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190-133
PM (ck,1330 Regg;James B (DOA) Sent: Monday, Well ne 10egri 3 Coordinator 0 32 AM [AKDCWelllntegrityCoordinator @bp.com] ��r J 6/��/i 3 To: Regg, James B (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 ( ` Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; lgbokwe, Chidiebere; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; Schwartz, Guy L (DOA) Cc: AK, D&C DHD Well Integrity Engineer; Holt, Ryan P; Well Integrity Coordinator Subject: UNDER EVALUATION: Drill Site 09 Producers with Sustained Casing Pressure on the Inner Annulus During Plant Shutdown Attachments: DS09 TIO and Wellbore Schematics.zip All, The following wells were found to have sustained casing pressure above MOASP on the inner annulus on 06/08/2013 during a plant shutdown . Each well is listed with the tubing/inner annulus/outer annulus pressures. The wells are reclassified as Under Evaluation to facilitate evaluation. 09-01 (PTD#1750760), TIO: 1810/2010/640 psi 09-11 (PTD#1760840), TIO: 2340/2340/140 psi 09-13 (PTD#1770080),TIO: 2050/2110/690 psi 093L(PTD#18316.00 ,TIO: 2000/2010/650 psi SCANNED 09-46(PTD#1901330),TIO: 1380/2010/180 psi Plan forward: 1. DHD: Place wells on production and perform TIFL If any of the TIFL5 fail, the AOGCC will be notified separately for each failure. A copy of the TIO plots and wellbore schematics are included in the attached zip file for reference. Please call with any questions. Thank you, Jack Disbrow 1F-_T dlci 1'Rfi'r{- -+i hJt-/ BP Alaska-Well Integrity Coordinator GOtlobal' .!�rcjanizatioell r Office: 907.659.5102 WIC Email:AKDCWelIIntegrityCoordinator @bp.com 1 Q I- 2 <0 0 . G _ _ M I � M 1 . f M 1 1 M � M O M CL C) ° G) M C) N a co 0 O_ O o I� - TREE= 4-1/16"CM/ SAFEk r NOTES:**4-1/2"CHROMETBG*** WELLHEAD= FMC 09-/� 6 ACTUATOR= ? (,� KB.ELEV= 52' BF.ELEV= I I KOP= 1500' Max Angle 64°@ 13300' Datum MD= 14850' 1 I 2008' -I4-1/2"HES X NIP, ID=3.813" I __. Datum TVD= 8800'SS GAS LIFT MANDRELS 20"CONDUCTOR,94#,H-40,ID=19.124" H 110' ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 3031 2896 39 MMG DOME RK 16 02/15/08 13-3/8"CSG,68#,L80 BTC,ID=12.415" —1 4551' 1 , 6 5938 4536 57 MMG DOME RK 16 02/15/08 © 5 8094 5619 61 MMG SO RK 28 02/15/08 4 9751 6386 61 MMG DMY RK 0 02/04/08 Minimum ID = 3.725" @ 14675' 3 11413 7198 60 MMG DMY RK 0 02/04/08 4-1/2" OTIS X N NIPPLE 2 12652 7792 62 MMG DMY RK 0 02/04/08 1 13975 8408 62 MMG DMY RK 0 _02/04/08 I 1 14420' 1-14-112"HES X NIP,ID=3.813" X ,X 14441' 1--I9-5/8"X 4-1/2"BKR S-3 PKR, ID=3.875" I 1 1 14466' 1-14-1/2"HES X NIP,ID=3.813" I 4-1/2"TBG, 12.64, 13CR-80 VAM TOP, H 14525' I---- .0152 bpf, ID=3.958" / 14540' J—J 9-5/8"X 4-1/2"OVERSHOT CUT LIP GUIDE 4-1/2"TBG STUB(02/03/08) H 14535' I�// -1 14565' 1-I4-1/2"BKR SEAL ASSY, ID=3.812" I 14568' 1-I9-5/8"X 4-1/2"BKR MOD D PKR,ID=4.75" I J'-- 14582' 1-16"MILLOUT EXTENSION,ID=6.00" ''----, 14588' H6"X 4-1/2"XO,ID=3.958" I TOP OF 7"LNR -I 14626' 14626' I-19-5/8"X 7"BKR LNR TOP PKR, ID=? 1 4�\ 14637' 1-19-5/8"X 7"BKR LNR HGR w/TIEBK.ID=? I 4-1/2"TBG-IPC, 12.6#,L-80,.0152 bpf, ID=3.958" H 14687' I\ 1 i 14675' 1--14-1/2"OTIS XN NIP, ID=3.725" I 9-5/8"CSG,47#,L-80 BTC-M,ID=8.681" H 14954' \ 14686' 1-14-1/2"BKR SHEAROUT SUB,ID=3.958" I PERFORATION SUMMARY 14687' --14-1/2"WLEG,ID=3.958" I REF LOG: BHCS on 11/06/90 ANGLE AT TOP PERF: 57°@ 15036' 16. 14689' -I ELMD TT LOGGED 05/06/91 Note: Refer to Production DB for historical pert data 14980' I-17"MARKER JOINT I SIZE SPF INTERVAL Opn/Sqz DATE I 3-3/8" 6 15036-15046 0 12/27/08 3-3/8" 2 15046-15066 0 02/10/92 3-3/8" 2 15072-15078 0 02/10/92 I 3-3/8" 2 15082-15088 0 02/10/92 3-3/8" 0.5 15103-15113 0 05/17/91 ?? FISH-FASDRILL DEBRIS DRLG 02/03/08 3-3/8" 6 15114-15124 0 12/26/08 ' 1� ( ) 1 ftrik_3-3/8" 2 15131 -15150 0 05/06/91 15131' I-I FISH-IBP RUBBER ELEMENT(09/01/01) I 12/07 3-3/8" 4 15165-15191 0 12/07/90 3-3/8" 4 15207-15220 0 12/07/90 PBTD H 15278' 11111111 1111111 11111N 1111111♦ 7"LNR,29 4,L-80, .0371 bpf, ID=6.184" H 15369' 11111111114 1*1 -- 11111111111 TD -1 15371' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/14/90 N28E ORIGINAL COMPLETION 01/09/11 KAL/PJC ELMD TT CORRECTION WELL: r09-46 02/06/08 D14 RWO PERMIT No: 1901330 02/15/08 KSB/TLH GLV C/O API No: 50-029-22092-00 04/13/08 AJW/PJC DRLG DRAFT CORRECTION SEC 1,T1ON,R15E,935'FSL&162'FWL 11/05/08' PP/SV FISH CORRECTIONS 01/13/09 RRD/SV ADPERF(12/27/08) BP Exploration(Alaska) • . bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 aZ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission Q Q 3 3 333 West 7 Avenue l A ` 4.(4° nchorage, Alaska 99501 o9 Subject: Corrosion Inhibitor Treatments of DS -09 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from DS -09 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, *' -1 A --)- Mehreen Vazir BPXA, Well Integrity Coordinator • III 1 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) DS-09 10/20/11 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal 09-01 1750760 50029201880000 Sealed conductor NA NA NA NA NA 09-02 1760160 50029201980000 Sealed conductor NA NA NA NA NA 09-03 1760350 50029202090000 Sealed conductor NA NA NA NA NA 09-04A 1930240 50029202120100 Sealed conductor NA NA NA NA NA 09-05A 1930260 50029202150100 Sealed conductor NA NA NA NA NA 09-06 1760480 50029202160000 Sealed conductor NA NA NA NA NA 09-07A 1990220 50029202230100 Sealed conductor NA NA NA NA NA 09-08 1760700 50029202300000 Sealed conductor NA NA NA NA NA 09-09 1760760 50029202320000 Sealed conductor NA NA NA NA NA 09 -10 1760820 50029202350000 Sealed conductor NA NA NA NA NA 09-11 1760840 50029202360000 0.7 NA 0.7 NA 3.4 7/17/2010 09-12 1770070 50029202390000 Sealed conductor NA NA NA NA NA 09 -13 1770080 50029202400000 Sealed conductor NA NA NA NA NA 09 -14 1770250 50029202490000 Sealed conductor NA NA NA NA NA 09-15A 2070220 50029202560100 Sealed conductor NA NA NA NA NA 09-16 1770370 50029202570000 Sealed conductor NA NA NA NA NA 09-17 1770380 50029202580000 Sealed conductor NA NA NA NA NA 09-18 1770390 50029202590000 Tanko conductor NA NA NA NA NA 09-19 1770400 50029202600000 Sealed conductor NA NA NA NA NA 09 -20 1770410 50029202610000 Sealed conductor NA NA NA NA NA 09 -21 1831600 50029210360000 2.5 NA 2.5 NA 25.5 7/17/2010 09 -22 1831730 50029210490000 6.7 NA 6.7 NA 42.5 7/8/2010 09 -23 1980440 50029210667100 2.2 NA 2.2 NA 15.3 7/8/2010 09-24 1852020 50029214280000 Dust Cover NA NA NA 9.4 10/20/2011 09-25 1840280 50029210830000 3.2 NA 3.2 NA 23.0 7/8/2010 09-26 1840370 50029210910000 0.3 NA 0.3 NA 1.7 7/8/2010 09-27 1850280 50029212910000 Dust Cover NA NA NA 6.8 10/20/2011 09-28A , 1930430 50029212920100 Dust Cover NA NA NA NA NA 09-29 1850960 50029214220000 13.5 3.0 0.5 7/13/2011 11.9 10/20/2011 09-30 1851840 50029214117000 Dust Cover NA NA NA 8.5 10/20/2011 09-31C 1960640 50029213960300 0.2 NA 02 NA 1.7 7/27/2010 09-32 1851180 50029213710000 Sealed conductor NA NA NA N/A NA 09-33A 2081560 50029213650100 9.3 NA 9.3 NA 66.3 7/18/2010 09-34A 1932010 50029213290100 Sealed conductor NA NA NA N/A NA 09-35A 1930310 50029213140100 2.0 NA 2 NA 17.0 7/27/2010 09-36C 1951140 50029214290300 Dust Cover NA NA NA 9.4 10/20/2011 09-37 1940280 50029224510000 Open Flutes NA 0 NA 3.4 10/20/2011 09-38 1890210 50029219190000 0.1 NA 0.1 NA 6.8 10/20/2011 09-39 1910120 50029221330000 1.2 NA 12 NA 11.9 7/17/2010 09-40 1901690 50029221180000 1.3 NA 1.3 NA 10.2 7/17/2010 09-41 1900740 50029220540000 Dust Cover NA NA NA N/A NA 09-42A 1990070 500292205901 SC Leak 09-43 1901070 50029220780000 11.3 6.0 1.0 7/13/2011 8.5 7/18/2011 09-44A 2091570 50029220870100 1.5 NA 1.5 NA 102 9/16/2010 09-45 1901150 50029220830000 0.2 NA 0.2 NA 3.4 10/20/2011 -� 09-46 1901330 50029220920000 1.5 NA 1.5 NA 102 7/18/2010 09-47 1901460 50029220980000 1.3 NA 1.3 NA 6.8 7/18/2010 09-48 1910040 50029221280000 1.3 NA 1.3 NA 6.8 7/18/2010 09-49 1921340 50029223170000 0.7 NA 0.7 NA 2.6 10/20/2011 09-50 1921490 50029223250000 Dust Cover NA NA NA 4.3 10/20/2011 09-51 1921410 50029223200000 Dust Cover NA NA NA 3.4 10/20/2011 03/24/11 W NO. 5709 Alaska Data 8 Consuhing Services Company: State of Alaska 2525 Gambe6 Street, Suite 400 Alaska Oil 8 Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job d Log Description Date BL Color CD 01-20 BBSK -00054 PRODUCTION PROFILE - 03104111 1 • _ 1 09-46 BMSA-00006 PRODUCTION PROFILE .1iNZINk •, - 1 14.05A BBKA -00090 PRODUCTION PROFILE 1!l► 1 12 -30 BBSK -00055 LDL _Y32j�! ' ' • 74- 2 1 D -22C BCRD -00086 SCMT _ ! 03/04/11 __ • .. _ 1 _ 1 09 -02 BBSK -00052 PRODUCTION PROFILE 1 09-41 BBSK -00053 PRODUCTION PROFILE ^ T re • _ 1 15 -05A BCRD -00084 SCMT L'L �X(. _ TA�3' 1 1 14 BCRD -00083 USIT - — 4:1 02/11/11 6 , 1 1 , F -35 BG4H -00037 PRODUCTION PROFILE yi( 0 $ l 02122111 1 • `fig 1 • Z -31 BJOH -00009 INJECTION PROFILE el p j ) ' " { / g 02/12/11 1 _ • O 1 06 -16 BCRD -00090 .PRODUCTION PROFILE !! b( - (5? 03107111 1 1 X -17 BJOH -00008 RST /'f /..../ L Ipq qy, 02/11/11 1 g�ggr 1 H-20 BBSK-00051 RST 06-20A BNWP -00003 RST �Q— " '1� -1- 02117/11 1 p ojr,"Y 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 • MililiED MAR 6 2011 s t 1- � . .. 4i 1"-i n r ", ~~~ I;;I `~? ~ STATE OF ALASKA t ALASKA OIL AND GAS CONSERVATION COMMON ~~ REPORT OF SUNDRY WELL OPERATIONS RECE1~/E~ DEG 3 1 2008 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate^ as a I Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extens{ADrage Change Approved Program ~ Operat. Shutdown ~ Perforate ~ R Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ ~ Exploratory 190-1330 ` 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-22092-00-00 7. KB Elevation (ft): 9. Well Name and Number: 52 KB PBU 09-46 8. Property Designation: 10. Field/Pool(s): ADLO-028345. PRUDHOE BAY Field/ PRUDHOE OIL Pool • 11. Present Well Condition Summary: Total Depth measured 15371 feet Plugs (measured) None true vertical 9 @e ~ •~•o~J Junk (measured) 15131' 9/1/01 D qr Effective Depth measured 15278 feet ~ ~ s~- ~ ; ~ r,, `~ Eb;, ~~ ~ " ' ~~~~~' ~ " ~ ~~ ~ true vertical 9088 feet ' ~ `" ' ` ' ° Casing Length Size MD TVD Burst Collapse Conductor 105' 20" Surface - 105' Surface - 105' 1490 470 Surface 4551' 13-3/8" 68# L-80 Surface - 4551' Surface - 3801' 4930 2270 Intermediate 14954' 9-518" 47# L-80 Surface - 14954' Surface - 8909' 6870 4760 Liner 743' 7" 29# L-80 14626' - 15369' 8731' - 9138' 8160 7020 Perforation depth: Measured depth: SEE ATTACHED - _ True Vertical depth: Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR-80 Surface - 14525' 4-1/2" 12.6# L-80 14535' - 14687' Packers and SSSV (type and measured depth) 9-5/8"X4-1/2" BKR S-3 PKR 14441' 9-5/8"X4-1 /2" BKR MOD D PKR 14568' 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 173 0 5362 283 Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development ~' ~ Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas WAG r GINJ WINJ ~ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary PrebJ Title Data Management Engineer Signature Phone 564-4944 Date 12/29/2008 Form 10-404 Rwised 04/2006 `" ~, ~~ ~ Q `~ 1D~g ~~ ~ ` Submit Origin~~nly~• Z • Gp ~ /I 09-46 190-1330 PEKE ATT~4CHMENT • Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 09-46 12/7/90 PER 15,165. 15,191. 9,025.33 9,039.68 09-46 12/7/90 PER 15,207. 15,220. 9,048.52 9,055.71 09-46 5/6/91 APF 15,131. 15,150. 9,006.61 9,017.06 09-46 5/17/91 APF 15,103. 15,113. 8,991.23 8,996.72 09-46 2/10/92 APF 15,046. 15,066. 8,959.92 8,970.91 09-46 2/10/92 APF 15,072. 15,078. 8,974.21 8,977.51 09-46 2/10/92 APF 15,082. 15,088. 8,979.7 8,983. 09-46 11/6/99 BPS 14,614. 15,278. 8,724.76 9,087.77 09-46 10/12/01 BPP 14,614. 15,278. 8,724.76 9,087.77 09-46 12/26/08 APF 15,114. 15,124. 8,997.26 9,002.76 09-46 12/27/08 APF 15,036. 15,046. 8,954.42 8,959.92 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE C~ 09-46 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 12/26/20081*""WELL SHUT IN ON ARRIVAL"** INITIAL T/I/0= 1500/1480/140. TUBING FLUID PACKED PRIOR TO !ARRIVAL. RU ELINE FOR 3 3/8" 3406 POWERJET HMX, 6 SPF, 60 DEG PHASING INTERVALS 15114' - 15124' AND 15036' - 15046' IN TWO RUNS. PERFORATED 15,114-15,124 FT. DEPTH CORRELATED TO SWS CET j ~ DATED 22-NOV-1990. 3 ~***JOB CONTINUED 27 DEC 08""* 12/27/2008 '"'"CONTINUED FROM 26-DEC-2008*** ELINE PERFORATING 3 3/8" 3406 POWERJET HMX, 6 SPF, 60 DEG PHASING INTERVAL 15036 - 15046 FT. DEPTH CORRELATED TO CBL DATED 22-NOV-199. D T TAG TD. FINAL T/I/O 1520/1520/140. WELL LEFT SHUT-IN. NOTIFIED DSO AND APPROVED ALL VALVE POSITIONS UPON DEPARTURE. NOTIFIED DSO THAT WELL IS READY TO POP. "*"JOB COMPLETE*"* FLUIDS PUMPED BBLS 1 diesel .5 meth 1.5 Total STATE OF ALASKA -~~~RECEtVED ~~ AL~ OIL AND GAS CONSERVATION COM~ION A 0 5 2008 REPORT OF SUNDRY WELL OPERATIONS M R Ata~ca oil 8 Gas cons. commission 1. Operations Performed: 14nChOfa~ ^ Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ~~ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory ~~ 190-133 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 ~ 50-029-22092-00-00 7. KB Elevation (ft): ~ 52, 9. Well Name and Number. `~.;, PBU 09-46 8. Property Designation:.. 10. Field /.Pool(s): ~ ADL 028345 ~. Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 15371 feet true vertical 9139 feet Plugs (measured) None Effective depth: measured 15278 feet Junk (measured) 15131 true vertical 9088 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 105' 20" 105' 105' 1490 470 Surface 4551' 13-3/8" 4551' 3801' 4930 2270 Intermediate 14954' 9-5/8" 14954' 8909' 6870 4760 Production Liner 743' 7" 14626' - 15369' 8731' - 9138' 8160 7020 ~(Y~ APR ~. ~ 200 Perforation Depth MD (ft): 15046' - 15220' Perforation Depth TVD (ft): 8960' - 9056' 4-1/2", 12.6# 13Cr80 / L-80 14686' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 4-112" Baker'S-3' packer; 14441 ; 9-518" x 4-1/2" Baker Model 'D' packer 14568' 12. Stimulation or cement squeeze summary: Intervals treated (measured): :; ~ ~t~~~~ '.~ ~ rUO Treatment description including volumes used and final p ressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: [J Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Welt Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Aras Worthington, 564-4102 N/A Printed Name Terrie Hubble Title Drilling Technologist Si Prepared By Name/Number: D ~~ gnature Phone 564-462$ Date Terrie Hubble, 564-4628 Form 10-404 Revised 04/2006 ~~ ~ ~ ~ 1 ;4-~j Submit Original Only ~O l r ~ • • Well History Well Date Summary 09-46 1/5/2008 '**VVB_L S/1 ON ARRNAL'""(pre-rw o) DRFTID VVRH 3.70 OHYT. AND S.B TO 15,122' SLM (no sample recovered) '*'VVB_L L~ f S/t'*` DSO NOTN=1® 09-46 1/10!2008 TlVO= Assist E Line 09-46 1/10/2008 T/Y0=2100/2000!180 Assist E~Line w ith fasdrNl (Pre RUVO) Loaded TBG w ith 290 bbls crude, E-Line set fasdriN. Pumped 450 bbts crude dow n tbg taking returns up IA through jumper to Fiow line. Shut in jumper, Pumped 17 bbls dow n tbg to pressure TxtA to test pressures. CMIT TxIA PASS®to 3500 psi. Loss of 50/60 psi 1st 15 min, bss of 30/20 2nd 15 Alin. for a total of 80180 for 30 min test. Bled pressure to FL. Continued on 01-11-08 09-46 1/10/2008 VHBL SHUT N ON ARRNAL M1AL TN0:2000/700/150. (E LNE SET R.UG AND JET CUT 4.5" T8G). SET 4.5" FASDF~.L PLUG AT 14611' (MD ~t3V8V1) N TUBNG TAL TOP OF PLUG AT 14610.3'. BEGN CAIIT TO 3500 PSL ""JOB nK:UAlFI_ETE - GONIT9HU® ON 1 t-JAN-2008'""` 09-46 1/11/2008 Continued from 01-10-08 WSR Freeze protect FL w/ 5 bbls neat methanol, 45 bbls Crude. Tags hung, Casbg valves open to gauges. FWI-IP=3001320/180 09-46 1/11/2008 AWGRS CflMTW1J® FROM 10-JAN-2008. CMtT TO 3500 PSI PASSE JET CUT 4.5" TUBNVG AT 14528' TOP OF 1ST FULL JONT ABOVE THE PACKt3~. FNAL T/Y . 1 5 1 09-46 1/19/2008 T/Y0=200/250/180 Circ-Out, (~Tx1A PASS® to 3500 psi. AJIT OA PASS® to 2400 psi (Pre RVVO) Pumped 5 bbls meth spear, 1524 bbls 1 °/u KCL dow n Tbg and up W to Fbw tine. Freeze protected w eN w / 160 bbls of diesel. U-tube TxY~. CMT Tx W to 3500 psi. tamped 13.4 bbls diesel to achieve test pressure. T/I bst 0/20 psi 1st 15 miss, T!I bst OIO psi 2nd 15 rains for a total bss of 0/20 b 30 rains. Bled back -14 bbls. Ar1T=0A to 2400 psi.. Pumped 11.5 bbls crude dow n OA to achieve test pressure. OiA bst 100 psi 1st 15 inns, QA bst 40 psi 2nd 15 wins for a total bss of 140 psi b 30 rains. Bled back ~ 7 bbd. Freeze protected fbw Nne. Fina! tM-Ps-= 0!0!0 Annuli gauges tagged and open upon departure. 09-46 1/20/2008 7/Y~/OA= 0/0/0 Temp= cold PPPOT-T (PASS) PPPDT-IC (PASS) (PRE RV110 ) PPPDt T RU 2 HP bleed tools onto THA 100 psi to 0 psi, fA~sh void until clean returns achieved. R~essured to 5000 psi for 30 minute test, 5000/ 15 minutes, 5000130 minutes. Bleed void to 0 psi, RD test equipment, re instaNed Alerrite cap. Cycle and torque LOS "ET style" a1 functbned no problems PPPOT C RU 2 HP bleed tools onto C test void 500 psi to 0 psi. Ressured to 3500 psi for 30 irinute test, 3000/ 15 minutes, 3500/ 15 minutes, 3450/ 30 mmvmtes. Bleed C void to 0 psi, RD test equipment re instaNed Alemite cap. Cycle and torque LDS "t? style" aN functioned no problems 09-46 1/27/2008 T=VAC_ Set 4" FMC 1S-A 100 BPV. ~Re Doyon 14). 09-46 1 /28!2008 Cost placeholder for GBR to remove grating in the w eNhouse pre-rig. 09-46 1/31/2008 PliNed 4" ISA Test plug 09-46 1/31/2008 T/YO~/O/0. PuNed 4 1116 ~-A BPV. DOYON 14. 1-2' t7(T~ 78" NO PROBLBVIS ~ ~ ~~ ' 09-46 2/4/2008 TIYO = 0/0/0. SI. IA FL for Rig. IA FL ~ 7260 . 09-46 2/4/2008 T/YO = 0/0/0. Temp = SL fA FL (Doyon 14). IA FL ~ 3606'. 09-46 2/13/2008 PuNed 4 1/16" CNV H BPV @100"...post rig....no problems. 09-46 2/14/2008 '*'WB.L S/1ONARRNAL"'"(post rwo) ~~,~- '~ DIAL BALL & ROD FROM 14,455' SLM "'"C~NTI~AJE JOB ON 2/15108 WSR"* 09-46 2/15/2008 '*`CONIfM1® JOB FROM 2/14/08"* (Post rig) PIAL® DGLV'S FROM STA'S #5 ~ 8094' MD 8~ #6 (d~ 5937' AID. PIAL®STA# 7 DCR ~ 3031' AiD. SET LGLV'S N STA'S #7 ~ 3031' ND 8 #6 ~ 593T ND SET S/O GLV N STA# 5 @8094' MD. PIAL® 41/2" RHC PLI1G BODY @ 14,466' MD. *'"VVB_L LB-T S/I, DSO NOT~~"'" Well Date Summary 09-46 2/27/2008 T/VO = 480/940!1880_ Temp Hot. Shoot IA FL for GLE IA FL @ 6858' sta #2. • • BP EXPLORATION Page 1 of 7 Operations Summary Report Legal Well Name: 09-46 Common Well Name: 09-46 Spud Date: 10/12/1990 Event Name: WORKOVER Start: 1/29/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 2/6/2008 Rig Name: DOYON 14 Rig Number: Date I From - To Hours I Task Code NPT Phase Description of Operations 1/26/2008 22:00 - 00:00 2.00 RIGD P PRE RD rig on well 02-31A in preparation to lay down derrick. 1/27/2008 00:00 - 12:00 12.00 RIGD P PRE Cont. RD rig on well 02-31A in preparation to LD derrick. LD 12:00 - 14:00 2.00 RIGD P PRE 14:00 - 15:30 1.50 RIGD P PRE 15:30 - 20:00 4.50 RIGD P PRE 20:00 - 22:00 2.00 RIGD P PRE 22:00 - 00:00 2.00 RIGD P PRE 1/28/2008 00:00 - 02:00 2.00 RIGD P PRE 02:00 - 03:00 1.00 MOB P PRE 03:00 - 12:00 9.00 MOB P PRE 12:00 - 16:00 4.00 MOB P PRE 16:00 - 22:00 6.00 RIGU P PRE 22:00 - 23:00 1.00 RIGU P PRE 23:00 - 00:00 1.00 RIGU P PRE 1/29/2008 00:00 - 03:00 3.00 RIGU P PRE 03:00 - 04:30 1.50 RIGU P 04:30 - 07:30 3.00 RIGU P 07:30 - 08:00 0.50 RIGU P 08:00 - 12:00 4.00 RIGU P 12:00 - 15:00 I 3.001 RIGU I P 15:00 - 17:00 2.001 WHSUR P 17:00 - 18:00 I 1.001 WHSUR I P 18:00 - 19:00 I 1.00 I W HSU R I P 19:00 - 21:30 2.50 W HSU R P 21:30 - 22:30 I 1.001 WHSUR I P PRE PRE PRE PRE PRE top drive Pin C-section. Hang bridle line and sheave Skid rig floor to moving position LD wind walls LD derrick Slid blocks forward in preparation to LD A-legs RD blocks. Pull back lines. LD A-legs Pull rig off well to DS 2 access road Move rig f/ DS 2 to DS 17 Cont. moving rig f/ DS 17 to DS 9. Spot rig on pad. Raise derrick and wind walls Skid rig floor Position rig on well 09-46 Spot Rig over Well. -Shim rig. Skid Rig Floor. UD Bridle Lines. -Hang Bridle Lines in Derrick & Tie Back. -Set C-Section. UD Carriage for Blocks. P/U Top Drive. -Attach Top Drive Rollers. -Stand back Jump Rams. -C/O Roughneck Dies. -C/O Saver Sub to 4 1/2" IF. -Hook up Service Loop & Kelly Hose. -Hang Tongs. Hook up lines under Rig Floor. -Install Mud Manifold. -Install brace on Top Drive rails. -Install IBOP & Torque Tube on Top Drive. -Hang Mud Bucket. -Spot Tiger Tank. -R/U hard line to tank. DECOMP Ri Acce ted C«? 15:00 hrs. -Fill pits w/ 870 bbls of 8.5 ppg Seawater. -Load 5" DP in Pipe Shed. -C/O Bell Guide and Jaws on Top Drive to 5". -Install second valve on IA. DECOMP R/U DSM Lubricator. 1 -Test to 500 psi for 5 minutes. Chart test - ok. DECOMP R/U lines on Tree for Diesel Displacement. -Pressure test lines to 3500 psi. DECOMP Reverse in 45 bbls Seawater. -Pump 175 bbls Seawater the long way. -Allow diesel to migrate for 30 min. -Pump an additional 40 bbls Seawater down tubing w/ returns up the annulus. -245-300 gpm (~ 700-1100 psi. DECOMP FMC install BPV. Printed: 2/13/2008 2:25:02 PM • • BP EXPLORATION Operations Summary Report Page2of7~ Legal Well Name: 09-46 ,Common Well Name: 09-46 Spud Date: 10/12/1990 Event Name: WORKOVER Start: 1/29/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 2/6/2008 ,Rig Name: DOYON 14 Rig Number: Date i From - To Hours i Task Code ~ NPT ~ Phase Description of Operations r - -- - _ 1 /29/2008 ~ 21:30 - 22:30 _ 1.00 WHSUR P DECOMP -Test from below w/ 2000 asi. Hold 30 min & Chart Test - ok. ~ -Good Test. ~ 22:30 - 00:00 1.50 WHSUR P DECOMP N/D Tree. -FMC reps decommission tree. 1/30/2008 00:00 - 00:30 0.50 WHSUR P DECOMP Install BPV Blanking Plug. -Remove Tree from Cellar. 00:30 - 09:00 8.50 BOPSU P DECOMP Install Adapter Flange & Spacer Spool. -N/U BOPs iser, Pitcher Nipple & Flow Line. -Remove spacers from Choke line & N/U. 09:00 - 10:00 1.00 BOPSU P DECOMP M/U Test Jt to XO & Screw into Blanking Plug. -R/U to test BOPS. 10:00 - 12:00 2.00 BOPSU N SFAL DECOMP Attem t to test BOPS. pHigh Pressure test unsuccessful. -Blanking Plug leaking. -Contact FMC for Blanking Plug Rebuild Kit. 12:00 - 13:00 1.00 BOPSU N SFAL DECOMP Continue to test surface BOPE until FMC arrives. 13:00 - 14:30 1.50 BOPSU N SFAL DECOMP Pull Blanking Plug. -FMC reps rebuild Plug. -Attempt to reinstall Plug thru stack. -Unsuccessful. 14:30 - 16:00 1.50 BOPSU N SFAL DECOMP N/D BOP stack & Choke Line. 16:00 - 18:00 2.00 BOPSU N SFAL DECOMP Attempt to install Blanking Plug. -9" LH Acme threads match, but ID of Plug too large. -Internal Seals in Plug not engaging. -Get correct Plug & Install. 18:00 - 19:30 1.50 BOPSU N SFAL DECOMP N/U BOP stack & Choke line. 19:30 - 20:30 1.00 BOPSU N SFAL DECOMP R/U to test BOPs. 20:30 - 00:00 3.50 BOPSU P DECOMP Test BOPE: - IBOPs [Manual IBOP leaking], Choke Manifold. -Choke, Kill Line Valves & Floor Valves. -Test per BP procedures. -Test 250 psi low, 3500 psi high for 5 min per test. -Chart all tests. -Test witnessed by WSL &Tourpusher. -AOGCC rep John Crisp waived witness. 1/31/2008 00:00 - 03:30 3.50 BOPSU P DECOMP Test Bottom Rams w 4 1/2" test jt. -Test per BP procedures. -Test 250 psi low, 3500 psi high for 5 min per test. -Chart all tests. -Test witnessed by WSL &Tourpusher. -AOGCC rep John Crisp waived witness. -Replace Manual IBOP & Retest. -Complete BOP test -Good Test. 03:30 - 04:00 0.50 BOPSU P DECOMP RID Test Equipment. -Pull BPV Blanking Plug w/ test jt. 04:00 - 09:00 5.00 WHSUR P DECOMP R/U Lubricator Extension. -P/U & R/U DSM Lubricator. -Test Lubricator to 500 psi for 5 min. Chart test. -DSM pull BPV. ;Had trouble pulling BPV. Took 5 tries before successful. -R/D DSM Lubricator & Lubricator Extension. 09:00 - 10:30 1.50 PULL P DECOMP P/U Bails & Elevators & 1 jt 5" DP. -M/U Spear per Baker rep & RIH. -Screw in Top Drive Printed: 2/13/2008 2:25:02 PM • BP EXPLORATION Operations Summary Report Page3of7~ Legal Well Name: 09-46 Common Well Name: 09-46 Spud Date: 10/12/1990 Event Name: WORKOVER Start: 1/29/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 2/6/2008 Rig Name: DOYON 14 Rig Number: Date j From - To ~ Hours 'I Task ~~ Code NPT Phase Description of Operations __ ~_ -_ ! _1 _ _ L_ ~ I -__ _ - - - -- 11/31/2008 109:00 - 10:30 I 1.501 PULL I P 10:30 - 12:00 1.501 PULL P 12:00 - 13:00 ~ 1.001 PULL P 13:00 - 13:30 0.50 PULL P 13:30 - 14:30 1.00 PULL P 14:30 - 17:30 3.00 PULL P 17:30 - 18:00 0.50 PULL P 18:00 - 00:00 6.00 PULL P 2/1/2008 00:00 - 05:00 5.00 PULL P 05:00 - 05:30 0.50 PULL P 05:30 - 07:00 1.50 PULL P 07:00 - 07:30 0.50 PULL P 07:30 - 08:30 1.00 CLEAN P 08:30 - 11:00 2.50 CLEAN P 11:00 - 11:30 0.50 CLEAN P 11:30 - 12:00 0.50 CLEAN P DECOMP -Engage Tubing hanger. -BOLDS. -Pull Hanger to Rig Floor. -PUW = 180K. DECOMP Circulate the following Surface to Surface: -40 bbls Safe Surf O. -50 bbls Seawater. -40 bbls Safe Surf O. -380 gpm @ 1760 psi. DECOMP Continue Circulating Safe Surf O Pills. -380 gpm C~ 1760 psi. DECOMP UD Spear & Tubing Hanger. DECOMP PJSM -Pull & UD Tubing. -R/U to Pull Tubing. -R/U Control Line Spooling unit. -R/U Stacked Tongs. DECOMP UD 4 1/2" 12.6# L-80 BTC-M Tubin to SSSV. -51 jts of Tbg recovered. DECOMP R/D Schlumberger Control Line Spooling Unit. -Recovered 27 S/S Bands (of 30). -Recovered 25 Clamps (of 25). DECOMP Continue to UD 4 1/2" i2.6" L-80 BTC-M Tubing. DECOMP UD 4 1/2" 12.6# L-80 BTC-M Tubing. -(UD - 344 jts total, plus 1 cut jt ~ 11.1'). -(UD 10 GLMs & 1 SSSV). -Description of Jet cut is a text book cut. -Belled bottom O.D. = 4 7/8". DECOMP Clear Rig floor of Tbg running tools. DECOMP Clean Rig floor. DECOMP Install Wear ring. DECOMP PJU BHA. DECOMP PJSM. - M/U BHA. DECOMP P/U 5" D.P. DECOMP M/U RTTS. P/U 3jts 5" D.P. & RIH. Stand back 1 Std of D.P. 12:00 - 13:00 1.00 CLEAN P DECOMP R/U & test RTTS to 3500 psi / 30 minutes - OK. 13:00 - 13:30 0.50 CLEAN P DECOMP Pull Wear ring. 13:30 - 22:00 8.50 BOPSU P DECOMP N/D Stack & Choke line. Remove IA double valve. -Remove Spool &Packoff. -Cut 1"off of Stump. -M/U running tool & set new Packoff. -RILDS. UD running tool. -P/U Tbg Spool. 22:00 - 23:00 ! 1.001 CLEAN I P -Install Riser, Flow line, Hole fill & Bleed off line. -M/U Turnbuckles & IA double valve. -Test Packoff to 3,500 psi f/ 10 minutes - OK. DECOMP Install Wear ring. -R/U to test Flanges, Choke & Kill line. -Test same to 250 si low & 3 500 si High. -Chart each test f/ 5 minutes -Pass. -R/D test equipment. Panted: 2/13/2118 2:25:02 PM • BP EXPLORATION Operations Summary Report Legal Well Name: 09-46 Common Well Name: 09-46 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To Hours Task ~ Code NPT 2/1/2008 22:00 - 23:00 1.OOTCLEAN P I 23:00 - 00:00 1.00 CLEAN P 2/2/2008 00:00 - 01:00 1.00 CLEAN I P 01:00 - 12:00 I 11.001 CLEAN I P 12:00 - 14:00 2.00 CLEAN P 14:00 - 15:00 1.00 CLEAN P 15:00 - 17:30 I 2.50 I CLEAN I P 17:30 - 20:00 I 2.501 CLEAN I P 20:00 - 21:30 I 1.501 CLEAN I P 21:30 - 00:00 2.50 CLEAN P 2/3/2008 00:00 - 04:00 4.00 CLEAN P 04:00 - 05:30 1.50 CLEAN P 05:30 - 06:00 0.50 CLEAN P 06:00 - 07:00 1.00 CLEAN P 07:00 - 07:30 0.50 CLEAN P 07:30 - 09:30 2.00 CLEAN P 09:30 - 12:00 2.50 CLEAN P 12:00 - 15:30 3.50 CLEAN P 15:30 - 16:30 1.00 CLEAN P 16:30 - 17:30 1.00 CLEAN P 17:30 - 18:30 1.00 CLEAN P 18:30 - 20:00 1.50 CLEAN P 20:00 - 21:30 1.50 CLEAN P 21:30 - 00:00 2.50 CLEAN P 2/4/2008 ~ 00:00 - 00:30 ~ 0.50 ~ CLEAN ~ P 00:30 - 01:00 I 0.50 I CLEAN I P 01:00 - 03:30 I 2.501 CLEAN I P Start: 1 /29/2008 Rig Release: 2/6/2008 Rig Number: Page 4 of 7 Spud Date: 10/12/1990 End: Phase ~ Description of Operations DECOMP -Blow down Choke & Kill lines. DECOMP R/U to retrieve RTTS. -P/U 1 Std of D. P. & Running tool. DECOMP Stin into RTTS r -Pull 1 Std. UD RTTS. DECOMP Run in racked backed Std of D.P. -P/U 5" D.P. & sin le in hole to 13,668' md. DECOMP Continue to P/U D.P. to 14,527' md. DECOMP P/U 1 jt of D. P. & obtain parameters. -PUW= 280K, SOW= 190K, ROT wt=225K. -RPM=60, T0= 15K, GPM= 336 ~ 680 Psi. -Dress off Tbg stump f/ 14,533' to 14,535' md. DECOMP Pump two Hi Vis Sweeps. -Rotate and reciprocate. -60 ft strokes 10 RPM. -GPM= 714 C~ 2,330 Psi. DECOMP Flow check well -static. -Pump dry job. UD 1 jt of D.P. -Blow down Top Drive. -POH f/ 14,535' to 13,098' md. DECOMP Cut & slip drilling line. -Service Top Drive, Blocks & Crown. DECOMP Continue to POH f/ 13,098 to 9,489' md. DECOMP Continue to POH to BHA C~ 329' md. DECOMP UD Dress off BHA. Clean Junk baskets. DECOMP M/U Junk baskets. UD Jars & Junk baskets. DECOMP R/U to test 9 5/8" Casing. -Test Casin to 3,500 si f/ 30 minutes -Pass. DECOMP Clear floor of Fishing tools. DECOMP M/U 2.875" Drillout assembly. DECOMP RIH w/ Drillout assy on 5" D.P. to 5,800' md. DECOMP Continue to RIH to 12,044' md. DECOMP Adjust KeAy hose & reposition service loop tie downs. DECOMP RIH f/ 12,044'to 14,421' md. DECOMP Performed D-1 & Rig evacuation drill. -Held post drill discussion. DECOMP PJSM. -Cut & slip Drlg line. DECOMP Single in the hole f/ 14,421' to 14,535' md. -Tag Tbg stump @ 14,535' md. DECOMP Sheared out C~ 7K. -Continue in hole, tagged up C~3 14,616' md. -Obtain SPRs @ 14,585' and / 8,683' tvd. -Obtain Milling parameters: -PUW= 280K, SOW= 190K, ROT wt= 225K. -RPM= 80, Tq= 8K. GPM= 271 @ 1,750 psi. -Be in millin on Plu ~ 14,616' md. DECOMP Continue to mill on Plug ~ 14,616' md. -275 GPM / 1750 psi. -RPM= 80, Tq= 8K. DECOMP Push Pluq to 14,690' and out of Tbq tail. -Blow down Top Drive. DECOMP Attempt to fill backside without success. Printed: 2/13/2008 2:25:02 PM BP EXPLORATION Operations Summary Report Page 5 of 7 Legal Well Name: 09-46 Common Well Name: 09-46 Spud Date: 10/12/1990 Event Name: WORKOVER Start: 1/29/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 2/6/2008 Rig Name: DOYON 14 Rig Number: NPT ` Description of Operations Date From - To I Hours Task Code Phase 2/4/2008 01:00 - 03:30 2.50 CLEAN P DECOMP -Losses ~ 720 bbls. -Contact DHD to come out and shoot fluid levels. 03:30 - 04:00 0.50 CLEAN P DECOMP hile utilizin constant hole fill method: -POH UD D.P. f/ 14,611' to 13,656' md. -DHD arrives. 04:00 - 05:30 1.50 CLEAN P DECOMP DHD to shoot fluid levels. -Fluid levels established @ 7 260' md. 05:30 - 07:00 1.50 CLEAN P DECOMP Continue to POH. -UD D.P. f/ 13,656' to 12,300' md. -Pum in 20 bbls eve 5 Stds. 07:00 - 07:30 0.50 CLEAN P DECOMP DHD -shoot fluid level ~ 7,326' md. 07:30 - 09:30 2.00 CLEAN P DECOMP POH UD D.P. f/ 12,300' to 10,100' md. -Pum 25 bbls eve 15 minutes. 09:30 - 10:30 1.00 CLEAN P DECOMP DHD -shoot fluid level C~ 3 606' md. 10:30 - 12:00 1.50 CLEAN P DECOMP Continue to POH. -UD D.P. f/ 10,100' to 8,700' md. -Pump 15 bbls every 15 minutes. 12:00 - 13:30 1.50 CLEAN P DECOMP PJSM. -Continue to POH. -UD D. P. f/ 8,700' to 7,300' md. -Pump 15 bbls every 15 minutes. -Fluid loss for Tour= 1 050 bbls. 13:30 - 15:00 1.50 CLEAN P DECOMP DHD -shoot fluid levels @ 2,460' md. 15:00 - 20:00 5.00 CLEAN P DECOMP Continue to POH. -UD D. P. f/ 7,300' to 429' md. -Pump 15 bbls every 15 minutes. 20:00 - 23:00 3.00 CLEAN P DECOMP UD BHA: Pump out sub, Oil Jar, Bumper sub, Bit sub, -2 x Boot baskets, Double Pin sub, 2 x XOs, -6 X 3 1/8" DCs, Shear Pin Guide assy, Junk Mill, -Bushing, Washpipe extension & Cut Lip Guide. -Pump 15 bbls every 15 minutes. 23:00 - 00:00 1.00 CLEAN P DECOMP Clear Rig floor of Fishing tools, Tongs, Slips. -UD Elevators. -Pump 15 bbls every 15 minutes. -Fluid loss for Tour= 720 bbls. -Fluid loss for da = 1 770 bbls 2/5/2008 00:00 - 00:30 0.50 CLEAN P DECOMP Pull Wear ring. -Pump 15 bbls every 15 minutes. 00:30 - 02:30 2.00 BUNCO RUNCMP R/U to run 4 1/2" 13Cr Vam Top Tbg. -Pump 15 bbls every 15 minutes. 02:30 - 12:00 9.50 BUNCO RUNCMP PJSM -Run 4 1/2" Tbg per program to 7,170' md. -Utilize: "Jet Lube Seal Guard" thread compound, -Stabbing guide, Single jt compensator, -Torque turn each connection, -Baker Lok all connections below the Packer. -Optimum Tq= 4,440 fUlbs. -Maximum Tq= 4,880 fUlbs. -Pump 15 bbls every 15 minutes. -Fluid loss for Tour= 690 bbls. 12:00 - 20:00 8.00 BUNCO RUNCMP Continue running 4 1/2" 13Cr Tbg. -Run Tbg f/ 7,170' to 14,528' md. -Pump 15 bbls every 15 minutes. 20:00 - 23:00 3.00 BUNCO RUNCMP R/U to wash over stump to No-Go ~ 14,538' md. -No pressure increase noted washing over stump. Printed: 2/13/2008 2:25:02 PM ., BP EXPLORATION Operations Summary Report Page 6 of 7 Legal Well Name: 09-46 Common Well Name: 09-46 Spud Date: 10/12/1990 Event Name: WORKOVER Start: 1/29/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 2/6/2008 Rig Name: DOYON 14 Rig Number: Date ~ From - To Hours ~ Task Code NPT Phase ~ Description of Operations 2/5/2008 20:00 - 23:00 I 3.00 23:00 - 00:00 I 1.00 2/6/2008 100:00 - 01:00 f 1.00 01:00 - 05:00 I 4.00 05:00 - 07:30 I 2.50 RUNCMP -P/U jts 341 & 342. -No-Go'd the stump C~ 1 -First shear ~ 12K, second shear ~ 13K. -PUW= 195K, SOW= 124K. -L/D 3 jts of Tbg. -P/U 9.74' pup for spaceout. -P/U 1 jt, Tbg hanger & landing jt. -Set Hanger & RILDS. RUNCMP R/U to pump down annulus. -Take returns thru Mud bucket line. -Clean casing equipment. -Clear Rig floor of Tbg running tools. -Fluid losses for tour= 841 bbls -Fluid loss for day= 1,531 bbls. Total losses to well= 3 301 bbls. RUNCMP Pump 400 bbls of Seawater w/ corrosion inhibitor. -Pump @ 126 gpm / 150 psi. RUNCMP Drop Ball & Rod. -Fill Tbg w/ Seawater, chase Ball & Rod. -Pressure u set Packer 3 500 si / 30 minutes -OK. -Bleed down Tbg to 1,500 psi. -Fill annulus. -Pressure up & test annulus to 3,500 psi / 30 minutes-OK. -Bleed Tbg and shear DCR valve 2,500 psi differential. -Confirm ability to circulate both ways. -Down Tbg 126 gpm 1280 psi. -Down annulus 126 gpm / 330 psi. RUNCMP R/D test equipment. L/D landing jt. -Suck out Stack. Test TWC from below 1,000 psi / 30 minutes. - -61ow down lines, suck out Stack. 07:30 - 10:30 3.00 BUNCO RUNCMP N/D Flow line, Riser & Choke line. -N/D Stack. L/D Spacer spool. -Attach Adaptor flange. -Stand back BOPs. 10:30 - 13:00 2.50 BUNCO RUNCMP Nipple up Adaptor & Tree. -FMC -test to 5,000 psi / 10 minutes. 13:00 - 16:30 3.50 BUNCO RUNCMP R/U & fill Tree w/ diesel. -Test Tree to to 5,000 psi / 10 minutes -P/U Lubricator, test to 500 psi. -Pull TWC. 16:30 - 18:30 2.00 BUNCO RUNCMP PJSM w/ Hot Oil svs. -R/U & pump diesel 84 gpm / 600 psi. -Pump 160 bbls of diesel down IA. 18:30 - 20:30 2.00 BUNCO RUNCMP U-tube diesel from 1A to Tbg. 20:30 - 21:30 1.00 BUNCO RUNCMP Suck back lines. R/D lines & hoses. -FMC- install BP 21:30 - 22:30 1.00 BUNCO RUNCMP Test BPV t/ 1,000 psi / 30 minutes -Pass. 22:30 - 00:00 1.50 BUNCO RUNCMP R/D test lines and secure well. -OAP= 0 psi, IAP= 0 psi, TbgP= 0 psi. Printed: 2/13/2008 2:25:02 PM r~ Printed: 2/13/2008 2:25:02 PM TREE _ FMC GEt+J 4 tNt:LIHt=A Ff~IC Af:1~tATOR= KE. EIEV = S2' BF. ELEV = __ __ KOP ~ _ _ 1560' Max Angle = 64 ~ 13364' Datum MD - 14850' Datum Ti)©= 880CT' SS CSG, n ~J °T fiC1= 12.415" ~--{' 4551 (UI[tlltl"lUf7t 1Q = ,~~~`~ ~ 14~~5' 4-'f12" ~~'IS XN LANDING NIPPLE 4-112" TE3G, 12.fi#, 13Cr80, ,4152 bpf, ~3 = 3,958" ~ '~' SA NOTt~S: ""`'ixtA CC3MM. <3Ft3iATfNG LtfJItTS: 0 9 4 6 MA ~x13t<a P~t, ~~~ OAP =1tt4ft PSI {02f2df06 - WANB~ WB:L SL13GC61NG 4N AL. LEAK IN 13-318" tit4Git ASS~VIt3LY, **'3Ct~tQlfiflB HGt t~2~a:'• 1 ,. 2~Ct$' 4-112" h#ES x Nlf'NLL, tD a 3.$12" GAS LSFT ~'t'<t1~rle~l.S a r h4C1 "!V D t7z'-`J tY Fi< ~"~'~l `.A ~c:Y s r C):~ 4~ w,`A' ? 3J31 '~88r~ 39 ':'it ~K ~ t ca S'33? 430 5r 11° RK <<~ ~~~~` _, w 8i)~4 5U19 61 ~'h ?a Q ` 3 4 X759 ~:, t t1 ,~ ' .: { 3 91413 71l~8 ,i, ."1 ~ CR ~',t~I(`; ~ 9 tSz32 7732 „ _ _ , 'r<it Ct ~ i. ; _ ; 1 130`> 5 84t1fi 62 twt"° , '".-'~' ~~F: fl ~ .a ;,, - - ~~#3` 4-112" HES X-NiPP~~ ID = 3.812" ' '~~`I' 9 5/,4" x 4 112" Baker S-3 Packer ~~~ 4-112" NFS X-r~IIPPLE„ it? = 3,#912" 1~~~' 4-1/2" x H 518" Gr Unuque Overshot 'I~Lvt`i5i' 4-112" BA4GER SEAL ASSY, 1~- 3.892" '(456tt` s-~i~" x 4-i1z" sail=~t rwoD~ p PKr (4112" 'fBG-iFG, i 2.sf1, L-84, .0152 bpf, ID = 3.858" ]-I 14686' I TflP C3F T' LtJR 1 5-St8" CSG, 47#, L-84, U] = 8.681" PERFt3RAT1QN Sl1A+IVU4Y REP LOG: BHGS on 911Q6{;~ A NGLE AT TOP PERT: 57 +~ 15046:' Note: Refer to Production C1E3 for historical perf data SQE 5PF INTERVAL OpnlSgz L)11TE 3-318" 2 15046 - 15066 Q 02110192 3-318'" 2 15072 - iS078 t3 02/10192 3-318'" 2 15082. - 1x088 © 02110/92 3-318" 0.5 15903 - 15113 © '#}5117191 3-31$" 2 15131 - 15150 O 05/06191 3-318" 4 15185 - 15151 4 12147/~t 3-318" 4 15207 - 15220 4 12/07194 i~ 15278• ( 7" LNR, 29~, L-sb, .437'9 bpfi, 1L7 = 6.184" ~ fi4-1/2" t3T15 XN IBC}-t;~Gl LANDING NIP, Ia = 3.725" 1468f" -~ 112" BAKER SNFARpl17 SUt3 14687' 4112" WLEG 1+4$$2' gMLi TT L4)GGEC> 051061f}9 DATE.... REV BY COMMEMS 11M4/9t} OPoGINAL C©IrItPLETtt3N fit/06!08 0314 TRW(] t?2/15108 -KSHRLH C3LV C1(3 APISH - iE3P RtJBiER F.LEMINI` ~ PRlJQFiC}E BAY UNfI" VVEQ.L: 09-46 No: 1941334 Ate Na` 50-029-22E192-4t} 5EG 1. T14fV, R1 SE, 4497.43' FEL & 9749,42' f=NL F3P Exptbra#ior~ (At.~skx) 09-46 (PTD #1901330) Internal ~ver Cancellation -Not Operable Well Page 1 of 1 Re James B DOA • 99, ( ) From: Lau, John, Jack [IaujjO@BP.com] on behalf of NSU, ADW Well Integrity Engineer ~~ ~ rl 'Ij~ ~(~ [NSUADWWeIIlntegrityEngineer@BP.com] ~ Sent: Monday, December 31, 2007 7:32 AM To: NSU, ADW Well Operations Supervisor; Rossberg, R Steven; GPB, FS2 DS Ops Lead; GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, Wells Opt Eng; GPB, EOC Specialists; Engel, Harry R; Regg, James B (DOA); Maunder, Thomas E (DOA} Cc: Phillips, Patti J; NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech; Lau, John, Jack; Holt, Ryan P (ASRC); Dahlem, Jason E; Culpepper, Jerry K. (Orbis}; Boyles, Gerald J Subject: 09-46 (PTD #1901330) Internal Waiver Cancellation -Not Operable Well 1_~, ( Ce,,,,:~1e All, An internal waiver was issued for TxIA Communication on well 09-46 (PTD #1901330) on 02/24/06. The dispensation from the Well Integrity System Policy for this well has expired. If not already done, please ensure the well has been shut- in by the end of today and arrangements are made to freeze protect the well. The well has been reclassified as Not Operable. A secure program will be sent shortly. Please remove all Waivered well signs and the laminated copy of the waiver from the wellhouse. Please call if you have any questions. Thank you, Jack Lau (for Anna Dube) Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 t~./~~ JAN 2 4 200 1/17/2008 BP Exploration, (Alaska) Inc. Post Office Box ] 96612 PRB-24 Anchorage, Alaska 995 ] 9-66] ?_ August 13, 2001 Mr. Tom Maunder, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: 09-46 (PTD 190-133) Wellhead Welding RECEIVED AUG 2 0 2001 Alaska Oil & Gas Cons, Commission Anchorage Dear Mr. Maunder: At the request of the AOGCC, the intent of this letter is to inform you of our plans to repair the wellhead on well 09-46 (PTD 190-133). A leak has developed on the bradenhead. On 09/99, the Drill Site Operator reported fluid dripping from the bottom of the bradenhead. Subsequent diagnostic work indicates the metal-to-metal seal containing surface casing pressure no longer has integrity. The lock screw was tightened without improving the seal integrity. A remedial repair procedure involving welding on the wellhead has been developed. FMC Engineering has approved the welding procedure and provided drawings indicating areas to be welded to re-establish pressure integrity. They have approved leaving the full lock ring in place. The Edison Institute researched the metallurgy and has provided a weld procedure including pre- and post-heating and rod type. A well preparation procedure has been developed that lowers the tubing and IA fluid levels below the wellhead and provides for a nitrogen purge across the CA. FMC has informed us the elastomers in the production casing hanger are rated for over 250 degrees and should not experience any degradation from the welding process. BP is confident this is the appropriate repair procedure for this problem. This work is currently scheduled for mid-September. We will notify the slope AOGCC Inspector prior to initiating this work. If you require any additional information or clarification, please contact me at (907) 564-5637. Sincerely~ Cc: NSU Well Operations Supervisor George Blankenship Len Seymour Chris Phillips Fritz Gunkel ) ALASKA OIL & GAS CONSERVATION COMMISSION 333 W. 7TH AVE, SUITE 100 ANCHORAGE, AK 99501-3539 \<;.a-\~> FACSIMILE TRANSMITTAL SHEET TO: Jv,,~,- ~~G.~ \ð-\ ~~ AÐGCC W~ - COMP ANY: FROM: ~~~ DATE: ~ I i/61 TOTAL NO. OF PAGES INaUDING COVER: \0 FAX NUMBER, ç, s-<;. .- ;:)...~ \ \ PHONE NUMBER: SENDER'S REFERENCE NUMBER: RE: YOUR REFERENCE NUMBER: o URGENT 0 FOR REVIEW 0 PLEASE COMMENT 0 PLEASE REPLY 0 PLEASE RECYCLE NOTES/ COMJv.1ENTS: tÄ~~~~ì") \-~ ~k,,>~'ì~ C-~~ ,\ÐQ:k'ð<.è' ~ <t \- 6- \ ~ ~ \ '" \ (À ~<r\'¿)è.'~~rD-\'O G a0\"- o \2J ç,\ \L;Ó --C;- L\ Co. Ç" \e. c'" W ~ ~ Î~ ~'DW 'ið~,-\k0\~-\-) A~ ·...'1..\'--· 1l c; n ?onJr. SCAh,~EL ...It) . (.. {:, L ...' PHONE NO. (907) 279-1433 FAX NO. (907) 276-7542 · Feb-14-01 09:48pm From-ARCO WELLS 659-5058 T-791 P.Ol/09 F-438 ) ') BP Alaska Wells Group Prudhoe Bay, Alaska FAX # (907) 659-5053 tJ~¡P FOR: Tom MaundªL LOCATION: AOGCC FROM: Joe Anders ..' ......, ..... ." ... ~"'" .. LOCATION: Prudhoe Bay, phone 659-51 og__,__,.,,,,,..,,,.,.,,..,," ,n, PAGES TO FOLLOW: ª-- (excluding this cover) DATE: 12/14/01 RECEIVED / L~C)-\"S~ Alaska au & Gas Cons. Commission Attached is the welding package for well 09-46, Included is the following; Anchorage .. Wellhead Welding Procedure, - Wellhead temperature profile during welding, - Welding Procedure Specification, ¡"CoB 1 5 2001 Hello Tom. We have tentatively scheduled this work for Saturday, 2/24. Thanks for the help. Call if you have any questíons. Joe Joe Anders, P.E. I Kevin Yeager Well Integrity Engineer BP Exploration Ala.ska, Inc. (907) 659~51 02 em ail: GPBWelllntegrityEngineer@bp.com . Feb-14-01 09:48pm From-ARCO WELLS 659-5053 r-h~' w-..-- WËLLÖŠ:'46' ._-~_¥~ -- ) 02124/01 T-791 P,02/09 F-438 Status: 9-46 is a producer with a wellhead leak at the 13~3/8" lock ring. The well is currently shut-in, has an IBP set in the tubing¡ and is loaded with water/MaOH. The tubing and IA are on vacuum, the OA fluid is near the surface with 0 psi pressure. The IGV is closed, .the flowline is disconnected from the wellhead and is de-pressured. The artificial lift spool is removed. The wellhouse is installed. A 13 3/8" annular valve has been added and the VR plug removed for purging N2 through the casing during the welding operation. WELL HOUSE/TREE PRE~A~~TION: RECEIVED 1. Thaw and remove cellar gravel around the tree to a depth of 2-3~feet. f·t~8 75 2001 · Ensure that hydrocarbons are not present around the wellhead. AJaskaOiI&G · Remove any hydrocarbons from outer casing. as Cons. Go '. · NOTE: Confined space entry permit & corresponding procedures will be recfilhri9êhoVflSSlOn is 41 deep or deeper around wellhead. 2. Replace wellhouse. 3. Steam clean tree and well house interior, if needed. Install a heater on the well house. WELL ~_~~.F.'.~a_I(TlON: 1. Verify integrity of mandrel hanger wall thickness by Ultrasonic Inspection before welding. 2. Install a nitrogen bleed / purge manifold on the 13-3/811 annulus. Pressure the 9-5/8" x 13- 3/811 annulus with N2 to depress the fluid level. · The fluid level in the 13-3/811 is at the surface. There is no cement casing shoe in this oompletion, but the annulus will not take injection (LLR 0.3 gpm @ 2000 psi). · A N2 purge will be held on the OA to keep vapors from accumulating around the weld area. Also, the fluid level can be depressed below the weld point by hOlding backpressure on the OA discharge from the annular valve while simultaneously charging. The purge discharge can be monitored for proper 02 and LEL mixture, 3. Circulate the MeOH freeze protect out of wellbore. · Pump 1000 bbls 120QF seawater down the tubing with returns up the 9-5/811 to the flow line via 2" hard-line to the Cosasco valve on the flowline. 3BPM max rate to avoid damage to the gas lift mandrel. · Pressure test tubing and casing to 2000 psi. Bleed tubing and IA to zero psi. · Freeze protect flowline with H20/MeOH. 4. Depress tubing & IA fluid levels with N2. · Install a nitrogen Bleed / Purge Manifold to the tubing. Inject 2 bottles N2 into the tubing taking returns up the IA and to a slop trailer. · Bled tubing7 put 1 bottle N2 down IA. S. Disconnect hardline from weUhead. 6. Line cellar with fire blankets. 7. Start nitrogen purge on the 13-3/8" annulus. . Feb-14-01 09:48pm From-ARCO WELLS 659-5053 T-791 P.03/09 F-438 8. Ensure DSO can quickl.. }range piping in manifold building to ~ }w pumping PW down flowline in the event of a well control situation. Also, the adjacent injector wells 9-15/9-16 will have a Cosasco valve on the flowline. This will provide another source of water if needed. 9. Have DSO or Safety sniff area with multi-gas meter for LEL readings, obtain Hot Work permit. Monitor wellhead throughout job. 10. Minimize other wallwork and maintenance operations on the drìllsite during the welding operation. 11. Establish Fire Watch, stage portable and wheeled fire extinguishers. 12. Prep the area to be welded by using a torch and wire brushes. Absolute cleanliness is essential. 13. Weld per the We1ding Requirements procedure specifying preheat temp (500 OF), joint detail, filler metals, welding parameters, etc. Welders are to be qualified to the WPS and are to be specified by BP Welding Supervisor. BP QA Inspector will monitor and record the welding parameters as required. 14, These recommendations have been suggested for the welding operation: · Use two burners for pre-heating. · Employ two welders for welding in opposite quadrants. · Monitor wellhead temperature across the upper packoffs, anow wellhead to cool if temperature could cause damage to elastomers (above 250 OF). · Rs-heat weld area to 500 of and then wrap with blankets for cool-down. .. Rig down equipment used on job and clean up the area. .. After the weld has cooled to less than 100 of (minimum of 12 hrs), perform a Dye Penetrant test or magnetic particle exam of weld / tree. POST W,E,LDING: 1.--testweld: MITOA to 2000 psi, dye penetrant test. 2. If welds test OK, return well to production. PuIlIBP, dummy GLM #6. Hookup flowline. Freeze-protect lA, tubing, and flowline if well cannot be brought immediately on line. 3. If welding is unsuccessful, freeze-protect well. CONTACTS: Welllntegríty Engineer, Joe Anders I Kevin Yeager DH Lead, Kevin Parks 1 Troy Snow VEGa Welding, Chunk Davis VECO Maintenance, Scott Terrell VECO Safety, Brian Dobson QA Inspector, Ed Pechack I Bob Warpack DSM Supervisor, Pat Mikels I Doug Barnes Safety Specialist, Gary Hunt Facility Engineering, Dave Fetzner / Steve Teeters Corrosion, Tom Moffett FS2 Supervisor, Roy Wells Well Operations Supervisor, gary McBride I John Smart RECEIVED ~i~~ (pager 1934{E8 15 2001 2393 Alaska Oil & Gas Coos Comm~in.. 5026 . ~I 5133 Anchorage 8120 5161 5255 5143 5670 5492 5872 . '-.-. ":... ~-=~''':_:-'~:'~:=::=~::;;:::~~~~,~:'f·.::..':~:::.:'~4,~. ,,---.. ~:,~ -- ..:-::',... ..~"'~-::...~~:=;-:"~"".~"';~~:;:;,:~ , ~... ,_ 'j~,i . '¡ ·~li .\~ 1 ~r i'i ,:;:j : {!~ < !t[! , ~ 'fJ~I -r; 'i' ,-} :.¡ . Feb-14-01 09:48pm From-ARCO WELLS 659-5058 . . ·..r - .,. - )',:, "~.:. '-".'.:'::<":,;:' . ..' :' - . -" NJ)':I LyâJ j~ '-"' 'n. .~ -. :::;:. ·0 b ,@, \~ 'l~~» .:- .( ~3~_, '" ~~'@ ~ "@ , . ..-' ¡-----/~~. :- 1, ,- , '" -^'\" ,-'" .....~.._,_8~~ tAllY! p6'-c.)¿ - X '? /20 _.,...__".7~ J ~~, fS> , r_ J ..J ð ¿., '" $,'tV\ _."... r __'" V"1 <:, ..¡ ~ J _ (r~ __. ·~x 120',:) .()a v, ') ~ _p.{l~ (.J\J.JÞ]. '.- --... -r ,.., ~. ...........-" "",p.., ~ ,® ~- .: -.... , ; --... --..('" " ~ , --f """""""- , ~ ~"" '-... .....-.... ..' ~..... t ............ f -.... ..... ~- i i ..........., ."Jt , ~fd +tWtf'~-Iu~ pro~· ( d\Jr:...~ 'J We J;t'j T-791 P.04/09 F-48S o O' ... - Il-- -J "... ~ ''"'''':. - ,. , ( l' ., . ' ~ ~. \ '.", , ,'''' ".- . 'l ~ ." ,~,' .~, ~ : ..,.~ . ,~ ~ rES 1 5 2001 Alaska Oil & Gas Cons. Commission:' Anchorage Feb-14-01 09:44pm From-ARCa WELLS 659-5053 T-791 P.05/09 F-438 ') ) .... -" . ~."f - _. -~ December 81 2000 One: ~A Files xc; I.8MoyMlangstrom · Feu:enrfFanmey ~ uoss Q~etter No. 00-133 ConU'Q.Clor I3P Alaska, Inc. North Slope Construc1ion P.O~ Box 100360 Anchorage, Alaska 99510-0360 Attention: D. FetznerlS~ Fahrney Mechanical/Piping Engineßr Reference: Contract No. AK-9a-OS33 RECEIVED Subject: Weld;ng Procedure Specification Î"::.8 ., 5 2001 Alaska Oil & Gas Cons. Commission Anchorage Gentlemen: Please find attached for your review and approval> the supplemental Welding Procedure Specifications, WPS..SM..P-009, to be used on various O&M projects. If you have any questions or need additionat information, please do not hesitate to contact Jerry Cunningham/Scott Duncan at extension 8139. "-'" Sincerely. VECO Alaska, Inc. V'" ß'Ú+t"t'ók-t¿- --"-. Bret Allard/Mike Ebersole Project Manager BP Alaska. Irlc~ ; !/~...- '% D:f~erls, Fahrney Date Mechanlçal/Piping Engineer . . . "'-_: - .~.""" BAlME:jo ,:'g~'::' yaf:tl······ .. _l?~f- ,_. CQ. Attachment{ s) POSf..lt- Fax Note 7671 ,~o '"J~D' ~r:S- CøJPept. W r;.._~ ?"-; Pn0f18ff ~ ,"" , Fax f S-o:rf3 xc: Kevin Mahoney/Sam Baker, Veco Pre]. Supt. ..... '" --" r,,-- Scott Duncan/Jerry Cunningham, Veco QC Lead In$p. Judy ColefT J Tingley. Veoo QCffurnover Coord. Phone #' -"'fiX 4" S7~.3 "_:___u_ "--/ ¥::,q;v¿ Pt-'7IN ~ ~ I~ ~ CZItti 6ila:- ~ µ;.. 4-~c..s~ ~ S;Wec:g\OC'\OC SlJpervisQr\'r\imoveJ'\..,;iOoD\.qÇ\føner.¡\wetC,,"Ð praceaure tSllM SCA, Fetzner-Faflrney,(1Qf; VECO Alaska. Inc. · 9~9 e~$t 36th Avenue. Suite 500 · An(:horage, Alaska 9950B · Tel' 1907 762·1500 III Fax: (907) 762·1600 Feb-14-01 09:44pm From-ARea WELLS 659-5053 ., ~ . -. ) VECO CORPORATION ASME SECTION IX WELDING PROCEDURE SPECIFICATION T-791 P,D6/09 F-438 ~ I. ,11,1' I . ... ...,~,__,_ _...,...,. .'P.~ ._ ..._.._....._...._~.~.."..._ ,_ --<II ""',.. ........._.n._I.......-¡"'...YI o...·!"~,..."I._...... "...__--... ... ._....,....-,.. ............~~I_'ðl..."1I·....·, .11 ......^_..._._....."'_..-..."t ..,.....,,,., . ,..".".."... - ·\........;ompany ~ame ~ECO Cørporat~øn By 1<lr" C~r::penter Welding Prøcedure Speclflca¡ìon No. WPS·SI\l1~P.009 Date . ~ 110710D Revi$jøn No. Supporting Procedure CuaUfication ReGord Na,(s) PQR-SM::P-009 Welding Process(es) SMAW _ "nn. "~' ,TVPt!(s) ",Mª,,µar ,..,pt:~' f~m:'~ ', S~ml·~,,'a. "';'~'''"'. Av~"";mc) ... .. .....~~..,.... (J Date - ......~ .., U;, .. n",/II".., , " ,.,~....... ""' ..". . .. . ~"... JOINTS (QW-402) Joint Design Fillet Weld, S~1ir ~~~c~ed I~chni~ue sheet Jo!. Oem\. o_~a_~~ f11etal.b.unerin9,!~~uirements and rilleJ weld e¡,qfila(s) Baoking (Yes) , t:!.(A No N/A Sacking Material (Type) N/A Con~. N/A RECEIVED ¡":.t3 '1 5 2001 ......_"...,. ".. ... t:J Metal [J NQnfl.l$ing Mß1al Retainers o Nonmelalic Aetaioere CJ Other Alaska Oi~ & Gas Cons. Commission Anchorage . . ..,~.- ... \ 1!'t ,.._ ""..,.. . SASE MEiALS (QW--403) P No. N/A G(OUP ND. . _ N/A 10 PND. N/A Grøµp NQ. N/A A " -,,; .....,.¡r;, Specification Type and Grade ".AISI 4l~~ \ Sp8o~icatlon Type and Grade AI,~J. 41:';0 '-Cr Chem. AnaJY$i5 and MaC:h. Propertíes _ NfA to Chern. Analysis and Meeh. Proprieties NIA ThicknM9 Range: Søse Metal Groove Pipe Diameter Aan9~ Groove Otl1ar NJA Ntrtes WA ..-......,....."...... ., . T" '.... ."...,... -'-', NfA N/A Fillet FUllilt Unlimited ~ --,~. ~~ ....' -.... " .....,,,. ......." All .......'O,,, .. -..,- .......-.................. .... -..... ,. ,.........,,.. ,~~"'.... ~~ "'·V·, ... ,. - ...... -..- ,~ . - .,_ I ,. _ _ ..,~~,.... .-... .. "... '......_,..' ... ,- .'~ ~ _' , ." _, - ,," _0, ,,,,,!, ~~, FILLER METAL.S (QW-404) SFA Specification AWS C1a~moat;on Filler Metal F~No. Weld Metal A-No. Síze of rUler Metal Weld Metal Thi-=kness Range: Peposlu~d Weld Melal GfOQve Fi11et Electrode-flux (Class) F1IIer Meta~ Trade Name uX Trade Name '--éøns;.fmaÞ,e In5en No'e! 5.1 E:7018 or E70' 8·' 4 1 .. -- ... ... 3/.32" & US" ,~ ~", ...-V-- ...,.......'...,......." .. ....n~ ".., ,.., -. ......"""., ~ - ._-..... --.. - .. --.. - ."".._,_....." ....,. .... .. -..........--.-.... ",Nlð. N/A Unlimited N/A L1nccln_ EJCc~.I!~~rn~t ~$aÞ Atom Arc NfA NlA - -" - - -... -. . .. N/A Feb-14-01 09:44pm From-ARCO WELLS WPS No. yv.e~~t;~..p..~~~ - ..... .-.- ~ - ..,~ . ,_....."", ,. .. - . ....- ~dèt ðll "G<\9 (;Qns. CommiSsion PREHEAT (QW-405) Anchorage Minimum Preheat Tempera1ur~ _, ~p.oQ F. Maximum Interpass Temparalure ~Qºn f. ... preheat MalOlen~nce a~,~e material rT!.~~.t be ma¡majn~¡td at QQDI ! ~, ... Cont. rhrougtL91,./\ ~~I~.o~t. .r~ß E~~~.w~~.gr~~eat ~~t~~d is.to US~ $~reB~ ~~rlëf h~~tecpads and ¡nsulat¡o,,!..~~a.~kßJ~:... .. . Other ro§e b'-lds m~y..~~ used as an .a,~t'-rJ)~tive. "'" POSITION (QW-405) PC51tlon of GroQve N/A "sid Prog rß$$ion Uphill. .. ··'-...,&'ont. NI A position of Fillet AU O~her NIf -~".~"""..."..... , ~evi$lon No. () - -..... .... ~ ~'". ......,.,.., RECEIVED -, ..........: - :. .~j 1 b 20Ul ELEOTRICAL CHARACTERISTICS (OW-409) AC ør 00 Current Dirac'( 9~rram PQlarity Type PraoeS$ fi1 Amperage (RSI1Q$), aO,.128. VOl1e (Range) 20·22 Electrode Wire Feed Speed Range Process #1 N/A GMAW Transfer Mode _.~(~. .. _ TECHNfQUe (OW..410) String or Weave Bead StrioQ.",.... ._" '. ,.' ,,__ _ . . .... .. _. _ '. .. _., Orifice or Gas CLIp Size _ Nt^... ..........."" .. . .. ..T"_... ""' ,. ".. 1i1ial or 1"~r1Jass Cleaning (Brushing, Grinding, etc-) ,_.9r~~~ Dr other. ~on1am¡nan'tS shall bt![e~~ved with acetcme.,prjºoo pQwer . ~cnt. _ griF!d'~i ~"~~r bru~.h~~9 b.~e "J~! 5L1~~C~ _,.". _. .'_'p _.. "''''"'-'' _.... _I -~ -- ... . ,.- 'WII.. . Method of Back Gouging ,..NI~,." . , ,...T'"".., ... . " Oscillation N/A _..~".,.... . . Contact Tl4be tQ Work Distance N~A Multipass or Single Pass (per ~iCle) MUltipass Singla or Multiple I!!!lec:trod~s ~.§Wle....., ___._." Travel Speed (Ranga) 8-J2JPM P~ening NQn$J~Uowed ._. . _ , . ,,",,_ ._. ""._,. ...... Other ,._" . . 7...._.. _ _.." . . " .."'".,,...,_..... ,\ . . - .-. ... .......,'......_~.. '" Notes The weldil:\Q p~.ramelers r~r,~~perage. "oltage.Jlnd travel ~~e~~ ~t'la faU wj~b¡D the,JªnQes nsted b~ o~!.~n~~ no~çn !o'lQhness, n is req~ired by the c:ont.r~lIing code _~.~~Dn the resultant.~eat inp~'.,~.~~lt,~lso tall witni~ t~~_.~axlmum 9peeltí.~d range "...".n, , .~........ ........ u Weld Welding Layera pro;t¡l$~ AWS Clan 6utte.t:. . SMAW.. Sutter ~MAW 1:7018-' E_?o.18· 1 , _, .r.""........... 'Sl 2nd 'em '----'T SMAW ,SMAW SMAW A...._ _ .......... E70,8-, E701 B-1 57018-1 .' T"t*', ..,....._.. ,_, .... ... ..",~ "'... . - ~ .,...-.......-.... "'. 659-5053 T-791 P. 07109 POS1WEL.D HEAT )EATMENT ,(CW..407) TemperQtur9 Range None Hold Time N/A .._ Heatìng Rate ~!~, .. Cont. .NI'" Cooling Rate __N/A ConI. N/A Other N/~.___. F-438 ..._,,_.~ .......,. .. SHIELDING (OW-40B) Percent Compcsi1ior¡ (MiJr:ture) FlOW Rata , ,,,~m GMAW ShieldJng Ga$ FCAW Shielding Ga$ GTAW Shielding Gas . Backing/Purge Gas Other N/A GeUi(O') *'''''.' '--"'''- .-.. ", NfA N/A N/A N/A .. ._-".... ...... . .... ....' ~... .... r. ......-..,... . - ., . ~.. -....... ",.. - ,¡¡., SMAW: Reve~~~ (DC!:I!l., I=Þrac:e~$ ¡t2 N/A Tungsten Electrode Sjze and Type N!A _...,,_.,....... ......."..... _ Process *~ NIB .' .........".""..".. ($pr.y ::IIC, IM"- cilC:\llIinø ~r: ~r' .. . . .I:"..K~ . -"..,.,..#Ir .", , "........_' ..... r~. ~ ~ - ......~....-.,._..... __ ...~ r~~. .......__,...."...... .,...iWI"'.. ...,,,.,, ....--~...,.,_...-.... ......... ..-.-- .... ......."..". ""-..,. - 'O" ....._... , '" -. .......-..,.. OfamMr Pat· wity CUrren, an~ voluave Peak eac!\grcund Ampef~Ð Cu rron I Current Range Vallagt3 RanliJiI rravel Speed Range Maximum He~1 Inplft K lIn. or Other Note Filler Metal 3IS,2" CORP. ,~~'" , "DQRf . _, N/A N/" N/A N/A 20·?~.._,_1.." ,.~.~,~ IP~ 20-~ 8-101PM - - --....----.. 6.S Ki/ln. ma~~ ." 20.~_~¥.~~,' rT1l!1x... 80.85 '18-'22 3132P PCRP N/A NlA e0-65 20·22 10-121PM 6.5 Kj/in., !!!ax. - --........ "....." ... ... 1/6~. DCRP N/A N/A 118-'22 20..22 8-101PM 20.S Kj/in. rna)(. _"·u··_ .. _ . . .. r 1/~" OCRP N/A N/A 121·1~~.. 20·22 8--10 JPM 21.5 KJ/in. max. .'."'---. "The defrnitian Qf "All" 1$ ~ha dBposl~ed weld mesal thi~$SS by proceSs Ils,ed on the firs' page of Ihe WPS. He~t Inpùt is calcula'ød by AmpS X "o,'~ .. !<JAn. Tn~vel $pee~ (Ipm) X '000 F,eb-14-01 09:44pm Frcm-ARCO WELLS 659-5053 ) Welding Technique T-791 P. 08/09 F-438 ) Step ,: 1 st Layer B~ttering Bead \..-/' 1"!od size: 3/3~" I ;·."c'>".X~.= Starting at the juncture of the two joining base metals, aþply the required number of passes to obtain the desired fmat weld sìze. Maintain a flat weld surface contour. ,.........".,,, \ \ ~ .... , L Flat top the 1st 'aY$t bead by grìnding. Remove approximately half of the 'st layer w"h a grjnder. Step 2: 1/2 Bead Removal ..... , ,. _,¿ ...... .'__. . ~~~, 'n i . '""'" ;., '-- r -- -".. ,."'- .-- .... Rod Size: 1/811 "'~·~5 ~ .> Start at the outboard end of the weld and work toward the junction of the two base metals. The ~oe of the first pass should be 1'16" frøm the outboard pass of the fltst layer. Step ~: 2nd Layer Buttering Bead -- r- ~ 1/16·' \.. ." T ..",-~;,. .c;..~ t \....,~. Rod Size: 3/32"11 Lay in 1he roQt pass. RECEIVED I,~-:,~~ -'Ç ~ \... ~ , '-- Step 4: Apply Root Pass : . ,:~::3 5 2001 Alaska Oil & Gas Cons. Commission Anchorage Step 5: Weld out .... ~. '< '-"""'(,- ~ ,\-. .\,. Rod Size: 118'1 Lay In ~he fill and cap passes In accoraance with the WPS parameters, ,--: ~ ~ i L en _ :::, u.l1I 3=:.. o ) 01: O::l ..ee- l: ¡: Q .- "- , .....0 :t .. o e po' a. .... ~: CD : CJß - I ~ d ~- 1: CD. IL ) FIGu = ) z liooootßIß52.180 ) o j W - 'ê > g 8 _ C".J u) 4) W ~ ð~ U ~ æ'5 W 't·r C) .:f ,'.1 OCS c.:t::' ~:<.. is j2 ~ 4D - WELD HEAD TŒ MANDREL HANGER AS SHOWN PER CUSTOMER APPROVED WELD PROCEDURE ~ U> C::J U> J CD IS) u::> .-. ~- ----') ~ /"r"',-" ! 1 ~ : I f ~.(. J L__~...._. si¢k -. ......t- Þ ; J .: L~._I ~: ! . ~][. .~.. : .' I . . ' r .< ." /! - , ~ co ~ <- I 1L- 0) c:¡. "- CD C) n... CJJ t- J ..- a75 ~ \ t ,¡ , ~ " -, ( ___..,......-----~--r--~..--....., /' - ....---........-. _....--_..~. , ~ '1 fr ' . ....-.- -, ) ~---,- ? " ___J " l ~·_h I ! I '/ < • Well hello uipment Division FMC Corporation 700 West International Airport Road Building A Anchorage Alaska 99508 Phone 907 563 3990 Fax 907 563 5810 4CMC Energy Systems November 23, 1999 \10 Alaska Oil and Gas Commission Mr. Blair Wondzell E APR () 6a Attn.: Mr. Wondzell REF: Well 9 Mr. Wondzell, in regards to our conversation and walk through last week, I would like to present the following recommendations from FMC Corporation concerning the issues surrounding Well 9 -46. After several attempts by Arco Production to facilitate a seal on the FMC Generation 4 -A wellhead system, the Wells Operation Group from WOA contacted FMC with a request for welding procedures. After initial assessments by FMC it was determined that the problem would seem to stem from a leakpath which affects the metal to metal seal on the mandral hanger /casing head connection. Inasmuch as this well is fully completed with both an intermediate 9 -5/8" string as well as a full completion string, it is FMC's recommendation that no welding take place on this system until such remedial actions take place as to facilitate a approved method for welding the inner seal surface of the system. In addition to the inner weld procedure, it is FMC's OEM recommendation that all welding be accompanied by full preheating as well as postheating of the affected area. A full workover procedure is attached to this document. FMC recognizes the additional cost of this recommendation, but feels that in order to deliver a fully complete product as an end result; these additional procedures must be adhered to. To attempt a weld fix while the inner and completion string are in place would require procedures and equipment not found outside of most technical laboratories. To fully preheat and postheat the additional area to be externally stick welded while keeping the sealing packoff elements of the intermediate and completion string below the design specifications would be beyond any field capabilities. Two other options have been raised as to temporary proposals: #1 would be a pressure activated bleeder line from the annulus to a bleed tank. This bleed line would be subject to a maximum pressure to be determined by a combination of present annular pressure; casing design criteria and maximum allowable pressure build up. #2 is the external welding of the leakpaths with a cold design weld method. The possibility of an Argon or TIG weld method is under consideration. These methods are being researched and more information will be supplied it becomes available. These possileties may have some potential to offset the preheat an postheat concerns of FMC Corporation. Sincerely, Kevin Hite Service Manager CC: Tom Maunder, AOGC Alan McArthur, FMC Corporation • Energy Systems Group Alaska Division t Decompletion Procedure for "ISA" equipped Tubing Hangers 1) Identify Wellhead System Features as Follows: Wellhead System Completion System Hanger Lift Threads Control Line Style 2) After verification of Well Kill operations, set the Back Pressure Valve in tubing hanger profile. Verify through mechanical and if the completion allows, hydrostatically test the Back Pressure Valve to 500 PSI. 3) Document absence of pressure in both the tubing head/adapter and annulus voids. Open the tubing X production casing annulus valve. This valve is to remain open during all decompletion operations. 4) Nipple down Tree and Tubing Head Adapter. 5) Install the FMC Blanking Plug into the lift threads of the tubing hanger. 6) NU BOP Stack. 7) Test Blind Rams to Operator Recommended practices. 8) Remove Blanking Plug utilizing the Blanking Plug Retrieval tool attached to a joint of tubing or drill pipe. 9) Install the BOP Test joint and complete remainder of BOP Test. (pipe rams, annular, choke lines, etc.) 10) Remove Test Joint 11) Pull BPV as per Recommended Practices. 12) Install Landing Joint. Verify absence of pressure in tubing X intermediate annulus. 13) Back out Lock Down Screws and retrieve hanger to rig floor. Close annulus valves and report condition of well to appropriate Operator personnel. Kevin Hite Page 1 11/24/99 • • _ U_ Energy Systems Group Alaska Division Decompletion Procedure for Gen IV -A 9 -5/8" Mandrel Packoff and Hanger This step assumes that the 9 -5/8" casing has been cut. 1) Using a FMC High Pressure Bleeder tool, verify the absence of void pressure in the 9 -5/8" Packoff annulus. . 2) RIH and set a RTTS or Bridge plug. Test as per OEM recommendations 3) Verify the absence of 13 -3/8" X 9 -5/8" annular pressure by opening the annulus valve and bleeding any expansion gas or fluid into a bleeder tank. This valve is to remain open during this entire operation. 4) Nipple down the BOP stack, and remove the 13 -5/8" X 11" tubing head. Install a 13- 5/8" X 13 -5/8" drilling spool. Upon lower connection makeup, test the flange void area against the 9 -5/8" packoff. 5) Nipple up the BOP stack and test tubing head connection with a 13 -1/2" BOP test plug. 6) From the rig floor, on either a joint or full stand of pipe, make up and inspect the 9- 5/8" Packoff running and retrieving tool. Lower through the stack until contact is made with packoff. Jay the retrieval tool into the packoff and record the RKB. 7) Retract Lockdown screws on casing head and verify disengagement. 8) Pull the packoff out of the head profile with a straight upward pull using the blocks and the stand of pipe made up in step 3. 9) Pull the packoff to the rig floor and inspect for damage. 10) RIH with 9 -5/8" casing spear and retrieve the mandrel hanger and pipe. 11) Nipple down BOP stack at the upper casing head flange. Set Aside. 12) Clean area of upper 13 -3/8" hanger neck area and the lower section of the casing head. Prep area for welding. Remove the 1/2" test port from the casing head. 13) Wrap the outside of the casing head lower end with insulation. Lower a 13 -3/8" HOT HED into the bore of the casing head and align the deflector with the weld area. Ignite and place cover on casing head bore. 141 Allow HOT HED to burn and bring the casing head up to proper temperature. Verify weld area temperature using tempel sticks. It is required that this pre -heat temperature Kevin Hite Page 2 11/24/99 • • Energy Systems Group Alaska Division be from 500 -600 degrees Fahrenheit. (NOTE) This temperature must be maintained throughout the procedure. 15) Begin welding the hanger nose to the casing head using a step weld method and utilizing the recommended E9018G welding rods. NOTE: The casing hanger and casing head are made from AISI 4130, -75 Degree material. This matched material will facilitate a good weld, as opposed to dissimilar material applications. 16) After the initial step welds, begin continuos beads of seal welding until interior weld is complete. 17) After the weld is complete, lower second HOT HED into well bore and ignite. Cover flange of casing head and allow HOT HED to burn until it self extinguishes. Leave HOT HED in place and allow to cool slowly. The insulation on the casing head should remain in place for a minimum of 4 hours. After that time, begin to slowly remove in stages. Do not allow any fluids or cold air to contact casing head until such time as you can touch the assembly with your bare hands. 18) Remove the HOT HED at this time and inspect weld area. Drift the casing to ensure the weld bead does not interfere with downhole tools. 19) Nipple up the BOP Stack and test the casing/tubing head connection. Test the weld by pressuring up against the bridge plug and Blind Rams. Monitor the external area of the casing head and mandrel 13 -3/8" hanger. 20) Retrieve the Bridge plug and resume rig operations to repair casing. As it will be necessary to tie into the intermediate casing, emergency slips and packoffs will be utilized. (Refer to the New Standard Running Procedures) Kevin Hite Page 3 11/24/99 11 -17 -00 15:06 From -FOC 9076595917 7-343 P.01 /01 F -265 • Fax Cover Sheet 4 ARCO Alaska, inc. Date: November 17, 1999 Mcshat QC To: Tom Nu.m.chAr Fax 276 -7542 From: Joe Anders / Jerry Dethlefs Phone: (907) 659 -5102 Problem Well Specialists Fax: (907) 659 -5917 Subject: Wellhead Welding Number of pages including cover sheet: 1 Tom: The list of wells that have had welding performed on the wellhead in the EOA is: 01 -23, 01 -24, 03 -29, 04 -26, 06 -17, 06 - 19, 06 - 22, 12 - 15, and 12 - 23. This should not be considered comprehensive; this is just readily available on my computer. Should you have questions regarding the welding procedures or prior notifications (or lack thereof) please call me or Joe Anders at 907 -659 -5102. Jerry Dethlefs ARCO Problem Wells DS 9 -46 Casing Repair • • Subject: DS 9 -46 Casing Repair Date: Sat, 23 Oct 1999 03:16:58 +0100 From: "PRB Problem Wells" <P1041 @mail.aai.arco.com> To: Blair Wondzell @admin.state.ak.us, john_spaulding @admin.state.ak.us CC: "Well Operations Supervisors AAI" <P2010 @mail.aai.arco.com >, "PRB Problem Wells" <P1041 @mail.aai.arco.com> Blair / John: Attached is a summary of the procedure ARCO proposes to follow to repair DS 9 -46 surface casing leak. As per our meeting 10/21/99 with John Spaulding, the first action is to kill the pressure on the 13 3/8" annulus before starting further work. The second step is the relieve the stresses on the tree and tubulars, as recommended by FMC. Should that not work, preparations will be made for welding the casing head. We will keep you informed of the status of the well after the initial "repositioning" prior to welding. Please call if you have any questions. Jerry Dethlefs ARCO Problem Wells(See attached file: DS 09 -46 Wellhead Repair 10- 22- 99.doc) Name: DS 09 -46 Wellhead Repair 10- 22- 99.doc DS 09 -46 Wellhead Repair 10- 22- 99.doc Type: Winword File (application/msword) Encoding: base64 Description: Mac Word 3.0 1 of 1 10/25/99 8:02 AM • • ARCO DS 09 -46 Surface Casing Head Leak Repair October 22, 1999 The following procedure is proposed to safe -out and repair well 09 -46 surface casing head leak. 1. DSM: • Load OA with kill fluid and freeze- protect cap. • May require lubricating; injectivity is low. • Goal is to be able to bleed OA to zero or vacuum pressure for subsequent work. 2. DHD: • Attempt to bleed OA. Evaluate bleed results and monitor. 3. WL: • Freeze protect tubing and flowline. • Run DGLV's in GLM #1, 2 & 3; • Pull GLV #9; leave open for circulating wellbore. • Set TTP. 4. DSM: • Disconnect and blind flowline and tree (tapped flanges) to relieve lateral stresses. • Install circulating hardline from IA to tank or nearby flowline. • Load well with SW; pump down T, returns up IA to tank or flowline. • Test TTP @ 1500 psi. • Circulate 2 or more volumes SW to cool tubulars and relieve vertical stresses. 5. FMC: • Check tree alignment and adjust as needed; � J • Adjust / tighten Acme lock ring, g g, • Test metal -to -metal seal. 6. Passing seal test: • Reconnect flowline (may require re- fabrication to fit). • Put well on line and monitor. 7. Failing seal test: • Freeze - protect T and IA; leave SI for welding preparation. • Prepare weld package, obtain metallurgy inspection, prepare safety procedures and management approvals. • Prepare well as required for weld package; displace hydrocarbons, N2 purge, etc. • Seal weld Acme nut (2) places plus threaded ports in nut. • Perform weld QA testing. • Bring well on line and monitor repair. 9 -46 Repairs • F`E Subject: 9 -46 Repairs Date: Wed, 20 Oct 1999 13:24:12 -0800 From: John Spaulding <john_spaulding @admin.state.ak.us> Internal Organization: State of Alaska, Dept of Admin, AOGCC To: Blair E Wondzell <blair wondzell @admin.state.ak.us> , Problem Wells <1041 @mail.aai.arco.com> Aso I spoke with Blair earlier today about welding on wellheads and we agree that repair on wellheads should be in accordance with manufacturers recommendations, especially welding. All welding on wellheads or any pressure rated equipment should be done following the manufacturer's, or a reliably engineered, recommended procedure - which complies with the API requirements specified in "API Specification 6A, Wellhead and Christmas Tree Equipment, Seventh Edition, February 1, 1996: Section 500 WELDING -- GENERAL REQUIREMENTS. If welding becomes the apparent repair process, the welding procedure should be forwarded to the AOGCC Anchorage (Blair Wondzell) and Prudhoe Bay Offices (Inspectors) Thank you, John Spaulding 1 �f 1 10/20/99 2:24 PM THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 27 2000 P L MAT T H E E E W E R IA L U N D ER IS M A.R K E R Schlumberger I GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 A'rTN: Sherrie NO. 10025 Company: Alaska Oil & Gas cOns Comm Attn:;i Larry Grant 3001 PorcuPine Drive Anchorage, ~AK 99501 Field: Well Job # Log Description Date BL Prudhoe Bay ~ ~ Floppy RFSepia, DIRMWD Disk :D.S. 4-30 $-rl 3_~-- ~,~ ~__!PROD. PROFILE ..... 960'104 I I i ..... D.S. 5-25 ~_..~._"._.,/..~L ! PROD. PROFILE ......................... 960101 I ......... 1 .... O.S. ,-17 ~.~,_-'__~ FROD. FROFILE .... 960117 1 I ................. D.S. 6-17 ~__7..~ [_)IG~EN'rRY& FLUID IM/~GING TOoL .... 960117 I .1 ................ ~9.S. 7-6A .... ~r~_~_j? ~ TDT-P 960106 I 1 .D-S. 7-1~- ' ~o~/~_ LEA'~ DETECTION LOG. 9601 1 5 1 1 ': '. ......... D.s. 9:35~A .?c3-'_~ / STATIC BHP SURVEY ..... 960102 I I ..... D.S. 9-45 ......... ~(~._-_~/,_5"bTAT!cBHPSURVEY 960104 I .~ 1 D.S. 9-46 c~O_/~_.~ PROD. PROFILE 960105 I 1 O.S. 11-16 ST1 " ';~-~'7 ~ LEAK DETECTION LOG . . ' 960;1'11 ' I 1 ~: ...... D.S. '11-18., ~,-'/~.....~COMP. NEUTRONLOG 960117 .... I .. I ,. D.S. 15-1 ~ - (z~ TDT-p BORAX 960116 I 1 'D.s. 15-39, - ~. ~/..i..//5 LEAK DETECTION L'~3G ............ 960i'i 2 ..... i .... I .... .......... ., SIGNED' Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: FEB .:, 1,990 -- /~J~,s~a Oil & Gas C(;~,.~ Commission Anch n /7 ARCO .~l~skn0 Inc. P.O.Box 100360 AnChorage, Alaska 99510 DATE: 6-19-92 REFERENCE: 3-35 ~/..--,~ 11-17' ~'.--',~? z3-24.2~-~'..r- ARCO CASED HOLE FINALS 5-12-92 Jewelry Run 1, 5" C_~mco 5-21-92 -GR-Collar Run 1, 5" Camco 5-15-92 Prod Profile l~_m 1, 5" Camco 5-12-92 Prod Profile Run 1, 5" Camco 5-12-92 Jewelry Run 1, 5" Camco 5-17-92 Prod Profile Run 1, 2"&5" Camco 5-11-92 Prod Profile Run 1, 5" Camco 5-16-92 PITS Ih_m 1, 5" Camco 5-15-92 PITS/Flowmeter Run 1, 5" Camco 5-24-92 Prod Profile Run 1, 5" Camco 5-16-92 Prod Profile l~__m 1, 5" Camco 5,15-92 Prod Profile Run 1, 5" Camco 5-14-92 Prod Profile Run 1, 5" Camco 5-14-92 Prod Profile l~_m 1, 5" C~_mco 5-18-92 Gas Lift Run 1, 2"&5" Camco 5-25-92 InJ Profile Run 1, 5" Cs_ taco 5-14-92 InJ Profile Run 1, 5" C~mco 5-14-92 InJ Profile Run 1, 5" C~mco 5-19-92 CCL/GR/Junk Basket Run 3, 5" Camco · Please sign and return the attached copy as receipt of data. RECEIVED BY .~~ Have A Nice Day! Sonya Wallace ATO- 1529 # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO RECEIVED * The correct APl# for 9-30ST is 50-029-21411-00. AU(; 1 0 199 Alaska Oil & Gas Cons. Commission Anchorage ARCO P.l~,sk~,, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 6-19-92 REFERENCE: ARCO CASED HOLE FINALS ~/~ ~ * 1- lB 4-8-92 GR ?~- 2~ 7.9 3-22-92 Perf ?~-~) 9-46 2-10-92 Perf Record 9o -/¢~ 9-47 3-22-92 Perf ?~'- ~'3 14-4 3-6-92 Perf Record 21-"~2 16-13 3-29-92 Perf Record ~'- ~9/3 16-18 3-30-92 Perf Record Run 1, 5" HLS R,~_,m 1, 5" ~ R!~n 1, 5" HLS R!!n 1, 5" HIS Run 1, 5" HLS Run 1, 5" HLS R!!n 1, 5" HLS Please sign and return the attached copy as receipt of data. RECEIVED BY .~_~ Have A Nice Day! R[CEIVED Sonya Wallace ATO-1529 JUN 2 9 1992 Alaska Oil & Gas Cons. Commiss!or~ Anchorage # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL APPROVED Trans# 92122 # PHILLIPS PB WELL FILES R&D # BPX '# STATE OF ALASKA TEXACO * The correct APl# for 1-lB is 50-029-21007-01. STATE OF ALASKA ALASKA"~-' _ AND GAS CONSERVATION REPORT uF SUNDRY WELL OPEHATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 4. Location of well at surface 935' FSL, 162' FWL, Sec. 1, T10N, R15E, UM At top of productive interval 1652' FNL, 524' FWL, Sec. 8, T10N, R15E, UM At effective depth At total depth 1743' FNL, 789' FWL, Sec. 8, T10N, R15E, UM 12. Present well condition summary Total depth: RECEIVFD measured true vertical 15371' feet Plugs(measured) 9139' feet 6. Datum of elevation(DF or KB) 52' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-46 9. Permit number/approval number 90-133 10. APl number 50 - 029-22092 11. Field/Pool Prudhoe Bay Oil Pool Effective depth: measured true vertical 15278' feet 9087' feet Junk(measured) Casing Length Conductor 105' Sudace 4551' Production 14954' Liner 743' Size Cemented Measured depth True vertical depth 20" 48 SX AS 105' 105' 1840 sx CS III & 450 sx CL 'G' Top Job w/250 4551' 3801' 13-3/8" sx cs u 9-5/8" 565 sx CI 'G' 14954' 8909' 7" 225 sx CI 'G' 15369' 9138' Perforation depth: measured 15046-15066';15072-15078';15082-15088';15103-15113';15131-15150';15165-15191'; 15207-15220' true vertical 8960-8971 ';8974-8977' ;8979-8983' ;8991-8996' ;9006-9017' ;9026-9040' ;9049-9056' Tubing (size, grade, and measured depth) 4-1/2",12.6#,L-80,1PCT @ 14687' MD Packers and SSSV (type and measured depth) Baker Model 'D' pkr @ 14568' MD,Camco BaI-O SSSV @ 2153' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Produ~ionorlnjection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure 1350 950 980 4000 /'~ 3900 1700 Tubing Pressure 350 460 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas__ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ¢ ~~/z/ Title FS-2 Regional Operations Engineer Form 10-404 Rev 06/15/88 Date SUBMIT I'N DUPLICATE ,ILY REPORT OF WELL OPER. iONS DS 9-46 Perforating Operations' ARCO Alaska, Inc. perforated DS. 9-46 at selected intervals in the Sadlerochit Sand of the Prudhoe Bay Unit on 2/10/92. The intervals perforated were the following: 15046'-15066';15072-10578';15082'- 15088' MD (Reference Log: SWS-CET dated 11/22/90). Production fluid was in the wellbore during perforating operations. All wireline work was done through a 5000 psi WP BOP/Lubricator tested to 1.2 times the maximum expected surface pressure. A short summary of the work is given below: Began perforating operations on 2/10/92. RU perforating unit, pressure tested BOP's and lubricator to 3000 psi, okay. S.I. well, RIH and perforated 15082'-15088' MD at 2 SPF, Logged up and perforated 15072'-15078' MD at 2 SPF, POOH, and confirmed all shots fired. RIH and perforated 15046'-15066' MD at 2 SPF, POOH, and confirmed all shots fired. (ref: SWS-CET of 11/22/90). Rigged down and secured well. RDC: 4/15/92 ARCO ALASKA, INC. F'.O. BOX JO0360 '-~ ANCHORAGE, ALASKA 995', ~DATE: 8-2-9~ REFERENCE' ARCO CASED HOLE FINALS i-4 · 3-i 6-9i 2-~. 5-22-9t 3-2 - 4-~.~-9i 3-2 · 5-26-9i 3-22 · 7-~ 3-9i 3-27' 3-~ 5-9t 3-27' 7-t 3-9i 5-t 9' 7-i 4-9~ F'ERF RECORD PERF RECORD CCL F'ERF RECORD PDK-i<30/GR/CCL PERF RECORD F'DK-i<3<3/GR/CCL CNL COLLAR LOG F'ERF RECORD COLLAR LOG TUBING F'ATCH F'ERF RECORD PERF RECORD F'DK-i<3<3/GR/CCL-BORAX CCL-PERF RECORD JEWELRY-COMPLETION RECORD PERF-UEWELRY RECORD CNL PERF RECORD RUN i, 5" RUN t, 5" RUN i, 5' RUN t, 5' RUN i , 5' RUN i , 5' RUN i, S' RUN t, 5' RUN i, 5" RUN ~, 5" RUN RUN i, RUN t, S' RUN i, RUN i, RUN t, 5' RUN RUN RUN i, RUN i, 5' PLEASE SIGN AND RETURN THE ATI'ACHED COF'Y AS RECEIPT OF' DATA. RECEIVED BY ~ HAVE A NICE DAY! SONYA WALLACE AT0-i529 APPROVED TRANS~ 9 HLS HL$ HLS HLS ATLAS HLS ATLAS £CH HLS FiLS FILS HLS HLS HLS ATLAS ATLAS HLS I-tLS ,S'CI--t HLS DISTRIBUTION CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS F'B WELL FILES R & D BF'X STATE OF ALASKA TEXACO . THE C'ORRECI'ED LOG INTERVAL F'OR 9-46 IS t44<38'-t5t6'0'. ** THE CORRECTED AF'I~ FOR tt-25 IS 50-029--.0488-'0i. ***- THE CORRECTED API$ FOR t6-gA I~' 50-029-20558-0i STATE OF ALASKA ALASKA AND GAS CONSERVATION REPORT uF SUNDRY WELL OPEHATIONS 1.-Operations performed: Operation shutdown ~ Stimulate ~ Plugging Perforate X Pull tubing Alter casing Repair well ~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 935' FSL, 162' FWL, Sec. 1, T10N, R15E, UM At top of productive interval 1652' FNL, 524' FWL, Sec. 8, T11 N, R16E, UM At effective depth At total depth 1743' FNL, 789' FWL, Sec. 8, T10N, R16E, UM 5. Type of Well Development X Exploratory Stratigraphic 6. Datum of elevation(DF or KB) RKB 52 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-46 9. Permit number/approval number 90-133 10. APl number 50 - 029-22092 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 15371 feet Plugs(measured) 9139 feet Effective depth: measured 15278 feet true vertical 9087 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 105' 20" 48 sx AS 105' 105' Sudace 4499' 13-3/8" 1840 sx CS III & 450 sx CI 'G' 4551' 3801' Production 14902' 9-5/8" 565 sx CI 'G' 14954' 8909' Liner 743' 7" 225 sx CI 'G' 15369' 9138' Perforation depth: measured 15103'-15113', 15131'-15150', 15165'-15191', 15207'-15220' true vertical 8951'-8962', 8991'-8997', 9026'-9040', 9049'-9056' Tubing (size, grade, and measured depth) 4-1/2', 12.6/t, L-80, IPCT @ 14687' MD Packers and SSSV (type and measured depth) Baker Model 'D' packer @ 14568' MD; Camco !~. I,O SSSV~ 21~.~' MD 13. Stimulation or cement squeeze summary ~,~'~ ' i Intervals treated(measured) Treatment description including volumes used and final pressure ] 4. Hepresentalive Daily Average Prad~ion or Injection Data OiI-Bbl Gas-M~ ~ater-Bbl Oasing Pressure Tubing Pressure Prior to well operation 3100 4600 400 -- 330 Subsequent to operation 3100 4600 400 -- 330 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X_.~_ Gas...._ Suspended.._ Service. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .~,~/~¥U~ ,~ , Form 10-404 Rev 06/15/88 Title Sr. Area Operations Engineer SUN/nb Date ~/~O/~/ SUBMIT IN DUPLICATE DS 9-46 PERFORATING SUMMARY OF OPERATIONS ARCO Alaska, Inc. reperforated DS 9-46 in the Ivishak Sand of the Prudhoe Bay Unit on 5/6/91 (15131-15150' MD) and on 5/17/91 (15103-15113' MD), ref. log DIL 11/6/90. Produced fluids were in the wellbore during perforating operations. All wireline work was done through a 5000 psi WP BOP/lubricator tested to 1.2 times the maximum expected surface pressure. A summary of the work is below: Shot 15131-15150' MD, 2 spf. SI Well. Returned well back to production. Obtained well test data to test fractured interval. Rig up perforating unit on 5/6/91 and pressure tested equipment to 3000 psi. Open up well and produce for drawdown. Shot 15103-15113' MD, 1-1/2 spf. SI well. Secured well. RD. Returned well back to production to test fractured internal. ,. ARCO ALASKA, INC. '~'~' P.O, BOX i~OS60 · Ax'CHORAGC ALASKA DATE ' 5--i 2-'9i REF-Cn'ENCE· ARRn ~"A;2. ED Hn; E-. FTNA~ ? zNJ F'ROF LEAK DETECT ~. COLLAR-GR ~ TENPERATURE F'RO , F'ROF F'O~T BREAKDOWN F' I T ~:-HF'F M PROD F'ROF PROD PROF RUN i, 5" RUN i, 5' RUN i, --'~"&5" RUN ~ ~, · RUN i , 5" RUN i, 5" RUN i , ~'" RUN 1, 5" R UN i, 5 · RUN I , ~"~" RUN i , 5" F'LEA:',=E $!6N AND RETURN THE ATTACHED COPY A,"~ RECFIF"i' OF DATA. HAVE. A NICE DAY! ._ . ZONYA WALLACE: --' AT0-t529 APPROVED TRAN$:~ 9 CAM,-'n ,..~ :~, CAMCO CAMCO Cp. MCO CAMCO C A ,,',i C 0 C A M C 0 n A ~ C (3 C A m L; 0 CA~CO .CAMCO DISTRIBUTION · "' F'HIL~ ! P :_':,' F:'B WELL F']:LE,'.? F.: ,:..: D '"'-,,- BPX · ~ :-TTATE nF ALA~:KA TEXACO ?., I:., i') R r.I I:;,' ...I N i, RUN i.. F,'. U i'..! *1: t:;: U I"..! :i , I:.:: L.li:..! 'i , RIJ N i, F.i U r..! i , I.<L.IN i, RUN i , RUN i F;,' U N i , RLIN i, C 0 P Y A S R E C iii..'i: P T 0 I.:' D A 1' A. D I S T R I ii-,' U 'i" I C) F.i. :Jr C E N 't" R A !.. !:: I L E $ · ,,:"" CHFVRON. .. D & M :,",: EXTENSZON EXF'I...ORA'f' I Oi'~ · ,,- 'il' HAR~THON · ,,-'"' H 0 B I "" F:' I"I I I.. L. :1: F' ,'.'7 'Il' F-'B WIEI...L. F"IL.E:S R ,.*.,:. D '"' B f:' k' 'ti' . . ,":~ l' F.'.", "l E la I= ~:~ L. ¢, ~', t< A "f' E X A C O :,'" '1" I--I I!.=. F': Fi R I:;: F:' F: 'T' E D A P I ~ F' C) R 9"- 4 i I IS ~; ,lj~ JJlJ ~:j ~: ) I:;j Iii jjj ) .jj ) 0 "~ ~ -:~..x. 'T !'-I t.:: C C)F;.: R Ii" C: "1- Iii D R U N D A l'E !:: 0 R i 2 .... i I $ i '2'- i '-' 9 ('), · :":' .*(":".'- T I-'tIE C 0 F;..' F;,' E C T r..i: D B 0 T T 0 N L 0 C; I N i" E R V A L F:' 0 R ~ 2 .... 2 6 ]:$ i t 374, RFCEIVED FFR Z 7 1991 G~s Go[Is. CommJs$1o~ Anchorage ~ STATE OF ALASKA -- 0 R ALASKA .LAND GAS CONSERVATION CL..MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing ~ Alter casing ~ Repair well ~ Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. BOX 100360, Anchorage, AK 99510-0360 4. Location of well at surface 935' FSL, 162' FWL, Sec. 1, T10N, R15E, UM At top of productive interval 1652' FNL, 524' FWL, Sec. 8, T10N, R16E, UM At effective depth At total depth 1743' FNL, 789' FWL, Sec. 8, T10N, R16E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 52 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-46 9. Permit number/approval number 90-133 10. APl number 50 - 029-22092 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth' measured true vertical 15371 feet Plugs(measured) 9139 feet Effective depth: measured 15278 feet true vertical 9087 feet Junk(measured) Casing Length Size Cemented Measured depth Conductor 105' 20" 48 sx AS 105' Surface 4499' 13-3/8" 1840 sx CS III & 450 sx CI 'G' 4551' Production 14902' 9-5/8" 565 sx CI 'G' 14954' Liner 743' 7" 225 sx CI 'G' 15369' feet True verticaldepth 105' 3801' 8909' 9138' Perforation depth: measured 15165-15191'; 15207-15220' R E C E~V E P true vertical 9026-9040'; 9049-9056' 2 0 ]991. c0mmissl. . Tubing (size, grade, and measured depth) 4-1/2", 12.6~, L-80, IPCT @ 14687' I~ & Gas Cons. ,~r~choracJ'a Packers and SSSV (type and measured depth) Baker Model 'D' packer @ 14568' MD; Camco Bal-0 SSSV @ 2153' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached Treatment description including volumes used and final pressure Prior to well operation Subsequent to operation Representative Daily Average production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 5107 3123 0 Tubing Pressure -. 400 14. 16. Status of well classification as: Oil X Gas..._ Suspended Service 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed J,Re~~C~:~4,~O_ %~ Title Sr. Area Operations Engineer F°rm 10-4'04 06/15/88 622 RAC c: J. Gruber, ATO-1478 Date SUBMIT IN DUPLICATE DS 9-46 DESCRIPTION OF WORK COMPLETED FRACTURE TREATMENT OF ZONE I I 2/7/90: Shot initial perforations at: 15165 - 15191' MD (Z1) 15207 - 15220' MD (Z1) Ref. Log :BHCS 11/6/90. I 2/9/90: MIRU & PT equipment to 8000 psi. perforations at: 15165 - 15191' MD (Zl) 15207 - 15220' MD (Z1 Performed a Perforation Breakdown, treating Ref. Log: BHCS 11/6/90. Pumped: a) 20 bbls 60/40 Meth-Water, followed by b) 83 bbls Gelled 1% KCI Water, w/ball sealers, @ 10 bpm, followed by c) 242 bbls Gelled Water Flush, followed by d) Shutdown. Surged well to unseat balls, and resumed pumping: e) 20 bbls 60/40 Meth-Water, followed by f) 83 bbls Gelled 1% KCl Water, w/ball sealers, @ 10 bpm, followed by g) 242 bbls Gelled Water Flush, followed by h) Shutdown. ISIP @ 2770. Surged well, then proceeded pumping a Propped Fracture treatment through perforations (listed above). Pumped: i) 300 bbls Gelled Crosslinked Pad, @ 30 bpm, followed by j) 225 bbls Slurry w/proppant concentrations @ 1-3 ppg, followed by, k) 173 bbls Linear Gelled Flush, @ 30 bpm, followed by I) Shutdown. Placed a total of 18,100 lbs of proppant into the formation. Rigged down. I 2/1 6/90: Performed a proppant fill cleanout to 15270' MD. Flowed well and obtained a valid welltest. P L. [ii] A ;:; E ;!? 16 N A N i) R E'i" U R N T H E A'i" T A C: H E I) C 0 P Y RECEIVED BY .~_~._.._. .......... i HAVti[ A NICE DAY! A;!i; RECE I F:"i" )i.. I"1 I I'1 ,. 0 F:' "'* .... H I... ,'!i.' D I ;};' l" R I B U '¥' I 0 N ( C H ) ( 0 H/G C: '¥' ) '"' J::' J"l ! 1... L I F:' ,? J::' B I,d iii] L.. L. F:' ]i L.. t~il R & D '"' B P X "11' ~ ;~;; 'T'A'i" E 0 I::' ~'::'~ I... A ;':i; K A 'ii* ft FC' IVED Oil & Gas Q)rm. Commissio~ D I ;!.:,' '¥' F;.: :i: B U T ]: 0 i'.,i ARCO ALASKA, INC. F'.O. BOX t00S60 ANCHORAGE, ALASKA 995t0 DATE' t-23-9t REFERENCE' ARCO MAC, NETIC 'I"AF't~."(Z) WITH LISTING(S) 9-.4.0 t-t O-':7i DIFL/BHC-AC/6R /~ "~'"'70 PLEASE SIGN AND RETURN THE ATTACHED COF'Y AS RECEIPT JOB:~ 4757 JOBO 78'7 OF DATA, ATI_Ae "~ELECO RECEIVED BY ___ HAVE A NICE DAY! SHARON WILSON AT0-i529 APPROVED TF:AN$O 9t DI~, I RIBUTION CENTRAL FILES (CH) CHEVRON 'D & M .......... TAMMA$ BROWN (OH/GCT) EXXON MARATHON MOBIL · "' PHILLIPS F'B WELL F'ILE.£' R & I) · .- BF'X '"' STATE OF ALASKA °i1'· I E.,.RUO RECEIVED JAN 2 9 1991 Alaska Oil & Gas Cons. Commission Anchorage · ' STATE OF ALASKA AL^ ..... A OIL AND GAS CONSERVATION COiv,,v,iSSlON . ,.~h''~_ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [~ GAS r-~ SUSPENDED [~] ABANDONED r"'] SERVICE [--"] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-133 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22092 4 Location of well at surface ~*...~,~ j(.-~-----~ 9 Unit or Lease Name 935' FSL, 162' FWL, SEC 1, T,0N, R15E UM~//'~'_._.__~~,~'~~~ ~ ! ,i" VE;~ ~ ~"~ .'J r ' 10 Well Number PRUDHOE BAY UNIT At Top Producing Interval 1652' FNL, 524' FWL, SEC 8, T10N, R16E UM ~ ~E~-~:-.~i~ ~ i ~. ;":'~ ! 9-46 At Total Depth ~~ ..' ' '17;;i"~.77~ 11 Field and Pool 1743'FNL, 789'FWL, SEC 8, T10N, R16E UM PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. PRUDHOE BAY OIL POOL RKB 52'I ADL 283'15 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 116 No. of Completions 10/12/90. 11/05/90. 1 2/07/90*I N/A feet U SLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 15371' MD/9139' TVD 15278' MD/9087' TVD YES ~ NO E~ 2153' feet MD 1900' (approx) 22 Type Electric or Other Logs Run CHT/TEMP/GR/BHC/DIFL, CBT/CET, GCT 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 105' 30" 48 SX AS CMT 13-3/8" 68.0# L-80 SURF 4551' 17-1/2" 1840 SX CS III & 450 SX CLASS G TOP JOB W/250 SX CS II 9-5/8" 47.0# L-80 SURF 14954' 12-1/4" 565 SX CLASS G 7" 29.0# L-80 14626' 15369' 8-1/2" 225 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) 4-1/2" 14687' 14568' 15165'-15191'MD/9025'-9039'TVD W/4 SPF, 180° PHASING 15207'-15220'MD/9048'-9055'TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27 N/A PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD ,,~ FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATi: ,~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. -, ... *NOTE; DRILLED & TUBING RUN 11/14/90. PERFORATED WELL 12/7/90. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKFJ:~ FORMATION TESTS NNV~ Include interval tested, pressure data, all fluids recovard and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP SADLEROCHIT 15035' 8954' BASE SADLEROCHIT 15220' 9055' NONE .: ... 31o LIST OF ATI'ACHMENTS WELL HISTORY (DRILL AND COMPLETE)~ WELL HISTORY ADD,ENDUM (SIGNED 12/27/90)~ GYROSCOPIC SURVEY (2 COPIES) 32. I hereby certify that 1/~e foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut. in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 I~ltmetteal: Prepam a[id~=~~:o~ the .flr~. Wednesday after a well Is spudded or wooer o~mtlonl are ~a~ed. Dally wo~:;~r~ ~nz~ on the fo~ giving Inclusive datel only. District ~CO ~S~~:'" '::.~: :. ]~un~,parish or~ ~OP~ Field PR~HOE ':~ iL.~or Unit ~L: 28345 I ~uth. orw.o. "~S3943 [~'"" DRILL & CO~LETE API: 50-029-22092 Operator ARCO Spudded or W.O~ IDate 10/12/90 ]H°ur 22:00 Data and depth &s of 8:00 a.m. 10/13/90 ( TD: 485'( SUPV:ZR 10/14/90 ( TD: 1749'( SUPV:ZR 10/15/90 ( TD: 3290'( SUPV:ZR Wall History - Initial Report - Daily IState AK w~ n 09 _ 4 lARGO W.I. 21 . 7000 Prior stslus if a W.O. Gomplet ...... d f~a~ r~d 1) 485) P/U BHA #2. MW: 8.7 VIS:300 RIG ACCEPTED AT 15~0 HRS, 10/12/90. N.U DIVERTER SYSTEM, FLOW LINES. TEST ALL. OK. M/U BHA #1. FUNCTION TEST DIVERTER. SPUD WELL @ 2200 HRS, 10/12/90. DRLG F/ 105'-485' POOH F/ BHA TO KICK OFF. L/D BIT. P/U DYNADRILL. DAILY:S59,105 CUM:$59,105 ETD:SO EFC:$3,449, i05 2) 264) SLIDING, BUILDING ANGLE. MW: 8.9 VIS:320 DRLG, SLIDING F/ 485'-1056'. MADE CONN. WASH LAST 10' TO BTM. CIRC TO COND M~JD. BUILT VIS UP TO 400. CONT'D DRLG BUT MOSTLY SLIDING TO BUILD ANGLE F/ 1056' TO 1749'. DAILY:S62,635 CUM:$121,740 ETD:S200,000 EFC:$3,311,740 3) 541) DRLG AHEAD. MW: 9.1 VIS:320 DRLG F/ 1749'-2441' PUMP SURVEY. CBU. PUMP PILL. POOH. P/U BHA #3. RIH. TEST TELECO. OK. DRLG F/ 2441'-3290' DAILY:S65,681 CUM:$187,421 ETD:S200,000 EFC:$3,377,421 10/16/90 ( 4) SHORT TRIP TO HW/SLM. 13-3/8"@ 4551' MW: 9.2 VIS:220 TD: 4560' ( 270) DRLG F/ 3290'-3447' CBU. SHORT TRIP TO 2400' DRLG F/ SUPV:ZR 3447'-4308'. MUD PUi~P SERVICE (CHANGE SWABS #1, #2). DRLG F/ 4308'-4560'. CBU. SHORT TRIP TO HWDP. SLM. / .~?;~: :DAILY~$66,121 CUM:$253,542 ETD:S450,000 EFC:$3,193,542 10/17/90 ( ~~~'-HOLE/MUD F/ CMT. 13-3/8"@ 4551' MW: 9.5 VIS:300 4560'( ;~~!.F/ 2084'-2175'. POOH TO L/D MOTOR. RIH. TIGHT @ TD: SUPV:ZR : j~=I~0""2845',~~ 2900'- 3285'. WORK TO BTM. WASH F/ : 5'-4560'. NO FILL. CIRC. SHORT TRIP 29 STDS. RIH. NO . '1 ....~'~"~i7~L. CIRC. DROP SURVEY & POOH. TIGHT F/ 2700'-2100'. STAB BALLF, D UP. R/U TO RUN 13-3/8" CSG. RUN 13-3/8" CSG. TIGHT @ 3084' & 4145'. CIRC. RECIPROCATED PIPE. DAILY:S215,846 CUM:$469,388 ETD:S450,000 EFC:$3,409,388 10/18/90 ( TD: 4560'( SUPV:LP The above is correct Signature 1 ~ For form p~eparatlon and distribution, see Procedures Manual, Section 10. Drilling, Pages 86 and 87. 6)- 0) DRILL CEMENT. 13-3/8"@ 4551' MW: 9.5 VIS: 58 CIRC. PUMP 100 BBLS WATER. PUMP 5 BBLS WATER AND TEST LINES TO 3000 PSI W/ BJ PUMP. PUMP 629 BBLS (1840 SX) CS III, 12.2 # CMT W/ 40 # R-7 / 200 SX CS III @ 8 BPM. PUMP 92 BBLS (450 SX) TAIL 'G' CMT W/ 1.2 A-7, 1 GHS FP-6L @ 15.8 #. KICK PLUG W/ 5 BBLS WATER. DISPLACE W/ RIG @ 10 BPM AND RECIP. BUMP PLUG @ 2000 PSI. CIP @ 1130 HRS. L/D LANDING JT'. N/D HYDRIL & DIVERTER. PUMP TOP JOB. PUMP 50 BBLS WATER FOLLOWED BY 50 BBLS (250 SX) CS II @ 15.3 #. INSTALL FMC CSG HEAD. TEST SEALS TO 1000 PSI. N/U DRLG SPOOL & BOPE. TEST BOPE, RAMS, CHOK~ VALVES, HCR KILL LINE, UPPER & LOWER KELLY, FLOOR VALVES TO 5000 PSI. ANNULAR TO 2000 PSI. P/U BHA. P/U MOTOR. RIH TO FLOAT COLLAR @ 4468'. FLOAT SHOE @ 4551' CIRC & TEST CSG TO 3000 PSI. DRLG FLOAT COLT.~R ~ ~u~ ~ WITHIn: ~' ~ AR3B-459-1-D Number ail dally well history forms consecutively no. as they are prepared for each well. IiPage I ARCO 011 , Gas Company Daily Well History--lnterin lalll~ctleal: Thee form il ulld during dfllllng or workover operations. If testing, coring, or_~erforeting_, sh?w formltion nlml in delcribin~ work performed. Number ail drill stlm tlltl ~ll~ly. A~ dl~ription of atl cores. Work performed ~y ~roducm~ ~echon will bi repOdl~ on "lalda' l~llll un~il final completion. Repo~ offtcill or ~lltlw t~ on "F~" fo~. 1) Submit "lallHm" sheets when filled out bul not lell fr~ulntly than every 30 dlyl, or (2) on Wednesdey ot the wNk in which oll ~ II .t. Submit weekly for workovers and following setting ot oil string unlil complelion. District Field I County or Parish ARCO ALASKA INC. I NORTH SLOPE ! ILea# or unit PRUDHOE [ DS 9-46 Complete record for each day while drilling or workover in progrsll NABORS 28E Date and depth ah of 8:00 a.m. 10/19/90 ( TD: 5991'( SUPV:LP 10/20/90 ( TD: 7460'( SUPV:LP 10/21/90 ( TD: 8379'( SUPV:LP 10/22/90 ( TD: 9560'( SUPV:LP 10/23/90 ( TD:10370' ( SUPV:LP 10/24/90 ( TD:11496' ( SUPV:LP 10/25/90 ( TD:12030' ( SUPV:ZR 10/26/90 ( TD:12971' ( SUPV:ZR The above is correct JState 7) 431) 8) 469) 9) 919) .0) L181) 1) 810) 2) .126) .3) 534) 4) 941) AK jWell no. POOH. 13-3/8"@ 4551' MW: 9.2 VIS: 38 DRLG HARD CMT F/ 4473'-4540'. CIRC. TEST SHOE @ 3000 PSI. DRLG CMT, SHOE AND 10' NEW HOLE TO 4570'. LOT W/ 8.9 MUD - EMW=13.1 PPG. DRLG 12 1/4" OH F/ 4570'-5991' DYNADRILL FAILURE. CIRC. DROP SINGLE SHOT. PUMP PILL. POOH. DAILY:S59,442 CUM:$734,778 ETD:S900,000 EFC:$3,224,778 DRILLING. 13-3/8"@ 4551' MW: 9.2 VIS: 38 POOH TO CHANGE MOTOR. C/O DYNADRILL AND BIT. RIH TO 5925'. REAM F/ 5925'- 5991' DRILL F/ 5991'-7422'. DAILY:S74,637 CUM:$809,415 ETD:S1,100,000 EFC:$3,099,415 DRILLING 13-3/8"@ 4551' MW: 9.4 VIS: 38 DRILL F/ 7460'-7685'. SHORT TRIP 18 STDS. DRILL F/ 7685'-7781'. DYNADRILL FAILURE. CBU. DROP SURVEY. PUMP PILL. POOH. C/O DYNADRILL & BIT. RIH W/ BIT #5. DRILL F/ 7781'-8379'. DAILY:S72,761 CUM:$882,176 ETD:S1,130,000 EFC:$3,142,176 POOH. 13-3/8"@ 4551' MW: 9.4 VIS: 40 DRILL F/ 8379'-9560' PUMP LOW/HIGH VIS SWEEP. CBU. DROP SINGLE SHOT. PUMP PILL. POOH. DAILY:S82,588 CUM:$964,764 ETD:S1,245,000 EFC:$3,109,764 DRILLING. 13-3/8"@ 4551' MW: 9.5 VIS: 46 POOH F/ BIT. C/O BIT, M~rD & FLOAT SUB. FLOW TEST MOTOR. RIH W/ BIT #6. DRILL F/ 9560'-10300' WORK STUCK BHA. DRILL F/ 10300'-10370'. DAILY:S76,728 CUM:$1,041,492 ETD:S1,300,000 EFC:$3,131,492 DRILLING. DRLG F/ 10370'-11496' 13-3/8"@ 4551' MW: 9.6 VIS: 49 DAILY:S69,044 CUM:$1,110,536 ETD:S1,400,000 EFC:$3,100,536 DRILLING. 13-3/8"@ 4551' MW: 9.7 VIS: 60 DRLG F/ 11496'-11528' CIRC HI/LOW SWEEP. DROP SURVEY. POOH. C/O BIT & MOTOR. RIH TO 4850' FLOW TEST W/ KELLY. RIH TO 8430' BREAK CIRC. WASH 42' TO BTM. DRILLED F/ 11528'-12030' DAILY:S92,870 CUM:$1,203,406 ETD:S1,500,000 EFC:$3,093,406 see Procedures Manual Section 10, Drilling, Pages 86 and 87 DRILLING. 13-3/8"@ 4551' MW: 9.7 VIS: 43 DRLG F/ 12030'-12971'. DAILY:S79,394 CUM:$1,282,800 ETD:S1,550,000 EFC:$3,122,800 'JAN 04 1991 Cons, AR3B-459-2-8 Number all daily well ~'lisloty forms consecul~vel¥ J¢,,ge ~o as they are prepared for each well ARCO Oh J Gas Company Daily Well History--lnterin IltltlliCtleltl: Th a form il'ule{I durin~ drilling or wo~over operations. If testing, coring, or perforating, show formation name in deacnbin~ work Derformed. Number all drill stem teltl seq~entlMly. Attach de~c:ription of iii cores. Work performed by Producing Section will be reported on "lnterll~' ,,heats until final completion. Report official or rel~ree~lt,~tl~ te~t Oll "FMaP' form. 1) Submit "llttertl~t" sheets when filled out but not leas frequenlly thin every 30 days, or (2) on Wednesday of the week in which oil ~11~1 II NS. Submit weekly for workovers and following setting ot oil strJn~ unlil completion. District ICounty or PsriShNoRTH J Stat. ARCO ALASKA INC. SLOPE Fiend PRUDHOE ILea~e or Unit DS 9-46 I Complete record for each day while drilling of workover in progrell NABORS 28E Date and depth as of 8:00 a.m. 10/27/90 ( TD:13721' ( SUPV:ZR 10/28/90 ( TD:13939' ( SUPV:ZR 10/29/90 ( TD:14509' ( SUPV:ZR 10/30/90 ( TD:14986' ( SUPV:ZR 10/31/90 ( TD:14986' ( SUPV:ZR 11/01/90 ( TD:14986' ( SUPV:ZR 11/02/90 ( TD:14986' ( SUPV:LPH/HP The e~ove is correct For ora Ilreparation and distribution see Procedures Manual Section 10. Drilling, Pages 86 and 87 5) 750) 6) 218) .7) 570) .8) 477) ,9) 0) :o) o) 1) o) AK IWell no. DRILLING. 13-3/8"@ 4551' MW: 9.7 VIS: 46 DRLG F/ 12971'-13003'. CBU. SHORT TRIP TO 10200'. DRLG F/ 13003'-13721'. DAILY:S69,436 CUM:$1,352,236 ETD:S1,580,000 EFC:$3,162,236 DRILLING. 13-3/8"@ 4551' MW: 9.7 VIS: 52 DRLG F/ 13721'-13920' ENCOUNTERED K-5 HARD SPOT @ 13920' CBU. DROP SS SURVEY. POOH. C/ BIT, TELECO, FLOAT SUB. SERVICE WEAR RING. TEST BOP. RIH. REAM F/ 13864'-13920' DRLG F/ 13920'-13939' DAILY:S74,985 CUM:$1,427,221 ETD:S1,700,000 EFC:$3,117,221 DRILLING. DRLG F/ 13939'-14509' 13-3/8"@ 4551' MW: 9.8 VIS: 51 DAILY:S72,760 CUM:$1,499,981 ETD:S1,600,000 EFC:$3,289,981 POOH. 13-3/8"@ 4551' MW: 9.9 VIS: 52 DRLG F/ 14509'-14986'. SURVEY W/ TELECO. CBU. PUMP HIGH/LOW VIS SWEEP. POOH FOR SHORT TRIP. TIGHT @ 13750'-13650' CONT'D SHORT TRIP. KELLY UP @ 13717' PUMP 12 SINGLES OUT OF HOLE TO 13330'. REAM F/ 13330'-13706' RIH TO BTM. DAILY:S76,639 CUM:$1,576,620 ETD:S1,625,000 EFC:$3,341,620 REAMING TO BTM. 13-3/8"@ 4551' MW:10.2 VIS: 64 CIRC. WT UP TO 10.2 PPG. CIRC HIGH/LOW VIS SWEEP. PUMP 29 JTS OUT OF HOLE. POOH 10 STDS. OK. POOH. L/D TELECO, MOTOR, BIT. P/U BHA #11. RIH TO 13939'. P/U SINGLES & REAM F/ 13939'-14362'. DAILY:S61,156 CUM:$1,637,776 ETD:S1,700,000 EFC:$3,327,776 RUNNING 9-5/8" CSG. 9-5/8"@14954' MW:10.2 VIS: 54 REAM F/ 14362'-14986'. CIRC LOW/HIGH VIS SWEEP. SHORT TRIP TO 13780'. RIH. PUMP 2 LOW/HIGH VIS SWEEPS. SPOT 100 BBLS 10.4 PILL ON BTM. POOH. L/D BHA. CHANGE TOP RAMS TO 9-5/8". TEST TO 2000 PSI. OK. RUN 9-5/8" CSG. DAILY:S56,859 CUM:$1,694,635 ETD:S1,760,000 EFC:$3,324,635 N/U CSG SPOOL. 9-5/8"@14954' MW:10.3 VIS: 47 RIH W/ 9-5/8" CSG. PIPE STUCK 7' FROM LANDING MANDREL HANGER. CIRC 2-1/2 ANNULUS VOLUMES. TEST CMT LINES TO 3500 PSI. PUMP 25 BBLS FRESH WATER/ ARCO PREFLUSH SPACER AND 565 SX CL 'G' CMT (115.8 BBLS) W/ ADDITIVES @ 15.8 PPG. DISPLACE CMT W/ 1095.6 BBLS MUD. DID NOT BUMP PLUG. TEST FLOATS. OK. N/D BOP. SET EI~RGENCY SLIPS. CUT CSG. INSTALL 9-5/8" 5000# FMC CSG SPOOL & PACKOFF. \~'~x~ \ ~ Drilling Supt. AR3B-459-2-B INumber all dally wail hiStOry forms consecuhvely ]Page nO as riley a,e prepared tor each well. ARCO Oil , Gal Company Daily Well History--lnterirr lalllltli~ll: Thil form il'Ull<l during drtllihg or wort~ver operations. If fasting, coring, or_perfor.~ting_, show formstion nlml in delcrtbing work performed. Number iii drill .tern testl lequMItiMly. AttlGh del~riptlon of III cores. Work performed hy I"roduclng :~ectlon will bi rlpoIled on "Interim" sheets until finil completion. Repor~ officill or rlprllMItMlvt ~ on "FilIM" form. 1) Submit "Interim" sheets when filled OUt but not Iisi frequently thin every 30 dlyl, or (2) on Wednesday of the week in which oil ~ il lit. Submit weekly for workovers end following setting of oil string until completion. District Field I County or pirishNoRTH ARCOpRuDHoEALASKA INC. ileal, or Unit DS 9-46SLOPE Complete record for each day while drilling or workover in progreu NABORS 28E Date end deDth al of 8:00 a.m. 11/03/90 ( TD:14986' ( SUPV:LPH/HP 11/04/90 ( TD:14991' ( SUPV:LPH/HP 11/05/90 ( TD:15298' ( SUPV:LPH/HP 11/06/90 ( TD:15371' ( SUPV:LPH/HP 11/07/90 ( TD:15371' ( SUPV:LPH/HP 11/08/90 ( TD:15371' ( SUPV:LPH/HP The above is correc~ ~, For fo~ ~mD~r~tion .nd di.tri~ution ~ Procedures MMUll ~ction I0, Odlllng, Pagee a6 and 87 IState 0) AK 3) 5) jWell no. :4) 307) RIH. 9-5/8"@14954' MW: 9.4 VIS: 36 TEST 9-5/8". N/U BOP. TEST BOP TO 5000 PSI. M/U BHA #12. RIH TO 14782'. TEST CSG TO 3000 PSI. DRLG CMT TO 14869'. DRLG FLOAT COLLAR @ 14869'. LOST 550 PSI. POOH LOOKING FOR LEAK. FOUND WASHOUT IN DP JT #304. L/D JT. P/U JT. DAILY:S87,624 CUM:$2,246,297 ETD:S2,200,000 EFC:$3,436,297 5) 73) DRLG NEW FORMATION @ 14991'. 9-5/8"@14954' MW: 9.8 VIS: 74 RIH. BREAK CIRC @ 14869'. DRLG FLOAT COLLAR, FLOAT SHOE @ 14941' WASH & REAM F/ 14955'-14983' RAN 2 HI VIS SWEEPSi CIRC. PACKING OFF IN CSG ANNULUS. SHORT TRIP 5 STDS. REAM F/ 14941'-14983'. CIRC 50 BBLS HI VIS SWEEP. PUMP 14 PPG HIGH VIS SWEEP. DRLG @ 14991' DAILY:S95,859 CUM:$2,342,156 ETD:S2,200,000 EFC:$3,532,156 6) 0) DRILLING. 9-5/8"@14954' MW:10.0 VIS: 46 DRLG F/ 14991'-14996'. CRIC. PERFORM L.O.T. TO 12.5 EMW. WASH & REAM F/ 14991'-14996'. DRLG F/ 14996'-15015'. WASH & REAM. DRLG F/ 15015'-15046'. SHORT TRIP TO SHOE. DRLG F/ 15046'-15298' DAILY:S56,795 CUM:$2,398,951 ETD:S2,200,000 EFC:$3,588,951 :7) o) RIH. 9-5/8"@14954' YrW:10.0 VIS: 52 DRLG F/ 15298'-15371' (TD). TD @ 11/05/90, 11:50 HRS. CBU. SHORT TRIP TO 9-5/8" SHOE. CIRC 50 BBLS HIGH VIS SWEEP. POOH. DOWNLOAD TELECO. R/U DRESSER ATLAS. RIH W/ CHT/TEMP/GR/BHC/DIFL TO 15340' HOLE STICKY. POOH. L/D TELECO MWD & LOGGING TOOLS. M/U CLEANOUT BHA. RIH. DAILY:S58,083 CUM:$2,457,034 ETD:S2,300,000 EFC:$3,547,034 RIH W/LINER ON DP 9-5/8"@14954' MW:10.0 VIS: 49 CUT DRILL LINE. FIN. RIH,- HOLE TIGHT IN SPOTS 14954-15371- NO FILL. CIRC.AND COND. MUD.COND. HOLE FOR LINER. (SHORT TRIPPED HOLE 4 TIMES. AVG. DRAG @ 400 K ON LAST SHORT TRIP). POOH F/ LINER. RU AND RUN 18 JTS. 7" LINER + MARKER JOINT RIH W/ LINER ON DP. DAILY:S192,138 CUM:$2,649,172 ETD:S2,450,000 EFC:$3,589,172 CBU AFTER DRLG. CMNT. INSIDE 7 9-5/8"@14954' MW:10.0 VIS: 58 CONT'D TO RIH,W/7" LINER ON 5" DP. CIRC. AND COND. MUD F/ CMT. JOB. TESTED CMT LINES TO 3000PSI. PUMPED 50 BBLS OF PRE FLUSH,-68 BBLS OF CMNT. SLURRY- DROP PLUG.DISPLACED CMNT W/MUD @ 10 BPM. BUMPED PLUG WITH 276 BBLS . (CALC. DISPLA CEMENT=284 BBSL) SET HANGER WITH 3000 PSI.ROTATED 35 TURNS. P/U PACKER . TEST BACKSIDE W/ 800 PSI. OK. PULL OUT OF SEAL ASSEMBLY & REV. CIRCULATE @6 BBLS/M IN. @ 800 PSI. POOH W/10 STANDS / PUMPED PILL .POOH L/D CMNT. HEAD. CONT'D TO POOH t,/n RtrkTntT~G TOOT, RTH W/ R-1/?" R~a . t,/n $aMm .CLmAR RIG HARD ~EME AR3B-459-2-8 INumber all dally well history forms Consecutively Page as they are prepared to, each well. ARCO Oi. & Gas Company Daily Well History--lntertn lalll1~tl~lll: Thil form il'ulld during dHIIill~ or wol'l<ove, Ol~l'etlonl. If testing, coring, or~eHor~tin~ show ~o.rmltion nlme in delcrlbin~ work DeHormed. Numar all drill stem teltl ~tl~ly. ~ ~HDtlon of all co~l. Work Derfo~m~d ~y Pm~uc~n~ ~/ction will be reposed on "la~tm sh~tl until final completion. RIDo~ offlcill or ~D~ ~ ~ "~" fo~. I) Submit "lall.~ sheets when filled out but not Ills frequently then every 30 dlyl, or (2) on Wednelday of the w.k in ~tch ~ ~ ~ ~ ~Dmlt w~kly for worko~ and following setting of oil string unlil completion. Diltrict ICounty or Perish I St.te ARCO ALASKA INC. I NORTH SLOPE Field PRUDHOE iL.,. or unit DS 9-46 I Complete record fol' each day while drilling or workover in progrell NABORS 28E D,,te and deptl~ aa of 8:00 a.m. 11/09/90 ( 2 TD:15371' ( SUPV:LPH/HP 11/10/90 ( 2 TD:15371 PB:15278 SUPV:ZR/LP 11/11/90 ( 3 TD:15371 PB:15278 SUPV:ZR/LP )) o) AK DAILY:S120,083 CUM:$2,769,255 ETD:S2,450,000 EFC:$3,709,255 POOH W/ RTTS X BP 9-5/8"@14954' MW:10.0 VIS: 53 CBU TO CLF_~AN HOLE F/ CSG. TEST. - ATTEMPTED TO TEST 9-5/8"X7" CSG. DID NOT TES T.POOH AFTER ELIMINATING POSSIBILITY OF SURFACE LEAKS.M/U 7" BRIDGE PLUG /9-~# RTTS,P/U 9 DC+ 3JTS OF 5" HWDP,RIH TO 3000' SET RTTS,TESTED CSG. BELOW /ABOVE TO 3000 PSI.TEST OK.-CONT'D TO RIH,- TAGGED TOL @ 14637'MD COULD NOT GET IN TO 7" LINER W/ BRIDG~ pLUG, CIRCULATED F/ 20 MIN. SET RTTS @ 14545'- TEST CSG. ABOVE AND BELOW RTTS TO 3000 PSI. - TEST PASSED. - RIH TO LINER TOP , ABLE TO GET INSIDE OF LINER W/ BRIDGE PLUG- TESTED ENTIRE STRING AGAIN TO 3000 PSI - TEST PASSED. POOH DAILY:S47,652 CUM:$2,816,907 ETD:S2,450,000 EFC:$3,756,907 L/D 3-1/2" BHA 9-5/8"@14954' MW: 8.6 FSW CONT'D TO POOH ,L/D 5" HW /9 6-1/2" DS'S/HOWCO BHA, M/U MULE SHOE ,7" CSG. SCRAPER, 3-1/2"DP, 9-5/8" CSG. SCRAPER, RIH TO 15278'MD, PUMP 300 BBLS OF FRESH H20 + 90- BBLS HI VIS. SWEEP DOWN DRILL PIPE,HOLE LOOKED CLEAN. BLOW DOWN KELLY/MUD LINES /FLUSH SUC.LINES W/ FSW- REV.OUT- DISPLACED 10.0 PPG MUD W/ FSW BY REV OUT. PUMPED TOTAL OF 1200 BBLS OF FSW. SLIGHTLY OVER CALCULATED VOLUME OF 1018 BBLS. TEST CSG. TO 3000 PSI. DROPED 100 PSI. IN 5 MIN. PRESS. BACK UP TO 3000 PSI. TOOK .5 BBLS ,PRESS DROPPED 400 PSI. IN 15 MIN. PRESS DRO PED 325-340 PSI IN 30 MIN. PRESS BACK UP TO 3000 PSI. TOOK .4 BBLS / PRESS LEAKED DOWN TO 2700-2675 . PRESS BACK UP TO 3000 PSI. TOOK 0.3 BBLS. LEAKED 30 0 PSI IN 30 MIN. - POOH CUT 104' DRILL LINE. DAILY:S53,687 CUM:$2,870,594 ETD:S291,190 EFC:$5,969,395 L/D RTTS/BP 9-5/8"@14954' MW: 8.6 FSW CONT'D TO POOH ,L/D 3-1/2" DP /4-3/4" DC'S , TESTED BOPS TESTED 9-5/8" CSG 7" LINER. BLED OFF 500 PSI IN 30 MIN. PICKED UP 9 6-1/4" DC'S ,STAND BACK SAME. P/U HALIBURTON 7" BP/ 2 JTS 3-1/2" HWT. 9-5/8" RTTS , RIH ,- SET RTTS @ 14559'MD , TESTED 9-5/8" FOR 35 MIN. 3000 PSI. - LOST 325 PSI IN 20 MIN. RELEASED RTTS . SET RTTS AGAIN @ 14559'MD- LOST 700 PSI. IN 10 MIN. , PRESS. BACK UP TO 3000 PSI. - TOOK 20 MIN TO LOOSE 800 PSI. - ATTEMPTED TO TEST ONE MORE TIME W/ RTTS SET @ 14559'MD - BLED OFF 900 PSI. IN 20 MIN. , POOH - L/D BP/9-5/8" RTTS. DAILY:S50,200 CUM:$2,920,794 ETD:SO EFC:$6,310,785 IWetl no. The &l~ove ia correct see Pro¢lClure$ MII~.II Section 10, Drilling. Plgel a8 ~ncl a7 Drilling Supt. AR3B-459-2-B Number all dady well history Iorms consecutively as they are prepared for each well. Page ~o ARCO Oi, J Gas Company Daily Well History--lnterirr IfllllliCti~ltl: This form il u~l dudng dialling or work0ver 01:~rati0ne. If testing, coring, or perforating, show f0rmlti0n nlml in dascribin,~ work Derf0rmed. Number all drill stem tells ~ltlally. Attach description of III corel. Work performed by Producing Section will be reDorted on "latertm' Shlltl until final completion. Report official or re~r~e~t~th~ t~ off "Filial" form. 1) Submit "latodl~" sheets when filled out but not leis frequently then every 30 days. or (2) on Wednesday of the week in w'hlch oll ~ II ,et. Submit weekly for workovere and following setting of oil Iff. in§ unlil completion. District rcounty or Parish I Stlte ARCO ALASKA INC. NORTH SLOPE AK Field ILeau or Unit IWell no. PRUDHOE DS 9-46 Date and depth Complete reCord for each day while drilling or workover in progreu as of s:oo a.m. NABORS 28E 11/12/90 (1) TD: 15371 PB: 15278 SUPV: ZR/LP 11/13/90 ( TD:15371 PB:15278 SUPV:ZR/LP The above ia correct ~,~% sm~tuq~"~ .~ 'X'\ r\, For ;o,m~mpar~tion and diltri~ution 32) POOH 9-5/8"@14954' MW: 8.6 FSW P/U TIW POLISH MILL , RIH ,POLISH TIE BACK RECEPTACLE. REVERSED CIRCULATE 1.5 DP VOLUMES. POOH, CUT AND SLIP DRILL LINE. CONT'D TO POOH L/D POLISH MILL , MU TIW LINER PACKER W/SEAL ASSEMBLY ,RIH TO 14634'MD -SET PACKER TEST LINER DOWN5~~J. DRILL PIPE TO 3000 PSI. TEST DOWN BACKSIDE TO 3000 PSI. POOH. DAILY:S53,270 CUM:$2,974,064 ETD:S0 EFC:$6,364,05 R/U TO RUN 4-1/2" COMPLETION 9-5/8"@14954' MW: 8.6 FSW L/D 5 HWDP + 6-1/4 DRILL COLLARS, R/U WIRELINE - SCHLUMBERGER, RIH W/JUNK BASKET/8-1/2" GAUGE RING- R/D WIRELINE, R/U TO RUN PACKER W/ TAIL ASSY. RIH W/ PACKER + TAIL ASSEMBLY ON DP. SET PACKER W/2000 PSI. AT 14568'MD POOH L/D 5" DP.L/D PACKER RUNNING TOOL. CAMCO 'BAL-O' SSSV @ 2153', BAKER 'D' PKR @ 14568', TT @ 14687' DAILY:S42,000 CUM:$3,016,064 ETD:SO EFC:$6,406,055 Oat ]Title J \~\~c~O Drilling Supt. see Procedures Manual Section 10, Drilling, Pagee 86 .nd 87 AR3B-459-2-B INumber all dally well h~slOry forms consecutively as [hey are prepared for eacll well. ARCO O.. and party ~ Dally Well History-Final Report Instructions: Prepare a~~:Wadneaday after all..owable has been as?lgned or well I1_ Plugg. ed. Aban. donad, o_r..Sold. "Final Repo~' shou d-' -~--~ ' ."Pended for an indennite or appreciable length of time· ~Jn worv. over~ when an omclal test ia not required upon completl~J~ .... '~tiat data In blocks provided. The "Flnll Repel1" form may be u~ed for reporting the entire operation if space is I Accountlng coat center code Field. PRUDHOE LeaseTitle or Unit ~J:~L: 28345 I wang°'9-46 Auth. orW.O, nD. AS3943 I DRILL & COMPLETE I API: 50-029-22092 Operator ARCO IA.R.Co. I Spudded or W.O. ~ IDate 10 / 12 / 90 I Complete record fo~:)[~fl~ re~l~ Date and depth as of 8:00 a.m. 11/14/90 ( TD:15371 PB:15278 SUPV:ZR/LP Old TD Released rig Classifications (oil, gas, etc.) Producing method Potential test data I otal number of wells (active or inactive) on thisI 21 7000 Dst center prior to plugging and · I bandonment of this well our 22: 00 IPrlor status If a W.O, I 33) RELEASED RIG 06:00 HRS 9-5/8"@14954' MW: 8.6 FSW RIH W/ 4-1/2" TBG. STRING , TAG PACKER + SPACE OUT ,"M/U TBG.HANGER, HOOK UP CONTROL LINES, TESTED BOTH TO 5000 PS~' FOR 20 MIN. PUMPED 150 BBLS OF DIESEL TREATED W/C-120 DOW~' TBG. U-TUBE DIESEL BACK TO ANNULUS. LAND TBG. RUN-IN -LOCK ~ DOWN , TEST TUBING TO 3000 PSI. TESTED BACKSIDE TO 3000 PS~. F/ 30 MIN. OK. SHEARED SOS ,PINNED FOR 4100 PSI. SET BPV/BLOW DOWN LINES. N/D FLOW LINE . BOP STACK. M/U FMC TREE RUN TEST PLUG, TEST TREE TO 5000 PSI. - PULL TEST PLUG - SET BPV, RELEASED RIG AT 06:00 MRS 11-14-90 DAILY:S328,269 CUM:$3,344,333 ETD:SO EFC:$6,734,324 New TD Date PB Depth IK nd of rg IType completion (single, dual, etc.) Official reservoir name(s) Well no. Date Reservoir Producing Interval Oil or gasTest time Production OII on test IGas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected ForTheab°veifoim ......., ' % ~'and distribution. I pre~aration see Procedures Manual, Section 10, Drilling, Pages 86 and 87. JAN 1991 AR3B-459-3-C INumberall dally well-'~ ~[~[t~l~~ely Page no. I aa they are prepared for each well. I DIvlelon of Allantk:RlchllelliCompany WELL HISTORY ADDENDUM WELL WORK LOG Well # (J-46 Date: 12/7/90 Work performed: INITIAL PERFORATIONS AFE: AS3943 Summary 1 2/7/90 RU Dresser Atlas. RIH w/22 grm, .51 hole diam., super omnikone gun. FL @ 3100'. Shoot interval f/ 15207'-15220' @ 4 spf, 180° phasing. POOH, all shots fired. RIH, FL @ 2750'. Bled off 175 psi; 100 psi more lost through choke before it was secured. Shoot f/ 15178'-15191' @ 4 spf, 180° phasing. No FL obtained, but tbg press was bled from 425 psi - 0 psi. Shoot interval f/ 15165'-15178' @ 4 spf, 180 o phasing. POOH, all shots fired. RD. Perforated f/ 1 51 65'- 1 51 91' 15207'-15220' DRILLING SUPERINTENDENT O~IG IN A L RECEIVED JAN ~ 1991 Alaska 0ii & Gas Cons, Commission Anchorage SUB - S URFA CE DIRECTIONAL SURVEY r~ UIDANCE r~ ONTINUOUS ~ OOL Company ARCO ALASKA, INC. Well Name D.S. 9-46 (935' FSL,162' FWL,SEC 1,T10N,R15E, UM) Field/Location PRUDHOE BAY, NORTH SLOPE, ALASKA Job Reference No. 74260 LocKled By: FORMICA Date 22-N0V-90 Computed By: KRUWELL SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING ARCO ALASKA, INC. 9-46 PRUDHOZ NORTH SURVEY D&T~E: 2Z-NOV-g0 :NGINEEP,',_ . J. FORMICA METHODS OF COMPUT~T.ION TOOL LOCATION: TANGENTIAL- ~VER~GED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET ~ZIMUTH OF SOUTH 75 DFG Z9 MIN ~AST COMPUTATION DATE: 30-gEC-gO ARCO AL~SKA~ D.S. 9-46 PRUDHOE BAY NORTH SLOPE~ INC. ALASKA KELLY DAT,6 OF .SURVEY: BUSHING ELEV4TICN: E~GINEER: INTERPOLATED VALUES FOR EVEN 100 :FEET OF MEASURED DEPTH MEASURED DEPTH TRUE SU3-SEA COURS'E VERTICAL VERTICAL DEVIATION AZIMUTH DE'PTH OEPTH DEG MIN DEG MIN VERTiC SECTI FEE AL DOGLEG RECTANGULAR COORDINATES HORIZ. ON SEVERITY NORTH/SOUTH EAST/WEST gIST. 'T gEG/IO0 FEET FEET FEET 0.00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 900.00 0.00 -5Z. O0 0 0 100.00 48.00 0 5 200.00 148.00 0 13 300.00 248.00 0 10 400.00 348.00 0 6 499.99 447.99 1 599.97 547.97 I 44 699.90 647.90 2 27 799.78 747.78 3 5 899.59 847.59 3 55 N 0 0 N 5') 30 S 5 59 S 4633 N 79 40 N 87 47 S ~36 17 S H9 3~ S 36 49 $ H3 11 O. O. O. O. O. '1 . 3. ll. 17. O0 0.00 0.00 N 0.00 E 0.00 10 0.00 0.02 N 0.11 E 0.11 07 0.55 0.07 S 0.05 E 0.09 14 0.53 0.17 S 0.10 E 0.20 29 0.32 0.41 S 0.19 E 0.45 08 0.60 0.35 S 1.OZ ~,: 1.08 36 1.11 0.43 S 3.35 E 3.38 98 0.47 0.52 S 7.08 E 7.10 58 0.82 0.64 S 11.79 E 11.81 64 0.84 1.17 S 17.92 E 17.95 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1800o00 1900.00 999.33 947.33 4 26 1098.98 1046.98 5 9 1198.50 1146.50 6 3 1297.86 1245.86 6 58 1397.01 1345.01 7 53 1495.89 1443.89 9 19 1594.38 1542.38 10 39 1692.28 1640.28 12 51 1789.23 1737.28 15 3 1885.53 1833.53 16 22 S 80 9 E 24.87 S 79 3 E 33.15 S 83 36 E 42.39 S 85 25 E 54.07 S ,33 37 c 66.89 S 84 28 ~ 81.61 S 84 6 E 98.73 S $1 35 E 118.91 S 76 1 6 143.I1 S 71 19 E 170.25 0.75 2.21 S 25.12 E 25.21 1.40 3.80 S 33,2,6 E 33.4'7 1.1'? 5.29 S 42.93 E 43.26 1.12 6.25 S 54.23 E 54.59 0.69 7.53 S 57.15 E 67.57 1.49 9.12 S B1.94 E 8.2.45 2.49 10.77 S 99.20 E 99.78 2.27 13.31 S 119.3'3 E 1ZO.1Z 2.12 18.06 S lq, 3.16 E 144.29 2.10 25.68 S 169.21 E 171.15 2000.00 2100.00 2Z00.00 2300.00 2400.00 2500.00 2600.00 Z700.O0 2800.00 2900.00 1981.23 1929.23 17 18 2076.25 2024.25 19 Z Z170.43 2118.43 ZO 9 2263.99 2211.99 21 15 2356.72 2304.72 22 46 2448.07 2396.07 ~5 26 2537.34 2485.34 28 22 2624.10 2572.10 30 57 2709.0~ 2557.08 32 57 2791.64 2739.54 35 33 S 69 32 S 69 36 S 70 3 S 72 42 S 75 29 S 7639 S 76 6 S 74 56 S 74 55 S 7548 199. 230. 263. 298. 33 5. 376. 421. 471. 524. 580. 09 O9 53 74 15 8O 82 54 24 64 1.65 35.55 S 196.43 E 199.64 2.00 46.43 S 225.65 E 230.38 1.84 58.10 S 257.17 E 263-66 1.70 69.48 S 290.60 E 298.79 2.04 79.67 S 326.60 E 336.18 2.71 89.30 $ 3.56.11 ~ 376.84 3.68 99.88 $ 409.87 4 421.87 1.67 112.~2 5 458.01 E 471.53 3.17 126.19 S 508.85 E 524.27 2.30 1~0.35 S 563.45 E 580.67 3000.00 3100.00 3200.00 3300.00 3400.00 3500.00 3600.00 3700.00 3800.00 3900.00 2871.85 2.B19.85 37 57 2948.30 2~96.30 42 20 3020.47 2968.47 45 11 3089.49 3037.49 47 22 3156.35 3104.35 48 37 3221.79 3169.78 49 39 3285.99 3233.99 50 2t 3348.63 3196.63 52 25 3407.63 3355.63 54 50 3454.37 3412.37 55 59 S 75 40 E S 73 46 E S 72 57~: s 7! 55 ~ $71 3= $ 70 49F=_ S 70 10 E S 69 59 E S 7O 45 E S 7Z 8= 640. 704. 773. 846. )ZO. 995. 1072. 1149. 1230. 1312. 34 75 9O 16 32 70 08 66 07 19 3.71 154.94 S 621.34 5 640.37 4.30 171.91 S 683.47 E. 704.75 2.65 191.87 S 7~+9.74 ~ 773.90 2.00 213.6,5 S 818.7~+ E 846.1~ 0.97 237.42 S 8))9.20 ~ 920.35 0.99 262.12 S 960.65 E 995.73 1.00 287.71 S 1032.94 E 1072.26 4.02 314.36 S 1106.1~ E 1149.98 1.58 341.51 S 11~2.21 :_ 1230.55 1.66 357.80 S 1260.23 -E 1312.91 J PAGE 1 Z2-NOV-90 52.00 FT J. FORMICA DEPARTURE AZIMUTH gEG MIN N 0 0 E N 77 5 E S 32 40 E S 28 52 E S 25 3 E S 7.1 16 E S 82 45 E S 85 ~B E S 86 53 E S 86 16 E S 84 58 E S 83 29 E S 82 58 E S 83 26 E S 83 36 E S 83 39 E S 83 48 E S 83 38 E $ 82 49 E S 81 22 E S 79 43 E S 78 22 E S 77 16 E S 76 33 E S 76 18 E S 75 18 E S 75 18 E S 76 13 E S 75 4 E S 75 1E S 76 0 E S 75 53 E S 75 39 E S 75 22 E S 75 3 E S 74 44 E S 7~ 26 E S 74 8 E S 73 53 E S 73 44 E COMPUTATIgN DATE: 30-DEC-gO ARCO ALASKA, INC. D.S. 9-46 PRUOHOE BAY NORTH SLOPE, ALASKA DATE ~F SURVEY: 2Z-NOV-90 KELLY 5USHING ELEVATION: 52.00 FT ENGINEER: J. FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET DF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGUL4R COORDINATES HOR'IZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SEC'TIgN SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH OEG MIN 4000.00 3519.33 3467.33 57 25 4100.00 3572.11 3520.11 58 49 4200.00 3623.13 3571.13 59 32 4300.00 367&.11 3622.11 59 14 4400.00 3724.99 3672.99 59 27 4500.00 3775.71 3723.71 59 51 4600.00 3825.65 3773.65 60 6 4700.00 3875.55 3823.55 59 53 4800.00 3927.07 3875.07 58 19 4900.00 397'9.58 3927.58 58 7 5000.00 4032.50 3980.50 58 5 5100.00 4085.27 4033.27 58 9 5200.00 4138.14 4086.14 58 Z 5300.00 4191.20 4139.Z0 57 59 5400.00 ~244.18 4192.18 58 0 5500.00 4297.36 4245.36 57 35 5600.00 4351.51 4299.51 57 17 5700.00 4405.35 4353.35 56 50 5800.00 4460.08 4408.08 56 51 5900.00 4514.82 4462.82 56 33 6000.00 4570.24 4518.24 56 43 6100.00 4623.92 4571.92 58 11 6200.00 4676.49 4624.49 58 32 6300.00 4728.22 4576.22 59 13 6400.00 4778.99 4726.99 59 51 6500.00 4828.92 4776.92 60 18 6600.00 4878.91 4826.91 59 42 6700.00 4929.19 4877.19 59 56 6800.00 497').65 4927.65 59 32 6900.00 5029.96 4977.96 59 52 7000.00 5080.00 5028.00 50 l 7100.00 5129.88 5077.38 60 5 7200.00 5179.73 5127.73 60 11 7300.00 5229.17 5177.17 60 31 7400.00 5278.28 5226.28 60 20 7500.00 53!8.11 5276.11 60 5 7600.00 5377.79 5325.79 60 23 7700.00 5426.92 5374.92 60 38 7800.00 5476.07 5424.07 60 44 7900.00 5524.56 5472.56 61 10 DEG MIN FEET DEG/IO0 FEET FEET FEET DEG S 73 21 E 1395.64 S 74 21 E 1480.54 S 75 Z E 1566.53 S 77 42 E 1552.53 S 78 50 E 1738.54 S 79 5,6 E 1824.50 S 80 O E 1910.87 S 79 49 E 1997.27 S 79 4F+ E 2082.73 S 79 36 .=- 2167.61 S 79 31 E 2252.24 S 79 22 E 2336.98 S 79 16 E 2421.67 S 79 9 E 2506.26 S 79 4 E 2590.90 S 78 49 E 2675.44 S 78 30 E 275':J.38 S 78 16 E 2843.54 S 78 13 E 2927.13 S 78 3 E 3010.73 S 78 0 E 3093.89 S 77 59 E 3178.18 S 77 44 E 3263.17 S 77 33 6 3348.69 S 77 20 E 3434.79 S 76 5~ E 3521.40 S 76 49 E 3607.98 S 76 24 E 3694.40 S 75 45 E 3780.73 S 75 2_6 ~ 3867.16 S 75 49 E 3953.73 S 75 39 E 4040.41 S 75 36 E 4127.09 S 75 1! E 4214.02 S 75 55 E 4301.13 S 76 II E 4387.82 S 75 58 E 4474.60 S 75 44 E 4561.70 S 75 41 E 4648.79 S 76 45 5 4736.23 1.82 1.43 I .83 0.95 2.21 0.86 0.30 0.98 1.0!5 0.22 0.65 0.15 0.54 0.18 0.51 1.24 0.99 I .05 0.39 1.47 1.53 0.41 0.27 0.50 0.55 0.57 0.45 0.74 0.64 0.75 0.33 0.52 0.52 0.23 2.07 0.31 0.66 0.72 I .31 0.94 392.59 S 1340.01 E 1396.33 S 73 40 E 416.17 S 1421.61 E 1481.27 S 73 41 E 439.11 S 1504.49 E 1567.26 S 73 44 E 459.31 S 1588.10 E 1653.19 S 73 52 E 477.01 S 1672.36 ~ 1739.06 S 74 5 E 492.61 S 1757.11 E 1824.86 S 74 20 E 507.70 S 1842.43 E 1911.10 S 74 36 E ') 522.88 S 1927.74 E -1997.40 S 74 49 E 538.10 S 2012.09 E 2082.80 S 75 2 E 553.35 S 2095.81 E 2167.63 S 75 13 E 5,68.74 S Z179.25 E 2252.25 S 75 22 E 5~4.3Z S 2262.75 E 2336.98 S 75 31 E 600.07 S 2346.16 5 2421.68 S 75 :39 E 615.96 S 2429.42 E 2506.29 S 75 46 E 632.02 S 2512.70 E 2590.96 S 75 53 E 648.26 S 2595.82 E 2675.54 S 75 59 E 664.79 S 2678.24 E 2759.52 S 76 4 E 681.73 S 2760.79 E 2843.72 S 76 8 E 698.79 S Z842.73 E 2927.35 S 76 11 E 715.97 $ 2924.63 E 3010.99 S 7,5 15 E 733.29 S 3006.05 E 3094.20 S 76 17 E 750.85 S 3088.57 E 3178.53 S 76 ZO E 768.77 S 3171.72 E 3263.56 S 76 23 E 787.11 S 3255.32 E 3349.12 S 76 24 E 805.85 S 3339.41 E 3435.25 S 75 26 E 825.12 S 3423.8~ E 3521.90 S 76 27 E 844.85 S 3508.21 E 3608.50 S 76 28 E 864.86 S 3592.30 E 3694.94 S 76 28 E } 885.66 S 3676.09 E 3781.23 S 76 27 E 907.14 S 3759.80 E 3867.6} S 76 26 5 928.67 S 3843.66 E 3954.26 S 75 25 E 950.00 S 39!7.67 E 4040.93 S 76 24 E 971.45 S 4011.66 E 4127.61 S 76 23 E 993.3~ S ~095.77 E ~214.52 S 76 22 E 1015.37 S 4180.05 E 4301.62 S 76 21 ~ 1036.08 S ~264.25 E 4388.32 S 76 21 ~ 1057.03 S 4348.47 E 4475.10 S 76 20 E 1078.16 S 4432.97 E 4552.20 S 76 20 E 1099.86 S 4517.31 E 4649.2~ S 75 19 E 1110.27 S 4602.35 E 4736.73 S 76 19 E CDMPUTATI3N DATE: 30-0EC-90 PAGE 3 ARCO ALASKAt INC. D.S. 9-66 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 22-NOV-90 KELLY BUSHING ELEVATION: 52.00 FT ENGINEER: J. FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SU~-SEA COURSE VERTICAL DOGLEG RECTANGULER C20ROINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN 8000.00 5573.03 5521.03 60 45 8100.00 5622.13 5570.13 60 43 8200.00 5670.11 5618.11 61 52 8300.00 5716.95 5664.95 62 26 8400.00 5763.06 5711.06 62 34 8500.00 5809.64 5757.64 62 9 8600.00 5856.08 5804.08 62 25 8700.00 5902.01 5850.01 62 57 8800.00 5947.23 5895.23 63 4 8900.00 5992.44 5940.44 63 17 9000.00 6038.24 5986.24 62 22 9100.00 6084.59 6032.59 62 33 9200.00 6130.30 6078.30 63 1 9300.00 6176.40 6124.40 62 11 9400.00 6222.94 6170.94 62 27 9500.00 6268.83 6216.83 62 50 9600.00 6314.79 6262.79 62 26 9700.00 6361.28 6309.28 61 31 9800.00 6410.47 6358.47 60 17 9900.00 6459.94 6407.94 60 35 10000.00 6508.94 6456.94 60 47 10100.00 6557.63 6505.63 61 3 10200.00 6605.77 6553.77 61 Zq 10300.00 6653.18 6601.18 61 49 10400.00 6700.82 664B.SZ 60 39 10500.00 6750.7~ 6698.78 59 51 10600.00 6800.89 6748.39 60 11 10700.00 6850.37 6799.37 60 36 10800.00 6899.50 6847.50 60 32 10900.00 6948.62 6896.62 60 33 ~11000.00 6997.73 6945.73 60 45 11100.00 7046.48 6994.48 61 1 11200.00 7094.53 7042.53 61 30 11300.00 7142.82 7090.82 60 27 11400.00 7192.28 7140.28 60 22 11500.00 7241.50 7189.50 60 41 11600.00 7290.46 723~.46 60 40 11700.00 7339.28 7287.28 60 56 11800.00 7387.85 7335.35 61 7 11900.00 7436.13 7384.13 61 13 DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN S 76 6 E 4~23.69 S 75 30 E 4910.80 S 77 5 E 499B.53 S 76 46 E 5086.85 S 76 9 E 5175.57 S 75 33 E 5264.05 S 75 15 E 5352.61 S 75 20 E 5441.44 S 76 24 E 5530.63 S 77 1 E 5619.80 S 77 9 E 5708.66 S 77 7 E 5797.23 S 77 6 E 5886.14 S 77 46 E 5974.83 S 77 20 6 60613.28 S 76 57 E 6152.09 S 77 17 E 6240.86 S 77 28 E 6329.35 S 77 33 E 6416.36 S 77 53 E 6503.20 S 78 16 E 6590.28 S 78 Z¢ E 6677.52 S 78 49 E 6765.05 S 78 51 E 6852.95 S 78 36 E 6940.73 S 78 34 E 7027.23 S 78 27 E 7113.65 S 77 50 E 7200.46 S 77 39 E 7287.49 S 77 47 E 7374.53 S 77 43 E 7461.57 S 77 44 E 7548.81 S 77 29 E 7636.45 S 77 31 E 7723.97 S 77 24 E 7810.83 S 77 5 E 7897.83 S 77 0 ~ 7985.00 S 77 0 E 8072.24 S 76 35 E 8159.53 S 76 27 E 8~47.19 0.97 1.04 1.33 0.55 0.66 0.69 0.36 0.71 1.9~3 1.3'7 0.55 0.68 0.64 0.15 1.08 0.44 0.32 3.23 0.66 1.00 0.25 0.36 0.81 0.53 3.03 0.45 0.69 1.16 0.74 0.70 0.75 0.78 0.50 1.12 0.21 0.~5 0.60 0.50 1.09 0.67 1140.77 S 4687.38 E ,%824.20 S 76 19 E 1162.27 S 477:1.80 E 4911.31 S 76 19 E 1183.27 S 4.856.99 E 4999.04 S 76 18 E 1203.17 S 4943.07 E 5087.39 S 76 19 E 1223.93 S 5029.33 E 5176.12 S 7-6 19 E 12,45.68 S 5115.11 E 5264.60 $ 76 19 E 1268.02 S 5200.81 E 5353.15 S 7.6 18 E 1,290.56 S 5286.72 E 5441.97 S 76 17 E 1312.67 S 5373.13 E 5531.15 S 76 16 E 1332.84 S 5460.02 E 5620.35 S 76 17 E 1352.82 S 554,6.64 E 5709.23 S 76 18 E 1372.54 S 5633.03 E 5797.83 S 76 18 E 1392.52 S 5719.69 E 5886.76 S 76 19 E 1411.75 S 5806.32 E 59'75.48 S 76 20 E 1430.81 S 5892.75 E 5063.97 S 76 Z1 E 1450.62 S 5979.36 E 6152.81 S 75 22 E 1470.44 S 6065.9~ E 6241.62 S 76 22 E 1489.81 S 6152.33 E 6330.14 S 7i5 23 E 1508.68 S 6237.32 i 6417.19 S 76 24 E 1527.15 S ,5322.24 E 6504.07 S 76 25 E 1545.20 S 6407.52 5 6591.21 $ 75 27 e 1562.87 S 6493.06 E 5678.50 S 76 28 1530.35 S 6578.95 E 6766.10 S 75 30 E 1597.51 S 6665.31 E 6854.08 S 76 31 E 1614.62 S 6751.55 E 6941.93 S 75 33 E 1631.82 S 6836.45 E 7028.50 S 76 35 E 1649.03 S 6911.25 E 7114.99 $ 76 36 E 1666.97 $ 7006.23 E 7201.87 S 76 37 E 1685.54 S 7091.38 E ?288.95 S 76 38 E 1704.06 S 7176.50 E 7~76.04 S 76 39 1722.57 S 7261.62 E 7463.13 S 76 39 E 1741.12 S 7346.93 E 7550.42 S 76 40 E 1759.95 S 7432.59 E 7638.11 S 76 41 E 1778.93 S 7518.07 E 7725.67 S 76 41 E 1797.84 S 7602.90 E 7812.5~ S 76 ~2 E 1817.02 S 7687.81 E 7899.62 S 76 42 i 1836.65 S 7772.77 E 7996.81 S 76 42 E 1856.23 S 7857.81 E ~074.08 S 76 43 E 1876.27 S 7942.90 E ~161.50 S 76 43 E 1896.78 S 8028.03 E 8249.07 S 76 42 E COMPUTATION DATE: 30-DEC-g0 PAGE 4. ARCO ALASKA, INC. D.S. 9-46 PRUDHOE BAY NORTH SLOPE, ALASKA 0.ATE OF SURVEf: 22-NOV-90 KELLY BUSHING ELEVATION: 52.00 FT ENGINEER: J. FORMICA INTERPOLATE3 VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL OOGL~G RECTANGULAR COORDINATES HORIZ. OEPARTURE SECTION SEVERITY NORTH/SOUTH E~,ST/WEST OIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 12000.00 746&.01 7432.01 61 31 12100.00 7531.65 7479.65 61 36 12200.00 7578.89 7526.89 62 12~00.00 7625.55 7573.55 62 23 12400.00 7672.69 7620.69 61 20 12500.00 7720.50 7668.50 61 38 12600.00 7767.62 7715.62 61 57 12700.00 7815.01 7763.01 61 6 12800.00 7863.18 7811.18 61 26 12900.00 7910.56 7858.56 62 2 S 76 32 E 8334.97 S 76 11 E 84.22.88 S 76 7 E 8511.02 S 76 10 E 8599.46 S 75 64 E 8687.54 S 75 64. E 8775.47 S 75 48 E 8863.67 S 75 43 E 8951.73 S 75 51 E 9039.36 S 76 2 E 9127.42 0.52 0 0.45 0.26 0.48 0.27 2.08 0.4.3 0.61 1.36 1917.30 S 8113.40 ~ 3336.86 S 76 42 E 1938.03 S 8198.84 E 8424.78 S 76 42 E 1959.17 S 8284.4.1 E 9512.92 S 76 42 E 1980.37 S 8370.27 E 8601.36 S 76 41 E 2001.80 S 8455.82 E ~6~9.54 S 76 ~1 E 2023.47 S 8540.93 E 8777.35 S 76 4.0 E 2045.22 S ~626.42 E 8865.55 S 76 40 E ~ 2066.91 S 8711.76 E 8953.59 S 76 39 E / 2088.~5 S 8796.70 E 9041.21 S 76 39 E 2109.83 S 8882.13 E 9129.27 S 76 38 E 13000.00 7957.Z0 7905.20 62 19 13100.00 8003.24 7951.24 62 52 13200.00 8068.54 7996.56 63 23 13300.00 8092.81 B040. ,':J1 64 2 13600.00 8136.58 8084.58 63 26 13500.00 8183.81 8131.81 60 4.8 13600.00 8232.30 8180.30 61 18 13700.00 8279.87 8227.87 61 52 13800.00 8326.73 8276.73 62 16 13900.00 8373.4.5 8321.45 62 6 S 76 7 E 9215..87 S 76 18 E 9306.63 S 76 30 E 9393.78 S 76 39 E 9683.43 S 76 28 E 9573.32 S 76 6 E 966.1.4.4 S 76 10 E 9748.90 S 76 14, E 9836.{35 S 76 21 E 9925.18 S 76 38 E 10013.59 0.59 0.50 0.6O 0.72 3.17 1.29 0.61 0.28 0.32 1 2131.09 S 8967.99 E 9217.72 S 76 38 E 2152.29 S 9054.19 E 9306.49 S 76 38 E 2173.28 S 9140.8?, E 9395.64 S 76 38 E 2194.15 S 9228.04 E 94.85.31 S 76 38 E 2215.01 $ 9315.50 E 9575.22 S 76 37 E 2235.92 S 9401.11 E 9663.35 S 76 37 E 2256.88 S 9436.03 E :?)750.80 S 76 37 E 2277.85 S 9571.45 E 9838.76 S 76 37 E 2298.77 S 9657.2~ E 9927.10 S 76 37 E 2319.52 S 9743.22 510015.52 S 76 37 E 1¢000.00 8420.34 8368.34 62 1¢ 14100.00 8467.47 8415.47 61 48 14200.00 8515.22 8463.22 61 17 16300.00 8563.79 8511.79 60 36 14¢00.00 8613.72 8561.72. 59 2 16500.00 8665.2') 8613.29 58 32 14600.00 8717.43 8665.43 58 6 14700.00 8770.54 871B.54 57 31 14800.00 8824.53 8772.53 57 Z 14900.00 BBTg.lg 8827.19 56 32 S 76 13 E 10101.90 S 75 4,2 E 10190.09 S 75 25 E 10277.96 S 75 I E 10365.37 S 74 50 E 10452.00 S 74 ~0 E 10537.67 S 74 16 E 10622.99 S 72 51 E 10707.67 S 71 47 E 10791.70 S 70 52 E 10876.23 0.92 0.27 0 0.72 4.0!3 1.B1 3 2.81 1.34 1.48 2340.35 S 9829.05 ElO103.84 S 76 36 E 2361.95 S 9914.55 E10192.03 S 76 36 E 2383.85 S 9999.66 E10279.88 S 76 35 E 2406.06 S10094.20 E10367.26 S 76 35 E 2428.61 S10167.85 E104,53.87 S 76 34 E 2451.35 S10250.46 510.539.50 S 76 33 E 2474,.23 S10332.66 E10624.77 S 76 32 E 2498.23 S10413.92 E10709.3~ S 76 31 E ') 2523.97 S10494.06 510793.32 S 76 29 E 2550.65 S10573.47-,, E10876.74 S 76 26 E ..,15000.00 8934.57 8682.57 56 33 15100.00 89EJ9.28 8937.28 56 44 15200.00 9064.36 8992.36 56 27 15300.00 9099.63 9047.53 56 27 15371.00 9138.88 9086.~8 56 27 S 72 4, E 1095~3.26 S 71 7 E 1104,1.74 S 71 2 E 1112~.99 S T1 Z E 11208.07 S 71 Z E 11267.05 2.84 1.32 0.00 0.00 0.00 2577.37 S10652.28 E10959.65 S 76 Z4 2604.22 510731.57 El1043.03 S 76 22 2631.33 S10810.54 E11126.17 S 76 19 E 2658.43 S10889.34. EllZO9.15 S 76 17 E 2677.67 510945.29 EllZ6B.O7 S 76 15 E COMPUTATION DATE: 30-DEC-90 PAGE 5 ARCO ALASKA, INC. O.S. 9-~6 PRUDHOE BAY NORTH SLOPE, aLASKA TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICal DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN D4TE OF SURVEY: Z2~NOV-90 KELLY ~USHING ELEVATION: 52.00 FT , ENGINEER: J. FORMICA INTERPDLATED VALUES FOR EVEN 1000 FEET OF MEASURED 9EPTH VERTICAL OOGLEG RECTANGUL;RR C~ORDiNA'TES HgRIZ. DEPARTURE' SECTION SEVERI'TY NORTH/SOUTH E*ST/WEST DIST. AZIMUTH FEET DEG/[O0 FEET FEET FEET gEG MIN 0o00 0.00 -52.00 0 0 1000.00 999.33 947.33 4 26 ZO00.O0 1981.23 1929.23 17 18 3000.00 2871.85 2819.35 37 57 4000.00 3519.33 3467.33 57 25 5000.00 4032.50 3980.50 58 5 6000.00 ~570.24 4518.24 56 43 7000.00 50~0.00 5028.00 60 1 8000.00 5573.03 5521.03 60 45 9000°00 6038.24 5986. Z4 62 22 10000.00 6508.94 6456.94 60 47 11000.00 6997.73 6945.73 60 45 12000200 7484.01 7432.01 61 31 13000.00 7957.20 7905.20 62 19 14000.00 8420.34 8368.34 62 14 15000.00 8934.57 8882.57 56 33 15371.00 9138.88 9086°88 56 27 N 0 0 E 0.00 S 80 g ~ S 69 32 E 19).09 S 75 40 E 640.34 S 73 21 E 1395.64 S 79 31 E 2252.24 S 78 0 E 3093.89 S 75 49 E 3953.73 S 76 6 E 4823.69 S 77 9 E 5708.66 0.00 0 1.65 3.71 1.82 0.65 1.53 0.33 0.97 0.55 0.00 N 0.00 E 0.00 N 0 0 E 2.21 S 25.12 E 25.21 S 84 58 E 35.65 S 196.43 E 199.64 S 79 43 E 154.94 S 621.34 E 6~0.37 S 76 0 E 392.59 S 1340.01 E 1396.33 S 73 40 E 568.7.4 S 2179.25 : 2252.25 S 75 22 E h 733.29 S 3006.05 3094.20 S 76 17 E ) 928.67 S 3B~3.65 E 3954.26 S 76 25 E 1140.77 S 4687.33 E 4.824.20 S 76 19 E 1352.82 S 5546.64 E 5709.23 S 76 18 E S 78 14 E 6590.28 'S 77 43 E 7461.57 $ 76 3Z E 8334.97 S 76 7 ~ 9215.87 S ?6 1l E 10101.90 S 7Z 4 E 10958.26 S 71 Z E 11267.05 0.25 0.75 0.52 0.59 0.92 2.84 0.00 1545.20 S 6407.52 E 6591.21 S 76 27 E 1722.57 S 7261.62 E 7463.13 S 76 39 E 1917.30 S 8113.40 E 8336.86 S T6 42 E 2131.09 S ~967.99 E 9217.72 S 76 38 E 2340.35 S 9829.05 E10103.84 S 76 36 E 2577.37 510652.28 E10959.65 S 76 24 E 2677.67 S10945.29 EllZ6B.OT S 76 15 E COMPUTATION D~TE: 30-DEC-90 P~GE 6 ARCO ALASKA, [NC. D.S. 9-66 PRUDHOE BAY NORTH SLOPE, ALASKA DATE gF SURVEY: 22-NOV-90 KELLY BUSHING ELEVATION: 52.00 FT ENGINEER: J. FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTIC=~L DEVIATIDN AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG M'IN VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/JO0 FEET FEET FEET DEG MIN 0.00 0.00 -5Z. O0 0 0 N 0 0 E 52.00 52.00 0.00 0 9 S 86 14 E 152.00 152.00 lOO.O0 0 7 S 67 46 W 252.00 252.00 200°00 0 6 N 51 39 E 352.00 352.00 300.00 0 13 S 33 39 E 452.00 452.00 400.00 0 27 N 93 41 E 552.02 552.00 500.00 1 18 S 87 26 6 652.06 652.00 600.00 2 10 S 88 5~ E 752.16 752.00 700.00 2 40 S ~8 50 E 952.30 852.00 800.00 3 33 S 85 12 E 0.00 0.00 0.00 N 0.00 E 0.01 0.00 0.00 S 0.0t E 0.08 0.39 0°05 N 0.10 E 0.17 0.72 0.17 S 0.13 E 0.17 0.57 0.35 S 0.08 E 0.44 1.71 0.38 S 0.35 E 2.13 0.6,3 0.35 S 2.11 E 5.10 0.76 0.50 S 5.14 E 9.23 0.78 0.55 S 9.39 E 14.57 0.7.5 0.86 S 14.83 E 0.00 N 0 0 E 0.01 S 85 10 E 0.11 N 63 40 E 0.22 S 38 15 E 0.35 S 13 30 E 0.52 S 43 28 E 2.14 S 80 36 E 5.17 S 84 24 E 9.41 S 86 41 E 14.85 S 86 42 E 952.54 952.00 900.00 4 10 1052.84 1052.00 lO00. O0 4 46 1153.25 1152.00 1100.00 5 39 1253.82 1252.00 1200.00 6 34 1354.58 1352.00 1300.00 7 30 1455.56 1452.00 1400.00 8 37 1556.92 1552.00 1500.00 10 5 1658.76 1652.00 1600.00 11 55 1761.45 1752.00 1'700.00 14 20 1865.10 1852.00 1800.00 15 58 S 81 52 E 21.33 0.37 S 78 38 E 29.11 0.54 S 61 15 E 38.16 0.96 S 85 36 E 48.72 0.79 S 84 8 E 60.87 0.96 S 83 51 E 74.76 1.53 S 84 39 E 91.10 1.07 S 82 43 E 110.12 1.84 S 78 7 E 133.34 2.47 S 73 7 E 160.5E 1.76 1.66 S 21.61 E 21.67 S 85 37 E 3.01 S 29.29 E 29.44 S 84 8 E 4.66 S 30.21 E 38.49 S 83 3 E 5.83 S 48.81 E 49.16 S 83 12 E 6.88 S 61.09 E 61.48 S 83 35 E 8.41 S 75.05 E 75.52 S 83 36 E 10.03 S 91.51 E DZ.06 S 83 45 E 12.10 S 110.62 E 111.28 S 83 45 E 15.85 S 133.63 E 134.57 S 83 14 E 22.73 S 159.95 E 161.57 S 81 55 E 1969.41 1952.00 1900.00 17 0 2074.38 2052.00 2000.00 18 34 2180.38 2152.00 2100.00 ZO 0 2287.14 2252.00 2200.00 21 5 2394.88 2352.00 2300.00 22 40 2504.36 2452.00 2400.00 25 32 2616.72 2552.00 2500.00 28 56 2732.61 2652.00 2600.00 31 25 2851.61 2752.00 2700.00 34 27 2974.96 2852.00 2800.00 37 11 S 69 26 E S 69 51 : s s9 s7 S 72 19 5 S 75 21 F S 76 36 E S 75 56 E S 74 42 E 75 33 75 190.13 0.55 221.88 1.44 256.83 0.86 294.09 1.76 334.15 1.91 378.69 2.59 429.87 3.36 488.41 1.36 552.88 2.53 625.07 2.52 32.49 S 187.99 E 190.77 S 80 12 E 43.58 S 217.92 E 222.23 S 78 42 E 55.80 S 250.85 E 256.98 S 77 28 E 68.09 S 266.16 5 294.15 S 76 37 E 79.17 S 324.67 E 334.19 S 76 18 E 89.74 S 367.95 E 378.73 S 76 18 E 101.83 S 417.68 E 429.92 S 75 18 E 116.7~ S 4]'4.29 E 488.45 S 76 10 E ,,) 133.4~ S 536.55 E 552.91 S 76 2 E 151.19 S 606.54 E 625.10 S 76 0 E 3105.00 2952.00 2900.00 42 31 3245.18 3052.00 3000.00 46 3393.43 3152.00 3100.00 48 32 3546.86 3252.00 3200.00 50 2 3705.55 3352.00 3300.00 52 38 3877.96 3452.00 3400.00 55 44 4061.45 3552.00 3500.00 58 18 4256.74 3652.00 3500.00 59 17 4453.09 3752.00 3700.00 59 28 4652.88 3852.00 3800.00 60 7 S 73 41 E 708.12 S 72 34 E 806.22 S 71 4 E 915.41 S 70 33 E 1031.~9 S TO 0 E 1154.05 S 71 49 5 1293.98 S 74 3 E 1447.56 S 76 4t E 1615.38 S 79 44 ~ 1784.13 S 79 55 E 1956.58 3.87 2.41 1.10 0.87 3.78 1.74 1.72 2.47 1.16 0.45 172.85 S 686.71 E 708.13 S 75 52 E 201.46 S 780.64 E 906.22 S 75 32 E 235.82 S 8.34.54 E 915.43 S 75 ~+ E 273.97 S 9'94.45 E 1031.51 S 74 36 E 315.86 S 1110.33 E 1154.3.6 S 74 7 E 362.16 S 12~2.85 E 1294.57 S 73 45 E 407.22 S 1389.96 E 1448.35 S 73 40 E 451.08 S 1551.85 E 1616.03 S 73 48 E 485.47 S 1717.26 E 17~34.57 S 7~ 13 E 515.70 S 1887.:57 E 1956.75 S 74 43 E COMPUTATION DATE: 30-DEC-90 PAGE ? ARCO ALASKA, INC. D.S. 9-46 PRUOHDE BAY NORTH SLOPEs ALASKA DATE OF SURVEY: 22-Nov-90 KELLY BUSHING ELEVATION: 52.00 FT ENGINEER: J. FORMICA INTERPOLATED VALUES FOR EVEN 100 PEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH OFPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG REC~TANGUL~R COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. ~ZIMUTH FEET OEG/IO0 FEET ~EET FEET OEG MIN 4847.63 3952.00 3900.00 58 26 5036.91 4052.00 4000.00 58 8 5226.14 4152.00 4100.00 57 57 5414.76 4252.00 4200.00 58 1 5600.91 4352.00 4300.00 57 18 5785.23 4452.00 4400.00 56 51 5966.96 4552.00 4500.00 56 17 6153.27 4652.00 4600.00 58 13 6346.60 4752.00 4700.00 59 25 6546.46 4852.00 4800.00 60 3 S 79 42 E 2123.20 S 79 28 E 228,3.50 S 79 14 E 2443.79 S 79 3 E 2603.39 S 78 30 E 2760.14 S 78 14 E 291¢.78 S 77 59 E 3366.37 S 77 49 E 3223.40 S 77 27 E 3388.74 S 76 4~ E 3561.71 1.62 0.58 1.04 0 1.03 0 1 .§1 0.76 0.61 1.45 545.34 S 2052.01 ~ 2123.24 S 75 7 E 574.46 S 2210.06 E 2283.50 S 75 26 E 604.21 S 2]367.94 E 2443.81 S 75 41 E 634.39 S 2524.93 5 ~603.46 S 75 54 E 664.94 S 2678.99 E 2'760.28 S 76 4 E 696.25 S 2830.6.2 E 2914.99 S 76 11 E 727.56 S 2979.10 E 3066.66 S 76 17 a ) 760.34 S 31.'32.83 E 3223.77 S 76 21 E 795.79 S 3294.44 E 3389.19 S 76 25 E 834.28 S 3463.15 E 3562.22 S 76 27 E 6745.42 4952.00 4900.00 59 42 6944.02 5052.09 5000.00 59 59 7144.32 5152.00 5100.00 60 4 7346.49 5252.00 5200.00 60 42 7547.95 5352.00 5300.00 60 9 7751.05 5452.00 5400.00 60 30 7956.79 5552.00 5500.00 61 1 8161.81 5652.00 5600.00 61 31 8375.97 5752.00 5700.00 62 37 8591.19 5852.00 5800.00 62 25 S 76 6 E 3733.68 S 75 33 E 3905.26 S 75 43 E 4078.81 S 75 15 E 4254.51 S 76 1 E 4429.40 S 75 3.9 E 4606.17 S 76 27 E 4785.94 S 76 21 E 4964.91 S 76 18 E 5154.24 S '75 1 8 E 5344. al 1.37 0 0.5'7 0.80 0.59 1.05 I .17 2.77 0.62 0.37 8'74.19 S 3630.46 E 3734.22 S 76 28 E 916.70 S 3796.69 E 3905.79 S 76 ~_6 E 959.51 S 3964.88 E 4079.33 S 76 24 E 1003.73 S 4134.9.2 E 4255.00 S 76 Z1 E 1046.06 S 4304.62 E 4429.90 S 76 ZO E 1089.24 S 4476.04 E 4606.66 S 76 19 E 1131.80 S 4650.72 E 4786.46 S 76 19 E 1175.55 S 4824.25 E ,~965.42 S 76 18 E 1218.85 S 5008.62 E 5154.79 S 76 19 E 1266.04 S 5193.25 E 5345.35 S 76 18 E 8810.54 5952.00 5900.00 62 59 9029.66 6052.00 6000.00 62 20 9247.54 6152.00 6100.00 62 32 9463.18 6252.00 6200.00 62 45 9680.36 6352.00 6300.00 62 4 9883.87 6452.00 6400.00 60 28 10088.38 6552.00 6500.00 61 0 10297.49 6652.00 6600.00 61 49 10502.42 6752.00 6'700.00 59 50 10703.33 6852.00 6800.00 60 38 S 76 38 E 5540.03 S 77 9 E 573~.92 S 77 30 E 5928.42 S 77 4 E 6119.35 S 'T7 25 E 6312.05 S 77 50 E 6489.17 S 78 23 5 6667.37 S 78 51 E 6850.75 S 78 34 E 7029.32 S 77 49 E 7203.35 I .31 0.39 2.63 0.66 2.51 0.96 0.61 0.52 0.53 1.29 1314.88 S 5382.26 E 5540.55 S 76 16 E 1358.66 S 5572.25 E 5735.50 S 76 18 E 1401.84 S 5760.95 E 5929.06 S 75 19 E 1443.26 S 5947.46 E 6120.07 S 76 22 E 1486.04 S 6135.43 E 6312.83 S 76 23 E 1524.19 S 6308.51 E 6490.03 S 76 25 E 1560.83 S 6483.10 E 66,68.34 S 76 28 E 1597.08 S 6663.14 E 6851.87 S 76 31 E 1632.24 S 6838.50 E 7030.53 S 76 35 E 1667.58 S 7009.12 E 7294.76 S 75 37 E ~10906.87 6952.00 6900.00 60 32 11111.39 7052.00 7000.00 61 4 11318.59 7152.00 7100.00 60 19 11521.43 7252.00 7200.00 60 40 11726.17 7352.00 7300.00 60 54 11933.02 7452.00 7400.00 61 20 12142.92 7552.00 7500.00 61 47 12356.60 7652.00 7600.00 61 46 12566.77 7752.00 7700.00 62 1 12776.67 7852.00 7800.00 61 19 S 77 47 E 7380.50 S 77 43 E 7558.77 S 77 30 E 7740.12 S 77 3 E 7916.51 S 76 52 E 8095.10 S 76 30 E 8276.14 S 76 3 E 8460.66 S 75 5~ E 8649.~0 S 75 46 E 8834.34 S 75 50 E 9018.88 0.53 0.47 0.63 0.27 0.53 0.34 0.41 1.77 1.35 0.43 1705.32 S 7182.3~+ E 7382.01 S 76 39 E 1743.24 S 7356.67 5 7560.33 S 76 40 E 1782.43 S 7533.$5 E 7741.83 S 76 41 E 1821.21 S 7706.01 E 7918.30 S 76 42 E 1861.40 S 7880.09 E 8096.95 S 76 43 E 1903.55 $ 8056.19 E 8278.02 S 76 ~+2 E 1947.08 S 8235.52 E ~462.56 S 76 42 E 1992.44 S ~418.84 E 8651.~+0 S 76 ~1 E 2038.01 S 8597.95 E 8836.22 S 76 40 f 2083.64 S 8776.84 E 9020.76 S 76 39 E COMPUTATION DATE: 30-DEC-90 PAGE 8 ARCO ALASKA, INC. D.S. 9-46 PRUDHOE BAY NORTH SLOPE~ ALASKA DATE OF SURVEYt ZZ-NOV-90 KELLY BUSHING ELEVATION: 52.00 FT ENGINi~ER: J. FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTIC*L DOGLEG RECTANGULAR COORDINATES HDRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 12988.80 7952.00 7900.00 62 16 13Z07.73 8052.00 8000.00 63 25 13433.73 8152.00 8100.00 62 11 13641.21 3252.00 8200.00 61 32 13854.16 8352.00 8300.00 62 4 14067.30 8452.0g 8400.00 61 43 14275.93 g552.00 8500.00 60 44 14474.45 B652.00 8600.00 58 54 14665.27 ~752.00 8700.00 57 47 14850.~1 8852.00 8800.00 56 57 S 76 6 E 9205.96 S 76 31 E 9400.69 S 76 21 E 9603.32 S 76 13 E 9785.09 S 76 26 E 9973.08 S 75 42 E 10161.28 S 75 10 E 10344.38 S 74 29 E 10515.36 S 73 18 E 10678.33 S 71 33 E 1083.3.B7 0.54 4.30 0.35 1.03 0.45 0.89 1.92 2.61 1.17 2128.71 S 8958.37 E g207.81 S 76 38 E 2174.89 S 9147.57 E 9402.56 S 76 38 E 2222.06 S 9344.65 E 9605.22 S 76 37 E 2265.53 S 9521.18 E 9787°00 S 76 37 E 2310.09 $ 9703.83 E 9975.01 S 76 37 E 2354.8.3 S 9886.65 E10163.22 S 76 36 E 2400.66 S10063.92 E10346.28 S 76 35 E 2445.56 S10229.42 E10517.69 S 76 33 E 2489.68 S10355.83 610680.07 S 76 31 E 2537.29 S10534.17 E10835.43 S 76 27 E 15031.80 8952.00 89'00.00 56 56 15213.83 9052.00 9000.00 56 27 15371.00 9138.88 9086. B8 56 27 S 71 17 E 10984.80 S 71 2 E 11136.48 S 71 Z E 11267.05 2.21 0.00 0.00 2535.71 S10677.54 E10986.16 S 76 23 E 2635.07 S10821.44 611137.65 S 76 19 E 2677.67 S10965.29 El1268.07 S 76 15 E ARCO ALASKA~ INC. D.S. 9-&.6 PRUDHOE BAY NORTH SLOPE, ALASKA MARKER 13 3/8" CASING TOP 7# CASING 9 5/8" CASING TOP SAD ZONE 2 ZONE lB LAST GCT READING BASE SAD PBTD BOTTOM 7" CASING TO COMPUTATION DATE: 30-DEC-90 PAGE 9 DATE OF SURVEY: Z2-NOV-90 KELLY BUSHING ELEVATION: 5Z.O0 FT ENGINEER: J. FORMICA INTERPOLATEO VALUES FOR CHOSEN HORIZONS SURFACE LOCATION : 935' FSL & [62 FWL, SEC1 TION R15E, UM MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA 4551.00 380[°20 3749.20 14626.00 8731.20 8679.20 14954.00 8909.00 8857.00 15035.00 8953.75 8901.75 15035.00 8953.75 8901.75 15127.00 9004.10 8952.10 15192.00 9039.95 8987.95 15220.00 9055.41 9003.41 15278.00 908'7.47 9035.47 15369.00 9137.77 9085.77 15371.00 9133.88 9086.88 RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 500.32 $ 1800.61 E 2480.29 S 10353.87 E 2565.45 S 10615.95 E 2586.58 S 10680.08 E 2586.58 S 10680°08 E 2611.52 S 10752.92 E 2529.14 S 10804.20 E 2635.75 S 10826.30 E 2652.47 S 10~7Z.01 E 2677.13 S 109¢3.72 E 2677.57 S 10945.29 E ARCO ALASKA~ 1NCo DoSo 9-46 PRUDHOE BAY NORTH SLOPE~ ALASKA MARKER p3/8" CASING 7" CASING 9 5/Be CASING TOP SAD ZONE Z ZONE tB LAST GCT READING BASE SAO PSTD BOTTOM '?" CASING TD COMPUTATION DATE: SURFACE MEASURED DEOTH BELOW KB 4551.00 1¢626.00 1495¢.00 15035.00 15035.03 15127.00 15192.00 15220.00 15278°00 15369.00 15371.00 30-DEC-g0 SUMMARY LOCATION KELLY : 935e FSL & 162 TVO FROM KB 3801.20 8731.20 8909.00 8953.75 8953.75 9004.10 9039.95 9055.41 9087.47 9137.77 913B.88 SUB-SEA 3749.20 8679.20 8857.00 8901.75 8901.75 8952.10 8987.95 9003.41 9035.47 9085.77 9086.88 PAGE 10 DATE OF SURVEY: BUSHIN~ ELEVATION: ENGINEER: Z2~NOV -90 52. O0 FT J. F3RMICA FWL, SEC1 T1 RECTANGULA NORTH/SOU 500.32 2480.29 2565.45. 2586.58 2586.58 2611.52 2629.14 2636.75 2652.47 2677.13 2677.$7 ON R15E, UM R COORDINATES TH EaST/WEST S 1800.61 E S 10353.87 E S 10615.95 E S 10680.08 E S 10680.08 E $ 10752.92 E S 1080~.Z0 E S 10826.30 E S 10872.01 E S 10943.72 E S 10945.29 E FINAL MEASURED DEPTH 15371.00 WELL LOCATION TRUE 'VERTICAL DEPTH 913B.88 ~.T TO: SUB-SEA VERTICAL DEPTH g086.88 HORIZONTAL DEPARTURE DISTANCE AZIMUTH ~EET DEG MIN llZ6B.O? S 76 15 E SCHLUMBERGER D I RECT I ONAL SURVEY COMPANY ARCO ALASKA, INC. WELL O.S. 9-48 FI ELD PRUOHOE BAY COUNTRY USA RUN ONE OATE LOOOED 22 - NOV - 90 REFERENCE ?4260 WELL: D.S. 9-46 ~---~ (935~' FSL, 162' FWL, SEC i /1ON, R15E, UM) HORIZONTAL PROJECTION SCIN..E · I/L~::X~ IN/FT 4000 ~UTH -8000 O 2000 4000 6,000 BO00 10000 12000 14000 ERST WELL' D.S. 9-46 VERTICAL PROJECTION 4000 ___rOt'lO___ 8000 ...... 10000 1 ~ 14000 i;~ T ~ ~ ~; ~' '~~-~' ..... ++?+"i-~"t''s'''$''' "?'~"?'+-~-~'~;'""q'?'~'~-'"'~'";" ~"+" : s ~ : ~ , : ~ ~ ~ - f; l~ ~'~--*~--~- ~-~-~--~+-~r.+-m'--~-~-~-+-~-~- ~-? 'T~ ~ ~ :'~'T~ ~ ~ ~ ~-~'~"~'--~'~-~'-~' ~ ~ ~ '~'~-?"~t~ ] i ~ ~ , ~ ~ ,lit ~ ~ I ; ' .... ~~ {~ ' ' ' ; , , , ' : ; ! : I : I~ · · :I ! , : , : : , ~ - · ; i : ~ ~ ~ : : · ~ i · : i:f4~~' ~ ~ ~ i i i i4 ~-~-4-~---~+.~--. · ~.+- .~-~.-+--~.-~ 5..~-~-~... ! ~ ~ ! ! ! ~ &.~J~.-~..i-~--~.-~.4 .... ~..4-~-.-~-i-.4..~4~4..~ -~.4--~i..-~..-C.-~4..~---i-~.~4-: ! L~.-.~.C.~ ! ! ;~-~.4-~.i-4.4.4..~.4 ...... ~..4...;...* ..... ~.-i..4..4 .... g4...; ....... ,...; ....... ~...i... ? ~ Y~ ~ ~ ~ ~ ' ~ ~-~" -T'~'77" 'T"~'"T"T" "T"t'? ~ / ~ ? ? T ' ~ ~ ~ ~ 7 ? ~ t i i ; ~ i i i : : ; ; : : ~ : ; ' -::' :' : ' ; ; ' ' : · i : : : i : ; : : : : ;/ : ; ; ~1~ : ~ ~ : : : ~~ ~ ; ( } i - i } i i i i f ~ ~! I t ~'~'~'"*"~-'?" "~'"T'":'"*"I'"?'"?'"?"'"'---~-t-r-?'~--t--'T---~'r- ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~l ~ ~'"T"rwr-?'";"TT .......... 7"7'T'T"77"w-~ ...... ~'-' ....... :"i ....... 7': -~ ...... ~ ......~ .................................................................. 1 ................................. , ................... i i i i ] i i ii i i i i I i ~_f i_. ; i~. :.~_.._...5..: ..... :...!......(..J ...... '...:...! ...... :-¢...;..--.1...~ ...... i...:.. ~ ~ ~ .~J.~~ .................. ; ................................ 1 .......... ; ...................... t ............... ~:T~i ~ ~ ~i I - ~'7~7'~ .... 77~'T'7"7"7"7'""T"; ........,'"':'"7'7": .... "-: ...... 5'I ....... 7':'7" m -i ..q PROOECTION ON VERTIClqL. PL~IE 105. - 2EL.~. SCALED IN VERTICPL. C~PTI~ HORIZ SCALE = 1/2000 IN/FT COl Teleco Oilfieid ~Secvices Inc. TELE 6116 Nielson w A nchorage, AK 99518 (907) 562-2646 0 t{ Iblrl /", L November 15, 1990 JOB #783 ARCO ALASKA, INC. WELL: DS-9-46 PRUDHOE BAY RIG: NABORS 28-E Attached please find a copy of the computer calculated MWD directional surveys for the above mentioned well. Teleco appreciates this opportunity to provide service to ARCO Alaska Inc. Teleco is committed to providing the highest quality MWD Service and we would welcome any comments or questions concerning these surveys or any of our other services. Sincerely, Jonathan Field Operations Supervisor JGM/el Enclosures A SrCNAT COMPANY Company- Arco Alaska Inc. Well' DS9-46 Location- Prudhoe Bay Rig' Nabors 28E TELECO OILFIELD SERVICES SURVEY CALCULATIONS Date 10/31/90 ,~,~ TELECO Job # Grid Correction: Magnetic Declination: Total grid correction: ~ Proposed Direction: 783tak 0.0° 30.8~ 30.8° 104.5° MINIMUM CURVATURE CALCULATION Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100' Tie in Coordinates 445 0 0.0 0.0 445.00 0.01 0.01N 0.01E 0.01 N 45.00E 0.00 Teleco Behind 2 degree ~,,~!~nt. Sub 597 152 1.5 71.9 596.98 1.68 0.64N 1.90E 2.01 N 71.36E 0.98 778 181 3.6 92.3 777.80 9.23 1.15N 9.83E 9.90 N 83.33E 1.25 959 181 4.7 96.9 958.32 22.14 0.03N 22.87E 22.87 N 89.92E 0.63 1148 189 6.3 99.7 1146.44 40.15 2.65S 40.78E 40.87 S 86.29E 0.86 PAGE 1 Company' Arco Alaska Inc., Well: DS9-46, Location' Prudhoe Bay, Riq: Nabors 28E Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity' feet feet deg deg feet feet feet feet feet deg deg/lO0' 1336 188 7.6 98.3 1333.06 62.78 6.18S 63.25E 63.55 S 84.42E 0.70 1527 191 9.4 .93.4 1521.96 90.65 8.93S 91.32E 91.76 s 84.42E 1.02 1715 188 13.1 98.3 1706.31 126.91 12.92S 127.74E 128.40 S 84.23E 2.03 1904 189 16.2 105.7 1889.16 174.58 23.15S 174.34E 175.87 S 82.44E 1.91 2093 189 18.5 108.1 2069.55 230.87 39.60S 228.23E 231.64 S 80.16E 1.27 2281 188 20.7 106.7 2246.65 293.85 58.41S 288.41E 294.27 S 78.55E 1.20 Teleco Behind Steerable Motor 2471 190 24.7 102.5 2421.91 367.11 76.67S 359.36E 367.45 S 77.96E 2.27 2660 189 30.1 104.3 2589.65 454.03 96.93S 443.90E 454.36 S 77.68E 2.89 2847 187 34.7 105.0 2747.50 554.21 122.31S 540.81E 554.47 S 77.26E 2.47 3035 ' 188 39.6 104.3 2897.30 667.70 150.97S 650.63E 667.91 S 76.94E 2.62 3225 190 45.9 106.4 3036.76 796.58 185.23S 774.88E 796.71 S 76.56E 3.40 3413 188 48.8 107.4 3164.12 934.71 225.45S 907.16E 934.76 S 76.04E 1.59 3603 190 50.2 108.8 3287.51 1078.89 270.35S 1044.47E 1078.89 S 75.49E 0.93 3788 185 54.8 108.5 3400.10 1225.24 317.26S 1183.50E 1225.29 S 74.99E 2.49 PAGE 2 Company' Arco Alaska Inc., Well- DS9-46, Location- Prudhoe Bay, Riq' Nabors 28E Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/lO0' 3974 186 57.0 106.7 3504.38 1379.02 363.79S 1330.30E 1379.15 S 74.71E 1.43 4162 188 59.6 105.0 3603.17 1538.90 407.44S 1484.16E 1539.07 S 74.65E 1.58 4350 188 59.5 101.8 3698.46 1700.91 444.99S 1641.79E 1701.03 S 74.83E 1.47 4495 145 59.9 99.7 3771.62 1825.82 468.34S 1764.77E 1825.86 S 75.14E 1.28 4700 205 60.0 101.1 3874.28 2002.81 500.37S 1939.30E 2002.81 S 75.53E 0.59 4888 188 58.2 100.8 3970.82 2163.81 531.02S 2097.67E 2163.84 S 75.79E 0.97 5202 314 58.2 100.8 4136.29 2430.12 581.02S 2359.81E 2430.28 S 76.17E 0.00 5518 316 57.9 102.2 4303.52 2697.87 634.47S 2622.54E 2698.20 S 76.40E 0.39 5737 219 57.0 102.2 4421.34 2882.32 673.48S 2802.97E 2882.75 S 76.49E 0.41 5926 189 56.8 102.2 4524.56 3040.52 706.94S 2957.73E 3041.04 S 76.56E 0.11 6084 158 57.8 103.2 4609.92 3173.41 736.18S 3087.43E 3173.98 S 76.59E 0.83 6270 186 59.1 102.9 4707.24 3331.86 771.96S 3241.84E 3332.48 S 76.61E 0.71 6491 221 60.2 103.9 4818.90 3522.53 816.17S 3427.35E 3523.19 S 76.61E 0.63 PAGE 3 Company: Arco Alaska inc~, Well: DS9-46, Location: Prudhoe Bay, Riq: Nabors 28E Meas Course True Vertical Coordinates Closure Dog Leg. Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100' ******************************************************************************************************* 6711 220 59.9 103.6 4928.74 3713.14 861.48S 3612.51E 3713.81 S 76.59E 0.18 6869 158 59.4 107.1 5008.59 3849.44 897.55S 3743.96E 3850.05 S 76.52E 1.94 7056 187 60.2 105.0 5102.66 4010.98 942.22S 3899.27E 4011.49 S 76.42E 1.06 7275 219 60.6 105.3 5210.84 4201.39 991.99S 4083.07E 4201.84 S 76.34E 0.22 7557 282 60.4 103.6 5349.71 4446.81 1053.23S 4320.73E 4447.25 S 76.30E 0.53 7716 159 60.9 103.6 5427.64 4585.39 1085.82S 4455.44E 4585.84 S 76.30E 0.31 8030 314 60.5 105.7 5581.32 4859.19 1155.06S 4720.34E 4859.61 S 76.25E 0.60 8345 315 62.8 104.6 5730.89 5136.37 1227.48S 4987.91E 5136.73 S 76.17E 0.79 8657 312 62.8 105.7 5873.51 5413.85 1300.00S 5255.76E 5414.15 S 76.11E 0.31 9001 344 62.2 103.9 6032.36 5718.95 1377.95S 5550.75E 5719.22 S 76.06E 0.50 9317 316 62.2 103.9 6179.74 5998.46 1445.10S 5822.09E 5998.75 S 76.06E 0.00 9603 286 62.5 104.6 6312.46 6251.80 1507.46S 6067.63E 6252.09 S 76.05E 0.24 9917 314 60.4 105.3 6462.53 6527.59 1578.60S 6334.10E 6527.84 S 76.01E 0.70 PAGE 4 Company' Arco Alaska Inc., Well' DS9-46, Location' Prudhoe Bay, .Riq: Nabors 28E Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100~ ii..0233 316 61.7 103.6 6615.49 6804.09 1647.57S 6601.85E 6804.33 S 75.99E 0.63 10553 320 60.1 102.9 6771.11 7083.62 1711.66S 6874.00E 7083.90 S 76.02E 0.54 10865 312 60.6 104.6 6925.47 7354.72 1776.12S 7137.36E 7355.03 S 76.03E 0.50 ~.1180 315 61.6 105.0 7077.70 7630.49 1846.56S 7403.98E 7630.77 S 76.00E 0.34 11463 283 60.6 104.6 7214.47 7878.24 1909.86S 7643.51E 7878.50 S 75.97E 0.37 7_1775 312 60.7 106.0 7367.40 8150.15 1981.61S 7905.81E 8150.38 S 75.93E 0.39 ~_2092 317 61.6 105.0 7520.36 8427.76 2055.80S 8173.36E 8427.94 S 75.88E 0.40 12406 314 61.3 105.7 7670.43 8703.54 2128.81S 8439.34E 8703.70 S 75.84E 0.22 '~2718 312 61.1 105.3 7820.73 8976.91 2201.88S 8702.80E 8977.03 S 75.80E 0.13 13032 314 62.5 105.0 7969.11 9253.61 2274.19S 8969.91E 9253.71 S 75.77E 0.45 13282 250 64.1 104.6 8081.44 9476.94 2331.24S 9185.84E 9477.04 S 75.76E 0.66 13498 216 60.8 105.6 8181.33 9668.41 2381.10S 9370.71E 9668.50 S 75.74E 1.58 13625 127 61.5 105.0 8242.61 9779.63 2410.45S 9478.00E 9779.71 S 75.73E 0.69 PAGE 5 Company: Arco Alaska Inc., Well: QS9-46, Location: Prudhoe Bay, Riq: Nabors 28E Meas Course True Vertical Coordinates Closure Dog Leg, Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/lO0° 13855 230 61.4 105.3 8352.54 9981.65 2463.25S 9673.01E 9981.72 S 75.71E 0.12 14064 209 61.6 105.3. 8452.26 10165.31 2511.71S 9850.18E 10165.37 'S 75.69E 0.10 14253 189 60.6 106.7 8543.60 10330.71 2557.31S 10009.22E 10330.75 S 75.67E 0.84 14381 128 59.1 106.4 8607.89 10441.32 2588.84S 10115.32E 10441.35 S 75.64E 1.19 14571 190 57.8 109.6 8707.33 10602.90 2638.83S 10269.28E 10602.91 S 75.59E 1.59 14761 190 56.2 108.0 88'10.81 10761.78 2690.20S 10420.11E 10761.78 S 75.52E 1.10 14921 160 56.2 108.0 8899.81 10894.49 2731.28S 10546.56E 10894.49 S 75.48E 0.00 PAGE 6 £C00ilfiel~ Sepv~r s PLAN VIEW Arco Alaska Inc. DS9-46 Prudhoe Bay Nabors 28E JOB# 783tak/O0 SCALE: I ~nch = t600 Ceet ~600 t600 0 ~ 4800 co CD 5400 8000 9600 ~200 !2800 1600 3200EAST 48~fOt) 6400 8000 960O 0 0 2000 4O0O -~6000 °8000 >10000 12000 14000 !6000 18000 TF SCO Oilfield Service VERTICAL PROJECTION 2000 4000 6000 BO00 lO000 12000 445 ' .O1 deg 959 ' 4.7 deg 1527' 9.4 deg ArCO Alaska Inc. ~ DS9-46 2093' 18.5 deg Prudhoe Bay -k,,,,2sso · 3o.1 oeg NaOors 28E ~k~22m . 4m.9 oeg JO8# 783tak/O0 '~974 . 57 ~eg SCALE: "~ae' me ~ ~eg 1 inch = 2000 feet ~.~' 60.4 deg 3 ' 60.6 oeg 149~1 Oeg ~0.6 · deg 56.2 deg VERTICAL SECTION (ft) cored intervals ~m~ drillinQ history core analysis CO. CONTACT check off or list data as it is receiv~d.*li~st received, date for 407. if not' re~juired list as NFl su~ey !A. ! well, tests d~ ditch intervals , di~lital data /_,/ ? ~,1 (oH.) RUN i INTERVALS ! SCALE NO. Ito the nearest foot} .... ! , /~1? ~'1- ! I ! 7,,1 .......... 91 ~ [1: ~ ~) ~ ., 11] ~?] i . PZ,q ................ ¢ ~1 ~. ~<~ / ?,e o p ......... < ~/,..,:'/?-,. ..m,.~, c ( c o ,. p ),l / AOGCC GEOLOGICAL i~ATE~.iALS iNVENTOrY LiST PERI, IT# ~ - /3.~ LOG TYPE .... ~.~), ~! ...... iii i ZUl,, :3'~) ' ' ' ii 33) i,I 3q 36,1 '37| 38) ~39| 4oi "',~.]! ,42) I, RUN NO. iNTERVALS [to the nearest foot] "'j SCALE {inchtl i i i I I ARCO ALASKA, INC I'-'~0· BOX i00360 ANCHORA(.iE, Al_AS'I< A 99510 DAI'E: t o ,-..-t 8--90 REF"E;i'"<Iii;NCli"' ARCO CASED I"lOl_lE FINAI..S. ¥-26 t t '"'2'$ .... 90 PII'S.' 4-2 t 2 .... t 2-90 CNI../[;I::,' · 1-5 t,,. '~ .... t 2'-9C' CNI.../C;R '/4-'t 8 t '')'~... .... t S-'-go CNL./E;I=,: /5:-'''~ t 2-t .S'-'9O I::'I)K-" t O0/Gi;:/CCI.. 5 "" 5 t t '- t 4 '"' 9 GP F:,' 0 D I=' !:;,' 0 F" I I.. lie ':';'-' 5 t '" .... ,:. t 5:-90 F:'DK-'t O0/GR/CCL 7"',..,5 ~ t/22& b/9e F"' ii': I=( F" BF~li'"AI(DOWN ~-'~..¥ t t .... 2t-90 I::'I:;~E-'F:'RAC I'EHP 9'"'S I 2-'t .4 .... 90 COI...I...AI",:/I='IEi";,'F" 9 .... 45 t2-8 .... 9() bL. LI..,AF~:/""I F'EI:;:I:= 9 .... .46 t 2-6 .... 90 COLL. AI::/PFRF' t :3 "" t 5 t 2 .... ',2"" 90 I N J F:' R 0 F'" I I..:liE t :.'~.. .... t ,..:, ~' t '."'~.. '"' 2. .... 90 I N ,J I'"" I",'" r.) F" I I... IE t4 .... 1 fi .... i(: .... 90 I='ROD PROFII..E RLJN t , 5" R LJN t , :i~" RLJN t , 5" R LJ Nt, .5" RUN t, 5' RtJ N t, .5 · RUN I , RLJNS t RLJN t , 5" RUN t, 5" RUN t, 5" RLJN t, 5" R U N t , '3" RUN t , RUN t, 5:" F:' I.. E A S' li'] S I (:; N A N D R E T' U R N 'F H Iii: A '¥ T'A C I"! E D C 0 F:' Y A S l:(ii': C I!i: i I::' "1" 0 F:' D A T' A. Riii:CEIVI!i:I) BY.,~~ ..... ~~..... HAVIii: A NICli= DAY! ;!i: A L.. L. Y !"10 F:' F' Iii: C I< E R 5'"9 A'T'O .... t .. ,;:. · CAHCO fi'l I_AS ATLAS A 'lr' I_ A S,' A'l" L. A,S' CAMCO ATLAS C A M C (3 C A M C 0 ATI_AS -' A1 L..A~> ATI...AS C A i"l f'; 0 C A H C 0 C A ~,1C 0 D I ,. 1 R I B LJ T I [)N :.": C E N "1' R A !... F I I... liE..'.'; '"' C H E V R · ,,. ON D & H · ,,.'"' E X T E N ~,q' I 0 N E X F:' L. 0 R A T I 0 N ~: I!:] X X 0 N I'tARATHON :.": MOBil.. :,",: F' I..I I I... !.. I F' S F'B Wli::L.I... F']:L.E:S l.i' & D '"' B F:' ~.' 'ti' / .. STAFF OF' AL. AS'KA TEXACO .RECEIVED DEC 7 IBBO Alaska 011 & Gas Cons. Com~nisslo~ Anchorage ARCO ALA~.?KA, INC,. P ,~ O. B 0 X i (:.~ (') S 6 (') A N C' H 0 R A (]~- Ii!i, A L. A S' K A 9 9'3 i (') R iii: r': E!:V Iii: D i:.: y .....,~....~ ............. t"1A V iii: A N.,.T C Iii: D A Y '. ;!i: A I... I... Y H 0 i::' F:' E C K iii: F;.: A'i" 0 .... i..,':' 2 9 'r', 'r ,S' i ,,. ]: B Li "i' 'r 0 i'...! :(::, & ki iii: X T Iii; i'..!,? ! C! i'.! iii. ';:.::: i::' !... 0 i:,.: A "f' :I: (:J i'.i iii: X X (:'..: N ;'.,'i ,'] i:;'/". ']" j-.' c'~ ;'.. i i ~!",., ..1"I I , i'i 0 B ]: I... (2 C :'i1::' :1: i::.,S' ) ARCO ALASKA, INC P · O, BOX i ANCHORAGF, ALA~'K A ¢795t DATE' i i--30--90 REI:'ERENCE · ARCO C'A;~:ED HOLE FrINAL£' i .-- t 6' i i -. :24 - 5.:' O t - i 2 i i -- ''~ '~ - o ;:', i -'i 3; i t -24-90 3-26 i i-23-?"0 6-'7 i i ...":,".;.'.-c;,¢...:.._,. , . 7--29 t i -i 7-9,:'::, 9-.3 i i .-22-90 9-4 i i i '-'"2--'~-;'0 9--.41 i i -:P':2-9':::' o-4'>, ..i i --'~_ i --:~0, '~;' -- 42 i i -- "'2 i -' c:, ('::, : ,,.0 ~. ':';'--46 i i-'::'":'-':';';:'" 9 ...... '~-a, i i-22--':;-;',:::, i i--'.:?::.;, i 4 -,i o..c.:,,:::, I i / : -u i "~--~": ~ i '-i ~:_.c~,-:', i 2-.:-3B i 0-22--96' i ':; .... ":' t i-2-9,::) ...-' ,~',. . i 5-4 i i '-i'5-96' iI.':' .-"~ i 6--'i 9 i i --t 7--90 / DUAL. BURST TDT--P' RUi',~9, 5" F'DK-i ;:;;:;/(:.~:;'/f"("~ / .............. RIJN i, '5" F'i)K-t ,:_-":,6'/GR/CCI_/TEMP '/ F;,'LJNi , ..;.'-'" F E. INt-- / RUN i 5 · COL. LAR/'" - "- DUAL BUF;:;?T 'FD'T'-P'"' RUN t., 5" CCL/F'F-'RF -' RUN V Er R T I I_ 0 G / I:;.:lj ?'4 i ~'" · , ~ ,--' CBT ~' Rur,I 2, ~" CET RUN '" S" · .' ) CBT.-"' RUN (:;El'/' RUN '~ ~" CBT -- RUN i E: iE T-' F;: L N .... t , ':';'," 'T'E?iF'.-.'~"~,._,~I::'V~:-'Y,-. ~ ..'- F;.:UN i , ..~--" C C ..... L / P E R F -,, F..' tJ N CCL Si-RIP i'0 :~'ET CSt; F'A'FCH~ F<I. JN Tt:ZHF:' SURVEY --' F;:t_INi , ...":"" COLLAR/PERF"~ i';:IJNt , 5 · T ~: ;'~*::' Z U F':: V E. Y F.: U Ni , ~" f:' E R F-' I:;:. L:.: C 0 F;.: D I;: U Ni., 5" R ECE:I.'-VED BY ~ .... ~"'~ H A V E: A N T.,. r,=..,,_~:." i) A 5'" ! :"'.." A i_ i... Y HOF:'F: E Ci,':: F: R A T C).- 4 ,::' '-, ,-, · , .2," 'Y S'Ci.-t (.~'F I_ A 3' ATLAZ Ai"I..AX $CH A I I..~..~,~' A 1' I... A ,':'.:: SCH SCH ZCH $ C I..I ZCI.-i HR$ ATL. AZ HRS A'FLA3' t-il-< £" S C H THE D I $1"R I BUT I ON · ~: CENTRAL FIL. IE$ · "'..- C H E V R U N D & M ~ EXTENSION EXF'LORATION ~ EXXON MAF;.'ATHON · ..'" MOBIl_ :,"~ F' FI I I.. I_ I F',.,':' F'B WELL F'II...Ei.': R & D ~: BF'X · ,' STATE OF ALASKA TEXACO RECEIVED DEC 5 1990 Alaska Oil & Gas Cons. Commission Anchorage AF,'CO At...A3'I<A, tNC,. F:',.C.i, BC)X ~ '~ .... i"l "'" .... O ,::.) ~::' r-.~Nt.,H_h..~.~,E, ALASKA ','. , ..,,'i ('.'.' F:' J... E A.? !ii: :? 'J: G N A N i';' i:;.'. E 'i" U i:;.: N 'T' J"l iii: ~':'."~ 'T' 'TA C i"i iii: D C 3 t::' Y A.'.'? R i:.:: C E i I::"1" "i F:' I) A "i' A., HA'v'E A NIC::iii: DAY; A "i" 0 .... i rS. 2 9 i) ]: ;?:,' 'f' F;.: :i: BLt T :I; 0 N C iii: N "f' F;..' A L.. F :J: L iii:,? ( C i"I ) C i"t Iii. V F;..' 0 N 'D & M 'TAHHA,? BF;.:C)WN < OH/GC':i" > E X iX 0 N H A R A T I.-I 0 N i"*; 0 B :!: L F:' i"i I t.. L I F:' :?:,' F' ii': W E t... I... F: ]: t... E .!';: F;.: &D ,11, · ,.. B P X ,iL · ,~ :ii: TA l" E i"~ F:' "~ '~' ':" '/ ... tc't ~... t"l ,::. i'.. I':"-i 'i" Iii: X A C 0 ;'..,:;I,-.a Oil & i~as Cons. Commiss/o~ ,' Anchorage F:' ,. 0 B 0 X i '":; ':'!:' ,:, 4 ,:'::, ANCHC'IF;,'A(.';.E: AL.A;:":K A DATE;' i i-i 4-9¢' H A V iii: A N ;i; C: iii: D A Y ! A .'};: F;.: liil C iii; :t: F' f' (.J F' u. I' I ,;:. A 'f' L. A ,):.' D :1; ;:.7 '1" F;.: i B i.. 'i" ]: 0 N TO: THRU: MEMORANDUM State of A aska ALASKA OIL AND GAS CONSERVATION COMI~ISSION · · Lonnie C. Smi~-/ DATE: November 8, 1990 Commissioner FILE NO: JT. DA. 118.2 TELEPHONE NO: SUBJECT: BOPE/RIG Inspection AAI PBU DS 9-46 Nabors Rig 28E Prudhoe Oil Pool FROM: Doug Amos Petroleum Inspector . , ~ Sunday Oct 28, 1990: I traveled thzs date from Conoco s ~PU to AAI's ~~=4~6-~e~ to conduct a BOPE/RIG Inspection on Nabors Rig No. 28E. I found all the BOP equipment and the IADC records in compliance. In suum~ary: I conducted a BOPE/RIG Inspection at AAI's PBU DS 9-46 well on Nabors Rig No. 28E. 02-00lA (Rev. 6/89) 20/ll/MEMO1.PM3 October !, !990 Telecopy: (907)276-7542 J. D. Gillespie Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Prudhoe Bay Unit DS 9-46 ARCO Alaska, Inc. Permit No. 90-133 Sur. Loc. 935' FSL, Btmhole Loc. 1837'FNL, !63'FWL, Sec. 1, T10N, R!5E LR~. 541'FWL, Sec. 8, T10N, R16E UM. Dear Mr. Gi!lespie~ Enclosed is the approved application for permit to drill the above referenced well. The pe~it to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. Sincerely, ~Lonnie C. Smith Commissioner Alaska Oil and Gas Conservation Commission BY O~ER OF THE COMMISSION d!f Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA .L AND GAS CONSERVATION C .IMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~_ Redrill lb. Type of well. Exploratory ~ Stratigraphic Test ~ Development Oil Re-Entry - Deepen Service - Developement Gas ~_ Single Zone - Multiple Zone 2. Name of Operator ARCO Alaska, Inc. 3. Address ?. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 935'FSL, 163'FWL, Sec. At top of productive interval 1800'FNL, 400'FWL, Sec. At total depth 183 1, T10N, R15E, UM 8, TiON, R16E, UM 7'FNL, 541'FWL, Sec. 8, T10N, R16E, UM 12. Distance to 'nearest prop. e_rty line 541' feet 13. Distance to nearest well D~6~-al~ 1040' TVD/Mgeet 16. To be completed for deviated wells 6o. 24° Kickoff depths00' feet Maximum hole angle 18. Casing program size Hole Casing 20" .3-3/8" 9-5/8" ~ncy 9-5/8" 30" 16~, 12-1/4" 12-1/4" Specifications WeightlSradelCoup,ingi~ngth I~-~o ~c/~Cl~ 1473 IL-80 DTC/BTCffM 1515 5. Datum Elevation (DF or KB) RKB 52 ' feet 6. Pr~p~r:ty ~,_~nation ADL: 28345 7. Unit or property Name Prudhoe Bay Unit 8. Well number PBU DS 9-46 9. Approximate spud date 10/20/90 14. Number of acres in property 2560 10. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 11. ~pe Bond(see20AAC25.025) Statewide Number ~o. U-630610 Amount $200,000 15. Proposed depth (MD and TVD) i~"~D feet 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 2 8 4 0 psig At total depth Q'VD) 3 7 5 0 psio Setting Depth Top Bottom I 1' 31'/ 31' !15182'! Quantity of cement TVD (include stage data) 110' 280 sx CS II 3800' 1500 sx CS III/350 sx 8907' 410 sx C1 G 9115' lO0"sx Ci" G 9115' 700 sx C1 G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Conductor Surface Intermediate Production Liner 'Perforation depth: Length Size Cemented measured true vertical Measured depth RECEIVED SEP 2 7 ]990 ~_~.0il & 6as Cons. ' ~ch0raf¢ True Vertical depth 20. Attachments Filing fee [] Property plat [] BOP Sketch ~' Diverter Sketch ~ Drilling program Drilling fluid program ~ Time vs depth plot [] Refraction analysis ~ Seabed report D 20 AAC 25.050 requirements Form 10-401 Rev. 12-1-85 21. I hereby certify.that the foregoing is true and correct to the beSt of my knowledge S~gned ~ Title Regional Drilling Engineer Date '~/'be ~'~'[ A5P Commission Use Only (D'N) PD4"/O12 ' Permit N r' I number I Ap.p~v,~-,da, t~,., See cover letter 9~--/~ ! 0-02. ¢~ ~_ ~_..c; ¢ ~ J .LU/U±/~U for other requirements conditions of approval Samples requ~ired rq. Yes ,/~ No Mud log required L-] Yes /~ No Hydrogen sulfide.measures [] Yes .,~[,No Direcbonal survey required ~ Yes [] No Required working pressure for BOPE/E]'t2M; [] 3M; ,I~ 5M; [] 10M; [] 15M Other: ~/? ' ' "" by order of /~ [,._--.,~ Commissioner the commission Date Approved byi_ ~_~. Submit in triplicate :L H PBU DS 9.46 OPERATIONS SUMMARY 1. MIRU drilling rig. NU diverted and function test same. 2. Drill 16" hole to 500' TVD / MD. , Kick off and build angle at 1.0 degrees / 100 ft. to 1495' TVD / 1500' MD, then build angle at 1.5 degrees / 100 ft. to 2446' TVD / 2500' MD, and then build angle at 2.0 degrees / 100 ft to a final angle of 60 degree 24' in the S 75 degree 29' E direction. End of build is at 3726' TVD / 4270' MD. Drill to 3800' TVD / 4420' MD. 4. Set 13-3/8" casing and cement same. Nipple up BOPE and test to 5000 psi. . , Pick up 12-1/4" BHA and RIH. Test casing to 3000 psi for 30 minutes. Drill 10' of new hole and perform leakoff test. Drill 12-1/4" hole to 8907' TVD / 14,761'MD maintaining the hole angle of 60 degree 24' and the direction of S 75 degree 29' E. 7. Set 9-5/8" casing and cement same. 8. Pick up 8-1/2" BHA and RIH. Test casing to 3000 psi. 9. Drill 10' of new hole and perform EMW test. 10. Drill 8-1/2" hole to 9115' TVD / 15,182' MD maintaining the hole angle of 60 degree 24' and the direction of S 75 degree 29' E. 11. Run wireline logs as programmed. 12. Set 7" liner and cement same. 13. Clean out the liner and test liner to 3000 psi for 30 minutes. Circulate well to brine. 14. Run cased hole logs. 15. Run 4-1/2 tubing and packer assembly with GLMs, treater string and SSSV. Test tubing and casing to 3000 psi. Freeze protect with diesel, p~ E C E JV E P 16. N/U tree and test to 5000 psi. Release drilling rig. SEP 2 7 ]990 17. Rig up wireline unit and perforate. ~i~?~.~a 0~Jl.& 6as cons. (;~0m~issl,~: Anch0ra§~ NOTE: In the event that the mud weight requirement is less than or equal to 10 ppg at the intermediate csg. point ( 8907' TVD/14,761' MD) the option to drill the 12-1/4" hole to TD (9115' 'I'VD ,15,182' MD) will be evaluated. Recall that DS 941, DS 942, DS 9-43 and DS 9-45 required a 9.8 ppg mud weight to drill the K5 shale interval. o Anticipated BHP: 3750 psi (8.2 ppg EMW) @ 8800' TVD o Maximum Anticipated Surface Pressure: 2840 psi o Planned Completion Fluid: 8.6 ppg Seawater NOTE: PBU DS 9-46 OPERATIONS SUMMARY CONT. ac Excess non-hazardous fluids developed from the well operations and as necessary to control the reserve pit fluid level will be pumped down the 9-5/8" x 13-3/8" annulus. The annulus will be left with a non-freezing fluid during any extended period. The annulus will be sealed with 300 sx of cement followed by Arctic Pack. b. Minimum distances of wells within 200 ft. of the proposed well are' o DS 9-15 · 58.47' @ 540' TVD / 540' MD o DS 9-14 · 179.75' @ 600' TVD / 600' MD O DS9-16 '55.97'@ 1040'TVD/1040'MD 0 DS 9-17 · 161.11' @ 1460' TVD / 1465' MD o DS 9-22 · 131.51' @ 2879' TVD / 3600' MD c. The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.033. d. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/fi). e. Based on previous logs on DS 9, no potential productive zones are anticipated above 3500' TVD. f. No potential hazardous levels of H2S are anticipated in this well. RECEIVED SEP 2 ? ~990 Gas Cons. Anchora(je DS 9.46 MUD PROGRAM DEPTH DENSITY PV YP INT 10 MIN FL OIL SOLIDS (TVD) (PPG) (CP) (#/ft) GEL GEL cc/30min (%) (%) MUD TYPE SPUD 8.8 300 70 30+ 50+ 25 0 2 to to to to to 13-3/8" 9.2 100 40 6 csg pt. SET 13-3/8" CASING GEL~BENEX SPUD MUD DEPTH DENSITY PV YP INT 10 MIN FL OIL SOLIDS MUD (TVD) (PPG) (CP) (#/ft) GEL GEL cc/30min (%) (%) TYPE 13-3/8" 8.7 10 6 2 4 25 0 2 LIGHTLY to to to to to to to to TREATED 5000 9.0 15 16 4 10 10 9 POLYMER 5000 9.0 15 16 4 10 10 0 9 LIGHTLY to to to to to to to to TREATED 9-5/8" 10.0 20 25 6 12 6 11 POLYMER csg pt. SET 9-5/8" CASING DEPTH DENSITY PV YP INT 10 MIN FL OIL SOLIDS MUD (TVD) (PPG) (CP) (#/ft) GEL GEL cc/30min (%) (%) TYPE 9-5/8" 8.7 10 6 2 1 8 0 4 LIGHTLY to to to to to to to to TREATED TD 9.2 15 10 4 10 6 6 POLYM E R SET 7" LINER THIS MUD PROGRAM IS ONLY A GUIDELINE. ACTUAL HOLE CONDITIONS WILL DICTATE THE ACTUAL MUD PROPERTIES. 13-5/8" 5000 psi BOP STACK DIAGRAM I IPE RAMS SPOOL ~ __~IPE RAM CASING SPOOL BRADEN ~ HEAD ~ ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVIOR TO THE PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT THE ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH THE CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRES- SURE. 13-5/8" STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH A NON-FREEZING FLUID. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACTED. MARK THE RUNNING JOINT WITH PREDETERMINED PLUG SEATING DEPTH. RUN THE TEST PLUG ON DRILL PIPE AND SEAT IN WELL- HEAD. 3. CLOSE ANNULAR PREVENTER AND UPSTREAM VALVES. 4. FUNCTION TEST CHOKES. 5. IN EACH TEST, FIRST HOLD 250 PSI FOR 3 MINUTES PRIOR TO THE HIGH PPRERSSURE TEST. 6. INCREASE PRESSURE ON ANNULAR TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 7. OPEN ANNULAR PREVENTER AND CLOSE TOP PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 8. CLOSE VALVES DIRECTLY UPSTREAM OF THE CHOKES AND OPEN CHOKES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 9. OPEN TOP SET OF PIPE RAMS. CLOSE BOTTOM PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 10. TEST REMAINING MANIFOLD VALVES (IF ANY) WITH 5000 PSI UPSTREAM OF THE VALVE AND ZERO PRESSURE DOWNSTREAM. 11. BLEED PRESSURE TO ZERO. OPEN BOTTOM PIPE RAMS. 12. BACK OFF RUNNING JOINT AND POH. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 3 MINUTES. 13. BLEED OFF ALL PRESSURE. OPEN BLIND RAMS. FILL MANIFOLD AND LINES WITH NON-FREEZING FLUID. SET ALL VALVES IN THE DRILLING POSITION. 14. TEST STANDPIPE VALVES TO 5000 PSI. 15. CHECK DEGASSER OPERATION. 16. RECORD BOP TEST INFORMATION ON THE BOP TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 17. PERFORM COMPLETE BOP TEST WEEKLY AND FUNCTION TEST DAILY. NABORS 28E DIVERTER SYSTEM ARCO ALASKA, INC. FILL-UP LINE RISER FLOWUNE I 20" 2000 PSI DIVERTER I 1(7' BALL VALVE 10" BALL VALVE I I I I I I CONDUCTOR I NOTE: ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES. THE SECOND VALVE WILL REMAIN CLOSED UNLESS CONDITIONS REQUIRE THE USE OF THE SECOND VENT LINE. THE SECOND VENT LINE VALVE CAN BE OPENED USING CONTROLS LOCATED AT THE ACCUMULATOR. THIS IS THIS IS A VARIANCE FROM 20AAC25.035. 10" VENT LINE RESERVE PIT 10" VENT UNE DIVERTER LINES DISCHARGE 100 FT. FROM RIG IGNITION SOURCE. ALL TURNS ARE TARGETED TEES. NABORS 28E MI~ SYSTEM PIT #1 130 BBLS PIT #2 81 BBLS PIT #5 117 BBLS PILL PIT 20 BBLS PIT #6 135 BBLS TRIP TANK 170 BBLS PIT #3 137 BBLS ~XT $4 179 BBLS EQUIPb~T - DRILLING FLUID SYSTEM (3) DERRICK FLO-LINE C?.W.~NER (1) DERRICK MUD C?.~.~NER (1) BRANDT CF-2 CENTRIFUGE (1) PIONR. W.R MARK I CENTRIFUGE (1) RIG BUILT GAS BUSTER (1) DRILCO DEGASSER (1) PVT SENSOR PER PIT w/ visual and audio warning devices (1) AGITATOR PER PIT (1) DRI?.?.ING FLOW SHOW SENSOR W/ readout convenient to the driller's console AKO ALASKA. |,~o. D.S. 9. g. I I Ne, 46 PPoposed PPudho. BBy. NePtk Slope. Aleeko I000 2000 3OOO 40QO 5000 6000 7000 8OOO go00 W ELL'/ATIOIIe S~' KOP TVD-500 TflD-SO0 DEP-O IOO EOC #! TVD'14gs TPID'ISOO DEP'8? Bud 1'4Ir1' EOC 112 TV0-2446 T1"10-2500 OEP,,38? IO4) FT K-15 FINAL EOC TVD-3726 TIID-4270 DEP-1568 13 3/8' CSG PT TVO-3800 TIID-4420 DEP-1698 TVD-4SOQ Tt'ID-5837 DEP-2931 TVO-S2S2 TflO-?360 DEP-4255 AVERAGE ANGLE 60 DEG 24 fllN 10000 0 1000 2000 3000 CEIV. ED K-lO TVO-?gs2 Tt'ID-12827 OEP-goog K-5 TVD-8452 T1~-13839 DEP-g889 g 5/8' CSG PT TVD-8go? T1'10-14761DEP-10690 LCU / TOP $ADLEROCHIT TVD-SgI? TI'ID-14?81 OEP-10?08 TARGET / BASE SADLEROCHIT TVDeg032 TI10-15014 DEP-10910 TD TVD-g115 TriO-IS182 DEP-11057 I I I I I 4000 SO00 6000 7000 8000 VERTICAL SECTION I 10000 I 11 OOO 1 12000 100 5O 5O 100 150 _ 200 250 _ :300 _ 100 50 0 50 I 3500 3300 ~t, 900 , 2900 ~1~$0o 1oo ~--"~oo p 8'-,J I I I I 100 150 200 250 300 :350 400 I I I I I I I I I 1 O0 1 50 1 O0 50 0 50 I I I I I 200 250 300 350 400 .100 _ 5O _0 _ 5O 100 150 _ 200 .250 _ 300 2000 1000 _ z 0 _ : 1000 2OOO 3000 _ HORIZONTAL PROJECTION SCALE I IN. = 1000 FEET ARCO ALASKA. In.. / ~ ~ D.S. 9. Well Not 46 Propomed Prudhoe Bmy, North Slope. AImoko ~~ WEST-EAST 000 0 1000 2000 3000 4000 $000 6000 I I I I ! I I SURFACE LOCATION' 935' FSL. 163' FWL SEC. 1. TION. R1SE SURFACE S 75 DEG 29 MINE 10910' (TO TARGET) ?000 8000 I 9OOO i 10000 I TARGET TVD=g032 TMD=15014 DEP-IOgIO SOUTH 2735 EAST 10562 TARGET LOCATION, 1800' FNL. 400' FWL SEC. 8. TION. 16E TD LOCATON 1837' FNL. 541' FWL SEC. 8. T 1 ON, 11 000 I CHECK LIST FOE NE~ ~ PE~TS IT_tM APPROVE DATE (2 :hr= 8) (8) (!0 ~d (14 zhru 22) (£3 =hru 28) Company 1. Is :he parmA: fee an=ached .......................................... 3. 4. 5. 6. 7. 8. e 10. i1. i2.' 13. 14. 15. 16. i7. 18. 19. 20. 2!. 22. Is well :o' be located in a defined pool ............................. is well located proper distance from property line .................. Is well located proper dis:anco from other wells ........ ~ ........... Is sufficient undedica:ed acreage available in this pool ............ Is we!! :o be deviated and is we!lbore plat included ................ Is opera:or the only affected par~ ................................. Cam permit be approved before fifteen-day wain ...................... Does operator have a bond in force .................................. Is a conserve:ion order ueeded ...................................... Is ad~s:ra:ive approval needed ................................... is :he lease number appropriate ..................................... Does :he well have a unique name and number ......................... Lease & Well No. YES NO ,, IS c6nductor s=ring provided Wi~ surface cas~g pro,ac: ~ zones reasonably ~ec:ed ~o sa~a as ~ ~derground source of dr~g wa:er ..................... is enough c~an= used =o circuia=a on conduc:or ~d suvaco ......... W~ c~an: =ia ~ surface ~d in=a~adia=e or produc=ion s=rin~s .. W~I caman= cover ~ ~o~ productive hot, ohs ..................... Wi~ ~! cas~g give adequate s~e~y ~ co,apse, ~a~ion ~d burs=. Is =~s well ~o be ~ckad off ~rom ~ ~s:~g w~bora ............. Is old wa!!bora ab~do~en= procedure included on 1~403 ............ is adequa=a weilbore separa=ion proposed ..................... ' ...... Is a diver=er system recuired. ....................................... 23. 24. 25. 26. 27. 28. m ,i m m Is :he drilling fluid program schematic and !is: of equipment adequate Are necessary diagr~ and descriptions of diveruar a~d BOPE a=uached. Does BOPE have sufficient pressure rating -Tes: to ~O. Ck~ psig .. Does :ha choke ~ifoid comply w/API K?-53 (Fray 84) .................. Is :he presence of H2S gas probable ............................. ~... , (6) OTIIER (_99 thru 3i) rev: 01/30/89 6.011. · For 30. 31. 32. expiorauory amd Surauigraphic wells: Are data presented on pouentia! overp, ressure zones? ................. Are seismic analysis dana presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented INITIAL GE0. UNIT ON / OFF POOL. CLASS STATUS AREA NO.. .... SNOP~E m m C Well Histo.ry 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 APPENDIXi .. No special'effort has been made to chronologically organize this category of information. ,o LIS VERIFICATION LISTING FOR: ARCO ALASKA INC. WELL D.S. 9-46 PRUDHOE BAY ' CROFILMED PROGRAM: LIS REVISION: 4.1 PART NUMBER: W5550-MICRO Start of execution: Fri 18 JAN 91 8:17am WELL DATA FILE: G:kDATA~W00787.WDF ECC: 787.00 COMPANY NAME: ARCO ALASKA INCORPORATED WELL NAME: D.S. 9 - 46 FIELD: PRUDHOE BAY LOCATION: Top of Well: Bottom of Well: Level Spacing: 14900.000 15400.000 0.500 NUMBER OF CURVES: 72 DEPTH AC01 ACQ01 ADMCD ADMDD BDCMS02 CACM CACM02 CHT01 CILD01 CPCM CPCM02 CSSN01 DPEM DPEM02 DRHM02 DRHMS DRHMS02 GR01 GRCM GRS01 NFBM NFBM02 NFGM NFGM02 ~NNGM02 NPAM NPAM02 NPLM NPLM02 NPSM02 NPSMS NPSMS02 PDDI PDDI02 --PDEM02 RACM RACM02 RFOC01 RILD01 RPCM RPCM02 SP01 SPD01 TCDM BDCM BDCM02 BDCMS CLSN01 CN01 CNC01 DPEMS DPEMS02 DRHM GRCM02 GRCMS GRCMS02 NNBM NNBM02 NNGM NPLMS NPLMS02 NPSM PDDM PDDM02 PDEM RILM01 ROPS ROPS02 TCDM02 TEMP01 TTEN01 COMPANY:ARCO ALASKA INCORPORATED WELL:D.S. 9 - 46 FIELD:PRUDHOE BAY COUNTY:NORTH SLOPE STATE:ALASKA TAPE INFORMATION FILE:WLMAIN.001 FILE INTERVAL: DEPT 14900.000 14925.000 14950.000 14975.000 --15000.000 15025.000 15050.000 15075.000 15100.000 AC CN SPD -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 97 0 21 ACQ START= 14900.000 CHT END= 15400.000 CILD CN CN CNC GR GRS RFOC RILD RILM TEMP TEN .250 -999.250 -999.250 .250 -999.250 -999.250 .250 -999.250 -999.250 .250 -999.250 -999.250 .250 -999.250 -999.250 .250 -999.250 -999.250 .250 -999.250 -999.250 .250 -999.250 -999.250 .250 -999.250 -999.250 .250 -999.250 -999.250 .250 -999.250 -999.250 .250 -999.250 -999.250 .250 -999.250 -999.250 .250 -999.250 -999.250 .250 -999.250 -999.250 .250 -999.250 -999.250 .250 -999.250 -999.250 .250 -999.250 -999.250 .390 0.000 1307.787 .000 26.389 26.428 .762 166.716 7784.281 91.025 0.000 662.526 0.000 29.081 28.675 21.998 166.597 6734.680 73.325 0.000 611.658 0.000 90.514 88.031 SP -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 37.491 0.000 200.012 200.012 18.477 26.673 15.219 -41.292 42.040 0.000 200.012 200.012 20.984 23.787 15.435 -41.197 57.854 0.000 200.012 200.012 12.300 17.285 14.799 -7.960 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 21.998 15125. 000 15150.000 15175.000 ~15200.000 15225.000 89. 0. 22. 96. 0. 22. 87. 0. 21. 78. 0. 21. 72. 0. 21. 862 O00 653 180 0OO 998 888 OO0 998 953 O00 998 643 000 998 15250.000 78. 0. 29. 337 000 997 15275.000 76. 0. 30. 047 000 233 D.S. 9 DEPT - 46 AC CN SPD __15300.000 15325.000 15350. 000 79. 50. 30. 50. 50. 30. -999. -999. -999. 553 000 233 000 000 997 250 250 250 15375.000 -999. -999. -999. 250 250 250 166.458 0.000 27.574 166.137 0.000 29.089 165.609 0.000 33.877 164.927 0.000 96.323 164.399 0.000 87.229 163.274 0.000 106.512 163.328 0.000 120.955 100.000 ACQ GR TEMP 0.000 0.000 100.000 0.000 0.000 100.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 6591.559 662.245 27.581 6536.910 713.245 29.172 6569.977 589.041 33.916 6496.848 635.864 95.747 6575.633 694.967 87.868 6648.051 764.751 106.252 6814.031 804.937 120.820 6822.520 CHT GRS TEN 804.923 0.000 6772.016 187.791 0.000 5500.680 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 45.318 17.087 56.439 14.875 59.039 14.969 86.474 12.548 103.447 9.152 161.359 5.618 161.201 5.817 CILD RFOC 217.860 4.292 0.000 4.620 -999.250 -999.250 -999.250 -999.250 0.000 22.066 0.000 17.718 0.000 16.938 0.000 11.564 0.000 9. 667 0.000 6. 197 0.000 6.203 CN RILD 0.000 4.590 0.000 0.200 -999.250 -999.250 -999.250 -999.250 200.012 13.672 200.012 11.560 200.012 11.880 200.012 8.755 200.012 8.896 200.012 6.011 0.000 6.224 CN RILM 0.000 4.581 0.000 4.788 -999.250 -999.250 -999.250 -999.250 200.012 -34.898 200.012 -43.635 200.012 -40.617 200.012 -14.116 200.012 10.624 200.012 9.546 0.000 7.124 CNC SP 0.000 12.233 0.000 13.078 -999.250 -999.250 -999.250 -999.250 15400.000 ~ 15400.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 WELL DATA FILE: G:kDATAkW00787.WDF ECC: 787.00 COMPANY NAME: WELL NAME: FIELD: LOCATION: ARCO ALASKA INCORPORATED D.S. 9 - 46 PRUDHOE BAY Top of Well: Bottom of Well: Level Spacing: 14900.000 15400.000 0.500 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 NUMBER OF CURVES: 72 DEPTH AC01 ACQ01 BDCMS02- CACM CACM02 CPCM CPCM02 CSSN01 DRHM02 DRHMS DRHMS02 GRS01 NFBM NFBM02 NNGM02 NPAM NPAM02 NPSM02 NPSMS NPSMS02 PDEM02 RACM RACM02 RPCM RPCM02 SP01 ADMCD ADMDD BDCM BDCM02 BDCMS CHT01 CILD01 CLSN01 CN01 CNC01 DPEM DPEM02 DPEMS DPEMS02 DRHM GR01 GRCM GRCM02 GRCMS GRCMS02 NFGM NFGM02 NNBM NNBM02 NNGM NPLM NPLM02 NPLMS NPLMS02 NPSM PDDI PDDI02 PDDM PDDM02 PDEM RFOC01 RILD01 RILM01 ROPS ROPS02 SPD01 TCDM TCDM02 TEMP01 TTEN01 FILE:MWDMAI.002 FILE INTERVAL: START= 14900.000 END= 15400.000 -- DEPT 14900. 000 BDCM BDCM CACM CAPM DPEM DPES DRHM DRHS GRCM GRCS NFBM NFGM NNBM NNGM NPAM NPLM NPLS NPSM NPS S PDDI PDDM PDEM RACM ROP RPCM TCDM -4.799 -4.799 -999.250 -999.250 -0.240 -0.240 -10.242 -10.242 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ~ 14925.000 14950. 000 14975.000 15000. 000 15025.000 15050.000 15075.000 15100.000 15125.000 15150.000 15175.000 -999. -4. -10. -999. -999. -4. -10. 87. -999. -4. -10. -999. 1098. 0. 41. -999 . O. 39. 68. . O. 22. 20. . 18. 47. . O. 17. 39. . O. 24. 33. · O. 19. 28. 250 799 242 250 250 799 242 265 250 799 242 250 35O 352 120 360 250 490 073 885 037 202 OO3 874 933 299 012 601 192 523 012 628 200 256 009 685 250 307 007 411 350 386 036 -999. -4. -999. -999. -999. -4. -999. 90. -999. -4. 136. -999. 6. . 194. 43. -999. . 181. 41. 4. · 25. 24. 25. · 31. 19. 13. · 94. 18. 10. . 30. 26. 22. . 34. 20. 19. . 250 799 250 250 250 799 250 699 250 799 158 250 046 351 219 516 250 490 859 976 693 203 163 146 523 299 545 653 799 523 347 630 254 256 502 049 528 306 078 506 943 386 161 133.491 -999.250 -999.250 -999.250 109.994 -999.250 -999.250 94.422 80.871 165.394 136.043 -999.250 137.207 -999.250 197.411 44.973 23.099 213.079 187.162 41.975 15.998 39.180 26.195 24.162 59.448 72.467 29.655 19.498 39.157 97.525 97.604 16.754 15.603 44.390 31.454 24.710 49.124 50.144 32.759 22.212 42.226 67.603 37.532 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 9.297 91.473 -999.250 91.046 -999.250 -999.250 10.983 -999.250 16.344 47.187 -999.250 119.069 16.969 45.715 8.398 30.496 27.437 28.509 32.791 48.411 32.547 24.134 20.656 75.461 34.312 23.137 13.252 37.157 26.281 30.357 26.913 46. 129 31. 312 24.967 21.678 54.852 32.906 -999.250 -0.240 -999.250 -999.250 -999.250 -0.240 12.667 92.596 -999.250 -0.240 -999.250 86.823 -999.250 5.380 7.000 46.863 145.962 4.229 8.000 45.885 153.387 1.994 12.000 28.127 153.275 2.401 13.000 23.694 154.400 2.814 14.000 21.700 155.525 2.442 12.000 29.108 155.750 3.169 12.000 26.534 155.750 2.478 12.500 -0.240 -999.250 -999.250 -0.240 6022.333 -999.250 -0.240 -999.250 463.500 5.371 6438.500 -999.250 4.234 6529.000 2586.200 2.000 6979.000 2949.000 2.390 7081.000 3564.750 2.819 7189.000 4440.600 2.433 7079.000 4878.500 3.170 7045.000 5339.000 2.499 7047.000 -10.242 -999.250 -999.250 -10.242 1453.667 -999.250 -10.242 -999.250 99.035 0.126 1352.000 -999.250 0.065 1370.000 21.211 0.000 1327.000 18.496 -0.013 1368.500 74.926 0.014 1350.000 15.175 0.002 1458.000 15.043 0.006 1389.000 24.850 -0.037 1381.000 18. 167 30.460 D.S. 9 - 46 DEPT BDCM DRHS NPAM PDEM 15200.000 . 0. 26. 59. 361 069 947 075 -- 15225.000 15250.000 . 0. 20. 95. . 24. 92. 529 069 252 943 463 004 207 642 15275.000 15300.000 . 0. 20. 88. . 30. -999. 476 029 980 192 411 007 321 250 15325.000 15350.000 . 33. 103. -4. -10. -999. 63. 487 0O5 239 117 799 242 250 600 ~15375.000 -4. -10. -999. -999. 799 242 250 250 19.198 14.792 BDCM GRCM NPLM RACM 2.362 101.931 28.423 10.903 2.531 104.255 21.390 10.589 2.465 126.619 25.546 5.231 2.475 113.945 22.156 5.537 2.412 152.423 31.962 4.143 2.487 151.283 35.019 4.089 -4.799 -999.250 -999.250 6.847 -4.799 -999.250 -999.250 -999.250 18.811 30.545 CACM GRCS NPLS ROP 91.716 103.698 26.814 31.543 94.435 104.836 22.166 12.184 191.177 131.135 25.444 10.268 180.614 116.483 23.752 17.687 241.376 149.674 31.875 9.401 244.531 152.421 33.575 12.085 146.043 -999.250 -999.250 13.198 -999.250 -999.250 -999.250 -999.250 23.690 18.231 CAPM NFBM NPSM RPCM 66.355 24.281 32.659 15.071 106.128 30.094 25.827 9.423 175.751 25.969 29.870 5.690 163.707 28.812 26.573 6.108 223.102 21.469 36.082 4.482 233.944 20.094 39.030 4.275 136.725 -999.250 -999.250 7.314 -999.250 -999.250 -999.250 -999.250 23.482 155.975 DPEM NFGM NPSS TCDM 3.445 11.500 31.288 157.100 4.314 11.000 26.975 157.550 4.722 10.500 30.081 158.450 4.567 10.500 27.686 158.450 4.972 10.000 37.628 158.844 4.797 9.000 36.880 161.038 -0.240 -999.250 -999.250 161.150 -0.240 -999.250 -999.250 -999.250 5886.714 DPES NNBM PDDI 3.455 6981.000 6611.000 4.338 6980.000 7892.400 4.745 6892.500 9482.500 4.547 6866.000 10712.500 4.981 6748.000 -999.250 4.809 6741.500 13432.000 -0.240 -999.250 14445.000 -0.240 -999.250 -999.250 34.620 DRHM NNGM PDDM 0.077 1348.000 12.667 0.095 1335.500 64.727 -0.022 1302.000 65.826 0.036 1318.000 70.996 -0.025 1344.000 -999.250 -0.006 1312.500 68.152 -10.242 -999.250 65.451 -10.242 -999.250 -999.250 15400.000 -9 -9 -9 -9 99. 99. 99. 99. 15400.000 -999. -999. -999. -999. WELL DATA FILE: ECC: COMPANY NAME WELL NAME FIELD LOCATION Top of Well: Bottom of Well: Level Spacing: 250 250 250 250 250 250 250 250 NUMBER OF CURVES: 72 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 G: kDATAkW00787.WDF -999.250 -999.250 -999.250 -999.250 787.00 : ARCO ALASKA INCORPORATED : D.S. 9 - 46 : PRUDHOE BAY : 14900.000 15400.000 0.500 DEPTH AC01 ACQ01 BDCMS02 CACM CACM02 CPCM CPCM02 CSSN01 DRHM02 DRHMS DRHMS02 GRS01 NFBM NFBM02 NNGM02 NPAM NPAM02 NPSM02 NPSMS NPSMS02 PDEM02 RACM RACM02 RPCM RPCM02 SP01 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ADMCD ADMDD BDCM BDCM02 BDCMS CHT01 CILD01 CLSN01 CN01 CNC01 DPEM DPEM02 DPEMS DPEMS02 DRHM GR01 GRCM GRCM02 GRCMS GRCMS02 NFGM NFGM02 NNBM NNBM02 NNGM NPLM NPLM02 NPLMS NPLMS02 NPSM PDDI PDDI02 PDDM PDDM02 PDEM RFOC01 RILD01 RILM01 ROPS ROPS02 SPD01 TCDM TCDM02 TEMP01 TTEN01 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 FILE: MWD02.003 FILE INTERVAL: START= 14900.000 END= 15400.000 DEPT --14900.000 BDCM BDCS CACM CAPM DPEM DPES DRHM DRHS GRCM GRCS NFBM NFGM NNBM NNGM NPAM NPLM NPLS NPSM NPSS PDDI PDDM PDEM RACM ROP RPCM TCDM -4.799 -4.799 -999.250 -999.250 -0.240 -0.240 -10.242 14925.000 -- 14950.000 14975.000 15000.000 15025.000 15050.000 15075.000 15100.000 15125.000 _15150.000 -10 -999 -999 -4 -10 -999 -999 -4 -10 90 -999 -4 -10 -999 1100 2 0 40 -999 2 0 36 67 2 -0 22 20 2 -0 18 49 2 0 17 36 2 0 24 33 2 0 19 28 .242 .250 .250 .799 .242 .250 .250 .799 .242 .270 .250 .799 .242 .250 .944 .355 .120 .007 .250 .499 .095 .200 .005 .208 .003 .779 .592 .283 .013 .763 .175 .515 .011 .051 .242 .256 · 009 .685 .250 .307 .007 .411 .350 -999 -999 -999 -4 -999 -999 -999 -4 -999 93 -999 -4 133 -999 6 2 199 42 -999 2 185 38 4 2 29 24 24 2 30 19 14 2 109 18 11 2 3O 26 22 2 34 20 19 .250 .250 .250 .799 .250 .250 .250 .799 .250 .779 .250 .799 .818 .250 .611 .356 .115 .102 .250 .499 .951 .120 .281 .208 .668 .047 .257 .283 .705 .824 .728 .515 .479 .023 .832 .256 .502 .049 .528 .306 .078 .506 .943 -999. -999. 133. -999. -999. -999. 110. -999. -999. 94. 78. 152. 134. -999. 147. -122. 197. 45. 16. 233. 190. 41. 14. 41. 27. 23. 63. 67. 30. 19. 37. 84. 109. 17. 13. 44. 31. 24. 49. 50. 32. 22. 42. 250 250 491 250 250 250 870 250 250 678 201 111 996 250 696 349 356 627 222 693 720 713 545 225 337 643 879 897 205 542 535 520 171 945 5O0 390 454 710 124 144 759 212 226 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 9.131 94.283 -999.250 112.872 -999.250 -999.250 9.128 -152.116 16.630 45.836 -999.250 128.836 18.163 42.015 7.764 30.383 27.594 28.413 32.913 35.726 32.312 24.302 27.991 56.013 35.000 22.543 17.853 37.157 26.281 30.357 26.913 46.129 31.312 24.967 21.678 -999.250 -999.250 -999.250 -0.240 -999.250 -999.250 -999.250 -0.240 13.784 94.510 -999.250 -0.240 -999.250 87.217 -999.250 5.399 7.764 47.937 146.048 4.594 8.955 43.546 153.495 1.741 11.000 27.969 153.275 1.962 13.000 23.979 154.400 2.408 12.000 22.134 155.750 2.442 12.000 29.108 155.750 3.169 12.000 26.534 155.750 -999.250 -999.250 -0.240 -999.250 -999.250 -0.240 6015.884 -999.250 -0.240 -999.250 495.833 5.388 6407.571 938.376 4.569 6508.943 2593.076 1.781 6997.000 2939.000 2.012 7089.000 3598.250 2.437 7156.000 4454.000 2.433 7079.000 4878.500 3.170 7045.000 5339.000 -999.250 -999.250 -10.242 -999.250 -999.250 -10.242 1451.204 -999.250 -10.242 -999.250 95.544 0.120 1355.055 -235.338 0.111 1313.650 18.678 -0.010 1364.000 16.173 -0.020 1376.000 67.740 0.009 1354.000 14.241 0.002 1458.000 15.043 0.006 1389.000 24.850 15175. 000 1 D.S. 9 DEPT - 46 15200.000 15225.000 15250.000 15275.000 15300.000 15325.000 15350.000 15375.000 2.378 -0.035 18.041 31.026 BDCM DRHS NPAM PDEM 2.505 0.041 25.948 56.642 2.604 0.021 21.612 95.721 2.463 -0.004 24.207 92.642 2.463 0.043 24.613 88.350 2.419 -0.005 29.389 -999.250 2.473 -0.014 27.069 103.217 -4.799 -10.242 -999.250 65.525 -4.799 -10.242 -999.250 2.378 39. 176 19.065 15.043 BDCS GRCM NPLM RACM 2.502 139.946 27.375 9.575 2.601 104.914 22.820 10.138 2.465 126.619 25.546 5.231 2.463 125.680 25.973 5.512 2.420 149.679 30.985 4.142 2.479 160.493 28.551 4.246 -4.799 -999.250 -999.250 6.639 -4.799 -999.250 -999.250 66.483 37.866 18.831 31.912 CACM GRCS NPLS ROP 104.434 136.164 26.447 21.933 98.676 104.657 22.592 11.157 191.177 131.135 25.444 10.268 181.435 126.815 25.200 16. 188 241.449 149.673 31.459 9.401 235.520 156.985 28.907 11.639 150.625 -999.250 -999.250 13.906 -999.250 -999.250 -999.250 53.361 33.360 23.561 18.747 CAPM NFBM NPSM RPCM 91.799 24.740 31.643 10.893 110.844 28.742 27.220 9.024 175.751 25.969 29.870 5.690 168.046 25.078 30.284 5.951 225.320 21.920 35.138 4.439 221.595 23.385 32.784 4.513 123.968 -999.250 -999.250 8.067 -999.250 -999.250 -999.250 2.527 12.154 23.511 155.975 DPEM NFGM NPSS TCDM 3.965 10.667 30.699 157.100 5.204 11.424 27.598 157.550 4.722 10.500 30.081 158.450 4.322 8.5O0 30.057 158.450 4.911 9.781 36.815 158.836 4.720 9.000 33.937 161.150 -0.240 -999.250 -999.250 161.150 -0.240 -999.250 -999.250 2.521 7104.041 5898.765 DPES NNBM PDDI 3.963 6912.000 6625.000 5.151 7001.689 7929.406 4.745 6892.500 9482.500 4.325 6740.000 10679.000 4.921 6725.469 -999.250 4.708 6750.000 13493.000 -0.240 -999.250 14542.000 -0.240 -999.250 -999.250 -0.035 1380.309 34.678 DRHM NNGM PDDM 0.032 1349.667 13.551 0.016 1324.642 60.602 -0.022 1302.000 65.826 0.048 1302.000 76.644 -0.021 1343.781 -999.250 -0.015 1331.333 59.497 -10.242 -999.250 62.416 -10.242 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -- 15400.000 15400.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 End of execution: Fri 18 JAN 91 8:18am ,Elapsed execution time = SYSTEM RETURN CODE = 0 19.99 seconds. PROGRAM: TAPESCAN REVISION: 2.34 Start of execution: Fri 18 JAN 91 8:25a ECHOING INPUT PARAMETERS INPUT PARAMETER FILE: TAPESCAN.INP 1 2 3 4 5 6 7 123456789012345678901234567890123456789012345678901234567890123456789012 1 AUTOCURV = 1 , 2 AUTOFILE = 0 , 3 COMMENTS = 1 , 4 INFORECS = 0 , 5 LISTMETHOD = 0 , 6 LISTFREQ = 0 , 7 LISTMAX = 0 , 8 STATS = 0 , . Automatic Curve renaming: 0=OFF,i=ON . Automatic FILE= generation: 0=OFF,i=ON . Decode LIS Comment records: 0=OFF,i=ON . Decode LIS Information records: 0=NO, i=YES · Listing Method: 0=depth units l=tape units · Listing Frequency: Every n units · Listing Maximum (0=no limit, value=list limit) Statistics generation: 0=OFF,i=ON 9 FORCETYP = 0 , ! (i=BIT,2=LIS ... thru 35=Array Accoustic) (see table) = ~ If 1, 10 WRITEASCII 0 , . all ascii files will be written (file0001.dat,etc.) --11 WRITETAP = 1 , .~ Write Tape-Image File: 0=NO,i=YES = ! If 1 and WRITETAP on, split LIS logical files to 12 SPLITLIS 1 , Physical -~ 13 SUBFILES = /0/ 14 INTERPOI.~TE= ' YE~ ' ('YES 'or'NO') 15 END - i Tape Subfile write selection (WRITETAP must be on) ! Set up for TAPE2WDS to interpolate datums ~-- USER INPUT PARAMETERS AUTOCURV = 1 AUTOFILE = 0 , COMMENTS = 1 ,--INFORECS = 0 LISTMETHOD = 0 , LISTFREQ = 0 , LISTMAX = 0 , STATS = 0 ~ FORCETYP = 0 'WRITEASCII = 0 WRITETAP = 1 SPLITLIS = 1 SUBFILES = /0/ INTERPOLATE= ' YES ' END PROCESSING INTERVAL FROM ~-- CONSTANT PARAMETERS AUTOCURV= 1.00000 FORCETYP= 0.000000E+00 LISTMAX = 0.000000E+00 SPLITLIS= 1.00000 WRITETAP= 1.00000 drlength= 0.000000E+00 -- minrecln= 0.000000E+00 numdatar= 0.000000E+00 tflevsp = 0.000000E+00 wcrlevsp= 0.000000E+00 0.000 TO 0.000 ! ----! AUTOFILE= 0.000000E+00 COMMENTS= 1.00000 INFORECS= 0.000000E+00 LISTMETH= 0.000000E+00 LISTFREQ= 0.000000E+00 SELFTEST= 0.000000E+00 STATS = 0.000000E+00 WRITEASC= 0.000000E+00 dpcoef = 1.00000 dpcte = 1.00000 listwave= 0.000000E+00 maxrecln= 0.000000E+00 nsamples= 0.000000E+00 numcurvs= numrecfl= 0.000000E+00 tfendep = tfstdep = 0.000000E+00 wcrbot = 0.000000E+00 0.000000E+00 0.000000E+00 wcrtop = 0.000000E+00 ~-- ARRAY PARAMETERS SUBFILES ( 1) SUBFILES ( 3) SUBFILES ( 5) = 0.000000E+00 = -9999.00 = -9999.00 SUBFILES( 2) = -9999.00 SUBFILES( 4) = -9999.00 SUBFILES( 6) = -9999.00 SUBFILES( 7) = -9999.00 -. SUBFILES( 9) = -9999.00 SUBFILES( 11) -- -9999.00 SUBFILES(13) - -9999.00 SUBFILES( 15) = -9999.00 SUBFILES(17) =-9999.00 -. SUBFILES(19) = -9999.00 SUBFILES(21) -- -9999.00 SUBFILES(23) = -9999.00 SUBFILES(25) = -9999.00 SUBFILES(27) =-9999.00 _. SUBFILES(29) = -9999.00 SUBFILES(31) = -9999.00 -- SUBFILES(33) = -9999.00 SUBFILES(35) = -9999.00 SUBFILES( 37) = -9999.00 SUBFILES(39) -- -9999.00 SUBFILES(41) = -9999.00 -' SUBFILES(43) -- -9999.00 SUBFILES (45) = -9999.00 SUBFILES(47) -- -9999.00 SUBFILES( 49) = -9999.00 SUBFILES(51) -- -9999.00 -' SUBFILES(53) = -9999.00 SUBFILES(55) - -9999.00 SUBFILES(57) -- -9999.00 SUBFILES(59) -- -9999.00 SUBFILES( 8) = -9999.00 SUBFILES(10) =-9999.00 SUBFILES( 12) = -9999.00 SUBFILES(14) = -9999.00 SUBFILES(16) =-9999.00 SUBFILES( 18) = -9999.00 SUBFILES(20) = -9999.00 SUBFILES(22) = -9999.00 SUBFILES( 24) = -9999.00 SUBFILES(26) = -9999.00 SUBFILES(28) = -9999.00 SUBFILES (30) = -9999.00 SUBFILES(32) = -9999.00 SUBFILES(34) = -9999.00 SUBFILES( 36) = -9999.00 SUBFILES(38) = -9999.00 SUBFILES(40) =-9999.00 SUBFILES (42) = -9999.00 SUBFILES(44) = -9999.00 SUBFILES(46) = -9999.00 SUBFILES(48) = -9999.00 SUBFILES(50) = -9999.00 SUBFILES(52) = -9999.00 SUBFILES(54) = -9999.00 SUBFILES(56) = -9999.00 SUBFILES(58) = -9999.00 SUBFILES( 60) = -9999.00 SUBFILES(61) =-9999.00 -. SUBFILES(63) = -9999.00 SUBFILES(65) = -9999.00 SUBFILES(67) = -9999.00 SUBFILES(69) = -9999.00 SUBFILES( 71) = -9999.00 _. SUBFILES(73) = -9999.00 SUBFILES( 75) -- -9999.00 "SUBFILES(77) = -9999.00 SUBFILES(79) = -9999.00 SUBFILES( 81) = -9999.00 .- SUBFILES(83) = -9999.00 SUBFILES(85) = -9999.00 -~ SUBFILES(87) = -9999.00 SUBFILES(89) = -9999.00 SUBFILES(91) = -9999.00 SUBFILES(93) - -9999.00 SUBFILES(95) = -9999.00 -- SUBFILES(97) = -9999.00 SUBFILES(99) = -9999.00 SUBFILES(101) = -9999.00 SUBFILES(103) = -9999.00 SUBFILES(105) = -9999.00 -- SUBFILES(107) = -9999.00 SUBFILES(109) = -9999.00 SUBFILES(lll) = -9999.00 SUBFILES(113) = -9999.00 SUBFILES (62) SUBFILES (64) SUBFILES (66) SUBFILES (68) SUBFILES (70) SUBFILES (72) SUBFILES (74) SUBFILES (76) SUBFILES (78) SUBFILES (80) SUBFILES (82) SUBFILES (84) SUBFILES (86) SUBFILES (88) SUBFILES (90) SUBFILES (92) SUBFILES (94) SUBFILES (96) SUBFILES (98) SUBFILES (100) SUBFILES ( 102 ) SUBFILES ( 104 ) SUBFILES (106) SUBFILES ( 108 ) SUBFILES (110) SUBFILES ( 112 ) SUBFILES ( 114 ) = -9999.00 = -9999.00 = -9999.00 = -9999.00 = -9999.00 = -9999.00 = -9999.00 = -9999.00 = -9999.00 = -9999.00 = -9999.00 = -9999.00 = -9999.00 = -9999.00 = -9999.00 = -9999.00 = -9999.00 = -9999.00 = -9999.00 = -9999.00 = -9999.00 = -9999.00 = -9999.00 = -9999.00 = -9999.00 = -9999.00 = -9999.00 SUBFILES (115) -. SUBFILES (117) SUBFILES ( 119 ) SUBFILES (121) SUBFILES (123) SUBFILES (125) _. SUBFILES (127) = -9999.00 = -9999.00 = -9999.00 = -9999.00 = -9999.00 = -9999.00 = -9999.00 i-- STRING PARAMETERS -- INTERPOL= YES SUBFILES (116) SUBFILES ( 118 ) SUBFILES ( 120 ) SUBFILES ( 122 ) SUBFILES ( 124 ) SUBFILES (126) SUBFILES (128) = -9999.00 = -9999.00 = -9999.00 = -9999.00 = -9999.00 = -9999.00 = -9999.00 Input Tape Device, LU ( 1) is: TAPEC: Output Tape-Image file, LU ( 2) is: G:~DATA~TEMP.TAP (Output Tape-Image file will be over-written) Listing options default to first and last sample on each tape subfile. ( LISTMETH=0, LISTFREQ=0 ) Listing output limiting (LISTMAX) not enabled... (to enable list limiting set LISTMAX positive) Data Statistics reporting ("STATS") has not been enabled. (Specify STATS=I to enable this feature) Automatic curve renaming is enabled. (This is the program default, AUTOCURV=i) (Specify AUTOCURV=0 to disable this feature) Automatic "FILE=n" card generation is disabled. (This is the program default, AUTOFILE=0) (Specify AUTOFILE=i to enable this feature) LIS comment record decoding (COMMENTS=i) has been enabled by user input. LIS information records will not be decoded. (This is the program default, INFORECS=0) (Specify INFORECS=i to enable this feature) The WRITEASC option has not been enabled... (to write ASCII subfiles specify WRITEASC=i) Tape Subfile 1 is type: LIS **** REEL HEADER **** LIS 9o/o8/o TELECO 01 ** LIS CUSTOMER LIBRARY TAPE TELECO OILFIELD SERVICES **** TAPE HEADER **** LIS 90/08/01 00000787 01 TELECO MWD AND ATLAS WL LOG DATA FROM ARCO WELL DS 9-46 Tape Subfile: 1 _Minimum record length: iMaximum record length: 2 records... 132 bytes 132 bytes Tape Subfile 2 is type: LIS i **** FILE HEADER **** ~ WLMAIN.001 1024 ~WD --~)EPTH WITH *** LIS COMMENT RECORD *** FILE 1 HOLDS THE WIRELINE LOG DATA, FILE 2 HOLDS THE TELECO TRIPLE COMBO DATA, FILE 3 HOLDS THE DEPTH SHIFTED TELECO DATA. THE TELECO DATA WAS SHIFTED TO THE WL GAMMA LOG. THE WL ACOUSTIC LOG APPEARS TO BE OFF DEPTH ALL THE CURVES. * FORMAT RECORD (TYPE# 64) Entry Type( 4) Size( 1) Repcode(66) Logging direction is down (value= 255) _Entry Type(12) Size( 4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size( 1) Repcode(66) Datum Specification Block Sub-type is: iEntry Block terminator. --Summary of entry types encountered: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 __ 0 0 0 1 0 0 0 0 0 0 0 1 0 0 0 1 iRep Code Count Bytes 68 17 68 ~ Sum: 17 68 68 ONE DEPTH PER FRAME ~Tape depth ID: FT 17 Curves: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 Name AC ACQ CHT CILD CN CNW CNC CNWL GR GRS RFOC RILD RILM SP SPD TEMP TEN Code Samples Units 68 1 US/F 68 1 68 1 LBF 68 1 MMHO 68 1 CPS 68 1 PU 68 1 PU 68 1 CPS 68 1 API 68 1 API 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 MV 68 1 F/MN 68 1 DEGF 68 1 LBF S i z e Length 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 14 FRAMES * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 72 Tape File Start Depth = 14900.000000 Tape File End Depth = 15400.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** --LIS representation code decoding summary: Rep Code: 68 2260 datums Tape Subfile: 2 Minimum record length: ~Maximum record length: 77 records... 62 bytes 1014 bytes Tape Subfile 3 is type: LIS **** FILE HEADER **** MWDMAI. 002 1024 *** LIS COMMENT RECORD *** THIS FILE CONTAINS THE TELECO RWD DATA. THE 'S' AT THE END OF THE 4 LETTER MNEMONIC INDICATES THAT THE CURVE HAS BEEN EPONENTIALLY SMOOTHED. ~* FORMAT RECORD (TYPE# 64) iEntry Type( 4) Size( 1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size( 4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size( 1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. _Summary of entry types encountered: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 0 0 0 1 0 0 0 0 0 0 0 1 0 0 0 1 Rep Code Count Bytes 68 26 104 Sum: 26 104 104 ONE DEPTH PER FRAME Tape depth ID: FT 26 Curves: 1 2 -~ 3 4 5 6 -- 7 8 9 -~ 10 11 12 13 14 15 16 -~ 17 18 19 -- 20 21 22 23 24 25 26 Name BDCM BDCW CACM CAPM DPEM DPES DRHM DRHS GRCM GRCS NFBM NFGM NNBM NNGM NPAM NPLM NPLS NPSM NPSS PDDI PDDM PDEM RACM ROP RPCM TCDM Code Samples Units 68 1 G/C3 68 1 G/C3 68 1 MMHO 68 1 MMHO 68 1 B/E 68 1 B/E 68 1 G/C3 68 1 G/C3 68 1 CAPI 68 1 -CAPI 68 1 CPS 68 1 CPS 68 1 CPS 68 1 CPS 68 1 PU 68 1 PU 68 1 PU 68 1 PU 68 1 PU 68 1 PTS 68 1 PPF 68 1 MIN 68 1 OHMM 68 1 FPH 68 1 OHMM 68 1 DEGF Size Length 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 9 FRAMES * DATA RECORD (TYPE# 0) Total Data Records: 112 978 BYTES * .~ Tape File Start Depth = 14900.000000 Tape File End Depth = 15400.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet ! NOTE: max curves transferable to WDF per tape subfile reference is: · **** FILE TRAILER **** ..LIS representation code decoding summary: Rep Code: 68 3966 datums Tape Subfile: 3 Minimum record length: ~Maximum record length: 117 records... 62 bytes 978 bytes 24 Tape Subfile 4 is type: LIS **** FILE HEADER **** MWD02.003 1024 *** LIS COMMENT RECORD *** ?HE THIS FILE HOLDS THE DEPTH SHIFTED MWD DATA. THE DATA WAS DEPTH SHIFTED TO WL GAMMA LOG. * FORMAT RECORD (TYPE# 64) Entry Type( 4) Size( 1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size( 4) Repcode(68) -- Null data value is: -999.250000 Entry Type(16) Size( 1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. ~Summary of entry types encountered: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 0 0 0 1 0 0 0 0 0 0 0 1 0 0 0 1 iRep Code Count Bytes 68 26 104 Sum: 26 104 104 ONE DEPTH PER FRAME Tape depth ID: FT 26 Curves: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 Name BDCM BDCS CACM CAPM DPEM DPES DRHM DRHS GRCM GRCS NFBM NFGM NNBM NNGM NPAM NPLM NPLS NPSM NPSS PDDI PDDM PDEM RACM ROP RPCM TCDM Code Samples Units 68 1 G/C3 68 1 G/C3 68 1 MMHO 68 1 MMHO 68 1 B/E 68 1 B/E 68 1 G/C3 68 1 G/C3 68 1 CAPI 68 1 CAPI 68 1 CPS 68 1 CPS 68 1 CPS 68 1 CPS 68 1 PU 68 1 PU 68 1 PU 68 1 PU 68 1 PU 68 1 PTS 68 1 PPF 68 1 MIN 68 1 OHMM 68 1 FPH 68 1 OHMM 68 1 DEGF Size Length 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 9 FRAMES * DATA RECORD (TYPE# 0) Total Data Records: 112 978 BYTES * Tape File Start Depth = 14900.000000 Tape File End Depth = 15400.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet · ' NOTE: max curves transferable to WDF per tape subfile reference is: · **** FILE TRAILER **** --LIS representation code decoding summary: Rep Code: 68 6226 datums Tape Subfile: 4 117 records... ~Minimum record length: _Maximum record length: 62 bytes 978 bytes 24 Tape Subfile 5 is type: LIS **** TAPE TRAILER **** LIS 90/08/01 00000787 01 **** REEL TRAILER **** LIS 90/08/01 TELECO 01 Tape Subfile: 5 --Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes End of execution: Fri 18 JAN 91 8:25a Elapsed execution time = 19.50 seconds. --SYSTEM RETURN CODE = 0 PROGRAM: LISCAN REVISION: 5.2 Start of execution: Fri 9 NOV 90 3:59p **** REEL HEADER **** LIS 90/11/ 9 AWS 01 PART NUMBER: W5790-MICRO **** TAPE HEADER **** LIS 90/11/ 9 01 RECEIVED NOV ] 9 1990 Alaska 011 & Gas Cons. Cornrnis$ioil. Anchorage . FILE # 1 LIS .001 **** FILE HEADER **** 1024 CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 9 - 46 : PRUDHOE BAY : N.SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 15 CURVES : NAME CODE SAMPLE# UNIT 1 AC 68 1 US/F 2 CHT 68 1 LBF 3 CILD 68 1 MMHO '4 CLSN 68 1 CPS 5 CN 68 1 % 6 CNC 68 1 % 7 CSSN 68 1 CPS 8 GR 68 1 API 9 RFOC 68 1 OHMM 10 RILD 68 ' 1 OHMM BYTES 4 4 4 4 4 4 4 4 4 4 + ICi OFIL ED 11 RILM 68 12 SP 68 13 SPD 68 14 TEMP 68 15 TTEN 68 OHMM 4 MV 4 F/MN 4 DEGF 4 LBF 4 * DATA RECORD (TYPE# o) 966 BYTES * DEPTH AC CHT CILD CLSN CN CNC CSSN GR RFOC RILD RILM SP SPD TEMP TTEN 780.000 -999.2500 -999.2.500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 730.000 54.36023 872.5154 0.0000000E+00 0.0000000E+00 50.00000 1.911860 1.914950 -132.9279 1134.185 680.000 55.73112 875.1384 200.0117 200.0117 0.0000000E+00 1.911195 1.913618 -137.0438 1084.625 630.000 56.55122 300.0000 200.0117 200.0117 0.0000000E+00 1.913181 1.918904 -137.8013 5000.000 580.000 50.00000 300.0000 200.0117 200.0117 0.0000000E+00 0.2000000 0.2000000 -80.00000 5000.000 523.0510 0.0000000E+00 41.96010 523.2329 31.00807 43.59531 522.6897 25.49837 0.0000000E+00 0.0000000E+00 21.01131 0.0000000E+00 0.0000000E+00 2.407203 100.0000 0.0000000E+00 2.403292 79.71365 0.0000000E+00 0.2000000 78.06541 0.0000000E+00 0.2000000 80.30519 TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 31 780.00 ENDING TAPE DEPTH = 550.00 FILE ~ 2 LIS .002 **** FILE HEADER **** 1024 CN : WN : FN : COUN : STAT : ARCO ALASKA INCORPORATED D.S. 9 - 46 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH I/NIT : F 15 CURVES : NAME 1 AC 68 2 CHT 68 3 CILD 68 4 CLSN 68 5 CN 68 6 CNC 68 7 CSSN 68 8 GR 68 9 RFOC 68 10 RILD 68 11 RILM 68 12 SP 68 13 SPD 68 14 TEMP 68 15 TTEN 68 CODE SAMPLE# UNIT BYTES 1 US/F 4 1 LBF 4 1 MM}{O 4 1 CPS 4 1 % 4 1 % 4 1 CPS 4 1 API 4 1 OHMM 4 1 OHMM 4 1 OHMM 4 1 MV 4 1 F/MN 4 1 DEGF 4 1 LBF 4 * DATA RECORD DEPTH CN RILD TTEN 15350.000 -999.2500 -999.2500 -999.2500 15300.000 0.0000000E+00 4.590096 6772.016 15250.000 200.0117 6.197363 6814.031 15200.000 200.0117 11.56418 6575.633 15150.000 200.0117 17.71837 6569.977 15100.000 200.0117 17.28494 6591.559 15050.000 200.0117 26.67339 7784.281 (TYPE~ AC CNC RILM -999.2500 -999.2500 -999.2500 o) 79.55263 0.0000000E+00 4.580607 78.33684 200.0117 6.011440 78.95265 200.0117 8.754929 96.17969 200.0117 11.55997 73.32513 200.0117 14.79930 97.38994 200.0117 15.21917 966 BYTES * CHT CSSN SP -999.2500 -999.2500 -999.2500 804.9231 50.00000 12.23347 764.7515 0.0000000E+00 9.545975 635.8635 0.0000000E+00 -14.11570 713.2454 0.0000000E+00 -43.63499 611.6577 0.0000000E+00 -7.959645 1307.787 0.0000000E+00 -41.29170 CILD GR SPD -999.2500 -999.2500 -999.2500 217.8604 0.0000000E+00 30.23280 161.3589 106.5122 29.99701 86.47394 96.32297 21.99780 56.43858 29.08870 22.99770 57.85382 90.51448 21.99780 37.49055 26.38905 21.76201 CLSN RFOC TEMP -999.2500 -999.2500 -999.2500 0.0000000E+00 4.291988 100.0000 0.0000000E+00 5.618190 163.3279 0.0000000E+00 12.54764 164.3990 0.0000000E+00 14.87498 165.6089 0.0000000E+00 12.30030 166.4582 0.0000000E+00 18.47684 166.7165 TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 45 15350.00 ENDING TAPE DEPTH = 15020.00 FILE # 3 LIS .003 **** FILE HEADER **** 1024 CN : WN : FN : COUN : STAT : ARCO ALASKA INCORPORATED D.S. 9 - 46 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 15 CURVES : NAME CODE SAMPLE~ UNIT 1 AC 68 1 US/F 2 CHT 68 1 LBF 3 CILD 68 1 MMHO 4 CLSN 68 1 CPS 5 CN 68 1 % 6 CNC 68 1 % 7 CSSN 68 1 CPS 8 GR 68 1 API 9 RFOC 68 1 OHMM 10 RILD 68 1 OHMM 11 RILM 68 1 OHMM 12 SP 68 1 MV 13 SPD 68 1 F/MN 14 TEMP 68 1 DEGF 15 TTEN 68 1 LBF BYTES 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 * DATA RECORD (TYPE# 0) 966 BYTES * DEPTH AC CHT CILD CLSN CN CNC CSSN GR RFOC RILD RILM SP SPD TEMP TTEN 760.000 .0000000E+00 .2OO0OOO 5000.000 50.00000 0.0000000E+00 0.2000000 63.40871 0.0000000E+00 1.896583 710.000 .0000000E+00 1.891935 0.0000000E+00 50.00000 -80.00000 1170.219 50.00000 -9.405626 0.0000000E+00 0.0000000E+00 0.0000000E+00 528.5593 0.0000000E+00 31.99680 0.0000000E+00 0.2000000 100.0000 0.0000000E+00 2.298727 100.0000 1128.448 660.000 56.17026 1146.953 200.0117 200.0117 0.0000000E+00 1.895496 1.899185 -12.22394 1117.080 610.000 58.28160 1106.757 200.0117 200.0117 0.0000000E+00 1.897976 1.901046 -19.54543 1101.732 527.5664 27.86836 31.40311 526.8772 28.14647 31.00281 0.0000000E+00 2.330591 90.15477 0.0000000E+00 2.298940 89.46205 TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 23 760.00 ENDING TAPE DEPTH = 590.00 **** TAPE TRAILER **** LIS 90/11/ 9 01 TOTAL RECORDS IN THIS LOGICAL TAPE : 114 **** REEL TRAILER **** LIS 90/11/ 9 AWS 01 TOTAL RECORDS IN THIS LOGICAL REEL : TOTAL RECORDS IN THIS PHYSICAL REEL: End of execution: Fri 9 NOV 90 Elapsed execution time = 1 minute , SYSTEM RETURN CODE = 0 115 115 4:00p 4.5 seconds. I Bill DIRECT DIGITAL LOGGING COMPUTER PROCESSED AN RECEIVED FEB lb 1991 ~tss ~~ ~t~$ Comm~ss,o. ilCIIOFILMED LLLLLLLLLL LLLLLLLLLL IIIIIIIIII IIIIIIIIII SSSS$$'~''' ~SS II SS Ii SS.' Ii SS Ii SSSSSSSSS ii 'SSSSSSSSS II SS Ii SS Ii SS SS IIiililiii SSSSSSSS~S IIIIIIIiii SSSSSSSS DDDDDDDDD UU UU DDDDDDDDDD UU UU DD DD UU UU DD DD UU UU Db DO UU UU' DD DD UU UU DD DD UU UU. DD DD UU UU DD DD UU. UU. DD DD UU UU DDDDDDDDDD UUUUUUUUUUUU DDDDDDDDD UUUUUUUUUU MM MM PPPPPPPPPPP MMM MMM MMHH MHMM PR Pi MM MM him MM PP Pi HN hlHHH him PP Pt HM HH HH ~'~PPPPi MM MM PR H M bi H P P HH MM P P NH MH PR 333333333 3333333333 33 33 33 3333 3333 33 -33 3333.333333 333333333 666666666666 66666666666 666666666666 66 66 66 66 666666.6666 00000000 0000000000 .00 O0 O0 O0 O0 O0 00' O0 O0 O0 O0 O0 O0 O0 O0 O0 00000000~00 00000000 III JJ JJ dj dj JJJJJJJJJJJJ JJJJJJJJJJ 2222222222 222222222222 22 22 22 22 22 22 22 22 22 222222222222 222222222222 AAAA AA AA AA AA AA AA AAAAAAAAAAAA AAAAAAAAAAAA AA AA AA AA AA AA AA AA il 111 illl 11 ii I! il ii I1 II lllliliiii lillilliii NN NN HN NN NNN NN NNNN NN N N NH N N NH NN NN NN NN NN NN NN NN NN NN NN NN NNNN NN NNN NN NN AA MM Hi AAAA MHM MMI AA AA lIMMM MMHI AA AA HH MH MM MI A~ AA MM HMi'iH MI AA AA MM him MI AAAAAAAAAAAA MM Mi AAAAAAAAAAAA MM Mi AA AA MM M' AA AA HH M AA AA MH M AA AA MM H 9999999999 ii 999999999999 99 99 11il 99 99 ii 99 99 11 999999999999 ii 999999999999 ii 99 11 99 99 99 11 999999999999 iliiiiiii.i 9999999999 lliiliilll REEL HEADER **** Service name: &GSFO! Pr~viou~ re~l: HEADER Date: 91/01/30 Origin: Commentz: RECORDS Reel name: 532235 Pag~ Continuation #: Ol ~** TAPE HEADER **** Service.name: &G5FO! -Pr z',.' i ou~ tape Date: 9~/01/30 Origin: Comments: Tape name: 532235 Continuation #: 01 File namm: .001 Maximum length: 102.4 Service name: File t~p¢: LO Ver.~ion #: Previous Date: MNEM CN WN FN COUN STAT CTRY APIN LATI LONG SECT TOWN RANG EKB EDF EGL PD LHF DMF RUN TIHE DATE ~ON LUN -FL LUL ENgI WITN DL ~BD 1 ~BLi TLI BL I TL~B BHT MRT MT DFD MY-IS DFPH DFL RMF HFST ~FSS RHC I NFORMAT I ON RECORDS - CONTENTS ARCO ALASKA'INC', D.S. 9-46 API NUM: PRUDHOE BAY NORTH SLOPE ....... ALASKA ....... USA ....... 22092,000 .................. 0 Deg,. 0 Nin. O, 0 S~c 0 Deg. O, 0 Sec iON ..... tSE ..... 52 000.'. 51 000. , 20 000, , K8 ..... Ji . 2/12/90'.. 532235 7611 NORTH SLOPE NORTH SLOPE RANDELL MORRIS/LAWLER 15278.000.. 15265,500,, 0,000 ..... 0,000 ..... 14545,000, 15264,00'0, 0,000 ..... 1434,000., 0,000 ..... 0,000 ..... SEA WATER 0 Min, i.amJ ii.ii Iiil IlilIi i m I m I i · ! · I i i m ~r 0 000., ..... 0 000 ...... 0 000 ...... 0 000 ...... 0 000 ...... 0,000 ...... 6'666 ...... ,.. m i . . i i I I i · · . ,, i i i i · i i i i i i i i i m I m ! ! , $ i ,, I DATE LOGGED ! i ! m m i · · i ,m i. i I. llm! |! Ii mi 1! IIIlIII IlIIIlI I$11lll IJlllI! · i l , ! i w ; I UNIT FT FT FT FT Fl' Fl' Fl' FT FT HR HR DEGF DEGF LB/G CP OHMH OHMH DEGF OHMM TYPE CATG O 0 0 0 0 0 'O 0 0 0 0 0 3 3 3 3 0 0 0 0 0 0 0 0 0 0 3 3 4 I 1 2 2 2 2 2 2 2 2 2 2 2 SIZE 40 40 40 20 4 .34 34 2 4 4 4 2 2 2 2 '2 10 20 2.0 20 20 4 4 4 4 4 ,4 4 4 4 20 4 4 4 4 4 4 4 J2 4 CODE page ERROR MNEM MCST MCSS CS BS I N-FORMAT I ON RECORDS CONTEN~S UNIT DEGF TYPE CATG SIZE 4 12 4 4 CODE 65 68 68 Page ERROR COMMENT RECORDS ~el ~ell Well ~ell aell I Location Comment l: SURFACE: 935 1' Location Commant 2: 1 'Location Comment 3: I Location Comment 4: File Comment I: ALL PASSES WERE File Comment 2: File Comment 3: File Comment 4: FSL & 163: FWL LOGGED Ot-1 SANDSTONE MATRIX. :~ LIS tape ~r. itten b~: ANCHORAGE COMPUTING CENTER · .. Ali curve and tool mnemonicz uzed ape thoze uhich mozt clozalp match '~:~ ~:~ H~ltibucton cucve and tool mnemonics, HALLIBURTON TO SCHLUMBERGER MNEM SERVICE UNIT MNEM SERVICE DEPTH FT DEPT GR CNT AP I GR CNT CCL CNT MV CCL CNI' FCNL CNT CPS FCNL CNT NCNL CNT CPS NCNL CNT NPHI CNT SSPU NPHI CNT NRaT CNT C/C NRRT CNT UNIT FT APl CPS CPS, SSPU C/C TOP DEF' TH 14875 O0 14889 50 14889 50 14889 50 14889 50 '14889 50 '14889 50 BOTTOM DEPTH 15295,00 15263,00 15263,00 15263,00 15263.00 15263,00 15263,00 Page DATA FORMAT ENTRY BLOCKS ENTRY TYPE 16 0 ~*.* ENTRY BLOCK LEGEND TYPE DESCRIPTION 16 Datum specification block zub-tppe 0 Terminator < no more entrims ) SIZE SPECIFICA CODE 66 TIONS Pag~ DATA FORMAT MNEM SERVICE SERVICE API ID ORDER # UNiT'LOG API API APl FILE TYPE CLASS MOD # DEPT ~R CCL FCNL NCNL NPHI NRAT 5~2235 FT 0 CNT 532235 'API 94 CNT 532235 MY 94 CHT' 532235 CPS 94 CHT 532235 CPS 94 CNT 532235 SSPU 94 CNT 532235 C/C 94 · 0 0 0 310 i i 0 150 i 1 0 334 31 1 334 30 1 0 890 3 i 0 420 1 1 0 'SPECIFICATIONS PRC # SiZE LVL SHPL RC 4 0 I 68 4 O J 68 4 0 I 68 4 0 1 68 4 0 I 68 4 0 I 68 PROCESS iNDICATORS 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 Pagm DEP? GR CCL DATR FCHL RECORDS HCNL NPHI NRflT Page 15263.000 '15200,000 15i00.000 15000,000 149,00,000 0.000 69.100 57.600 88,100 73,200 0.000 .7i0 ,320 .310 °560 0.000 323,?00 368,400 183,i00 149.600 0.'000 378.~00 424,600 264,600 227,000 60,270 27.450 26.630 51,850 56,830 0,000 1,243 1.i84 1,42i 1,502 ~*******************~m~ ~** FILE TRAILER **~ File name: iGSFO~.O0! Maximum length: 1024 TRAILER RECORDS S~rvice name: Version File type: LO Next ~ile: Date: Page · ** FILE HEADER File name: .002 Maximum length: 1024 Service namel Version File type: LO Previous tile: Date: MHEI'I CONTENTS INFORMATION RECORDS UNIT TYPE CATG :SIZE CODE ERROR 'CH WN FN COUN STAT CTRY AP t N LATi LONG SECT TOWN RANG EK8 EDF £GL PD LMF DMF RUN TI HE DATE LCC SON LUN FL ..LUL ENGI WITN DD DL CBDI CBLI TLI 8L! TCS TLA8 8HT MRT MT MSS DFD MVIS DFPH DFL RM .RMF 'HFST MFSS RHC ARCO ALASKA D.S. 9-46 PRUDH.OE BAY NORTH SLOPE ALASKA USA 22092,000 ..... O.Dmg. 0 Deg, ION ..... 15E ..... 52.000.. 51,000. . 20.000. . 2/1~/90... ~0 ........ 5~22~5 7611 NORTH SLOPE NORTH SLOPE RANDELL MORRIS/LAWLER 15278.000.. 15265.500,, 0;000 ...... 0,000 ...... 14545.000., 15264,000.. 0,0'00 ...... 1434,000.,, 0,000 ...... 0,000 ...... SEA WAI'ER 0 Min 0 Nin Itl Itl INC. 0-, 000. 0,000. O. 000. O, 000. '0,000. 0.000,. 6'666", . [, 1 It ii AP1 HUH: DATE LOGGED: . · · It W · , ! i ! . 50-029-22092 2-05-90 ,i .,, . i, . , ! ! ii ! · . . m FT FT FT FT FT FT FT HR HR DEGF DEGF L 8 ,.' G CF' 0 H H t'1 0 Ft H M [~ E G F 0 H H H 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 2 i. t 2 2 2 2 2 2 2 2 2 2 40 40 40 20 2O 20 4 .34 .34 2 4 4 4 2 2 2 2 4 8 2 10 i0 20 20 20 20 4 4 4 4 4 4 4 4 4 4 .~0 20 4 4 4 4 4 4 4 i2 4 65 65 65 65 65 65 65 65 65 65 65 65 &5 65 r~5 6.,. 65 65 65 65 65 68 68 68 68 68 68 68 65 65 68 68 68 68 68 ,S 8 68 6 ~ 68 NCST MCSS CS BS I NFORMAT I ON RECORDS CONTENTS UN I T O.000 ................................................... "6661 ...... i ........................................... 0.000 .................................................... DEGF TYPE CATG SIZE 4 i2 4 4 CODE 6,8 Pag~ E R F.' 0 R 10 COMMENT RECORDS Well Location Comment Well Location Comment Well Location Comment ~ell Location Comment Well File Comment 1: Well File Comment 2: Well File Comment 3: SURFACE: 4: ALL PASSES 935~ FSL ~ 163' FWL WERE LOGGED ON SANDSTONE MATRIX, Comment 4: LIS ~ape wpitten bp: ANCHORAGE COMPUTING CENTER All cupve and tool mnemonics used ape tho~e ~hich mo~t. closely match Halliburton cur.'¢e and tool mnemonics, HALL IBURTON TO SCHLUMBERGER TOP BOTTOM MHEM SERVICE UNIT MNEM SER¥ICE UNIT DEPTH DEPTH FT DEPT FT 14875,00 GRi CNT RPI GR CNT AP1 14892, O0 CCL1 CNT NV CCL CHT MV 14092, O0 FCNL. I CNT CPS FCNL CNT CPS i 4:992, O0 NCNLI CNT CPS NCNL CNT CPS 14892, O0 NPHII CNT SSPU NPHI CNT SSPU 14892, O0 NR~TI' CHT C,.-' C NRAT CNT C,..' C 14E~92, O0 DEPTH 15295 O0 15291 50 1529i 50 15291 50 1529i 50 i529i 50 1529i 50 Page ii ~ATA · ~:~ ENTRY BLOCKS ~'~-'~ · :~ ENTRY .FORMAT SPECIFICA TYPE SIZE CODE 16 1 66 TIONS Page :~:~* ENTRY BLOCK LEGEND TYPE DESCRIPTION 16 Datum speci¢icmtion block sub-type O Tmr. minator ( no more entries ) DATA FORMAT SPEC I F I CA *** DATUH SPECIFICATION BLOCKS SERVICE SERVICE APl MNEM ID ORDER # UNIT LOG API API APl FILE TYPE CLASS NOD # DEPT 532235 FT 0 QR ONT 532235 APl 94 COL CNT 532235 HV 94 FCNL CNT 532235 CPS 94 NCNL CNT 532235 CPS. 94 NPHI' CNT 532235 SSPU 94 NRAT CNT 532235 C/C 94 0 0 0 2 310 I .3 I 150 1 3 J 334 31 3 1 334 30 3 J 890 3 3 1 420 1 3 1 TIONS PRC ~ SIZE LVL SMPL RC 4 0 1 68 4 0 ! ~8 4 0 1 68 4 0 1 68 4 0 I 68 4 O 1 68 4 0 1 68 PROCESS INDICATORS 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 Pagm 13 DATA RECORDS DEPT CCL FCNL NCNL NPH I NRAT Page 14 '1529'1 ,500 15200, 000 15100, 000 J 5000. 0'00 14900. 000 0, 000 66.600 58. 200 92. 000 67,700 0.000 .250 ,230 .270 ,440 O,O00 309.500 380,700 1cji .800 149.800 0.O0O 382,400 434,500 266,200 227,1 00 56,8'10 30.360 27.230 51 ,850 61 .240 0,000 1 .284 1, '189 1 ,383 1 ,564 FILE TRAILER File name: &GSFOJ .00'2 Maximum length: 1024 TRAILER RECORDS Verzion #: File type: LO Next ¢ilm: Date: Page 15 File'name: .003 Maximum length: !024 SePvice name: Film type: LO Version #: Previous ?ile: Date: WN FN COUN STAT CTRY APIN LATI LONG SECT TOWN RANG EK8 EDF EGL PD LMF DMF RUN TIME DATE LOC. SON LUN FL LUL ENGI WITN DD DL CBD ! CSL 1 TLI BLI TLAB BHT MRT MT DFD MVI8 DFPH DFL RM RHF HFST HFSS I NFORMAT I ON RECORDS CONTENTS UNIT ARCO ALASKA INC, D, $. 9-46 PRUDHOE BAY NORTH SLOPE ALASKA USA ....... 22092.0 O0 .................. O'Deg. 0 Min O. 0 Sec 0 Deg. 0 M in O. 0 Sec 1 ON ............. 15E ............. 52, OOO .......... 5I 00.0 I i i · i i · i I I i 20 . 0 O0 .......... KB ............. i i ! i i i i i i i i i · I 1434. O00 ....... 2712/90 ........ 30,.,. .......... 5`32235 . , .... 7611 , NORTH SLOP~ .... NORTH SLOPE RRNDELL MORE I S/LAWLER ~ 5~78.000 ....... 15265. 500 ....... · 000 0.000 ........... ~4545. 000 ~ 5264. ~ 00 ....... O. 000 ........... ~434. 000 ........ 0 '000 8.000 ........... SE~ WRTER I ! i. i' I m m I : I 8,.600 ..... 0,000 ...... O, 000 ...... 0,000 ...... 0.000 ...... 0.000 ...... O, 000 ...... ,i I i I I IiIiIilllel API NUH: 50-029.-22092 ........... [)ATE LOGGED: 12-'~ ' U,~-~ 0 ........... Illllllllllllllell&llllllllIIII IlmlilmIllllIlllltIlllllIIlllli I I· I I· · I! " Im I II I I I I I' ,I '1 · · I I. · IlII · mm Ii · Il ii i ii ! I m i I , · I lliiIii iii Ill III III · · · m · I I I I I · m i I i i I · ! i · · m i i i · i ii 1 i i i i ii I I I · i m i · I I I ~ i i i I ,t ,I m i I i I I I i|ll IiIi i I i · m i i I FT FT FT FT FT FT FT FT FT HR HR DEGF DEGF LB/'G CP OHMM OHHM DEGF OHMM TYPE CATG S I ZE CODE 0 0 40 65 0 0 40 65 0 0 40 65 0 0 20 65 0 0 20 0 0 20 65 0 0 4 0 0 34 6.,5 0 0 34 65 0 0 2 o~"~ 0 0 3 65 0 0 3 65 0 3 4 68 0 3 4 68 0 ,3 4 68 0 3 2 65 0 ,3 2 65 0 3 '2 0 0 2 79 0 0 4 68 0 0 8 65 0 0 2 79 0 0 10 65 0 0 1 0 65 0 0 20 65 0 0 20 65 0 0 ":',. 0 65 0 0 20 65 0 3 4 6 :'_.3 0 3 4 o 0 3 4 0 3 4 6:3 0 3 4 6 8 0 :3 4 68 0 2 4 68 0 4 4 68 0 1 4 68 0 I 4 68 0 2 .-c'O 65 0 2 20 65 0 2 4 68 0 2 4 68 0 2 4 68 0 2 4 68 0 2 4 68 0 2 4 68 0 2 4 68 0 2 12 65 0 2 4 68 Page ERROR '16 NCSS CS BS INFORMATION RECORDS CONTENTS UNIT O. 000 ................................................... DEGF TYPE CATG 2 2 3 SIZE 4 12 4 4 CODE 68 65 68 68 ERROR 17 COMMENT RECORD Well Location Commmnt i: SURFACE: 935' FSL & 163' FWL Well Location Comment 2: Well Location Commmnt 3: Well Location Comment 4: Well File Comment 1: ALL PASSES WERE LOGGED ON SANDSTONE MATRIX. We 11 File Comment Well File Comment 3: Well Film Comment 4: LIS tape written by: ANCHORAGE COMPUTIHG CENTER · All curvm and tool mnemonic~ u~ed arm t.ho~e which Halliburton curve and tool mnmmonics, most closelsJ match HALL I BURTON TO SCHLUNBERGER TOP BOTTOM MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT 14875,00 15295.00 ~R2 CNT APl GR CNT APl 14882.,00 15289.00 CCL2 CNT HV CCL CNT MY 14882.00 15289,00 FCNL2 CNT CPS FCNL CNT CPS 14882..00 15289.00 NCHL2 CHT CPS NCNL CNT CPS 14882.00 15289,00 NPHI2 CHT SSPU NPHI CNT SSPU 14882.00 15289.00 NRAT2 CNT C/C NRAT CHT C/C 14882,'00 15289.00 Page i8 ~ATA ENTRY BLOCKS ~:~:~ ENTRY FORMAT SPEC I F I CA TYPE SIZE CODE 16 i 66 TIONS Page · ~ ENTRY BLOCK LEGEND TYPE DESCRIPTION Datum z~eci'~ication block sub-type Terminator' ( no more entries ) DATA FORMAT DATUM SPECIFICATION 8LOCKS .~mmm SERVICE SERVICE APl AP1 APl AP1 FILE MNEM ID ORDER It UNIT LOG TYPE CLASS HOD II DEPT 532235 FT 0 0 GR CNT 532235, APl 94 310 CCL CNT 532235 MV 94 150 FCNL CNT 532235 'CPS 94~ 334 NCNL CNT 532235 CPS 94 '334 NPHI CNT 532235 SSPU 94 890 NEAT CNT 532235 C/C 94 420 SPECIFICR PRC ~ SiZE LVL SHPL J 4 '2 4 0 i 31 4 ;2 4 0 i' 30 4 '-2 4 0 i 3 4 .-"~ 4- 0 1 i- 4 '2 4 0 i TIONS RC 6.8 68 68 PROCESS iNDiCATORS 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000.000000 . 000000 000000 000000 000000 000000 000000 000000 000000 000000 Page 2O DEPT GR CCL DATA FCNL RECORDS NCHL NPHI HRAT F'.=, gm 2i 15289,000 15200.000 15100.000 15000. 000 14900,000 O, 000 ' :72, '000 55,600 8'-.3,800 7'2,400 O. 000 · 530 .150 ,870 .190 0,000 308°500. 363,400 181,200 149,600 0.000 371,800 423,200 259,300 228,000 -6,257 28,700 26,780 51.850 59,320 0,000 1.256 1.217 1.421 1.541 *** FILE TRAILER **** Fil~ n~ma: &~SF'OI.O0~ Haximum length: 1,024 TRAILER RECORDS Version #: Film type: LO Next ~ile: Date: Page *** FILE HEADER . File name: .004 Maximum.length: 1024 SePvice name: File tppm: LO Version #: Previous ~'ite: Date: WN FN COUN STAT CTRY APIN · .LATI LONG SECT TOWN RANG EK8 EDF EGL PD LHF RUN TIHE DATE LCC SON LUN FL LUL EN~I WITN DD DL CBD1 CBLI TL! · BLI TCS TLAB BHT MT DFD H¥'I S DFPH DFL RH RHF HFST HFSS AMC I HFORHRT I OH RECORDS P a g e CONTENTS UNIT TYPE CATG SIZE CODE ERROR ARCO ALASKA IHC, D. S, 9-46 PRUDHOE BAY NORTH SLOPE ALASKA USA zz092. 000 .......... 0 Deg, 0 Min, 0 0 Deg. 0 Min 0 O! ........... iON .......... 15E .......... 52.00.0 ....... 51 . OOO ....... 20.000 ..... .. , his ............ KB ........... KB ........... 143:4. 000 ..... 2/12/90 ...... 3'0 ........... 532235 .... 761 1 ,.. NORTH SLOP~- NORTH SLOPE RANDELL HOER I S/LAWL ER 15278 · 000 ....... 152'65.5'00 ....... 0.000 .......... 0,000 .......... t 4545. 000 ...... 15264,000 ...... 0 000 i w I i i I I t i I ~ 1'434 000 I I I I I I I · 0 000 i i m I · I i I I I I 0.000 .......... SEA WATER .......... I , i i . I i i i i i i 0,000 .......... 0.000 .......... 0.000 .......... 0.000 .......... 0.000 .......... O,OOO ............ illllillllllllli API HUH: 50-029-22092 ............ [)ATE LOGGED: 12-05-90 ................ IIIlIllIllmmlllllmllllmllmmllmiIllll IIiillillilliiiililllliiiIIiilllllIi I I I m I I m I I I a I "6 ....... fi". i W =1 I i I I i i m i m · i i i · m I i i · i i m i m I I I ! I I · I I · m I m I m · m I i m I i I I · I I i I i i i i I i i · i · · ! ! · m ! imiall Ii I I · I ! I i i I m I m m · il ii 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O 0 0 0 0 FT 0 3 FT 0 3 FT 0 3 0 3 0 3 0 3 0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 FT 0 3 FT 0 3 F'T 0 3 FT 0 3 FT 0 3 FT 0 3 HR 0 2 HR 0 4 DEGF 0 1 DEGF 0 1 0 2 0 2 LB/G 0 2 CP 0 2 0 2 0 2 OHMM 0 2 OHHM 0 2 DEGF 0 2 0 2 OHMH 0 2 4O 40 40 20 20 20 4 34 34 2 3 4 4 4 2 2 2 4 8 2 10 ~0 20 20 20 20. 4 4 4 4 4 4 4 4 4 4 20 4 4 4 4 4 4 4 12 4 65 65 65 65 65 65 68 65 65 65 68 65 65 79 ~ .2, 65 68 48 6@ m ii i ii m s I t I m 23 MNEM MCSS CS I NFORM~T I OH RECORDS' CONTENTS 0.000 ................................................... "~'~ ...... ' ......... i ......................... '. ...... 1 i I i i i i i · i i i · i i i i I I I I I I I I I I i I I I I I I I I I · 0 . O0 0 ................................................... UNIT DEGF TYPE _.HTG SIZE 4 i2 4 4 CODE Page ERROR 24 COMMEN T RECORDS Well Location Comment 1: Well Location Comment 2: Well LocatiOn Comment Well Location Comment Wmll File Comment 1: Wmll File Comment 2: Well Film Comment 3: SURFACE: 935' FSL & 163' FWL 4: ALL PASSES WERE LOGGED ON SANDSTONE MATRIX. Well File Comment 4: mm LIS tape written b~: ANCHORAGE COMPUTING CENTER mm All curve and tool mnemonicz used are those which mozt closmly match m~ Halliburton curve and tool mnemoni.cz. HALLIBURTON TO SCHLUMBERGER TOP BOTTOM MNEM SERVICE UNIT DEPTH FT AVG COMPUT SSPU SDD COMPUT MNEM SERVICE UNIT DEPTH DEPTH iIiI IIIIill IiIl i DEPT FT 14875,00 15295.00 RVG COMPUT ~':~H , o.~ 14892 O0 15263.00 SDD COMPUT 14892.00 15263.00 Page DATA FORMAT *** EHTRY BLOCKS ENTRY \ *** ENTRY BLOCK LEGEND TYPE DESCRIPTION 16- Datum $~ecigication block sub;type 0 TeK'mina or ( no more entries TYPE 16 .0 SIZE SPEC I F I CAT IONS CODE 66 Page 2~ DATA FORMAT ~m'~ DATUM SPECIFICATION BLOCKS m:~mm SERVICE SERVICE APl AP1 AP1 AP1 FILE MNEM ID ORDER # UNIT LOG TYPE CLASS MOD # OEPT 5322'35 FT 0 0 0 0 4 AVG COMPUT 53~235 SSPU 94 890 3 1 3 SOD COMPUT 53~35 ~4 0 0 ! 3 SPECIFICATIONS PRC # SIZE LVL SMPL RC 4 0 1 'G8 PROCESS INDICATORS 000000 000000 000000 000000 000000 000000 000000 000000 000000 27, DEPT '.3DD DATA RECORDS Page 1 526.7,. 000 1 52.00. 000 15t00.000 15000.000 1 4900,000 42°443 28. 803 26. 855 51 .850 59. 178 I 1 ,559 .973 .742 1 .477 2.140 · FILE TRAILER *********************** File name: &GsFo!.004 Maxin, um length: !024 TRAILER RECORDS Version #: File type: LO Next ~ile: ---- Date: Page 29 REEL TRAILER Service name: &GSFO't Date: 9'1/0'1/'30 Origin: Next reel: ************************** ,*** TAPE'TRAILER Service name,.t ~.:GSF'OI Next tape,{. Comments: Reel name: 532235 corn~:~i nuat i on #~ 01 Date: 91/01/30 Origin: Comments: Tape name.: .. 532235 ContinuatiOn #:. 01
