r" .:':i hi C 0 !':] ...':~ ,qi C 0 Ch evr o'n Mol:) i L D & H Ho l:)i I. Iii: ~..: F:' Exp Lo'rat ion Ser'v i ce...'.:.' F'h i L L i p.".~ Exten.~ion Exp I.o'ra!' io'n F:"rucli"~c,e T.!.:.-'.',.';.' WeLL E x x o n F;..' ~...- D Ge t t y Soh i o Na'r...':'~'~t';,.'::,n State of ALa.ska F:' i l.e.s ARCO Alaska, Inc. Post Offic~y"'ox 360 Anchorage[, ,aska 99510 Telephone 907 277 5637 April 2, 1984 Reference- ARCO Cased Hole Finals D.S. 3-25 ~'' 12-2-83 ACBL/VDL/Signature/GR D.S. 3-26'" 11-10-83 ACBL/VDL/S ignature/GR D.S. 13-19 /' 12-28-83 EPL D.S. 13-21~' 1-2-84 EPL · D.S. 13-98~'' 3-7-84 CPL/GST Run 3 D.S. 14-7-- 3-3-84 Temperature D.S. 14-36f 1-5-84 CBL/VD Run 1 5" DA Run 1 5" DA Run 2 5" Sch Run 2 5" Sch 5" Sch Run 1 5" Otis Run 1 5" Sch and return the attached copy as receipt of data. HAVE A HAPPY EASTER! Kelly McFarland ATO-1429F Trans. # 124 DISTRIBUTION Chevron D&M Dallas Drilling Ext. Exploration Exxon Getty Marathon Mobil Mobil E & P Phillips Prudhoe Bay Well Files R&D Carolyn Smith Sohio State of Alaska ARCO Alaska, In~" Prudhoe B~, Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F, Scheve Regional Operations Engineer February 29, 1984 Mr. C. V. Chatterton State of Alaska Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: RE: DS 13-6 Permit No. 81-121 DS 13-9 Permit No. 81-158 DS 13-15 Permit No. 82-157 DS 13-16 Permit No. 82-148 DS 13-17 Permit No. 82-26 DS 13-18 Permit No. 82-35 DS 13-19 Permit No. 81-180 DS 13-20 Permit No. 82-9 i~DS 13-21 Permit No. 82-53 DS 13-22 Permit No. 82-77 DS 13-23A Permit No. 82-23 DS 13-24 Permit No. 82-65 DS 13-25 Permit No. 82-91 DS 13-32 Permit No. 82-123 In 1983, several Prudhoe Bay Unit producing wells were converted to injection as part of the Flow Station 3 Injection Project. By review of our records, we have found that intent sundry notices for these conversions were submitted, but no subsequent sundry notices were filed to confirm the conversions. Attached are subsequent sundry notices which provide formal notification of the completed injection well conversions. The dates of the first injection included for each well correspond with data previously submitted in the semiannual progress reports for the Flow Station 3 Injection Project. Very truly yours, D. F. Scheve DFS/RSS/STATE/lmi cc: Sohio Petroleum Company File 100.0 ARCO Alaske, Inc. ts a Subsidiary of At anticRIchfleldCompany STATE OF ALASKA ALASK~ )IL AND GAS CONSERVATION MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-53 3. Address 8. APl Number P.O. BOX 360, Anchorage, Alaska 99510 50- 029-20789 4. Location of Well 2523' FSL, 106' FEL, Sec. 14, T10N, R14E, OM (surf) 2273' FSL, 2581' FWL, Sec. 18, T10N, R15E, UM (top producinc 2187' FSL, 3174' FWL, Sec. 18, T10N, R15E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 84 RKB I ADL 28330 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number r) DS 13-21 12. 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions cm Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. has converted DS 13-21 to a Water-Alternating-Gas Injection well. Th date of first injection was 4/11/83. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .,~_ ~')~. ~/,K~~ Title Regional Engineer The space below for Commission use Date Conditions of APproval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit '~lntentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, inc. Post Offic~...~ox 360 Anchorao~ .aska 99510 Telephone 907 277 5637 February 24, 1984 Reference: Arco Pressure Data D.S. 11-2 ~"-1-18-84 'D.S. 13-19 "-12-28-83 D.S. 13-21'~1-2-84 D.S. 14-14 "~-12-84 D.S. 18-1 ~'~ 2-4-84 2-4-84 PBU Data Sheet PBU Horner Plots w/Listing Horner Plots w/Listing Homer Plots w/Listing PBU · PBU Data Sheet DA Sch Sch Sch Camco se sign and return the attached copy as receipt of data. HAVE A NICE DAY! Kelly McFarland ATO-1429F Trans. f/ 069 Chevron DaM Dallas Drilling Exxon Getty Marathon Mobil DISTBIBUTION North Geolo~ Phillips Prudhoe Bay R&D Caroline Smith Sohio State of Alaska ARCO Alaska, Inc. Prudhoe Bay_ gineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 29, 1983 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 13-6 DS 13-19 DS 13-21 DS 13-24 Permit No. 81-121 Permit No. 81-180 Permit No. 82-53 Permit No. 82 -65 Enclosed are "Subsequent" Sundry Notices detailing work done on the above-mentioned wells. Very truly yours, D. F. Scheve Regional Engineer DFS/JCD/lw Attachments cc: Sohio Petroleum RECEJVE JUL i .§B3 Alaska Oil & Gas Cons, Commissior~ .Anchorage STATE OF ALASKA Ir~ ALASK~ OIL AND GAS CONSERVATIONC~L~MMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL I]~X WAG Injection OTHER E~X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchoraqe, AK 99510 4. Location of Well 2523' FSL, 106' FEL, Sec. 14, TION, R14E, UM (Surf) 2273' FSL, 2581' FWL, Sec. 18, TION, R15E, UM (Top Prod) ?lR7' FSI; .3174' FWI_; Sec; !8: TION; RI~F= lin (Tn) 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 84' RKB I ADL 28330 12. 7. Permit No. 82-53 . 8. APl Number 50- 029-20789 9. Unit or Lease Name Prudhoe Bay'Uni t 10. Well Number D.S. 13-21 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] ' -- Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation 4/20/83. RU perforating unit, pressure tested surface equipment. RIH with gun #1, shot 12986-13006' MD 4 spf (20' ref: CNL 5/31/82). POH--all shots fired. RIH with gun #2, shot select-fire 12976-12986' MD and 12950-12960' MD 4 spf (20' ref: CNL 5/31/82). POH--all shots fired. RIH with gun #3, shot 12930-12950' MD 4 spf (20' ref: CNL 5/31/82). POH--all shots fired. RIH with gun #4, shot 12904-12924' MD 4 spf (20' ref: CNL 5/31/82). POH--all shots fired. RIH with gun #5, shot 12884-12904' MD 4 spf (10' ref: CNL 5/31/82). POH--all shots fired. RD. Ran SSSV. Secured well 4/25/83. 14. I hereby,~ertify that the foregoing is true and correct to the best of my knowledge. Signed .... Title The space below for Commission use Date Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 29, 1983 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 13-6 DS 13-9 DS 13-19 DS 13-21 DS 13-24 DS 14-!3 DS 14-14 Permit No. 81-121 Permit No. 81-158 Permit No. 81-180 Permit No. 82-53 Permit No. 82-65 Permit No. 81-101 Permit No. 81-102 Enclosed are the Completion Reports for work done on the above-mentioned well s. Very truly yours, D. F~ Scheve Regional Engineer DFS/JCD/lw Enclosures cc: Sohi'o 'Petroleum Co. RECEJV'ED AlasKa Oil & Gas Con,';~ Commissior~ Anchorage STATEOF ALASKA ( ALAS . ~.,,L AND GAS CONSERVATION .. .... MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG -i / 1. Status of Well Classification of Service Well f OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE EX WAG _TNJECT_TON U~' 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-53 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 5o-029_20789 4. Location of well at surface 9. Unit or Lease Name 2523' FSL, 106' FEL, Sec. 14, TION, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2273' FSL, 2581' FWL, Sec. 18, TION, RI5E, UM 13-21 At Total Depth 11. Field and Pool 2187' FSL, 3174' FWL, Sec. 18, TION. RI5E. UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 84' RKBI ADL 28330 12. Date Spudded 13. DateT.D. Reached 14. Date Comp., Susp. orAband. 115. WatorDepth, ifof_fshoro 116. No. of Complotions 04/25/82 05/19/.82 05/24/82 N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 13420'MD~9211'TVD 13350'MD,9175'TVD YES[~] NOF-] 2024 feetMa 1750' 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL/GR, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 75' 30" 360 sx AS 11 1~-3/8" 72.0~ L.-80 Surf · 2513' 17-1/2" 2500 sx FOndu & 400 sx Permafrost C q-.~/R" 47_(1~ L-80 & Surf 12579' 12-1/4" 500 sx ClaSs C & 31)0 sx Permafrost ( · S00-96 7" 29.0# L-80 12295' 1'3404' 8-1/2" 350 sx Class C 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) 12882'-12922' MD 4 spf 5-1/2" 12320' 12209' 12928'-1'2958' MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12974'-13004' MD 8925'- 8989' TVD DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED Ref' BHCS 5/18/82 N/A · . 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) WAG. Injection N/A, .... Date of Test Hours Tested ..PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO N/A TEST'PERiOD ~ Flow Tubing Cas:lng Pressure CAL.C.ULATED.I~ OiL:BBL ' G'AS-MCF WATER-BBL OIL GRAVITY-Apl (corr) Press. 24:-HOURRATE !~F ~ : : . . 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. : None :'' ' ' 3UL Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate NAME Top Sadlerochit O/W Contact Base Sadlerochi MEAS. DEPTH TRUE VERT. DEPTH 12718' 13183' Not Reach( 8846' 9092' d Include interval tested, pressure data, al GOR, and time of each phase. N/A fluids recovered and gravity, 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed 2r~ ~-~~~.~~~_~¢~--~ _ Title Regional Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam njection, 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 foF'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 (G L) 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 · ALASI~" STATE OF ALASKA L AND GAS CONSERVATION ~ MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OILY~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, I nc. 82-53 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20789 4. Location of well at surface 9. Unit or Lease Name 2523' FSL, 106' FEL, Sec. 14, T10N, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2273' FSL, 2581' FWL, Sec. 18, T10N, R15E, UM 13-21 At Total Depth 11. Field and Pool 2187' FSL, 3174' FWL, Sec. 18, T10N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 84' RKBI ADL 28330 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 04/25/82 05/19/82 05/24/82t N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)19. DirectionalSurvey [ 20. Depth where SSSV set I 21.Thickness of Permafrost 13420'MD,9211 'TVD 13350'MD,9175'TVD YES ~ NO [] 2024 feet MD 1750' (approx) 22. Type Electric or Other Logs Run D IL/SP/BHCS/GR, FDC/CNL/GR, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 75' 30" 360 sx AS II 13-3/8" 72.0# L-80 Surf 2513' 17-1/2" 2500 sx Fondu & 400 sx Fermafrost C 9-5/8" 47.0# L-80 & Surf 12579' 12-1/4" 500 sx Class G & 300 sx Permafrost C S00-95 7" 29.0# L-80 12295' 13404' 8-1/2" 350 sx 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) 5-1/2" 12320' 12209' None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production i Method of Operation (Flowing, gas lift, etc.) ,,, Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD II~ 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 oit, gas or water. Submit core Chips. None £81 o 1983 Alaska Oil &llr~chora~~as Cons Commission Form 10-407 Submit in duplicate Rev. 7-1-80 GRU1/WC25 CONTINUED ON REVERSE SIDE I NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadl erochit 12718' 8846' 0/W Contact 13183 ' 9092' N/A Base Sadlerochit Not Reached 31. LIST OF ATTACHMENTS Workover Hi story 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ Title Area Dri t 1 ing Engineer)ate 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 c..ompletion), so state in item 16, and in item 24 show the prod~ucing 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 ARCO Alaska, Inc( Post Office~ ..x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 10, 1983 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are monthly reports for January on these drill sites- 1-24 1E-20 7-18 1E-21 7-19 1E-22 7-20 1F-1 12-17 1G-6 12-18 1G-7 13-9 1Y-13 13-98 WSW-IO WSW-11 Tract Well 24-11-14 CIRI Wolf Lake Well Ravik State #1 #1 Also enclosed are well completion reports for: 2-11 1E-23 7-17 1F-2 12-19 1F-3 13-11 1G-8 13-21 WSW-8 13-24 WSW-9 The survey for 2-22 this well will be su We also are includin 13-21 (3 reports), a needs to be reran; a completion report for bmitted when an approved survey is received. g sUbsequent Sundry Reports for 1-24A, 2-11, nd 13-24. ARC-O Alaska. Inc. is a subsidiary of AllanticRichfieldCompany STATE OF ALASKA ALASKA LAND GAS CONSERVATION C v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-53 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 50- 029-20789 4. Location of Well Surface' 2523' FSL, 106' FEL, Sec. 14, T10N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 84' RKB 37' Pad ADL 28330 9. Unit or Lease Name Pru&hoe Bay Unit 10. Well Number 13-21 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10.407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The proposed work described in our Sundry Notice, dated 04/16/82, been performed. Also, the wortc_~is, not scheduled to be done in the immediate future. has no t 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~ Title Area Drilling Engineer The space below for Commission use Date Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA (~'~' AND GAS CONSERVATION CCf' MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 360, Anchorage, AK 4. Location of Well Surface' 2523' FSL, 106' FEL, 5. Elevation in feet (indicate KB, DF, etc.) 67' RKB 12. 99510 Sec. 14 T10N, I 6 . Lease Designation and Serial No. ADL 28330 R14E ,U 7. Permit No. 82-53 8. APl Number 50- 029-20789 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 13-21 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans' [] Repairs Made ]~] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Accepted rig @ 2230 hrs, 01/11/83. Pulled BPV. Circ. hole w/9.8 ppg NaC1. Set BPV. Tstd packoffs - ok. ND tree. NU BOPE & tstd - ok. Pulled tbg hanger & tbg. Latched onto K-anchor & rotated out. POH & LD PBR & K-anchor. Tagged pkr @ 12,246' DPM & milled on it. POH & LD pkr. Ran 5-1/2" completion assembly w/tail @ 12,320', pkr @ 12,209', sliding sleeve @ 12,123' & nipple for SSSV @ 2024'. Tstd tbg hanger - ok. Set- BPV. ND BOPE. NU tree & tstd - ok. Dropped ball & set pkr. Disp tbg to diesel. Closed SS. RIH w/SSSV & set. Closed SSSV. Secured well & released rig @ 2400 hrs, 01/17/83. 14, I hereto the best of my knowledge. Signed f f --- ~ ~' ' '" ~-- Title Area Drilling Engineer The space below for Commission use Date ~//~ Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate 13-21 WORKOVER HISTORY Accepted rig @ 2230 hrs, 01/11/83. Pulled BPV. Circ. hole w/9.8 ppg NaCl. Set BPV. Tstd packoffs - ok. ND tree. NU BOPE & tstd - ok. Pulled tbg hanger & tbg. Latched onto K-anchor & rotated out. POH & LD PBR & K-anchor. Tagged pkr @ 12,246' DPM & milled on it. POH & LD pkr. Ran 5-1/2" completion assembly w/tail @ 12,320', pkr @ 12,209', sliding sleeve @ 12,123' & nipple for SSSV @ 2024'. Tstd tbg hanger - ok. Set BPV. ND BOPE. NU tr~e & tstd-- ok. Dropped ball & set pkr. Disp tbg to diesel. Closed SS. RIH w/SSSV & set. Closed SSSV. Secured well & released rig @ 2400 hrs, 01/17/83. JG:sm 01/31/83 GRU1/WH5 STATE OF ALASKA · ALASKA LAND GAS CONSERVATION C ,~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~XX OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-53 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20789 4. Location of Well Surface= 2523' FSL, 106' FEL, Sec. 14, T10N, R14E, UN 5. Elevation in feet (indicate KB, DF, etc.) 84-1.' RKB 12. I 6. Lease Designation and Serial No. APL 28330 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 13-21 11. Field and Pool °Prudhoe Bay Field Prudhoe Bay 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Spudded well @ 0915 hrs, 04/25/82, Drld 17-1/2" hole to K0P (~ 1400' TVD, Picked up jetting assembly; jetted and drilled 17-1/2" hole to 2532'; ran, cmtd & tstd 13-3/8" csg. Drld 12-1/4" hole to 12,590'; ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 13,250'; ran logs; continued drlg to 13,420' TD. Ran, cmtd & tstd 7" csgo Ran 5-1/2" completion assembly° Secured well & released rig @ 1330 hrs, 05/24/82° F'EB i o 1982 Alaska Oil~,~ ~' Gas Cons: Oommissior.~ ,Anchorage 14. I hereby certify th. at the foregoing is true and correct to the best of my knowledge. Signed Title Area Dri 11 ing Engineer The space below for Commission use Date Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 6RU1/SN30 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 360 Anchorage,[ .~ka 99510 Telephone ~ 2.77 5637 January 6, 1983 RE: ARCO Cased Hole Finals D.S. 13-21 11-24-82 Temperature Survey D.S. 14-19 11-25-82 Spinner D.S. 15-14 11-26-82 Spinner D.S. 11-7 12-5-82 Spinner Run 1 Camco Camco Camco Camco Please sign and return the attached copy as receipt of data. Becky Benedict AFA- 403 Transmittal #016 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfietdCornpan? ARC;Ct ~i~ka, Ir~c. Post Office Box 360 Anchorage. ,¥ .... '~a 99510 Telephone 90~ ..77 5637 January 3, 1983 RE' ARCO Cased Hole Finals D.S. 13-13 12-7-82 Radioactivity Log Run 1 D.S. I3-21 .12-4-82 Perf. and Collar Log Run 1 D.S. 6-3 11-29-82~ CH CNL Run 7- d(leasesi§n and return the attached copy as receipt of data. Camco Camco SCH Becky Benedi ct AFA- 403 Trans. #006 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON ARCO Alaska. Inc, is a Subsidiary of AtlanticRichfieldCompan~, EXXON MOBIL GETTY .D&M STATE OF ALASKA DALLAS Alaska Oil & Gas Cons. Anchor;~ge ARCO Alaska, Inc. {r Post Office Bo~ ,~60 Anchorage, Alaska 99510 Telephone 907 277 5637 January 5, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' DS 13-21 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose repairing the communciation between the production tubing and casing. Since we estimate starting this work on January 11, I983, your prompt approval will be appreciated. Sincerely, M. A. Major Area Drilling Engineer MAM/JGL21' 11 m Enclosures RECEIVED JAN 0 5 1983 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ,LAND GAS CONSERVATION C ,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL I~ COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-53 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20789 4. Location of Well Surface: 2523' FSL & 106' FEL, Sec. 14, TION, R14E, UM Bottom Hole: 2187' FSL & 3174' FWL, Sec. 18, TION, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 67' RKB 6. Lease Designation and Serial No. ADL 28330 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 13-21 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [~[X Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to repair the communication between the production tubing and casing. A leaky packer is suspect. The 5-1/2" completion string will be pulled and the packer milled. The well will be recompleted with the original 5-1/2" plastic-coated tubing and the necessary provisions for subsurface safety equipment. A 13-5/8", 5000 psi, RSRRA BOP stack will be used on well work performed by the workover rig. The BOP equipment will be pressure tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Approximate start date: January 11, 1985 oo ~or~Xt 1,~o. '"'-- JAN 0 1983 /~aska Oil & Gas Cons, Oomr~/Ss/or~ ~chorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~~'~ Title Area Dril ling Engineer The space below for Commission use Date Conditions of Approval, if any: Approved by BY L~iE g. ~glllt COMMISSIONER Approved Zopy Returned By Order of the Commission Date Form 10-403 Rev. 7-1-80 GRU1/$N9 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc.#'~[' Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Re: D.S. 13-9 D.S. 13-21 Permit No. 81-158 Permit No. 82-53 Enclosed are "Subsequent" Sundry Notices detailing work done on the above-mentioned wells. Very truly yours, DFS/TKKW/1 mi Attachments cc' Sohio Petroleum RECEIVED DEC2 9 1982, Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~(x OTHER [] 2. Na~oOP/~O~ka, Inc 7. Permit No. · 82-53 8. APl Number 3. Ad~re~. . BOX 360, Anchorage, Alaska 99510 5o- 029-20789 4'k°~"35f~L, 106' FEL, Sec. 14, TION, R14E, UM (surf) 2273' FSL, 2581' FWL, Sec. 18, TION, R15E, UM (top producinc 2187' FSL, 3174' FWL,.Sec. 18, TION, R15E, UM (TD) ,, 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 84' RKB I ADL 28330 12. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number :) D.S. 13-21 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [X]X Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation 11/17/82 RU perforating unit, pressure tested surface equipment. RIH with gun #1, shot 13066-13086' MD, 4 spf (20' Ref: CNL 5/31/82). Opened well to tank. No measureable fluid was produced. POH - all shots fired. RIH with gun #2, shot 13030-13050' MD, 4 spf (20' Ref: CNL 5/31/82). Produced some completion fluid to tank before well died. Perforating operations were suspended and Well 13-21 was shut-in. RECEIVED DEC 2 9 1982 Alaska 0il & Gas Cons, C0m~iissi0n Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ........ Title Regional Engineer The space below for Commission use Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 . Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Prudhoe B<' ~gineering Post Office b,.,x 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer November 22, 1982 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re· , D,S. 13-6 Permit No. 81-121 D.S. 13-9 Permit No. 81-158 D.S. 13-15 Permit No. 82-157 D.S. 13-16 Permit No. 82-148 D.S. 13-19 Permit No. 81-180 D.S. 1~-21 Permit No. 82-53 D.S. 13-22 Permit No. 82-77 D.S. 13-23A Permit No. 82-23 D.S. 13-24. Permit No. 82-65 D.S. 13-25 Permit No. 82-91 D.S. 13-32 Permit No. 82-123 Attached are "Notice of Intention" Sundry Notices work proposed on the above-mentioned wells. Very tr.uly yours, D. F. Scheve DFS/TKKW/lmi. Attachments cc' Sohio Petroleum RECE V'ED DEC 0 8 i~82 Alzska Oi{ & Gas Cons. Anchorage ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2' N a-"~oOp~r~ ~°~ k a, Inc. 3. Ad~r:s~). BOX 360, Anchorage, Alaska 99510 4. Location of Well 2523' FSL, 106' FEL, Sec. 14, TION, R14E, UM (surf) 2273' FSL, 2581' FWL, Sec. 18, TION, R15E, UM (top producinc 2187' FSL, 3174' FWL, Sec. 18, TiON, R15E, UM (TD) Elevation in feet (indicate KB, DF, etc.) 84 RKB 6. Lease Designation and Serial No. ADL 28330 7. Permit No. 82-53 8. APl Number 5o- 029-20789 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number ) DS 13-21 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [~X Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO,Alaska, Inc proposes to convert this well to Water-Alternating-Gas Injection service. Injection will be into the Sadlerochit; surface piping and instrumentation have been installed as necessary for injection. A downhole safety valve will remain in service in this well following the initiation of injection. A non-freezing fluid was left in all uncemented annuli within the permafrost interval. 14. I hereby,F,,eftify that the f~egoin~q, is true and correct to the best of my knowledge. Signed _ . _ . _. Title Regional Engineer The space below for Commission use Date Conditions of Approval, if any: Approved by Approved Copy Returned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc Post Office...× 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 8, 1982 Mr. C. V. Chat Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Re' D. S. 13-18- Permit No. 82-35 D. S. 13-20 - Permit No. 82-9 D. S. 13-17- Permit No. 82-26 D. S. 13-24 - Permit No. 82-65 D. S. 13-25 - Permit No. 82-91 D. S. 13-9 -Permit No. 81-158 · D. S. 13-21 - Permit No. 82-53 Attached are "Subsequent" Sundry Notices detailing work done on the above-mentioned wells. Very truly yours, D. F. Scheve Regional Engineer DFS'MAM:mlc Attachments cc' Sohio Petroleum Co. NOV 0 9 i982' Alaska 0il & Gas Cons. Commisaio.,,-, Anchorage '; ~<;~, ~,~,~,-,ka. Inc is a s~b.~idiary of AllanticRichfieldComp3ny STATE OF ALASKA ALASKA L AND GAS CONSERVATION C ~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-53 3. Address 8. APl Number P.O. Box 360 Anchorage, AK 99510 5o-029-20789 4. Location of Well 2523' FSL, 106' FEL, Sec. 14, TION, R14E,_UN (surface) 2273' FSL, 2581' FWL, Sec. 18, TION, R15E, UM (Top-Producing) 2187' FSL, 3174' FWL, Sec. 18, TION, R15E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) RKB 84' 6. Lease Designation and Serial No. ADL 28330 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 13-21 11. Field and Pool Prudhoe Bay 'Field Prudhoe Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate IX]. Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10~407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate selected intervals within the Sadlerochit Sand in this Prudhoe Bay Unit well. Upon perforating, the well will be flowed to a tank for clean-up and evaluation. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to working pressure. The SSSV will be installed at the conclusion of the perforating' and clean-up operation. Proposed perforation intervals' 13064' - 13084' MD 12882' - 12922' MD 12928' - 12958' MD 12974' - 13004' MD 13018' - 13048' MD Ref: BHCS 5-82 RE£EJVED NOV 0 9 ],982' Alaska 0il & Gas Cons,CoJnm~sm~,~' ' Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed z~~ _~_~~f-'~ Title RegiOnal Operations Enaineer The space below for Commission use Date Conditions of Approval, if any: Approved by COMMISSIONER ApprOved ::opy [~,eturned By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Anchorage. Alaska 99510 Telephone 907 277 5637 August 24, 1982 Reference: D.S. 13-2i' D.S. 13-24 · D.S. 13-25 Arco Magnetic tapes 5-18-82 DG SWF field tapes DG SWF field tapes 7-2-82 DG SWF field tapes 5-16-82 ACC 65407 Ru n~l~ ACC 65410 Run ACC 65411 D.S. 2-23 8-16-82 OH tape and listing ACC 65465 Run 1 D.S. 18-3 8-13-82 OH tape and listing ACC 65454 Run l&2 D.S. 14-22 6-6-82 OH tape and listing ACC 65170 Please sign and return the attached copy as receipt of data. Run'l Kelly McFarland Trans. # 417 ,Z DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS. SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M GEOLOGY STATE OF ALASKA DALLAS ARCO Alaska, Inc. Post Oflice Be .;0 Anchorage. AlasKa 99510 Telephone 907 277 5637 August 9, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton' Enclosed are monthly reports for July on these drill sites' 2-25 13-25 18-3 2-26 13-30 1E-15 6-17 13-33 1H-3 6-18 14-21 1H-4 6-19 18-2 Also enclosed are three subsequent sundry reports for Kuparuk 1H-5 and completion reports for' ~I'3~21 15 13-24 18-1 13-26 1E-14 14-17 1H-5 14-22 /.5'-_5- The gyroscopic survey for DS 2-22 needs to be reran; a com- pletion report for this well will be submitted when the approved survey is received. Sincerely, P. A. VanDusen Regional Drilling Engineer PAV/JG-sm Enclosures AUG 1 o 1982 Alaska Oil & Gas Cons. ComrnlssiOi/ A~chorage GRU]/L61 ORIGINAL WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OILY~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, inc. 82-53 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20789 4. Location of well at surface-- 9. Unit or Lease Name 2523' FSL, 106' FEL, Sec. 14, TION, R14E, UM ~LOCATiONSI Prudhoe Bay Unit At Top Producing Interval ~ VERIFIED ~ 10. Well Number 2273' FSL, 2581' FWL, Sec. 18, T10N, R15E, UM iSur~. ~__~_~[ 13-21 At Total Depth JB.H. ~----~ 11. Field and Pool 2187' FSL, 3174' FWL, Sec. 18, T10N, R15E, UM -~ Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) J 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 84' RKBJ ADL 28330 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore I 16. No. of Completions 04/25/82 05/19/82 05/24/82 N/A feet MS LI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey [ 20. Depth where SSSV set I 21. Thickness of Permafrost 13420'MD,9211'TVD 13350'MD,9'I'/5'TVD YES IjX-I NO [] nipple @2095feet MD 1750' (approx) 22. Type Electric or Other Logs Run D IL/SP/BHCS/GR, FDC/CNL/GR, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ZU" ~J1.5# H-40 Surf 75' 30" 360 sx AS II 13-3/8" 72.0# L-80 Surf 2513, 17-1/2" 2500sx Fondu & 400 sx Perinafrost C 9-5/8" 47.0# L-80& Surf . 12579' 12-1/4" 500sx Class C S00-95 7" 29.0# IL-80 12295' 13404' 8-1/2" 350sx 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) None 5-1/2" 12308 ' 12229' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A ,, : : 27. N/A PRODUCTION TEST Date First ProductiOn 1 Meth°d of. Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEsT pERIOD I~ Flow Tubing Casing Pressure CALCULATED .l~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITYIAPI (corr) '~ ' Press. 24IHOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None . Form 10-407 Submit in duplicate Rev. 7-1-80 GRU1/WC17 CONTINUED ON REVERSE SI DE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadl e rochi t 12718' 8846' N/A O/W Contact 13183' 9092' Base Sadlerochit Not Reached 31. LIST OF ATTACHMENTS Drilling_ History, Gyroscopic Survey_(2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ Title Area Drilling Enginee~ate, ¢/~/'(~d~ 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 pertine.nt 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. DS 13-21 Drilling History NU 20" Hydril & diverter. Spudded well @ 0915 hrs, 04/25/82. Drld 17-1/2" hole to 2532'. Ran 61 jts 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2513'. Cmtd 13-3/8" csg w/2500 sx Fondu & 400 sx Permafrost C cmt. ND 20" Hydril & diverter. Pumped 75 sx Fondu cmt top job. Instld 13-3/8" packoff & tstd to 5000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 2000 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg. Drld 12-1/4" hole to 12,590'. Ran 314 jts 9-5/8" 47#/ft, L-80/SO0-95 BTC csg w/shoe @ 12579'. Cmtd 9-5/8" csg w/500 sx Class G. Instld 9-5/8" packoff & tstd to 50(~0 psi - ok. Tstd csg to 3000 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 13,250'. Ran DIL/SP/BHCS/GR & FDC/CNL/GRf/13250'-2513'. Cont drlg 8-1/2" hole to 13420' TD (05/19/82). Arctic packed 9-5/8" x 13-3/8" annulus. Ran 27 jts 7" 29#/ft, L-80, BTC liner f/12,295'-13,404'. Cmtd 7" lnr w/350 sx Class G cmt. Drld cmt to 13,~0' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1. Ran CBL. Ran 5-1/2" completion assy w/tail @ 12308' & pkr @ 12229'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Dropped ball & set pkr. Tstd tbg to 3000 psi & annl to 200 psi - ok. Tstd tbg to 200 psi & annl to 3500 psi - ok. Nipple for SSSV set @~']~. Instld tree cap & tstd to 5000 psi - ok. Secured well & released rig @ 1330 hrs, 05/24/82. Gyroscopic survey ran 07/11/82 JG: 1 lm 08/06/82 GRU1/DH1 ' . :.[~[ .,7~-:1/-.lil~-' "'J-' ':':'~' "-"' '.7608Highlander Drive '1- ~~1 I :' ' ':'.:.. -' .:.AnChorage;·:Alaska 99502 ~, \~......~/ ..: .'..'...:.. '" -:' .:(907) 349,3'114' . · . May 20, 1982 Mr. Jack' Messner Arco Alaska, Inc. P.O; Box 360 Anchorage, AK 99501 RE: Magnetic Single Shot Survey Job No. 0582-019 Well Drill Site 13 - 21 Prudhoe Bay Field North Si.ope, Alaska Date' of Survey: 4-23-82. to 5-19-82 .Dear Mr. Me.ssner: Ple~ find enclosed the "Original" and six (6) copies of our Mag~tic Single'.Shot Su~vey °n the above well.' The method used ~klculat. ing this survey, was Radius of Curvature. The depth of the survey was 13.00 12,590. · Thank you for giving us this opportunity to be of service. Yours very truly, Controlled Drilling Consultants Dale. He,ndrix Directional Supervisor RECEIVED' JO.M _ 8 ~982 A~aska Oil & Gas Cons. 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DRIFT VERTICAL' .~,UI~, .~ DRIFT ~TOTAL COORDINATES '~ C L 0 S U R E .S SEVERITY SECTION DEPTH AHGLE DEPTH: ~ ~ SEA DIREC~':~ 4627 54 0 411'5,07' 4031.07 N88.OOE 292,'22 N;:.'--~I409.:I9 E 1439.17 N 78 l? 5 E ,274 1412.72 , .j. . 5147 53 45 ..4421 ,63 4337,,-63 NeS,80E 306,~=87 N ~1828.95 E 1854,52. N 80 28 30 E .048 1832.63 5669 52 0 . 4736.67 4652,67 'SeV',OOE ~?'.::,:~::::' ::,:::.''-.:~-{:.:~.: ~ :~::~.:.::~:~,.~' ::~-. ,.:., ~:~::: '.:~.' ?;.",,::~' '~:..'.-~... '.~.~:::~ ...~: ~:``~::~:::~y~:~:::~`~.:~.~:~.`~.:.~:?~:~`~;~:~?[:.F~.~::~::?~`~;~:~;?~;~ ............................... ........ ........ '; .......... 7943 57 '30 6041'38 5957,'30 ~SSS,00E 257,19 N. 4!02.82 E 4110.88 N 86 24 47 E .488 4105.71 8445 59' 0 6305.45'~ 6221.45 S88,00E 242.29 N ~; 4529.43 E 4535.90 N 86 56 16 E ,299 4532.09 10259 53 0 7302,2e 7210,28 SS9,OOE 195.62 N 107'15 52 '15 7'579,08 7495.018 S86.00E ,' 179',81 N 6404.80 E 6407',33 N 88 23 :30 E tt269 50 0 7926.7'6 ?842,?6 NVO,OOE 164,76 N 6835.7,2 E 6837.71 N ee 37 9 E :. :.. :.::.....,¥..:..:.: :.:, ,:..:. :. ~...,..:............:: :.,. :..: ,: .: .:: ..:.-. ;. :.~,..:.. :, .: ..~, ...: :.:~,.....,¥. :...... :.., :c. ::.::, :. ,...,:.p,, :: .:. :...:,. ,..;~.::. ::,.?. j..~:.. ,.,..:c,x.>~..,.:.,,. ~.:~;.::.:~. :,~x,,.:.....:.:.:,.-..: ?.~..:~.:?.....:~. ~..,.........~........~.....,.~..,,.,.,.....,. .......... ~ ................... : ...... ., .., ..,.. ,. ~..-...-,-.. ,.,.... ~,.,.....~., ~..,...??...¢~::~ ................. ..:. ~ ,-, ~?.,..~,? ,.....? ....q ?~.-.. ,...-.....~... ~..~. -.. ?.,......~. ,?.~.~.~,.....:....~ ?..,.:....,.:........,.-.......~,.. ~. c.....~........ :, :..,.., .,.:., :~.:....,.:.....,.:,,:,..,.,.:.~..,, :,.:, ,..,.:. · .... BOTTOH HOLE CLOSURE [~857.79 FEET AT N 89 17 14 E . , , : , ~ . - ~ ,~.;.}.~,.~...,.~..:.,......,.,....~,..? ~,~. ,,.. ,....~.......~,,.... ~ !.,........., .~ ........... ,....~ ....... [.; ,...,...,.., ....... ..... ,......, ............ .443 64 0~4 · 587 683~ .-)4 · ., · · 2729 2684. 2600 3296 3~84. 3100 2618 2584. 2500 34 44 97 3200 '127 il' la4 : 184. i 100, 0 , 0-: '-: -. '.O0'S .00 W ' · 284 284, 200 0 ':i' 0::':: · ,00 S ,00 W ~ ...... ' ................... ~"~"~' ................. ' ................................... :':":'":':':'"~'~"~"~'"':' ................................ :'~'"'6"~'""~ .................... =:'6 ................................................. :'"'~':':'"""~:: .......... :"':"::~=?'~:'":'7::?"~'":':':'':= ........................... ':' ....................... '" ":'"':"' .... 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I t . , , ~~ ' ' ~ ] i t I t 4 I I I { { I I .] t 1'4 : { ] t:l I J ........... :,i_':~ii~? :'~,~ ~i:i_ ~l: it : : {ii t ~ ~ ' _ l..l'Ji J !-~ ' I ~ ~ ~ I ~ : ~ I ~ t 1 I I .~ t ~ t ] ~ 1 ~- i ~ I I I I' [ Ii · , - .... . ' - ' ' ' :': ' ', : ~ { ~: ~ I : i ~ : t ' { "!:: .. . EPT~8~ , ! -I ~ ~ 1'! 'I]] ~ ( ili~ .... ; t {... , I i i 1 I ] t .~ i ~ I t ~ !-I {,.I i. t I i t: I ! 11{1 ' .... ~ 'i ~ August 2, 1982 Mr. Bob Hines ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No.: Boss-16081 Well: 13-21 (SECl4 T10N R14E) Prudhoe Bay Field North Slope~ Alaska Survey Date: July 11, 1982 OPerator: John Samec Mr. Hines: Please find enclosed the "Original" and one (1)~ copy of our Boss Qfroscopic Multishot Directional Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Kirk Afflerbach District Supervisor Ka/jr Enclosures Z;~.. ---- ~.-,~,r-~-~,, r'- .~ ~---.' ....... ,'...'~...'--'~,.--T ~ .~.'..~'~ ,~.~--r~.~ C~ ~ ~ ,---,--,~n ,..,~ ~,,,~ ~,n~ ~' ,--' -.' ..-, '--,~,~-"~'~"-.', *".-. ~."-.',~**-~ F:'RLI[;U-'.tOEJ E~:~,Y ~ ~ ~ ~ ,JULY Z ~:, ~ '~':D2 dOD i~ILIHDER DC[$:~;- ~ 60:3 i F~L.(~SI-:::A B° ~ ~ KELLY BUE;I"'IINC~ E:L. EV. . ..... .... r;'r. B ' F]F'~: ~:' ~' TE'5"-S~EC ........................................................ : .... 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O:L :3 ::-': :':: , 9:":: S :3546.0:3 E F"BTD t34,20 '.;,'2.1.1,00 9127,00 336,12 S 0559.71 E TOTAL DEF'TH DRILLER © © 0 i~:-?~!i~': ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::~::::}::~::::}::::::::::::~::~}}~[[:::::~::::~:::~::::~}::::~::~::::~}::~::::~::::::~::::::~::~::~::::~::::~:~::~}~::}~:::::::::::::::~::::::::[~::::::::::::::::~::~::::::~::~::::::~::::~::::~::::::[:~::::::~::~::::::~::::::~::~::~::~}::::~::~::::~::}:~::~::}~::::}::::~:::::::~::::::}::~}~::[::}}::::::~::::::~::::~::~::}::[::::::~.:::::}:*~:~::~::~::::::::}::}::::}}::~::::~}~::~}::::~::~:::::~::~::~:::; 'd?~ ?i ::::::::::::::::::::::::::::: iil:: :~i::~.i~::~i!~i::i~ ~::~::i:,!::i~::!~i::~i::::i::i::::::~ ~ii!i!i::~ ~i:: ~:. ~rl TI I I~ '--~ I ! ~r'~ I ~ *.~1 ifil I I & I.* '--~--~i II Ir"Il E 1::1'-~ t VED IJS Z NG D Z L DEF TIDE; ~ND ::,F Ehk ~ TRUE NORTH SURFACE: LOCASTION (2757FNL 0106FEL -! O~O. O0 -1000,00 ARCO Alaska, Inc. Our Boss Gyroscopic Survey Job No.: Boss-16081 Well: 13-21 (S~Cl4 T10N R14E) Prudhoe Bay Field North Slope, Alaska Survey Date: July 11, 1982 Operator: John Samec Scale: 1" = 1000' -2ooI].'oo ............. ~OOI~.O~~ 6n_O~. On_ '~OO~l. oo 800~. O0 HOR I ZONTRL PROJECT-ii ON' 0.00 2000.00 4000.'00 8000.00 ZO000. O0~ AROD Alaska, Inc. Our Boss ~yroscopic Survey Job No.: Boss-16081 Well: 13-21 (S~Cl4 T10N R14E) Prudhoe Bay Field North Slope, Alaska Survey D~te: July 11, 1982 Operator: John Samec Scale: 1" = 2000' 8566.31' @ S870 45' E 13420 2o5o. oo 4o~o. oo eo~o. oo ~ol~o. oo ~o~ooo. oo VER T I CRL PRIZIJE C T I ON Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. Operator, Wel 1 Name Number Reports and Materials tO be received by: _~- ~. 3 Date Required Date Received Remarks Cc~pletion Report Yes. ~/~ ~k_ Lf'x~t"~ _ · -samp, z~s 'i///'~-P / · D N , · , . ~ r e ~ ip s ~~.~~. ' ...... '614~ · , , , , Core ~scription ..... -- - , .ngistere~ ~'¢>~ ~~ .' .... ~. Inclination Su~ey ~~ ~ ,~ , Drill Stm Test Re. ms ~d ~:~ ~: ~ '~ ....... ~u~ion T~t Re~s ~ r ~S R=' Yes ~ --'~-Z-- ~ l~4~' , .... ~ , ARCO Alaska, Inc. Post Office Box 360 Anchorage, Alaska ~51f Telephone 907 277 5637 August 5, Reference: 1982 Arco Directional Surveys D.S. 13-25 7-13-82 D.S. 13-26 6-17-82 D.S. 18-1 6-30-82 Gyroscopic Multishot Gyroscopic Multishot Gyroscopic Multishot Gyroscopic Multishot SS EW SS SS Please sign and return the attached copy as receipt of Kelly McFar land Trans. $ 344 data. :.:2 Di'STEIBUTION NORTH GEOLOGY R&D; DRILLING S~MIO? MARATHON CHEVKON:- ARCO Alaska, Inc. is a sul3sidlary of AtlantlcRIchfleldCompany EXXON MOBIL GETT~ · D&M.: GEOLOGY STA~K OF ALASKA. · ECE VED AUG -6 Abska Oil & Gas Cons. Co~rnissior~ Anchorag~ Post Office Box 360 Anchorage,/,'~qska 9S$10 Telephone. ~ 277 5637 July 29, 1982 Reference: ARCO OPEN HOLE FINAL LOG D.S.13-21 5/18/82 Density Neutron-GR Run 1 2" NOTE: This log was not included in original shipment of open hole logs on 13-21 Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 326 DEST~IBUTION, NORTH GEOLOG~ R&D' DRILLING PHILL1T~' S8HIOr: MARATHON' CHEVRON ARCO Alaska, Inc. is a subsidiary of AtlanticRichfietdCompany EXXON. MOBIL GETTI D&M~ GEOLOG"f AUG-.. 3 i982 Alaska Oil & Bas Cons. Post Office Box 360 Anchorage, ~ ka 99510 Telephone 905 ..77 5637 July 23, 1982 Reference: ARCO CASED HOLE FINAL LOGS D.S.12-9 7/6/82 D.S.13-21 5/31/82 D.S.15-11 6/28/82 D.S.15-14 6/27/82 D.S.i-13 7/5/82 D.S.1-9 6/3/82 SPinner Run 1 5" CNL Run 1 5" Collar & Perf Log Run 1 5" Collar & Perf Log Run 1 5" Collar & Perf Log Run 1 5" EPL Run 1 5" Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 301 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M ~ GEOLOGY STATE OF' ALASKA ARCO Alaska, Inc. Post Office~;~=~x 360 Anchorage,~,. ~ska 99510 Telephone 907 277 5637 July 23, 1982 Reference: ARCO OPEN HOLE FINAL LOGS D.S.13-21 5/18/82 D.S.13-21 5/18/82 D.S.13-21 5/18/82 D.S.13-21 ~/18/82 D.S.13-21 5/19/82 D.S.13-21 5/18/82 Dens Neutron(Raw) Run 1 (2~J &/5'~ · Dens Neutron(Poros) Run 1 ~ !~to follow soon) DIL/GR Run 1 BHCS Run 1 ~ Cyberlook Run 1 Sonic Waveforms Run 1 Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 299 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GEOLOGY ARCO Alas k .,'~ A;',..;'io, age, Alas^,; :;uS 10 Telephone 90.7 2?7 $63? June 30, 1982 Reference: ARCO CASED HOLE FINAL LOGS D.S.2-15/ 5/21/82 D.S.2-11'/ 5/20/82 D.S.13-21v 5/23/82 D.S.13-24-/' 5/2i/82 D.S.14-9B v,' 4/16/82 D.S.2-20'-/ 4/8/82 D.S'.2-21''~ 4/27/82 D.S.6-2~/ 4/29/82 D. S. 6-1g~/ 4/30/82 D.S.7-1 4/29/82 D.S.12-7A~z 4/25/82 Perf Record & CCL D.S.12-8B.~. 4/3/82 Collar Log for Perforation D.S.13-21J 4/28/82 EPL Run 1 5" D.S.14-3~/ 5/2/82 CNL Run 4 5" D.S.15-4/ 4/26/82 CNL Run 1 5" DS..15-4~ 4/8/82 4 Arm Caliper Run 1 5" D.S.15-~' 4/t9/82 CNL/GR/CCL Run 1 5" CNL Run 2 5" CNL Run 2 5" ACBL/VDL/GR Run 1 5" ACBL/VDL/GR Run 1 5" CBL/VD Run 1 5" CNL/GR/CCL Run 1 5" CNL Run 1 5" CNL Run 4 5" CNL Run 4 5" CNL Run 4 5" Run 1 5" Please sign and return the attached copy as.receipt of data. Run 1 5" Mary F. Kellis North Engineering Transmittal # 247 DI'STRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO' MARATHON CHEVRON EXXON MOBIL GETTY D&M GEOLOGY /-7 r.; ,. ........... .~-- f'~.! ~ ~ .... ',:,, ~ & :.: Post Ollice Box 360 Anchorage, Al~,~ka 99510 Telephone 90 7 5637 June 10, 1982 Reference: ARCO MAGNETIC TAPES & LISTS D.S.15-6 5/28/82 Tape # 65134 D.S.13-21 5/31/82 Tape #65135 Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 225 DI'STRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILI~IPS D&M ~31~I0 ' GEOLOGY m RATHON CttEVRON ARCO Alaska, Inc. Post Office Bo ;0 Anchorage, Alaska 99510 Telephone 907 277 5637 June 8, 1982 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are monthly reports for Play on these drill sites' 1-9 13-26 2-21 14-17 2-22 14-22 2-24 15-5 ~s>1~3 ~ 2! '.~ 15-6 13-22 1H-6 13-24 1E-12 Also enclosed is a well completion report for Kuparuk 1E-11. Sincerely, P. A. Van Dusen Regional Drilling Engineer PAV/JG:llm Enclosures GRU1/Li$ ARCO Alaska. Inc s a ,",~J1~.idiary of Atlan/icRichlieldCompany STATE OF ALASKA , ALASKA('_ AND GAS CONSERVATION MISSION MONTHLY REPORT DRILLING AND WOR'KOVER OPERATIONS ;1. Drilling well [~ Workover operation [] 2. Name of operator 7. Permit No. ARO3 Alaska, Inc. 82-53 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 50- 029-20789 4. Location of Well atsurface 2757' FNL, 106'FEL, Sec. 14, T10N, R14E, ~ 5. Elevation in feet (indicate KB, DF, etc.) 37'Pad, 84' RKB 9. Unit or Lease Name Prud~oe Bay Unit 6. Lease Designation and Serial No. 28330 10. Well No. 13-21 11. Field and Pool Prud~oe BaY FieId Prudhoe Bay Oil Pool For the Month of May ,19 82 .12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 0915 hrs, 0'4/2'5/82. Drilled 17-'1/2" hole to 2532'. Ran, cemented & tested 13-3/8" csg. Pumped 75 sx Fondu cmt - top job. Drilled 12-1/4" hole to 12590' Ran,cmtd & tstd 9-'5/8" csg. Drld 8-'1/2" hole to 13250'. Ran logs. Cont. Drlg. to 134~0'. Ran & cmtd 7" liner. Disp well to NaC1. Ran CBL. Ran 5-'1/2~' completion assembly.. Secured well & released rig @ 1330 hrs, 0'5/2'4/82. See Drilling History 13. Casing or liner run and quantities of cement, results of pressure tests 20" 91.5#/ft H-40 Conductor @ 75' Qntd w/360 sx AS II ~ , , · . 13-3/8", 72#/ft, L,80, BTC csg W/shoe.@ 2513'. Cmtd w/2500 sx Fondu & 400 sx Permafrost C 9-5/8", 47#/ft, L-80/S00'95, BTC csg W/shoe @ 12'579'. Cmtd w/500 sx Class G. 7", 29#/ft, L-80, BTC liner 'f/12'295'-i'3404'. Cmtd w/350 sx Class G. See Drilling HistOry 14. Coring resume and brief description 15. Logs run and depth where run DIL/SP/BHCS/GR FDC/CNL/GR £/13250' -2513' CBL 16. DST data, perforating data, shows of H2S, miscellaneous data ,,u v - 91982 Alaska Oil & Gas Cons, Commission ~c.~orage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ ~:.~~ Area Drilling Engineer ~//.~//~ ~,~ ~ SIGNED. TITLE DATE . NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 DS 13-21 Drilling Hi story NU 20" Hydril & diverter. Spudded well @ 0915 hrs, 04/25/82. Drld 17-1/2" hole to 2532'. Ran 61 jts 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2513'. Cmtd 13-3/8" csg w/2500 sx Fondu & 400 sx Permafrost C cmt. ND 20" Hydril & diverter. Pumped 75 sx Fondu cmt top job. Instld 13-3/8" packoff & tstd to 5000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 2000 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg. Drld 12-1/4" hole to 12,590'. Ran 314 jts 9-5/8" 47#/ft, L-80/S00-95 BTC csg w/shoe @ 12579'. Cmtd 9-5/8" csg w/500 sx Class G. Instld 9-5/8" packoff & tstd to 5000 psi - ok. Tstd csg to 3000 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 13,250'. Ran DIL/SP/BHCS/GR & FDC/CNL/GRf/13250'-2513'. Cont drlg 8-1/2" hole to 13420' TD (05/19/82). Arctic packed 9-5/8" x 13-3/8" annulus. Ran 27 jts 7" 29#/ft, L-80, BTC liner f/12,295'-13,404'. Cmtd 7" lnr w/350 sx Class G cmt. Drld cmt to 13,404' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to NaCl. Ran CBL. Ran 5-1/2" completion assy w/tail @ 12308' & pkr @ 12229'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Dropped ball & set pkr. Tstd tbg to 3000 psi & annl to 200 psi - ok. Tstd tbg to 200 psi & annl to 3500 psi - ok. Nipple for SSSV set @ 2095'. Instld tree cap & tstd to 5000 psi - ok. Secured well & released rig @ 1330 hrs, 05/24/82. JG:llm 06/01/82 GRU1/DH1 [elephone 907 277 5637 ~iay 26, 1982 Reference: ARCO DIRECTIONAL SURVEY DATA · Cl~cl~'~ ~7~-L :I~,;/:'~ .... ~'- /5/2/82 to 5/14/82 Slng]_e Shot: Job No. ~'/D.S.2-20 4/20/82 Gyroscopic Job No. L/D.S. 13-18 5/6/82 Gyroscopic Job No. ~/D.S.15-4 4/26/82 Gyroscopic Job No. 0582-014 1341 1309 1330 ease sign and return the attached copy as receipt of dtaa. Mary F. Kellis North Engineering Transmittal ~] 187 ' PHILLI SOEIO :~xm~:::o~ .... CHEVRON Telephone 907 277 5637 May 26, 1982 Reference: ARCO DIRECTIONAL SURVEY DATA /2/82 to 5/14/82 D.S.2-20~/ 4/20/82 Single Shot Job No. 0582-014 Gyroscopic Job No. 1341 Gyroscopic Job No. 1309 Gyroscopic Job No'. 1330 D.S.13-186 5/6/82 D.S.15-4¢' 4/26/82 ase sign and return the attached copy as receipt of dtaa. t ' Mary F. Kellis North Engineering Transmittal ~/ 187 DISTRIBUTION NORTH GEOLOGY EXXON' R&D MOBi[.L DRILLING .GETTY PHILLIPS D&M SOHIO ' MARATHON CHEVRON GEOLOGY "~ ~.,,.. ~.S~TE*OF ~ALASKA', ARCO Alaska, Inc. Post Office Box 360 Anchorage, /~' ~ka 99510 Telephone 9, .'77 5637 5/1/82 Reference: ARCO MAGNETIC TAPES & LISTS D.S.13-21 5/19/82 Tape # 65113 D.S.5-12 5/15/82 Tape # 65101 D.S.2-4 5/19/82 Tape # 65111 D.S.2-5 5/20/82 Tape # 65112 ~Ple]se sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal // 205 D 1STRIBUTI ON NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO ' MARATHON CHEVRON EXXON ',iz MOBIL GETTY D&M GEOLOGY ~ - F - Alaska Oil & Gas Cons. Commission Anchorage ARC'O Alaska, Inc. Post Ollice Do:: Anchorage ,",i;~' .'-:.~= Telephone ?:,:7 ;' .:: '..;' .:.7 May 18, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska 0il & Gas Conservation Commission 3001 Porcupine Drive Anchorage~ AK 99501 SUBJECT: State Reports - Prudhoe Bay Dear Mr. Chatterton: Enclosed are Well Completion Reports For the Following drill sites: 12-7A 14-28 13-17 14-30 13-23A 15-3 14-9B 15-12 Also enclosed are monthly reports for April on these drill sites: 2-19 14-17 2-20 15-4 2-21 15-5 13-18 Eileen #1 13-21 West Sak 24 - Eileen #1 and West Sal< 24 are being reran; Surveys for 2 19, 2-20, , completion reports For these wells will be submitted when the corrected surveys aBe.received. The reports on Eileen #1 and West Sal< 24 are of a confidential nature~ We would appreciate it if you could store thi.s inFormaL~on in a secure area. Sincerely, P. A. Van Dusen District Drilling Engineer PAV:JG/llm Enclosures GRU6/A9 APCO AI,~'~-.: !,~: MAY! 9 ....... ia Oil & Gas Cons. / STATE OF ALASKA ~ ALASKA OILt_.,qD GAS CONSERVATION COM~ ;SION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, ]:nc. 82-53 3. Address 8. APl Number P.0, Box 360, Anchorage, AK 99510 50-029-20789 4. Location of Well at surface 2757' FNL, 106' FEL, Sec. lZ~, TION, RlZ~E, UN 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 37'Pad~ 8~' RKBI ADL 28330 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. 13-21 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool For the Month of A?~i_l 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0915 hfs, 04/25/82. Drilled 17-1/2" hole to 2532'. Ran, cemented & tested 13-3/8" csg. Pumped 75 sx Fondu cmt - lop job. Drilled 12-1/4" hole to 2990' of 0~,/30/82. as See Drillinq History 13. Casing or liner run and quantities of cement, results of pressur9 tests 20" 91 5#/ft H-~O Conductor ~ 75' Cmtd w/360 sx AS II 13-3/8", 72 #/ft, L-80, BTC csg w/shoe ~ 2513'. Cmtd w/2500 sx Fondu & 400 sx Permafro§t C. See Drilling Histoi'y 14. Coring resume and brief description 15. Logs run and depth where run 16. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ ~ Area Drilling Engineer SIGNED TITLE DATE NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 G'RUS/B19/20 Submit in duplicate Rev. 7-1-80 DS 13-21 Drilling Hiskory NU 20" Hydril & diverker. Spudded well ~ 0915 hfs, 04/25/82. Drld 17-1/2" hole ko 2532'. Ran 61 its 13-3/8" 72#/fk, L-80, BTC esg w/shoe ~ 2513'. Cmkd 13-3/8" csg w/2500 sx Fondu & 400 sx Rermafrosk C cmk. ND 20" Hydril & diverker. Rumped 75 sx Fondu emk kop job. Inskld 13-3/8" packoff & kskd ko 5000 psi - ok. NU BORE & kskd ko 5000 psi - ok. Tskd csg ko 2000 psi - ok. Drld FC & cmk. Drld FS & 10' new form. Tskd form ko 12.5 ppg. Drld 12-1/4" hole to 2990' as of 04/30/82. GRUB/B21 MEMOR/ , DUM / / ALASKA OIL AND GAS CONSERVATION COMMISSION ,/ T°:~erton THRU: Lonmie C. Smith Commissioner FROM: Bobby Foster i) Petroleu~ Irn~pector Sta e of Alaska DATE: April 30, 1982 FILE NO: TELEPHONE NO: SUBJECT: Witness BOPE test on Arco's D.S. 13-21 Sec 14, T10N, R14E Permit #82-53 T..hursd,ay, April 28,, 1982: The BOPE test began at 2:00 p.m. and was concluded at 7:00 p.m. As the attached BOPE report shows there were two failures. The lower Kelly valve failed. This was replaced and tested. A hub clamp between the annular preventer and the blind rmas leaked. This was tightened and tested. In summary I witnessed the BOPE test on Arco's D. S. 13-21. 02-00iA(Rev.10/79) f ; STATE OF ALASKA , ALASKA OIL & GAS CONSERVATION COMMISSION · B.O.P.E. Inspection Report Inspector Operator · Oon rac o.* Location, General well Sign General Housekeepi Reserve pit '.' · , · , BOPE Stack /' Annuiar Pr~v_'enter Choke Line ValvesL ':Kill Line Valves Check Valve , .. -. · · , *CCU ULATOR Full Charge ~ressure E/O~) psi9 Pressure After Closure /~O .psig · 200 psi~ ~bove Precharge ~ttained: - min~____~sec Full Charge Pressure A~tained:: ~ mi~__~_sec. 'Controls': Master ~ ~ . Re'mote~,~',,Blinds switch cover Kelly and Floor Safety valves / Test Pressure Upper Kelly. Lower ,KellY` / Bal 1 'Type / Inside BOP Choke Manifold No, Valves Test Pressure Test P~res su re Test Pres sure Test Pressure" Test Results: .'Failures Repair or Replacement"iof failed '.equipme.nt'~'to.'.,be ,m~de·'~th'ihi';' ~ -" daYs and Inspector/Commission o'f f ice', not i f i ed : !' i' ' ::"~ " ' ":;i "i"~v';' ' "' Remarks-, .... NO. flanges "~ .~, Adjustable'Chokes`. / / - Hydrauically Operated choke_~ / Test 'r'~m%*:' :"~'''. hrs :"'i" Distribution '' - AO&GCC.. .,,;,~ or ig .' . :_ ~ ...... c,c - Operator cc - Supervisor ARCO Alaska, Inc. Post Office Bo~' Anchorage, Alaska 99510 Telephone 907 277 5637 April 26, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBOECT: DS 13-21, Sundry Notice Dear Mr. Chatterton: Enclosed is our Sundry Notice of intent to change the kickoff point for this well from 2000' MD to 1400' MD. Sincerely, M. A. Major Area Drilling Engineer MAM/OG:hrl Enclosures GRU3/B9 ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany 0il & GaS Co~s. G0mmlssi0n C STATE OF ALASKA ALASKA ._AND GAS CONSERVATION C .,,,vllSSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, [nc. 82-53 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50_029-20789 4. Location of Well 2523'N and 106'W of SE cr Sec. 14, TION, R14E, UM 9. Unit or Lease Name Prudhoe Bay 10. Well Number DS 13-21 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 37' Pad 84' RKB I ADL 28330 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [~ Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes changing the kickoff point for this well from 2000' MD to i400' MD. RECEIVED ? ' 982 Alaska Oil & Gas Cons, Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~ff~~"~~'~'~% Title Area Drilling Engineer The space below for Commission use Conditions of Approval, if any: Approved by OI~iG~HA[ SIGNEI) Approved Cop~' By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 GRU3/Bi0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate AI~CO Alaska, Inc.(' Post Office BO...~60 Anchorage, Alaska 99510 Telephone 907 277 5637 April 16, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 13-21, Sundry Notice Dear Mr. Chatterton: Enclosed is our Sundry Notice of intent to change the kickoff point for this well from 1200' MD to 2000' MD. Sincerely, M. A. Major Area Drilling Engineer MAM/JG:hrl Enclosures cc: M. A. Morris GRU3/B9 APR 1 6 0~t & Gas Cons. Gommissl0ti ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCornpan~/ · (¢ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CC~'IvlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL I~ COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-53 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 5o-029-20789 4. Location of Well 2523'N and 106'W of SE cr Sec. 14, TiON, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 37' Pad 84' RKB I 6 . Lease Designation and Serial No. ADL 28330 12. 9. Unit or Lease Name Prudhoe [lay 10. Well Number DS 13-21 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans E~] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) I 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes changing the kickoff point for this well from 1200' MD to 2000' MD. The revised TD is 14,038' MD (9515' TVD) and the maximum hole angle is 55°. The 9-5/8" casing will be set at 12,719' MD (8759' TVD} and the 7" at 14,038' MD (9515' TVD). Subsequent Work BeportecI RECEIVED APl:? 1 6 1982 Oil & Gas Cons. Anchorago 14. I he--the for.~oing is true and correct to the best of my knowledge. Signed ~r ~. ~,- . % ~-~ Title Area Dri 11 i ng Engineer The space below for Commission use Date Conditions of Approval, if any: Approved by Approved Copy t~y G, ut~- of COMMISSIONER the Commission Form 10-403 . Rev. 7-1-80 GRU3/AiO Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate BUILD RATE CASE°I SOLUTION 2.50 DEG/IO0' BUILT-; RAT_IIUS : .~..-191.83 .......... TVD ...... DEV .................. ANGLE MD KICKOFF DEF'TH AT ANGLE ESTABLISHED AT OBJECTIVE AT 2000.00 0.00 3878~21 978,50 8884.00 8137.~S 0,00 2000,00 .... 55.04 ........... 4201-~-48 .................. 55,04 129S6,86 ADD[I'IONAL F'OINT AT AI)I:;i'I'IONAL. POINT Al' AI;I):I:TIONAL POINT AT ADB]:T:I:ONAL. POINT Al' ADDITIONAL POINT AT AI) I) :11T I ON A t.. 111'01 N TA T ADD:I:I']:ONAL F'OINT AT AI)D]:T]:ONAL. F'OINT AT ADI)ITIONAL. F'O]:NT At' ADI)]:TIONAL F'OINT AT ADDITIONAL POINT AT ADDITIONAL POINT AT 2500,00 55,21 7074,00 5548,84 7844.00 6650°02 8~69,00 7400,8~ 8759,00 7958.57 8769,00 7972,87 8794,00 8008.62 8859.00 8101,58 8884,00 8137,33 9119,00 847~.41 9429,00 8916~74 9'514.96 9039~67 12, 55.04 9778,31 55,04 11122,00 55.04 120~8o16 55.04 12718o?~ 55.04 127~6o18 55.04 12779,80 55.04 1289S.2S 55,04 :12936°86 55,04 1~46'o95 55o047,.::'1~887'~91 ~55o041ti: 140~7'.91 April 8, 198"1 Mr, P. A. Van Dusen Distriot Drillintl Engineer ARCO' Alaska, Ina. P. O. Box 360 Anchor&ge, Alaska 99510 Re: Prudhoe Bay Unit DS 13-11 ARCO Alaska, Ina. Permit No. 81-§3 Sur. Loc. ~i523'N, 106'W of SE cr Sec 14, T10N, R14E, Btmhole Loc. Z678'N, 3156'E of SW er Sec 18, T10~, RISE, Dear Mr. Van ~sen~ Enclosed is the approved application for permit to drill the above referenced wel 1. Well samples and a mud lot~ are not required. A oontinuous directional survey is required as per 20 AAC 25,0§0(b)(5). If available, a tape containtn~ the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys, Many rivers in Alaska and their drainage systems have been classified as important for .the spawning or migration of anad~'~us fish. Operations in these areas are subject to AS 16.05.870 and the rel~ulations Promull~ated thereunder (Title §, Alaska. Administrative Code). Prior to commencini~ operations you may be eontaoted by the Habitat Coordinator's OffiCe, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article ? and the radiations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 76) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in sehedulinz field work, we would appreciate your notifying this office within 48 hours after the well is Mr. P. A. Van Dusen Prudhoe Bay Unit DS 13-21 -2- spudded. We would also like to be notified so that a representative of the Commission may be present to witness testing of blowout preventer equipment before surface easing shoe is drilled. In the event of suspension or abandonment, please give this off tee adequate advance notification so that we may have a witness p~esent. Very truly yours, C. V. Chatterton Chat ~n of g¥ ORP,~I O~ '~t~' CO;~;;~;~;O~/ Alaska Oil and Gas Conservation Commission Eno 1 o sure Department of l~iah & Oame, Habitat Section w/o enel. Department of Environmental Conservation w/o enel. ~C ~ be ARCO Alaska, Inc.(' Post Office ~ , 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 2, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commiss ion 3001 Porcupine Drive Anchorage, AK 99501 RE: DS 13-21, Pemit to Drill Dear Mr. chatterton: Enclosed is our application for Permit to Drill DS 13-21 and the required $100 ifiling fee. Attachments to the application include a plat detailing the section and plan veiws of the proposed well- bore; and a sketch and description of the surface diverter, BOP equipment, and testing procedure. As we anticipate spudding this well approximately April 18, 1982, your prompt review of this application would be appreciated. Sincerely, P. A. Van Dusen District Drilling Engineer PAV: jm Enclosures RECEIVED APR 0 ]982 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfietdCompany {~ STATE Of ALASKA ALASKA ,- AND GAS CONSERVATION C ~MISSION PERMIT TO DRILL 20 AAC 25.005 #6 TH 2353H la. Type of work. DRILL [~ lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL[~ SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator RECEIVED ARGO Alaska, InC. 3. Address APR 0 5 1982 P. O. BoX,_ 360 ' Anchorage, Alaska' 99510 4. Location of, well at surface, ~.¢.t~-/~) .... , ].~j' ~ - 9..Unit or I{~ase name ~ '.__,_~'.~..,i~' S~.~I" / Alaska Oil & Gas Cons. uomm,ss,on 2523' l~, 106' r 4, T10N, R14E, UM Anchoraae Prudhoe Bray At top of proposed producin§ interval ' 10. Well number 2670' N & 2750' F. of SW cr Sec. 18, T10N, R15E, UM DR '1~; - ?.1 At total depth 11.'Field-a-nd poo-] 267R' N g 3156' E of gW r.r g~.r 1R Tln~T. RISE'_ tN Prudhoe Bay Field 5. mevation ~n feet I~ndicate KB, DF etc. I 1 -' 6?L-~sel~e-~'~-~a'ti0n and s%ria~ no. Prudhoe Oil Pool 37' PAD~ 84' RKB ADL 28330 ' " .... ' 12. Bond information (see 20 AAC 25.025) Type Statewide Suretvand/ornumber Fed. Ins. Co #8080-26-27Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 1½ Mi. NW of Deadh.ors~pi~es 5outhline ADL 28329-2602 feet 13-2(~e~@surface 118' feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 13,142' MD 9213 TVD feet 2512 April 18 ~ 1982 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures ~/'/b psig@~ Surface K~CK OFF POINT 1200 feet. MAXIMUM HOLE ANGLE 51 oI (see 2O AAC 25.035 lc) (2) 4498 Psig~2i3__ft. TD (TVDI 21 Proposed Casing, Liner and Cementing Program, SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTO~ TVD (include stage data) 30" 20" 94# H-40. PF, B 63 47' I 47' 110' ~1 l~J~., 250 sx PF II to Surf 17~" 13-3/8" 72# L-80 Butt 2453 47' ~ 47' 2500' 1~4,]....~300 sx Fondu +400PF 12,~" 9-5/8" 47# L-80 Butt 12374 46' - , 46' 114201 ~z.~ 500 sx "G' 1st Stage $00-95 Butt 1000 11420 ~ 8259 12420 I 8759 300 sx PF "C" 2nd sta 8~" 7" 29# L-80 Butt 1022 12120 ~, 8571 13142119213 750 sx Class "G" cmt 22. Describe proposed program: ARCO Alaska, Inc. proposes to directionally drill this well to 13,142' MD (9213' TVD) to product the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8" 5000 psi RSRRA BOP stack will be installed and tested to 5000 psi. The BOP equipment will be pressure tested each week thereafter. A string of 5½" 12.6# L-80 tubing, packeri and necessary provisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uncemented annuli within .the permafrost interval. The packer will be set above the Sadlerochit. The downhole safety valve will be tested and in- stalled upon conclusion of job. NOTE' Permafrost base at DSi 13 is 1850' TVD. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge The space I~elow f~r Commission use ~ ' - ~' - ~' ' ~ · CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required I APl number []YES J~NO []YES [~O ){~YES I-]NO '1 50- d~ 7..- ~ ~_c> 7 ~'~' Permit number Approval date ~ 7"~ .,,,,~'"'~(IR~. ,~ I SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY ,COMMISSIONER DATE A~,~.~ 1 ~ ~' ' ~"~" 7 "~ - by order of the Commission -'1-' .... Form 10-401 Submit in triplicate Rev. 7-1-80 CA~,;E I ,SOI.tJTXON Bt;Il_}) RATE :: 2 · 50 )lEG/100' BU.T.I.)) RAD:(U'~. = 229.'!. + 8~' KICKOFF DEPTH AT ANGLE ESIA~EI..T,SHED OBJECTIVE AT :i. 400,00 0o00 0o00 I400,00 Al' ~204o95 879 o 5:l 5I °9,4 ~478oS1 ................. l 8884°00 8.1S7, ?lB 5:i. ° 96 :1.2693,97j AI)DI T.T ONAI. POINT ADDITIONAl. POINT A'f 7074°00 5824·:i. 5 ADDITIONAl. POINT AT ................ 7844;00 6808,21 ADDITIONAl. POINT AT 8~69,00 7479,:i. 6 ADDITiONAl, POINT A'f' 8'75~,00 7977,58 ADDITIONAL F'O!NT AT - .....8769,00' ADDITIONAL POINT AT ADDITIONAl. POINT AT 8859,00 ADDITIONAl_ POINT Al' 8884~()0 ADDI]'IONAI_ POINT AT ~X1~,00 8437~66 ADDITIONAl. POINT AT _~429,00 88~3~84 ADDITIONAL F'OINT AT 2497,74 280,00 ADDITIONAl. POINT AT ~,~68,06 S20,00 ADDITIONAl_ F'OINT AT B471,37 1220,00 ADDITIONAL POINT AT 8682.65 7~80~00 5.';. ' '5I 51 5I 51 51 51 5I ,~0 51 5i 9756 · 77 v.. - ~ ,: · 96 118='8,, o2 °96 12491.08 96 .,.,:,,07, · 96 :t.2,547 o 88 · 96 :!. 265~ · 36 ~ 96 :i. 2693 ~ ,96 J.~075~ , 96 I3578,32 ,62 '-'2544,75 ,64 '~ 66 ,96 3910,65 .96 12~67,18 ANNULAR PREVENTER BLIND RAMS PIPE RAMS SPOOL PIPE RAMS ECEIVED APR 0 5 1982 Oi~ & Gas Cons, Commissior~ A~chorage 13-5/8" BOP STACK DIAGRAM Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultane- ously and record the time and pressure remaining after all units are closed with charging pump off. 4. Record on IADC report. {The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. 13-5/8" BOP Stack Test 1. Fill BOP stack and manifold with a non-freezing liquid. 2. Check that all hold down screws are fu-lly retracted. Mark running joint with predeter- mined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 3. Close annular preventer and chokes and bypass valves on manifold. 4. In each of the following tests, first hold a, 250 psi low pressure test for a minimum of 3~ minutes, then test at the high pressure. 5. Increase presure to 3000 psi and hold for a minimum of 3 minutes. Bleed pressure to zero. 6. Open annular preventer and close top set,of' pipe rams. Increase pressure to 500~psi and hold for at least 3 minutes. Ble~Kd pres- sure to zero. 7. Close valves directly upstream of chokes and open chokes. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero. 8. Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to 5000 psi below the bottom set of pipe rams and hold for at least 3 minutes. . 9. Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. 10. Bleed pressure to ze6o. Open bottom set of pipe rams. 11. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. 12. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full of non-freezing liquid and all valves are set in drilling position. 13. Test standpipe valves to 5000 psi. 14. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. 15. Check operation of Degasser. 16. Record test information on blowout preventer test form. Sign and send to Drilling Super- visor. 17. Perform complete BOPE test once a week and functionally operate BOPE daily. Rev. 5/13/81 SURFACE HOLE D IVERTER SYSTEM SCHEMATIC ARCO ALASKA INC. 10" HYD. OPR. BALL VALVE ALL 90*' TURNS ARE "TEE" CUSHION I I~LL (~ BORE I RESERVE PIT AREA FLOWL INE :DR ILL lNG RISER L 20" 2000 PSI WP ANNULAR PREVENTOR 20" CONDUCTOR PIPE "DETAIL" 2026010203 :'-'~ i-':"~:"';'-~-'~-'::~'.:-'q'~:"~;:~T ........ :-'F: .... ~>::~'~',.'-:"~-i',-'~"~'"'i ........... F.--.'-:-:"'~ ..... 7 ..... , .~. . OO · 300' :' ~ ..... ~ ..... ~00-- i ...... 200:! .... ~00- - ~ 0 ; "' :-' t ........~ ...... ~ "-~ ........... ~ ..... i "~ ' ' 1 ' ~ ~ ' .~_.~,._: ...... soo_. i "'i' ' i i' ' .~ ...... ~..~..~ ...... -. ............... RRCO--RLRSKR,- .INC .... . - , .... . ~ ~ · _ . -.-~ ....... DS. I3.~WELL NO:- 2~ PROPOSED-~ ........ ~ ~ ~ -" ~ '- i- - ~ ....... )RU~DE"B~Y',i NORTH SLOPE. ~L~SK~ ....... i ~ , ............ - . . ~ ........ L . ?'; .......... ' ................. , ........ ~-: ........................ ~:~ _:-~:~'.~ L~'-~..;~:":" '-~-~-'~T:g-~]' f:-:-~:~-'~:';~-~- t ' ..........~-, ........ : j . '~ ........... .... ~'~--'-:' :"f .......... -~'-';--'5 I .. :.. ' , .i .... :-- I ...... i - -- , -- ! :I · SURFACE DiVERTEF~ SYSTEM 'I L Note: Valves on di¥~erter lines open auto~n~.ticeil), ~'hen the ennular preventer is closed. 1. 20" BRADENHEAD 2. 20'" 2000 PSi DRILLING SPOOL . 3. 20" 2000 PSI ANNULAR PREVENTER 4. 10' BALL YALYES 5.- RIG DRILLh",~G RISER 6. ].0' LINES i'O SUN1P CHECK LIST EOR NEW WELL PERMITS Company ~-~ Lease & Well No. /7~ ~ ~. IT~M APPROVE DATE - /(2 thru a) (4) (.9//thru 11) --~12 thru 20) (5) BOPE ~f~2 ~21 t~hrU 24) (6) Add: I · · 3. 4. 5. 6. 7. 8. · 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21·¸ 22. 23. 24. 25. YES NO Is the permit fee attached ......................................... Is well to be located in a defined pool ........................... ~. ~__~v Is well located proper distance from property line ................ Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is well bore plat included ............... Is operator the only affected party ................................. Can permit be approved before ten-day wait .......................... _ Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is conductor string provided ............. ~ Is enough cement used to circulate'o~ ~~ ~ ~fa~'il[ 11.[1 Will cement tie in surface and intermediate or ............ production strings ...~ii'~~ Will cement cover all known productiVe horizons .......... '...' ..... Will sUrface casing protect fresh water zones · ........ ' Will all casing give adequate safety in collapse, tension and burst·' ' .... is this well to be kicked off from an existing wellbore ............. ~ REMARKS Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ............. ~ ............. Are necessary diagrams of diverter'~'~'~i~ at;~h~d Does BOPE have sufficient~ pressure rating - Test t° ~O~O Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Additional requirements ......... , ................................... Additional Remarks: INITIAL GEO. UNIT ON/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. i, M ?lE~i' ~ "~ CONT 81.~ TS' "~ : - : UNIT' TYPE' :' CATE" SIZE CODE W~ : O,S. ~'21: '~ . . /:: 000 000 010 065 ~J' i P~ t)~',H~'~ ~: ~i O00 000 012 065 RA~iG. 14 065 ~r~wN- ~ ~'~ 065 ~ q - O00 000 002 065 .S~C.... I., . - - COUNt NORTH SLOPE 000 000 012 065 : -, S :; 000 000 006 065 STAT, AI, A,~ KA. CTR~', U,~,' A, OOO. 000 006 065 ~,.j~ ~.~ COh)TE~,~TS 1jN-IT Type CATE SIzE CODE _ ~ · '~ '~' 000 000 007 065 ~AGF, 2 WELL .... : D,S, 13'21 COUNTY = ~O?TH SLOPE BOROUGH STAT= .............--....------.-----------.--...--.---..., TYPE F'[,[tID = CACL DENSITY MATRIX SANDSTONE !, : -32768,0000 1627,0000 1797,0000 t812o0000 1700.0000 1679.0000 1594.0000 18'43.0000 2116.0000 957.0000 I414.0000 1152.0000 FCNL 243.2500 GI~ 46.5<338 1109,0000 1067.0000 FILE TYPE : ~----SCHLUBBE9GER----~ LIS TAPE VERIFICATION LISTING LVP 010.HO1 VERIFICATION LISTING ** REEL HEADER ** SERVICE NAME :SERVIC DATE :82/05/25 ORIGIN : REEL NAME :REEL ID CONTINUATION # PREVIOUS REEL COMMENTS :REEL COMMENTS ** TAPE HEADER SERVICE NAME :SERVIC DATE :82/05/25 ORIGIN :6511 TAPE NAME : CONTINUATION # PREVIOUS TAPE : COMMENTS :TAPE COMMENTS ** FILE HEADER FILE NAME :SERVIC,O01 SERVICE NAME VERSION # DATE : MAXIMUM LENGTH : 1024 FILE TYPE PREVIOUS FILE ** INFORMATION RECORDS ** MNEM CONTENTS CN WN FN RANG: TOWN~ SECT~ COUN: STAT~ CTRY: PRES: ATLANTIC RICHFIELD COMPANY DRILL SITE 13-21 PRUDHOE BAY 1ON 14 NORTH SLOPE ALASKA U,S,A, CONTENTS DILOO~E RECORD TYPE 047 ** UNIT TYPE CATE SIZE CODE 000 000 026 065 000 000 0t6 065 000 000 012 065 000 000 003 065 000 000 003 065 000 000 002 065 000 000 012 065 000 000 006 065 000 000 006 065 UNIT TYPE CATE SIZE CODE 000 000 007 065 LVP OiO.HO1 VERIFICATION LISTING PAGE 2 RECORD TYPE 047 ** RECORD TYPE 047 ** ** COMMENTS ** SCHLUMBERGER ALASKA COMPUTING CENTER COMPANY ~ ATLANTIC RICHFIELD COMPANY WELL c DRILL SITE 13-2! FIELD = PRUDMOE BAY COUNTY = NORTH SLOPE BOROUGH STATE c ALASKA JOB Nt3HBER AT ACC: X0707,65~13 RUN #1, DATE bOGGED: 18 MAY 82 BOTTOM DEPTH = ~3232 FT. TOP DEPTH = 12546 FT. CASING = 9 5/8 IN. 12546 FT. BIT SIZE = 8.5 IN. TYPE FLUID m LIGNOSULFONATE DENSITY = 10.2 LB/G VISCOSITY = 40 S LYP 010,HO! VERIFICATION LISTING PAGE PH = 10 8 FLUID LOSS : 3,~ C3 RM = 1,68 ~ 67 DF R~F. i'1,32 ~ 67 DF 2,68 ~ 67 DF R~C - RM AT BHT = ,05 ~ X 190 MATRIX SANDSTONE ~ DATA FORMAT RECORD ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 4 8 4 73 6O 9 4 65 0 1 66 0 DATU~ SPECIFICATION BLOCKS ~NEM SERVICE SERVICE [3NIT API API API API FILE SIZE PROCESS SAMPLE REPR ID ORDER # LOG TYPE CLASS MOD NO. LEVEL CODE DEPT IL~ Din ILD DIL SP DIL GR DIS NPHX FDN RHOB FDN GR FDN CALI FDN DRHO FDN NEAT FDN NCNL FDN FCNL FDN DT BHC GE BHC NPHI CNL RNRA CNL GE CNL FT 0 0 0 0 0 4 OHMM 7 0 0 0 0 4 OHMM 7 0 0 0 0 4 OHMM 7 12 46 0 0 4 NV ? 1 0 0 0 4 GAPI 7 3t 32 0 0 4 PU 42 68 2 0 0 4 G/C3 42 35 1 0 0 4 GAPI 42 31 32 0 0 4 IN 42 28 3 0 0 4 G/C3 42 44 0 0 0 4 4~ 42 X 0 0 4 42 34 92 0 0 4 42 34 93 0 0 4 U$/F 60 52 32 0 0 4 GAPX 60 31 ~2 0 0 4 PU 42 68 2 0 0 4 42 0 0 0 0 4 GAPI 42 ~1 32 0 0 4 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 bVP OIO,HOI VERIFICATION LISTING PAGE 4 NCNb FCNL CNL 42 34 92 0 0 42 ]4 93 0 0 DATA ** DEPT SP NCNb NPHI FCNL 1~249 999 143 1!568 999 999 DEPT SP NCNB NPHI FCNb .0000 SFbU .2500 GR 3750 CALI :0000 FCNb ,2500 RNRA .2500 DEPT SP GR NCNB NPHI FCNb 13~00o0 70.6 143.3 3726.0 '999.2 '999,2 DEPT SP GR NCNb NPRI FCNL 131O0 -60 62 3174 -999 -999 DEPT SP NCNb NPMI FCNL 13000 -76 27 3570 -999 -999 DEPT SP NCNb NPHI FCNL 12900 -69 30 3658 -999 -999 DEPT SP GR NCNb NPHI FCNL 12800 -65 69 3378 -999 -999 12700 -24 123 2852 -999 -999 000 SFLU 875 GR 75O CALl 000 FCNL 500 RNRA 500 000 SFLU 563 GR 125 CALI 000 FCNb 500 RNRA 5O0 000 SFLU 625 GR 250 CAbI 000 FCNb 500 RNRA 50O 000 SFLU 875 GR 531 CALI 000 FCNL 500 RNRA 50O 000 SFbU 875 GR 875 CALl 000 FCNL 500 RNRA 5OO 000 SFLU 156 GR 125 CALI 000 FCNL 500 RNRA 50O -999 2500 ILS -999:2500 NPHI 8,5000 DRHO 6456.0000 DT -999,2500 GR 3.4512 28.8750 NPHI 8.3203 DRHO 1308.0000 DT -999,2500 13 7109 69:1875 NPHI $ 5547 DRHO 1464:0000 DT -999,2500 14.0313 33.9687 NPHI $ 5469 DRHO 1375!00O0 DT -999 2500 13 6094 28:5313 NPHI 8.414! DRHO 1354,0000 DT -999,2500 GR 37.5938 IbM 62.3125 NPHI 8.4063 DRHO 1189.0000 DT -999.2500 GR 50.7813 Ib~ 116,9375 NPHI 9.4063 DRHO 985.0000 DT -999.2500 GR 4 0 4 0 -999.2500 IbD 24,8047 RHOB 1.3926 NRAT -999,2500 GR-999.2500 NCNb 2.9180 ILD 30.4688 RHOB 0.0322 NRAT 91.5625 GR -999.2500 NCNb 11,5156 ILD 21.4355 RHOB 0.0186 NRAT 73.5625 GR -999,2500 NCNb 15,4297 ILD 26.5625 RHOB 9~.,0117 NRAT 7500 GR -999.2500 NCNb !5.1484 26'1230 -o.o ½,o 97,! GR -999,2500 NCNI~ 34.0625 28,369! RHOB -0,0029 NRAT 95"7500 GR -999.2500 NCNb 29.1250 29.4434 RHO8 -0.0020 NRAT 79.1875 GR -999.2500 NCNb 1 68 1 68 -999,2500 3 0879 -999 2500 -999 2500 2.7441 2,3125 2,7559 2 8750 1.5234 12.4473 2.1738 69,1875 -999.2500 18.8750 2.205! 2,5156 - .2500 8437 2~ 2363 4766 2 5313 -999,2500 45.8437 2,3086 2.6230 62.3125 -999.2500 23.5781 2.4473 2,7793 116,9375 -999.2500 LVP DEPT NCNL NPHI FCNL D~PT SP NCNb NPHI FCNL DEPT SP GR NCNb NPHI FCNL DEPT SP GR NCNb NPHI FCNL DEPT NCNb NPHI FCNL DEPT SP GR NCNb NPHI FCNL DEPT SP NCNb NPHI FCNL DEPT SP NCNb O~O.HO1 V£RIFICATION LISTING 12600.0000 SFLU -20 8281 GR 52:75oo C LI 4556.O0O0 CNL 21.3867 RNRA 871,5000 12500 -999 -999 -999 49 412, 12400 -999 -999 -999 55 349 12300 -999 -999 -999 47 376 12200 -999 -999 -999 509 12100 99 -999 47 342 12000 -999 -999 -999 57 344 11900 -999 -999 -999 0000 SFLU 2500 GR 2500 CALl 2500 FCNL 4141 RNRA 2500 0000 SFLU 2500 GR 2500 CALl 2500 FCNL 0781 RNRA 0000 0000 SFLU 2500 GR 2500 CALI 2500 FCNL 4609 RNRA 2500 0000 SFLU 500 GR 500 CASI 2500 FCNL 0078 RNRA 0000 0000 SFLU 2500 GR 2500 CALl 2500 FCNb 9980 RNRA 0000 0000 SFLU 2500 GR 2500 CALI 2500 FCNL 9102 RNRA 25O0 0000 SFDU 2500 GR 2500 CALl 2500 FCNb 28,1562 IbM 47.7500 NPHI 9.4297 DRMO 2390.0000 DT 2.6250 GR -999,2500 IBM -999.2500 NPH! -999,2500 DRHO -999.2500 DT 3.8398 GR -999.2500 IbM -999.2500 NPHI -999,2500 DRMO -999.2500 DT 4,453! GR -999 2500 IbM -999:2500 NPHI -999,2500 DRHO -999.2500 DT 4.0391 GR -999,2500 -999.22500 NPHI -999. 500 DRHO -999 2500 DT 3:4512 (JR -999.2500 IbM -999.2500 NPHI -999.2500 DRHO -999.2500 DT 4.5195 GR -999.2500 IbM -999,2500 NPHI -999.2500 DRHO -999.2500 DT 4.0000 GR -999.2500 -999.2500 NPHI -999,2500 DRHO -999.2500 DT 24.4688 15,4785 RHOB 0.0029 NRAT 75,3750 GR 80,6250 NCNb -999.2500 ILD -999.2500 RMOB -999,2500 NRAT -999,2500 GR 102.6875 NCNb -999.2500 ILD -999,2500 RHOB '999,2500 NRAT -999,2500 GR 75.6250 NCNb -999,2500 -999.2500 RHOB -999,2500 NRAT -999,2500 GR 69,8750 NCNb -999,2500 -999,2500 RHOB -999'2500 NRAT -999,2500 GR 49.6875 NCNb -999,2§00 ILD -999,2500 RHOB -999,2500 NRAT -999.2500 GR 69.3125 NCNb -999,2500 ILD -999,2500 RHOB -999,2500 NRAT -999.2500 GR 71,5000 NCNb -999,2500 -999.2500 RHOB -999,2500 NRAT -999.2500 GR PAGE 24 5313 2:4785 1.8496 47,7500 2288.0000 -999 2500 -999 2500 -999 2500 -999 2500 1583 0000 -999.2500 -999 2500 -999i2500 -999 2500 1555.0000 -999,2500 -999.2500 -999,2500 -999,2500 1521,0000 -999.2500 : o9 2 oo 999:2500 -999 25OO 1757:0000 -999 2500 -999 2500 -999 2500 -999 2500 1547 0000 ~999,2500 999 ' 2500 -999,2500 -999.2500 1377,0000 -999,2500 -999,2500 -999.2500 -999.2500 LVP 010.H01 VERIFICATION LISTING PAGE 6 NPHI 56.8359 RNRA FCNb 312.0000 4.9453 GR DEPT 11800.0000 8FLU SP -999.2500 GR GR 999.2500 CALI NCNL :999,2500 FCNL NPHI 52,8809 RNRA FCNL 383.2500 -999.2500 iL~ -999 2500 NPHI -999i2500 DPHO -999 2500 DT 3.8691 GR DEPT 11.700.0000 SFLU SP -999.2500 GR -999.2500 CAbI ~N5 -999.2500 FCNL NPHI 55.029, RNRA FCNL 331.7500 -999 2500 IbM -999:2500 NPMI -9'99.2500 DRHO -999.2500 DT 4.4492 GR DEPT 1~600,0000 SFLU SP 999.2500 GR GR -999.2500 CALI NCNb -999,2500 FCNL NPHI 40,5273 RNRA FCNL 421,0000 -999.2500 IbM -999.2500 NPHI -999,2500 DRHO -999 2500 DT 3.'7595 GR DEPT 11500,0000 SFLU SP 999.2500 GR GR -999,2500 CALI NCNb -999,2500 FCNL NPHI 53,4180 RNRA FCNL 382.5000 -999,2500 IL~t -999.2500 NPHI 999,2500 DRHO ~-999.2500 DX 4,0000 GR D~PT 11400 BP -999 GR -999 NCNb -999 NPHI 39 FCNL 413 .0000 SFLU 2500 GR 2500 CALI 2500 FCNb 11~3 RNRA 0000 -999 2500 IbM -999:2500 NPHI -999 2500 DRHO -999!2500 DT 3 6406 GR BP -999:2500 GR GR -999.2500 CALI NCNb -999,2500 FCNL NPHI 52 4902 RNRA FCNL 317:2500 -999.2500 IbM -999.2500 NPHI -999,2500 DRHO -999.2500 DT 4.3672 GR DEPT SP GR NCNb NPHI FCNL 11200.0000 SFLU -999.2500 GR -999.2500 CALl -999.2500 FCNL 42,8711 RNRA 401.5000 -999.2500 -999.2500 NPHI 99 2500 DRHD 3.@750 DEPT SP 11100,0000 SFLU -999.2500 GR -999.2500 IbM -999.2500 NPHI 130.8750 NCNb -999.2500 -999.2500 RHOB -999,2500 NRAT -999,2500 GR 112.0000 NCNb -999,2500 -999,2500 RHOB -999,2500 NRAT -999.~500 I20,8125 NCNL -999 2500 -999:2500 RHOB -999.2500 NRAT -999,2500 GR 78'562~ NCNb -999 2500 -9 9225oo -999,2500 NRAT -999,2500 GR 72.8750 NCNb -999.2500 ILD 99.2500 NR{%T -999,2500 OR 84.4375 NCNb -gg99 2500 IbD -99:2500 RHOB -999.~500 NRAT -999 2500 GR 72:0625 NCNb -999,2500 ILD -999.2500 RHOB 1544,0000 -999.2500 -999,2500 -999,2500 -999,2500 1483,0000 -999,2500 -999.2500 -999,2500 -999,2500 1477.0000 -999,2500 -999,2500 -999,2500 1999,2500 583,0000 -999.2500 -999,2500 -999'2500 -999,2500 1530,0000 -999 2500 -999 2500 -999 2500 -999 2500 i504 0000 -999,2500 -999 2500 -999 2500 -999 2500 1386 0000 '999,2500 '999i2500 '999'2500 '999,2500 i556.0000 '999 2500 '999:~500 LVP OIO.HOI GR -9 NCNb -9 NPHI FCNL 3 DEPT 110 SP -9 GR -9 NCNb -9 NPHI FCNL 4 DEPT 109 SP -9 GR -9 NCNb -9 NPHI FCNL 3 DEPT 108 SP -g GR "g NCNb -9 NPHI FCNL 5 VERIFICATION 99.2500 CALI 99 2500 FCNL 37:9853 RNRA 99,7500 00.0000 SFLU 99,2500 GR 99,2500 CALI 99,2500 FCNb 42.7734 RNRA 11.0000 00,0000 SFLU 99.2500 GR 99,2500 CALl 99,2500 FCNL 43,2129 RNRA 78,2500 00.0000 SFLU 99 2500 GR 99~2500 CAL! 9~,2500 FCNL 3 .3047 RNRA 50,50O0 DEPT 10700 SP -999 GR -999 NCNb -999 NPHI 37 FCNL 505 0000 SFLU 2500 2500 CALl 2500 FCNL 6465 RNRA 2500 DEPT 106 SP -9 GR -9 NCNb -9 NPHI FCNL 4 00,0000 SFLU 99,2500 GR 99,2500 CALl 99,2500 FCNL 35,4492 RNRA 43,2500 DEPT 10500, SP -999, GR -999. NCNb -999. NPHI 38. FCNL 407, 0000 SFLU 25OO GR 2500 CALI 2500 FCNL 7207 RNRA 5O00 DEPT 104 SP -9 GR -9 NCNb -9 FCNL 4 00.0000 SFLU 99,2500 GR 99,2500 CALI ~,2500 FCNL .9395 RNRA 23..7500 LISTING -999.2500 DRHO -999 2500 DT -999,2500 -999,2500 NPHI -999,2500 DRHO -999.2500 DT 4.0000 GR 999 2500 :99922soo -999,2500 URHO -999,2500 DT 3,773.5 GR -999.2500 IbM -999.2500 NPHI -999.2500 DRHO -999,2500 DT 3,0586 GP` -999,2500 IbM -999 2500 NPHI -999,2500 DEHO -999,2500 DT 3,1973 GR -999.2500 :999 2500 999:2500 DRHO -999.2500 DT 3.7305 -999.2500 IbM -999.2500 NPHI -999,2500 DEHO -999.2500 DT 3,8730 GR -999.2500 IbM -999 2500 NPHI -999;2500 DP. HO -999 2500 DT 3:53.95 GR -999,2500 NRAT -999 2500 GR 125.,'4375 NCNb -999,2500 -999 2500 RHOB -999:2500 NEAT -999,2500 GR 54.1875 NCNb -999,2500 ILD -999.2500 RHOB -999,2500 NEAT -999,2500 GR 60,3438 NCNb -999,2500 ILD -999 500 NEAT -999 500 GR -999 ~500 -999~ 500 RHOB -999 ~500 NEAT -999~ 500 GR 53.8437 NCNb -999.2500 ILD -999,2500 RMOB -999,2500 NEAT -999,2500 GE 64,9375 NCNb -999.2500 -999,2500 RMOB -999.2500 NRAT -999,2500 GR 57.6875 NCNb -999,2500 -99~ 2500 -99 ~2500 NRAT -999.2500 GR 56.6250 NCNb -999 .22500 -999: soo 3.355,0000 -999,2500 -999,2500 -999,2500 -999,2500 1644.0000 -999,2500 -999,2500 -999 2500 1427,0000 -999 2500 -999:2500 -999,2500 -999,2500 1684.0000 -999,2500 -999,2500 -999,2500 -999,2500 163.6,0000 -999,2500 -999,2500 -999,2500 -999.2500 1654,0000 -999,2500 -999,2500 -999,2500 -999,2500 1579'0000 -999.2500 -999.2500 -999,2500 -999 2500 3.4s52oooo bYP OlO.HO! VERIFICATION LISTING PAGE 8 DEPT 10300 SP -999 GR -999 NCNb -999 NPHI 42 FCNL 360 .0000 SFLU 2500 GE 2500 CAbI 2500 FCNL 1875 RNRA 5000 DEPT !0200 SP -999 GR -999 NCNb -999 NPHI 15 FCNb 1039 .0000 SFLU 500 GR '~500 CALI .2500 FCNL .8203 RNRA .0000 DEPT 1~100 SP 999 GR -999 NCNb -999 NPHI 43 FCNL 396 .0000 SFLU .2500 GR 2500 CALI :2500 FCNb .4570 RNRA .5000 DEPT !0000 SP -999 GR -999 NCNb -999 NPHI 43 FCNL 445 0000 SFLU i2500 GR 2500 CALI 2500 FCNL i 0664 RNRA 2500 DEPT 99O SP GR 99 NCNL -99 NPHI 3 FCNL 41 O, 9, 9. 9. 9. 1, 0000 SFLU 2500 GR 250O CAbI 2500 FCNb 0137 RNRA 5000 DEPT 98 G~ 9 NCNb -9 NPHI FCNL 5 O0 99 99 9 O! .0000 SFLU 2500 GR :2500 CALI 2500 FCNL i 3066 RNRA 0000 DEPT SP GR NCNb NPHI FCNb 9700 -999 -999 -999 47 351 0000 SFLU :2500 GR 2500 CAbI :2500 FCNL .5586 RNRA .2500 DEPT SP GR NCNb NPHI 9600 999 -999 50 .0000 SFLU .2500 GR .2500 CA5I 2500 FCNL :4395 RNRA -999 2500 ILM -999:2500 NPHI -999.2500 DRHO -999.2500 DT 4.2852 GR -999.2500 ILM 999.2500 NPHI 999,2500 DRHO 999.2500 DT 1.5000 GR 999 2500 IbM 2soo -ggg.2500 DT 3.8320 GR -999.2500 IbM -999.2500 NPHI -999.2500 DEHO -999.2500 DT 3.7031 GR -999.2500 IbM -999.2500 NPHI -999.2500 DRHO -999.2500 DT 3.5586 GE -999.2500 IbM -999 2500 NPHI -999:2500 DEHO -999.2500 DT 3.0645 GR -999,2500 IbM -999.2500 NPHI -999.2500 DRHO -999.2500 DT 4.4766 GR -999.2500 IbM -999.2500 NPHI -999.2500 DRHO -999.2500 DT 3.8184 GE -999.2500 IJ, D -999.25o0 R os -999 2500 NEAT -999:2S00 G. 51.8125 NCNb -999.2500 ILD -999.2500 RHOB -999.2500 NRAT -999.2500 GE 67.9375 NCNb -999.2500 ILD -999.2500 RHOB -999.2500 NEAT -999.2500 GR 51.7813 NCNb -999.2500 ILD -999.2500 RHOB -999.2500 NEAT -999.2500 GR 64.0000 NCNL -999.2500 ILD -999.2500 RHOB -999.2500 NRAT -999,2500 GR 48.9687 NCNb -999.2500 ILD -999.2500 RHOB -999.2500 NEAT -999.2500 GE 48.0313 NCNb -999.2500 ILD -999.2500 RHOB -999.2500 NEAT -999.~500 GR 54.7188 NCNb -999.2500 ILD -999 ~500 RHOB -999: 500 NRAT -999.2500 GR 65.9375 NCNL v -999.2500 -999,2500 -999,2500 -999.2500 1545.0000 -999.2500 -999,2500 -999,2500 -999.2500 1559,0000 -999.2500 -999,2500 -999,2500 -999,2500 1520,0000 -999.2500 .-999,2500 2999, 5oo 999,2500 ~649.0000 -999.2500 -999,2500 -999,2500 -999.2500 1465,0000 -999.2500 -999.2500 -999.2500 -999 2500 1536:0000 -999.2500 -999 2500 -999!2500 -999 2500 1573,0000 -999,2500 -999~2500 -999,2500 -999.2500 1388.0000 LYP 0~0.H0! V~RIFICATION FCNL 363.5000 DEPT 9500 0000 SFLU SP -999:2500 GR GR -999.2500 CALI NCNL -999.2500 FCNL NPHI 44,9219 RNRA FCNL 322.0000 DEPT 9400.0000 SFLU SP -999.2500 GR GR -999.2500 CALI NCNL -999.2500 FCNL NPHI 44.5313 RNRA FCN5 372.7500 DEPT 9300.0000 SFLU SP -999.2500 GR GR -999.2500 CALI NCNL -999.2500 FCNL NPHI 45.2637 RNRA FCNL 341.0000 D~PT 9200.0000 SFLU SP -999 2500 GR GR -999i2500 CALI NCNL -999 2500 FCNL NPHI 45 0684 RN~A FCNL 373.5000 DEPT 9100 0000 SFLU SP -999:2500 GR GR -999.2500 CALI NCNL -999.2500 FCNL NPHI 51.3184 RNRA FCNL 320.5000 DEPT 9000.0000 SFLU SP -999 2500 GR GR -999:2500 CALl NCNL -999 2500 FCNL NPHI 46:6797 RNRA FCNL 300.0000 DEPT 8900.0000 SFLU SP -999.2500 GR GR -999.2500 CALI NCNL -999.2500 FCNL NPH! 41.2598 RNRA FCNL 378.5000 DEPT 8800.0000 SFLU SP -999.2500 GR GR -999.2500 CALI LISTING 999.2500 ILM -'999.2500 NPHI -999.2500 DRMO -999.2500 DT 4.4688 GR -999.2500 .'9909 2500 NPH! 99~2500 DRHD '999,2500 D? 3.4551 '999,2500 '999.2500 NPHI '999.2500 DRHO '999.2500 DT 4.1484 GR '999.2500 '999 2500 NPHI '999:2500 DRHO '999.2500 DT 3.8633 GR '999.2500 ILM '999.2500 NPHI '999.2500 DRHO '999.2500 DT 4.6836 GR -999.2500 -999.2500 NPHI -999.2500 DPHO -999.2500 DT 4.1641 GR -999.2500 -999 2500 NPHI -999i2500 DR~O -999 2500 DT 3.9121 GR 999.2500 :999.2500 NPHI -999.2500 DRHO -999.2500 ILD -999.2500 RHOB -999.2500 NRAT -999.2500 GR 68.5625 NCNL -999.2500 ILD -999.2500 RHOB -999.2500 NRAT -999 2500 GR 63:6875 NCNL -999,2500 ILD -999.2500 RHOB -999.2500 NRAT -999.2500 GR 51.28~3 NCNL -999.2500 -999,2500 RHOB -999.2500 NRAT -999,2500 GR 54.8437 NCN5 -999.2500 ILD -999.2500 RHOB -999 500 NRAT 49,281] NCN~ .-999.2500 ILD 999.2500 RHOB 999,2500 NRAT 999,2500 GR 60,9375 NCNL -999 22500 ILD -999:500 ~HOB -'999.2500 NRAT -999.2500 GR 53.6563 NCNL -999.2500 ILD -999.2500 RHOB -999.2500 NRAT PAGE -999,2500 -999.2500 -999.2500 -999 2500 i440:0000 ~999.2500 .999.2500 -999.2500 -999.2500 1288.0000 -999.2500 -999 2500 -999:2500 -999,2500 I415.0000 -999 2500 '999, 500 '999.2500 2443.0000 ~999,2500 :999'2500 999,2500 -999,2500 1502.0000 -999.2500 -999.2500 -999.2500 -999.2500 1250.0000 -99~,2500 -99 , 2500 -999.2500 -999.2500 1481.0000 -999.2500 -999.2500 -999.2500 bVP 010.HOt VERIFICATION LISTING PAGE 10 NCNb NPHI FCNL DEPT SP NCNb NPHI FCNL DEPT GR NCNL NPHI FCNL DEPT GR NCNb NPHI ?CNb DEPT SP NCNb NPHI FCNL DEPT GR NCNL NPHI FCNL DEPT SP GR NCNb NPHI FCNL DEPT SP GR NCNL NPHI FCNL DEPT -999 2500 FCNb 41:7969 RNRA 380.0000 8700.0000 SFLU :999.2500 GR 999.2500 CALI -999.2500 FCNL 42,6758 RNRA 454.2500 8600.0000 SFLU -999,2500 GR =ggg,2500 CALI =ggg,2500 FCNL 37,2559 RNRA 510,5000 500,0000 SFbU ~999,2500 GR -999.2500 CALl -999 2500 FCNL 51:1719 RNRA 275.2500 8400.0000 SFLU -999,2500 GR -999.2500 CALl -999,2500 FCNL 40.3320 RNRA 414,2500 8300.0000 SFbU -999,2500 GR -999,2500 CALI -999.2500 FCN5 45 7520 RNRA 334:5000 8200.0000 SFLU :999.2500 GR ,3770 RNRA 617.5000 BlO0.O000 SFLU -999.2500 GR -999.2500 CALI -999.2500 FCNL 44.8730 RNRA 303.7500 BO00.O000 SFLU -999.2500 DT 3.9570 GR -999.2500 IbM -999.2500 NPHI -999.2500 DRHO -999.2500 DT 3.6055 GR -999.2500 IbM -999,2500 NPHI -999 2500 DRHO -999:2500 DT 3.3672 GR -ggg 2500 IbM -999:2500 NPHI -999,2500 DRHO -999.2500 DT 4.8828 GR -999 2500 -999:2500 NPHI -999.2§00 DRHO -999.2500 DT 3.5762 GR -999.2500 -999.2500 NPHI -999.2500 DRHO -999.2500 DT 3.7598 GR -999.2500 ILM -999.2500 NPHI 999.2500 DRHO ~999.2500 DT 3.3262 GR -999.2500 -999.2500 NPHI -999.2500 DRHO -999.2500 DT 3.7188 GR -999.2500 -999.2500 GR 49.9375 NCNb -999.2500 ILD 99.2500 GR 51.5625 NCNb -999.2500 ILD -999,2500 RHOB -999"2500 NRAT -999,2500 GR 47'6875 NCNb -999.2500 IDb '999.2500 RHOB -999,2500 NRAT -999.2500 GR 55.0938 NCNb -999.2500 ~999,.2500 RHOB 999,2500 NRAT -999.2500 GR 43.7813 NCNb -999.2500 IbD -999.2500 RHOB -999.2500 NRAT -999.2500 GR 48.2187 NCNL -999.2500 ILD -999,2500 RHOB -999.2500 NRAT -999.2500 GR 36.2813 NCNb -999.2500 16D -999,2500 RHOB -999,2500 NRAT -999'2500 GR 51.0000 NCNb -999.2500 ILD -999 2500 t504:0000 -999.2500 -999 2500 -999i2500 -999 2500 1638.0000 -999.2500 -999.2500 -999.2500 -999,2500 1719.0000 -999.2500 999 2500 -999 2500 1344 0000 -999,2500 -999,2500 -999,2500 -999.2500 1482,0000 -999,2500 m999,2500 '999,2500 '999,2500 1258.0000 -999 2500 -999:2500 -999,2500 -999,2500 2054,0000 -999 2500 -999 2500 -999.2500 -999~2500 1130 0000 -999,2500 SP NCNb NPHI FCNL DEPT SP GR NCNb NPHI FCNL DEPT SP GE NCNL NPHI FCNL DEPT SP GE NCNb NPHI FCNL DEPT GR NCNb NPHI FCNL DEPT GE NCNb NPHI FCNL DEPT SP NCNb NPHI FCNL DEPT SP GR NCNb NPHI FCNL 010.H01 VERIFICATION -999 2500 GR -999~25oo CAbI -999.2500 FCNL 44.3848 RNR~ 369.5000 7900.0000 SFbU -999.2500 GR -999.2500 CALI -999.2500 FCNb 35.7910 ENRA 550,0000 7800.0000 SFLU -999.2500 GR -999.2500 CALI -999 2500 FCNL 42!7246 RNRA 41! 0000 7700.0000 SFLU -999.2500 GR -999.2500 CALI -999.2500 FCNL 38.6719 ENRA 474.2500 7600.0000 SFLU -999 2500 GR -999:2500 CALl -999.2500 FCNb 37.7441 RNRA 596.0000 7500.0000 SF[.U -999.2500 GR -999.2500 CALI -999.2500 FCNL 51.5625 RNRA 350.5000 400!0000 SFLU 999 2500 GR 999 2500 CAbI 9 2500 FCNL 9~2 8809 RNRA 367 2500 7300.0000 BFbU -999.2500 GR -999.2500 CAbI -999.2500 FCNb 35.7422 RNRA 504.0000 LISTING -999 2500 NPHI . '999.2500 DEMO '999,2500 DT 3.4551 GE .-999 2500 IbM 999:2500 NPHI -999.2500 DRHD -999 2500 DT 3:2715 GR 999.2500 IBM 999.2500 NPHI 999.2500 DRHO -999.2500 DT 4.0820 GR -999.2500 IbM -999.2500 NPHI -999.2500 DRHO -999.2500 DT 3.8262 GR -999.2500 IbM -999.2500 NPHI -999.2500 DRHO -999.2500 DT 3.3887 GR -999.2500 IbM -999.2500 NPHI -999.2500 DRHO -999.2500 DT 4.1875 GE -999.2500 IbM -999.2500 NPHI -999.2500 DRBO -999.2500 DT 5.0430 GR -999.2500 -999.2500 NPHI -999.2500 DRHO -999.2500 DT ].4648 GR -999 2500 RHOB -999~2500 NRAT -999 2500 GR 52."0625 NCNb -999 2500 -999:2500 RHOB '999.2500 NRAT -999,2500 GR 35.4688 NCNb -999.2500 -999.2500 RHOB -999.2500 NEAT -999.2500 42.9375 NCNb ~99 2500 99:2500 RHOB -999.2500 NRAT '999.2500 GE 28,3125 NCNb -999.2500 ILD -999.2500 RHOB -999.2500 NRAT -999,~500 GR 34. 813 NCNb ~999,2500 ILD 999.2500 RHOB -999.2500 NEAT -999.2500 GR 38.1562 NCNb -999.2500 IBD -999.2500 RH00 -999.2500 NRAT -999.2500 GR 44.3750 NCNL -999 ~500 -999 500 -999 2500 -999 2500 30.0625 ILD RHOB NEAT GR NCNb PAGE -999.2500 -999.2500 -999.2500 1277.0000 -999.2500 .-999.2500 999.2500 -999.2500 1800,0000 -999 2500 -999 2500 -999 2500 -999 2500 1678 0000 -999 2500 '999i2500 -999 2500 -999 2500 !815.0000 :;;, 9:2500 -999 2500 -999:2500 2020.0000 -999 2500 -999 2500 -999 2500 -99~ 2500 146 0000 -999 2500 -999i2500 -999 2500 -999-2500 1853~0000 -999.2500 -999.2500 -999.2500 -999,2500 1747,0000 LVP OiO.HO1 VERIFICATION LISTING PAGE 12 DEPT SP GR NCNb FCNL DEPT GR NCNb NPHI FCNL DEPT SP NCNb NPHI FCNL DEPT GR NCNb NPMI FCNL DEPT SP NCNb NPHI FCNL DEPT SP NCNb NPHI FCNL DEPT SP GR NCNL NPHI FCNL DEPT GR NCNL 7200 -999 -999 -999 44 493 7100 -999 -999 -999 47 40! 7000 -999 -999 -999 49 337 6900 -999 -999 -999 48 326 6800 -999 -999 -999 54 286 6700 -999 -999 -999 42 362 6600 -999 -999 -999 54 296 0000 SFLU 2500 GR 2500 CALI 2500 FCNL 1406 ENRA 5000 0000 SFLU 2500 GR 2500 CALl 2500 FCN5 9980 RNRA 5000 ,0000 SFLU .2500 GR 2500 CA~I :2500 FCNL .5117 RNRA ,5000 :0000 SFLU 2500 GR ,2500 CALI .2500 FCNL 5352 RNRA '7500 . 0000 SFLU 2500 GR 2500 CALI 2500 FCNL 0527 RNRA 2500 0000 SFLU 500 CALI .2500 FCN~ .9199 RNRA .7500 .0000 SFLU .2500 GE .2500 CALI .2500 FCNL .3457 RNRA .2500 6500.0000 SFbU -999.2500 GR -999 2500 CAbI -999:2500 FCNL -999.2500 -999 2500 NPHI -999:2500 DRHO -999.2500 DT 3.4473 GR -999.2500 IbM -999.2500 NPMI -999.2500 DEMO -999.2500 DT 3.8320 GR -999.2500 IbM -999.2500 NPMI -999.2500 DRHO -999.2500 DT 4.1445 GR -999.2500 IbM '999.2500 NPHI -999.2500 DRHO -999,2500 DT 4.1562 GE -999 2500 IbM -999:2500 NPHI -999.2500 DRHO -999,2500 DT 4.9961 GR -999 2500 IbM -99912500 NPMI -999 2500 DEHO -999 2500 DT 3.8633 GR -999 2500 -999 2500 -999 2500 -999 250O 4 7188 IbM NPHI DEMO DT GR -999.2500 IbM -999.2500 NPHI -999.2500 DRHO -999.2500 DT -999 2500 -999:2500 -999,2500 -999,2500 36,?500 NEAT GR NCNb '999,2500 '999.2500 '999'2500 '999.2500 36.9375 RHOB NEAT GR NCNb -999.2500 -999,2500 -999,2500 -999 2500 IbD RHOB NRAT NCNL -999.2500 -999,2500 -999.2500 -999.2500 27'5156 NRAT NCNL -999.2500 -999,2500 '999,2500 '999,2500 54'0938 RMOB NRAT GR NCNb -999 2500 -9gg 250O -999 2500 -999 2500 39.4375 RHOB NRA? GR NCNb -999.2500 -999.2500 RHOB -999.2500 NEAT -999.2500 GR 41,1875 NCNb -999.2500 IbD -999.2500 RHOB -999.2500 NEAT -999.2500 GR -999.2500 -999.2500 -999;2500 -999,2500 1702,0000 .-999,2500 2999,2500 .999,2500 -999'2500 1539.0000 -999, 2500 -999 2500 -999 2500 -999 2500 1400 0000 -999 2500 -999 2500 -999 2500 -999 2500 1359 0000 ~999,2500 999,2500 -999.2500 -999 2500 1431:0000 -999 2500 -99 2500 -999 2500 1402.0000 ~999,2500 ~999,2500 :999,2500 999,2500 1399,0000 -999.2500 .-999,2500 999.2500 bVP NPHI FCNL DEPT SP NPHI FCNL DEPT SP NCNb NPHI FCNL DEPT SP GR NCNb NPHI FCN5 DEPT SP GR NCNb NPHI FCNL D~PT SP GR NCNb NPHI FCNL DEPT SP NCNI, NPHI FCNL D~PT SP NCNb NPHI FCNL DEPT SP VERIFICATION 48,6328 RNRA 299.2500 6400 -999 -999 -999 78 .0000 SFLU 2500 GR 2500 CALI 2500 FCNL 3691 RNRA 2500 6300 -999 -999 -999 42 370 .0000 SFLU .2500 GR ,2500 CALl 2500 FCNL :1387 R~A ,5000 6200 -999 -999 -999 48 317 0000 SFLU 500 GR 2500 FCNL 4375 RNRA 75O0 6100 -999 -999 -999 51 350 ,0000 SFLU .2500 GR .2500 CALI ,2500 FCNL 9531 RNRA :0000 6000 -999 -999 -999 55 .0000 SFLU 2500 GR 2500 CALl 2500 FCNL 2246 RNRA 5000 ~00,0000 SFLU 99.2500 GR -ggg.2500 CAbI -999.2500 FCNL 47.9980 RNRA 296.2500 ssoo.oooo sr u CA Z -999.2500 FCNL 55,B056 RNRA 352.0000 5700.0000 SFLU -999.2500 GR LISTING 4.1641 GR -999.2500 I5~ -999.2500 NPHI =-999 2500 DRHO 999:2500 DT 5,8164 GR -999 2500 IbM -999~2500 NPHI -999 2500 DRHO -999:2500 DT 3'7266 GR -999 2500 IL~ -999i2500 ~PHI -999 2500 DRHO -999,2500 DT 4,3711 GR -999 2500 -999:2500 NPHI -999,2500 DRHO -999,2500 DT 3,9512 GR -999.2500 IbM -999.2500 NPHI -999.2500 DRHO ~999,2500 DT 4,5859 GR -999 2500 -999 2500 -999 2500 -999 2500 4 1719 IbM DRHO DT GR -999,2500 IbM -999.2500 NPHI -999,2500 DRHO -999 2500 DT 4:2383 :999 2500 IbM 999:2500 NPHI 49,2500 NCNb -999,2500 IbD '999,2500 RHOB "999,2500 NRAT '999.2500 GR 27.9531 NCNb -999,2500 ILD 99,2500 GR 44.8437 NCNb -999,2500 ILD -999,2500 RHDB -999.2500 NRAT -999 2500 GR 45:3125 NCNL -999,2500 ILD -999.2500 RHOB '999,2500 NRAT -999,2500 GR 40'7188 NCNb -999,2500 IbD -999,2500 RHOB -999,2500 NRAT -999 ~500 GR 42:188 NCNL -999,2500 IbD -999,2500 RHOB -999,2500 NRAT -999.725500 GR 38, ~ O0 NCNb -999.2500 ILD -999.2500 RHOB -999.2500 NRAT -999,2500 GR 44.6250 NCNb -999.2500 IbD -999,2500 RHOB PAGE 1247,0000 -999 2500 -999 2500 -999 2500 -999 2500 1066 0000 -999 2500 -999;2500 -999 2500 -999!2500 1381 0000 '999,2500 '999,2500 '999.2500 --999.2500 i389.0000 -999.2500 -999.2500 -999.2500 -999.2500 1383.0000 -999,2500 '999,2500 -999.2500 -999.2500 1324,0000 -999,2500 '999,2500 -999.2500 -999.2500 1237.0000 -999.2500 -999.2500 -999'2500 -999"2500 1492,0000 -999 ~50o soo 13 5¥P OlO,HO1 YEEIFfCATION bXSTING PAGE 14 ~R NCNb NPHI FCNL DEPT NCNb NPH! FCN5 DEPT SP GR NCNL NPH! FCNL DEPT SP GR NCNb NPHI FCNL DEPT SP NCNb NPHI FCNL DEPT SP GR NCNb NPHI FCNL DEPT SP GR NCNb NPHI FCNL DEPT NCNb NPHI FCNb -999.2500 CALI -999.2500 FCNL 39.7461 RNRA 401,5000 5600,0000 8FLU -999.2500 GR -999,2500 CALI -999.2500 FCNL 49,8535 RNRA 352.7500 500.0000 SFLU ~999.2500 GR 99 2500 CALI 46.9238 RNRA 326.5000 5400.0000 SFLU -999,2500 GR 999 2500 CALI RNRA 209.2500 5300 -999 -999 -999 65 229 .0000 SFLU 2500 GR 2500 CALl 2500 FCN5 0391 RNRA 5000 2 9 9 -9 3 O0 99 99 99 51 31 .0000 SFLU .2500 GR .2500 CALI .2500 FCN5 .2207 RNEA .2500 51 -9 9 O0 99 9 40 ~5 .0000 SFLU .2500 GR 2500 CALI :2500 FCNL .6250 RNEA ,0000 5OOO ggg -999 54 325 .0000 SFLU .2500 GR .2500 CALI .2500 FCNL .1016 RNRA .7500 -999 2500 DRHO -999!2500 DT 3 4980 GR -999 2500 IbM -999i2500 NPHI -999 2500 DRHO -999,2500 DT 4.2344 GR -999.2500 Ib~ -999.2500 NPHI -999.2500 DRHO -999.2500 DT 4.2969 GR -999 2500 IbM -999:2500 NPHI -999.2500 DRHO -999 2500 DT 5:4570 GR 999,2500 IbM -'999.2500 NPHI -999,2500 DRHO -999.2500 DT 5,2852 GR 2999,2500 999,2500 NPHI -999.2500 DRHO -999,2500 DT 3,8965 GE -999 2500 IbM -999:2500 NPHI 999 2500 DRHO -'999i2500 DT 3 8066 GR -999.2500 IbM 999 2500 NPH! :999,'2500 DRHD -999,2500 DT 4,6992 GE -999,2500 NEAT -999,2500 GR 38,6875 NCNb -999.2500 IbD -999,2500 RHOB -999.2500 NEAT -999.2500 GR 34.7500 NCNb -999,2500 -999,2500 RHOB -999,2500 NEAT -999.2500 GR 35,0625 NCNb -999.2500 -999.2500 RHOB -999.2500 NEAT -999.2500 GR 49.4375 NCNb -999,2500 -999,2500 RHOB -999,2500 NEAT -999,2500 GR 47,5000 ~999, 500 999~)RH 500 OB -999.2500 NEAT -999.2500 GE 45.8750 NCNb -999 2500 XbD -999:2500 RHOB -999.2500 NEAT -999.2500 GR 20.4531 NCNb -999.2500 -999,2500 RHOB -999,2500 NEAT -999.2500 GA 39,9375 NCNb -999.2500 -999.2500 I405,0000 -999,250O -999 2500 -99~ 2500 -99 2500 1495 0000 -999 2500 -999 2500 soo 999 2500 1404,0000 -999,2500 -999,2500 -99912500 -999,2500 1142~0000 -999 500 -999 ~500 -999 2500 -999 2500 1213 0000 -999.2500 -999,2500 -999.2500 -999 500 -999,2500 -999.2500 -999.2500 -999,2500 1656.0000 -999.2500 -999,2500 -999.2500 -999,2500 1531.0000 bVP OiO.HO1 VERIFICATION LISTING DEPT 4900 SP -999 GR -999 NCNb -999 NPHI 50 FCNb 288 .0000 SFLU 2500 Gm 2500 CALI 2500 FCNb 0000 RNRA 7500 .-999 2500 99922500 -999,2500 DRHD -999,2500 DT 4,5625 GR DEPT 4800 SP -999 GR -999 NCNb -999 NPHI 41 FCNL 377 .0000 SFbU .2500 GR .2500 CALI ,2500 FCNL .3086 RNRA .25OO -999.2500 -999 2500 NPHI -999:2500 -999,2500 DT 3.7969 DEPT 4700,0000 SFLU SP -999,2500 GR GR -999,2500 CALI NCNb -999,2500 FCNL NPH! 55 1270 RNRA FC~L 285:oooo -999.2500 I~M -999,2500 NPHI -999.2500 DRMO -999 2500 DT 5:0664 GR DEPT 4600 SP -999 GR -999 NCNb -999 NPHI 47 FCNL 297 .0000 SFLU .2500 GR ,2500 CALl ,~500 FCNb . 516 RNRA ,5000 -999 2500 -999:2500 NPHI -999,2500 DRHO -999.2500 DT 4.2734 GR DEPT 4500 SP -999 GR -999 NCNb '999 NPHI 60 FCNL 276 .0000 SFLU .2500 GR ,2500 CALl .2500 FCNL .2539 RNRA .2500 -999.2500 IbM -999.2500 NPHI -999.2500 DRHO -999.2500 DT 4,7656 GR DEPT 4400 SP -999 GR -999 NCNb -gg9 NPHI 45 FCNL 340 .0000 SFLU .2500 GR .2500 CALI ,2500 FCNL ,4590 RNRA .0000 -999.2500 IbM -999,2500 NPHI -999 2500 DRHO -999:2500 DT 4.1875 GR DEPT ~00 SP 99 GR -999 NCNb -999 NPHI 45 FCNL 370 :0000 SFLU 2500 GR .2500 CALI .2500 FCN5 0684 RNRA :0000 -999.2500 -999.2500 NPHI -999,2500 DRHO -999.2500 DT 3,8262 GR DEPT !200 SP 999 GR 999 NCNb -999 NPH! 54 0000 SFLU : soo . 500 CALI 2500 FCN5 :9316 RNRA -999.2500 ILN -999.2500 NPHI -999.2500 DRHO -999.2500 DT 4,0508 GR -999,2500 ILL -999 2500 RHOB -999:2500 NRAT -999.2500 GR 46,1875 NCNb -999.2500 ILD -999,2500 RHOB -999,2500 NRAT -999,2500 GR 41,0000 NCNb -999 ~500 ILD '999: 500 RHOB -999,2500 NRAT -999.2500 GR 37.0000 NCNb -999 2500 -999."2500 }{HOB -999.2500 NRAT -999,2500 54,9687 NCNb -999.2500 ILL -999.2500 RHOB -999,2500 NRAT -999,2500 GR 46.2500 NCNb -999,2500 ILL -999,2500 RMOB -999,2500 'NRAT -999,2500 GR 33,9687 NCNb -999,2500 -999,2500 RHOB -999 2500 NRAT -999:2500 GR 5i,9375 NCNL -999,2500 ILD -999.2500 RHOB -999,2500 NRAT -999 ~500 GR 62~ 438 NCNb PAGE -999.2500 -999,2500 -999,2500 -999'2500 1318,0000 -999 2500 -999 2500 -999 2500 -999 2500 1433 0000 -999 2500 -999 2500 -999 2500 -999 2500 1444 0000 -999.2500 -999'2500 -999,2500 -999,2500 1272.0000 .-999.2500 ,999.2500 -999.2500 1317.0000 -999 2500 -999 2500 -999 2500 -999 2500 I425 0000 '999,2500 '999'2500 '999'2500 '999.2500 1416,0000 -999,2500 -999 2500 -999.2500 i325,0000 15 LVP OlO.HO1 VERIFICATION LISTING PAGE DEPT SP GR NCNL NPHI FCNL DEPT SP GR NCNL NPHI FCNL DEPT SP NCNL NPHI FCNL DEPT SP NCNL NPHI FCNL DEPT SP NPHI FCNL DEPT SP GR NPHI FCNL DEPT SP NCNL NPHI FCNL DEPT SP 327,0000 4100,0000 SFLU -999.2500 GR -999.2500 CALI -999.2500 FCNL 48 2422 RNRA 4000,0000 SFLU -999,2500 GR -999,2500 CALI -999 2500 FCNL 56i8848 RNRA 215 2500 3900,0000 SFLU -999.2500 GR -999,2500 CALI -999.2500 FCNL 77,246! RNRA 199,!250 3800,0000 SFLU -999.2500 GR -999.2500 CALI -999,2500 FCNL 53.9551 RNRA 261,7500 3700,0000 SFLU -999,2500 GR -999.2500 CALI -999 2500 FCNL 53:1250 RNRA 252.0000 600 0000 SFLU 69,7266 RNRA 248,8750 35oo.oooo SFLU ~999,2500 GR 999,2500 CALl -999,2500 FCNL 64.2090 RNRA 230,$750 3400.0000 SFLU -999.2500 GR -999.2500 CALl -999.2500 iSM -999.2500 NPHI -999.2500 DRHO -999.2500 DT 4,0898 GR -999,2500 ILM -999.2500 NPHI -999.2500 DRHO -999 2500 DT 5:2305 GR -999.2500 -999.2500 NPHI -999 2500 D HO -999:2500 DT 6.0781 GR -999.2500 IL~ -999,2500 NPHI -999,2500 DRHO -999,2500 DT 4.1836 GR -999 2500 -999".2500 -999,2500 DRHO -999.2500 DT 4.5977 GR -999,2500 ILM :909,2500 NPHI 999.2500 DRHO -999.2500 DT 4.9961 GR -999,2500 ISM -999.2500 NPHI -999.2500 DRHO -999.2500 DT 5.4258 GR -999,2500 -999.2500 NPHI -999,2500 DRHO -999 500 -, 9: soo -999,2§00 -999,2500 51,7188 -999,2500 -999,2500 -999.2500 -999,2500 40.0313 -999,2500 -999.2500 -999'2500 -999.2500 44,3438 -999.2500 .-999,~500 999,2500 -999,2500 36.9062 -999.2500 -999,2500 -999,2500 -999.2500 42.1~62 -999,2500 2500 -999.2500 45.03!3 -999,2500 -999.2500 -999.2500 -999,2500 48.4688 -999.2500 99,2500 RHOB GR RHOB GR RHOB NRAT GR NCNL ILD RHOB NRAT GR NCNL RHOB NRAT GR NCNL ILD RHOB NRAT GR NCNL RHOB NRAT GR NCNL RHOB -999,~500 -999, 500 -999.2500 -999.2500 1409,0000 -999 2500 -999 ~500 -999 500 -999 2500 1126 0000 -999 2500 -999:2500 -999 2500 -999i2500 12tl 0000 -999.2500 -999.2500 -999.2500 -999.2500 1096.0000 -999,2500 -999 2500 -999 2500 -999 2500 1159 0000 -999 2500 -999 2500 :999 2500 999 2500 ~ 244 0000 -999 2500 -999 2500 -999 2500 -999 2500 1253 0000 -999,2500 -999,2500 -999,2500 bVP 010,H01 NCNL -99 NPHI 6 FCNL 23 DEPT 330 SP -99 GR -99 NCNL -99 NPHI 6 FCNL 20 DEPT 320 SP -99 GR -99 NCNL -99 NPHI 5 FCNL 28 DEPT ~10 SP 99 OR -99 NCNL -99 NPHI 5 FCNL 27 DEPT ~0 SP 9 NCNL -9 NPHI FCNL 3 DEPT 29 Sp ~9 NCNL -9 NPHI FCNL 2 D£PT 28 SP -9 NCNb 9 NPHI FCNb 2 SP GR -99 NCNL -99 NPHI 6 FCNL 22 DEPT 260 VERIFICATION 9 2500 FCNL 4!9902 RNRA 0 8750 0 0000 SFLU 9:2500 GR 9.2500 CALI 9,2500 FCNL 8,5547 RNRA 2,8750 0.0000 SFLU 9.2500 OR 9.2500 CALI 9.2500 FCNL 5.2734 RNRA 5.5000 0.0000 SFLU 9.2500 GR 9 25OO CALl 9:2500 FCNL ,4453 RNRA .5000 0000 SFLU :2soo 9.2500 CALI 9 2500 FCNL 3:7598 RNRA 7,OOOO 0,0000 SFLU 9 2500 OR 9:2500 CALI 9.2500 FCNL 5 4785 RNRA 0:0000 0.0000 SFLU 9.2500 GR 9,2500 CAL! 9.2500 FCNb 0.7910 RNRA 9.0000 0000 SFLU :2500 GR 9.2500 CALl 9 2500 FCNL 7:1387 RNRA 5.7500 0,0000 SFLU LISTING -999.2500 DT 5.1406 GR -999 2500 -999:2500 NPHI -999,2500 DRHO -999,2500 DT 5,6680 GR -999.2500 -999.2500 NPHI -999.2500 DRHO -999.2500 DT 4.5859 GR -999 2500 ILM -999:2500 NPHI -.999 2500 DRHO 999:2500 DT 4.2930 GR -999 2500 -999i2500 NPHI -999 2500 DRHO -999.2500 DT 3.9492 -999.2500 -999,2500 NPHI ~999 2500 DRHO 999:2500 DT 5,1523 GR -999,2500 IbM -999 2500 NPHI -999i2500 DRHO -999 2500 DT 4 7461 GR -999.2500 IbM -999.2500 NPHI -999.2500 DRHO -999.2500 DT 5.2109 GR -999.2500 -999 ~500 GR 48:750 NCNL -999.2500 ILD -999.2500 RHOB -999,2500 NRAT -999.2500 GR 48.0313 NCNL -999.2500 -999,2500 -999.2500 NRAT -999 ~500 GR 48~ 063 NCNL -999 )500 ILD -999: 500 RHOB -999 ~500 NRAT -999:500 GR 45,8750 NCNL -99 2500 RHOB -999,2500 NRAT -999,2500 OR 51.0938 NCNL -999.2500 ILD -999.2500 RHOB -999,2500 NRAT -999,2500 GR 32.2500 NCnb -999.2500 -999,2500 RHOB -999 2500 NRAT -999!2500 GR 31 5000 NCNL -999,2500 -999.2500 RHOB -999,2500 NRAT -999.2500 53.0313 NCNb -999.2500 ILD PAGE -999 2500 X187:0000 -999 2500 -999:2500 -999,2500 -999,2500 1150,0000 ~999.2500 .-999,2500 ,999,2500 -999,250~ 1310,0000 '999,2500 '999,2500 '999,2500 '999,2500 1196,0000 -999 ~500 -999 500 -999 2500 -999 2500 1292 0000 '999,2500 '999'2500 '999.2500 '999,2500 i082,0000 -999.2500 -999,2500 -999,2500 -999.2500 1230.0000 -999,2500 -999,2500 -999,2500 -999,2500 1177.0000 -999,2500 17 bVP OIO,H01 VERIFICATION LISTING PAGE SP GR NCNb NPHI FCNL -~99.2500 GR - 99.2500 CAbI -999.2500 FCNb 40.9668 RNRA 274.0000 -999 2500 NPHI -999i2500 DRHO -999 2500 DT 4 2930 GR DEPT ~500,0000 SFLU SP 999,2500 GR GR -999,2500 CALI NCNL -999 2500 FCNL NPHI 63i1836 RNRA FCNL 260 5000 999.2500 IL)4 -'999.2500 NPHI -999 2500 DRHO -999:2500 DT 4.0625 GR DEPT !400.0000 SFLU SP 999.2500 GR GR 999,2500 CALI NCNb -999,2500 FCNL NPHI 71,4844 RNRA FCNL 233.7500 -999.2500 IbM -999.2500 NPHI -999.2500 DRHO -999.2500 DT 4,9258 GR DEPT !342,5000 SFLU SP 999.2500 GR GR 999.2500 CALI NCNb -999,2500 FCNL NPHI 68,8477 RNRA FCNL 213.8750 -999.2500 -999,2500 NPHI -999,2500 DRHO -999.2500 DT 5.1523 GR ** FILE TRAILER FILE NAME :SERVIC,O01 SERVICE NAME VERSION # DATE ~ MAXIMUM LENGTH : 1024 FILE TYPE NEXT FILE NAME ** TAPE TRAILER SERVICE NAME :SERVIC DATE :82/05/25 ORIGIN )651! TAPE NAME CONTINUATION # NEXT TAPE NAME COMMENTS :TAPE COMMENTS ** REEL TRAILER ** SERVICE NAME :SERVIC DATE )82/05/25 ORIGIN : -999.2500 RHOB -999,2500 NRAT -999.2500 GR 35.4688 NCNL -999 2500 ILO -999:2500 R~OB -999 2500 NRAT -999i2500 GR 20 4375 NCNb -999,2500 -99~,2500 RHOB -99 .2500 NRAT -999,2500 GR )1.1250 NCNb -999 2500 '999i2500 RHOB -999 2500 NRAT -999,2500 28,7188 NCNb :999,2500 999.2500 -999.2500 1177.0000 -999,2500 -999.2500 -999.2500 -999,2500 I059,0000 -999.2500 -999,2500 -999,2500 -999,2500 1152.0000 -999 2500 -999 ~500 -999 500 -999 2500 1102 0000 LVP OIO.HO! VERIFICATION LISTING REEL NAME :REEL ID CONTINUATION # ~01 NEXT REEL NAME COMMENTS :REEL COMMENTS EOF **********
