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Home My WebLink About190-085Originated: Delivered to:9-Oct-25HalliburtonAlaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun333 West 7th Avenue, Suite 1006900 Arctic Blvd.Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 2P-422A 50-103-20400-01 910312860 Kuparuk River Multi Finger Caliper Field & Processed 23-Sep-25 0 12 2P-422A 50-103-20400-01 910313140 Kuparuk River Multi Finger Caliper Field & Processed 28-Sep-25 0 13 2X-12A 50-029-21189-01 910262801 Kuparuk River Leak Detect Log Field- Final 26-Aug-25 0 14 3G-07A 50-103-20127-01 910313294 Kuparuk RiverLeak Detect LogField- Final 14-Sep-25 0 15 3K-20 50-029-23019-00 910312855 Kuparuk River Multi Finger Caliper Field & Processed 26-Sep-25 0 16 3K-32 50-029-22763-00 910292590 Kuparuk River Multi Finger Caliper Field & Processed 31-Aug-25 0 17 3Q-07 50-029-21682-00 910313132 Kuparuk River Tubing Cut Record Field- Final 28-Sep-25 0 18 3Q-09 50-029-21674-00 910313102 Kuparuk River Plug Setting Record Field- Final 13-Sep-25 0 19 3T-617 50-103-20918-00 910346072 Kuparuk River Radial Bond Record Field & Processed 25-Sep-25 0 110 1B-10 50-029-20656-00 910325714 Kuparuk RiverLeak Detect Log with IntelliScopeField & Processed 16-Sep-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T40970202-067195-176190-085201-088197-076186-194186-186225-053181-135T40974T40974T40975T40976T40977T40978T40979T40980T409813G-07A50-103-20127-01910313294Kuparuk RiverLeak Detect LogField- Final14-Sep-2501Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.10.09 13:02:18 -08'00' Originated: Schlumberger PTS- PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: rt f ' AOGCC . ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Com minion 333 W. 7th Ave, Suite 100 •-may Anchorage, AK 99501 1 1 TRANSMITTALDATE TRANSMITTAL# return via courier or sign/scan and email a copy to and CPAI. Schlumberger -Private SCANNED AUG 0 7 2019 ATransmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the Package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. SERVICE ORDER SERVICE FIELD NAME DESCRIPTION DELIVERABLE DESCRIPTION DATA Color DATE LOGGED Prints CD's 11-1-114 1H-111 1H-105 1H-113 1H-116 3M-19 3G•07A 50-029-23584-00 50-029.23581-00 50.029-20727-01 50-029-23588-00 50-029.23594-00 50-029-21737-00 50-103-20127-01 EOSH-00071 EAIS-00022 E118-00075 E118-00076 E118.00077 El 18-00078 E118-00079 I KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL1 WL WL WL WL WL (PROF (PROF-WFL (PROF-WFL IPROF•WFL ]PROF-WFL Caliper PPROF FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 15 -Jul -19 17 -Jul -19 19Ju1-19 20 -Jul -19 21 -Jul -19 22 -Jul -19 23•Ju]-19 1 1 1 1 1 1 3G-11 50.103-20133.00 E118-00081 KUPARUK RIVER WL (PROF FINAL FIELD 25 -Jul -19 1 3M-13 1B-16AL1 1A-17 1C-121 3N -14A 3G•08 50-029-21720-00 50-029-22457-60 50-029.22102.00 50-029-23015.00 50-029-21589-01 50-103.20128-00 E118-00084 EDEA -00009 E118.00085 E118-00086 EOSH-00074 EOSH-00075 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL Memory WL WL WL WL Caliper PPROF LDL (PROF LDL,Caliper LDL,Caliper FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 28 -Jul -19 28 -Jul -19 29 -Jul -19 1 -Aug -19 2 -Aug -19 3 -Aug -19 1 1 1 1 1 1 2N-317 50-103.20266.00 EOSH-00076 KUPARUK RIVER WL LDL FINAL FIELD 4 -Aug -19 1 15 return via courier or sign/scan and email a copy to and CPAI. Schlumberger -Private SCANNED AUG 0 7 2019 ATransmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the Package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /¢~.~' ~,,e ~u~er o, We,, ~,~,o~ ~,,e PAGES TO DELETE RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Complete COMMENTS: Scanned by: Beverly{~ Vincent Nathan Lowell Date: Is/ TO RE-SCAN Notes: Re-Scanned by: Bevedy Bren Vincent Nathan Lowell Date: /si NOTScanned wpd STATE OF ALASKA ALA.OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell 17 Aug Perforations r Perforate r Other 17 Set tubing patch Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development (y Exploratory r _ 190-085 3.Address: 6.API Number: Stratigraphic r Service r 50-103 20127-01 P. O. Box 100360,Anchorage,Alaska 99510 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25547 ' 3G-07A • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8767 feet Plugs(measured) None true vertical 6661 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 7668, 7672, 7692,7744 true vertical 0 feet (true vertical) 5725, 5728, 5743, 5783 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115 115 SURFACE 3614 9 5/8 3649 3006 PRODUCTION 8468 7 8503 6424 -' NOV 052013 Perforation depth: Measured depth: 7788'-7848',7906'-7926', 7942'-7962' `�� ("°> C True Vertical Depth: 5818'-5865', 5911'-5927',5940'-5956' a SCANNED Tubing(size,grade,MD,and ND) 3.5,J-55,7895 MD, 5896 TVD Packers&SSSV(type,MD,and TVD) PACKER-UPPER WEATHERFORD WIDE-PAK LE PACKER @ 7668 MD and 5725 TVD PATCH-PATCH: SPACER PIPE, SNAP LATCH, SEAL ASSEMBLY @ 7672 MD and 5728 ND PACKER-LOWER WEATHERFORD WIDE--PAK LE PACKER @ 7692 MD and 5743 ND PACKER-BAKER'HB' RETRIEVABLE PACKER @ 7744 MD and 5783 TVD SSSV-CAMCO TRDP 1A-SSA @ 1848 MD and 1810 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): NA 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 NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development F ' Service r Stratigraphic r 16.Well Status after work: Oil 17 • Gas r WDSPL r Daily Report of Well Operations x GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 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 Brent Rogers/Kelly Lyons Email n1617( cop.com Printed Name ,,- Lyons / Title Problem Wells Supervisor Signature Phone:659-7224 Date 11-3-13 Form 10-404 Revised 10/2012 ` 1.16^,3 Submit Original Only /..z/a. RBDMS NOV - 5 • • RECEIVED ConocoPhillips NOV 0 5 2013 Alaska �� P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 November 3, 2013 Mr. Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Seamount: Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 3G-07A (PTD 190-085) for a retrievable patch set in the tubing above the packer. Please call Brent Rogers or myself @ 659-7224 if you have any questions. Sincerely, Kelly Lyons ConocoPhillips Problem Wells Supervisor Enclosures • • 3G-07A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/04/13 (AC EVAL) : Re-TIFL FAILED due to IA inflow of 3342'and 200 psi increase. Initial T/I/O= 220/1120/820. IA FL @ 7162' (OV @ 6710'). SI well and LG. Stack out T for 1 hour. T/I/O= 1200/1200/600. Bled IA for 1 hour. T/I/O= 1280/760/600. IA FL @ 3849' (inflow of 2861'). T @ FL 5843'. 15 min T/I/O= 1320/840/500. IA FL @ 3510' (inflow of 339'). T FL @ T FL @ 5843'. 30 min T/I/O= 1380/890/500. IA FL @ 3453' (inflow of 57'). T FL @ 5843'. 45 min T/I/O= 1420/930/500. IA FL @ 3415' (inflow of 38'). T FL @ 5843'. 60 min T/I/O= 1460/960/500. IA FL @ 3368' (inflow of 47'). T FL @ 5843'. Final T/I/0= 1460/960/500. 06/27/13 LOG LEAK DETECT W/ DHD. STACK TUBING OUT W/IA GAS, JUMPER IA TO FLOWLINE AND PRODUCING WELL THROUGH LEAK. LEAK FOUND IN GLM#8 AT 7687'. LOG CORRELATED TO TUBING DETAIL RECORD DATED SEP 1990. WELL LEFT SHUT IN AND TURNED OVER TO DSO. 08/12/13 LOGGED 24 ARM CALIPER FROM 7800'TO SURFACE. RIG DOWN, TURN WELL OVER TO DSO. 10/17/13 SET 2.71"WFD ER PACKER @ 7697' RKB (MID ELEMENT), SET ER TEST TOOL IN ER PACKER @ 7697' RKB, LEAVE LRS TO CIRC OUT WELL WITH 200BBLS SW AND CMIT: TEST TO 2500PSI PASSED, SEE ATTACHED REPORT, IN PROGRESS CMIT passed. Initial T/I/0=1150/1150/750. Start CMIT TxIA T/I/0=2500/2500/840, 15 min T/I/0=2500/2500/840, 30 min T/I/0=2500/2500/840. 10/20/13 SET WIDE-PACK TEST TOOL IN LOWER ANCHOR @ 7697' RKB. GOOD CMIT-TxIA TO 2500#. SET UPPER PATCH IN LOWER ANCHOR, TOP OF PATCH @ 7672' RKB. TEST PATCH TO 2500#WITH TEST TOOL. GOOD MIT-T TO 2500#. BLEED IA DOWN TO 500# AND GAS LIFT VALVES APPEAR TO BE HOLDING...READY FOR DSO. 10/28/13 (AC EVAL) : RE-TIFL(PASSED). Initial T/I/O = 150/1075/880. IA FL @ 6710' (Station#6, OV). SI wellhead @ WV&double block AL. Stacked WHP's to 950/950/700 in 30 min. Bled IA from 950 psi to 475 psi in 1 hour. T/I/O = 1000/475/550. IA FL @ same location. Monitor for 1 hour. 15 min T/I/O = 1000/475/540. 30 min T/I/O = 1020/475/540. IA FL @ same location. 45 min T/I/O= 1050/475/540. 60 min T/I/O = 1080/475/540. IA FL @ same location (Passed). Bled OA to 400 psi in 2 min (gas) until fluid to surface. Final T/I/O = 1080/475/400. Summary 'Set Weatherford retrievable tubing patch. Integrity confirmed with passing TIFL. KUP PROD 3G-07A ConocoPhiihps a Well Attributes Max Angle&MD TD Alaska,Inc. - Wellbore API/DWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) u,,„,c upe 501032012701 KUPARUK RIVER UNIT PROD 52.57 5,600.00 8,781.0 ... Comment H25(ppm) Date Annotation End Date KB-Grd(k) Rig Release Date 3G-07A,10/30/20131:27:52 PM SSSV:TRDP 145 12/4/2011 Last WO: I 35.00 7/18/1990 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: SLM 8,067.0 5/19/2013 Rev Reason:GLV C/O,SET PATCH osborl 10/30/2013 laatalaaa®aOWapt HANGER;332 Casing Strings I1i I� II { Casing D cr p[ion OD(in) ID(in) Top(ftKB) Set Depth(kKB) Set Depth(ND) Wt/Len(I Grade Top Thread I `�tt ll 'I- CONDUCTOR 16 15.062 36.0 115.0 115.0 62.58 H-40 ' il Casing Descr ption OD(in) ID(in) Top(ftKB) Set Depth(kKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread III SURFACE 95/8 8.765 35.0 3,648.5 3,005.7 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(kKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 35.0 8,502.7 6,423.9 26.00 J-55 BTC ._,`Tubing Strings CONDUCTOR,36.0-115.0 Tubing Description I String Ma..I ID(in) (Top(ftKB) (Set Depth((t..f Set Depth(ND)(...I Wt(lb/ft) (Grade I Top Connection TUBING 31/2 2.992 33.2 7,89491 5,902.4 9.30 L-80 BTC MOD Completion Details Nominal ID SAFETY VLV 1,848.1 t. Top(ftKB) Top(ND)(ftKB) Top Inc!(°) Item Des Com (in) III 33.2 33.2 0.04 HANGER WKM GEN IV TUBING HANGER 3.500 I 1,848.1' 1,810.0 31.32 SAFETY VLV CAMCO 3.5"TRDP-IA-SSA SSSV 2.812 GAS LIFT;2,690.5 .3.- 7,729.9 5,772.7 39.06 PBR BAKER PBR w/10 STROKE 3.000 7,743.6 5,783.3 38.89 PACKER BAKER'HB'RETRIEVABLE PACKER 63K It SHEAR OR 2.890 ROTATE RELEASE 7,778.1 5,810.3 38.46 BLAST RINGS RICKERT BLAST RINGS(2) 2.992 SURFACE;35.03,648.5-A 7,8402 5,859.1 37.84 BLAST RINGS RICKERT BLAST RING(1) 2.992 7,875.3 5,886.9 37.55 NIPPLE AVA BPL PORTED NIPPLE w/2.75"SEAL BORE& 2.697 GAS LIFT;4,290.1 ` 2.697"BOTTOM NO GO 7,884.1 5,893.9 37.47 XO Reducing CROSSOVER 3.5"x2.875" 2.441 GAS LIFT;4,909.4 7,884.8 5,894.4 37.47 SEAL ASSY BAKER LOCATOR/SEAL ASSEMBLY 2.406 7,885.8 5,895.3 37.46 LOCATOR BAKER LOCATOR 2.992 GAS LIFT;5,531.9 7,886.8 5,896.1 37.45 PACKER BAKER'DB'PERMANENT PACKER 3.250 GAS LIFT;6,1512 e 7,890.5 5,899.0 37.42 SBE BAKER SEAL BORE EXTENSION 3.250 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT;6,710.4 Top(ND) Top Inc! Top(kKB) (kKB) (°) Des Com Run Date ID(!n) I 7,668.0 5,724.9 39.88 PACKER UPPER WEATHERFORD WIDE-PAK LE PACKER 10/24/2013 1.800 GAS LIFT;72390 7,672.0 5,728.0 39.83 PATCH PATCH:SPACER PIPE,SNAP LATCH,SEAL 10/24/2013 1.730 IF ASSEMBLY(OAL 30.61') _. PACKER;7,668.0 _ - 7,691.8' 5,743.2 39.55 PACKER LOWER WEATHERFORD WIDE--PAK LE PACKER 10/18/2013 1.800 V_ ` g ' 7,875.2 5,886.8 37.55 SLEEVE-C AVA BPC sleeve(29"OAL,2.31 ID) 5/25/2013 2.310 (� PATCH;7,672.0 GAS LIFT; 8,357.0 6,293.4 27.36 FISH TBG TAIL CUT TBG TAIL STRING CUT on 1/27/97; 1/27/1997 2.441 Knocked Off Downhole 8,370.0 6,305.0 27.05 FISH NO GO Camco'D'Nipple w/Dual Panex Guages 1/27/1997 2.250 FISH(JUNKED) PACKER;76511.; i_,g 8,375.0 6,309.5 26.94 FISH SHEAR OUT Baker(JUNKED) 1/27/1997 2.441 8,376.0 6,310.4 26.91 FISH TUBING TAIL(JUNKED) 1/27/1997 2.441 PBR;7,729.9 Perforations&Slots 7,743.6 Shot PACKER; `_ Dens ■.f Top(ND) Ste(ND) (shots/f r Top(kKB) Btm(kKB) (ftKB) (kKB) Zone Date t) Type Com PRODUCTION,7,759.9 7,788.0 7,848.0 5,818.0 5,865.3 C-4,C-3,C-2, 9/17/1990 10.0 IPERF 60 deg.phasing;4 1/2" 1 C-1,3G-07A Csg Gun IPERF,7,788.0-7,848.0- _ 7,906.0 7,926.0 5,911.3 5,927.3 A-3,3G-07A 9/17/1990 4.0 IPERF 180 deg.phasing;4 1/2" Csg Gun 1 s 7,942.0 7,962.0 5,940.1 5,956.3 A-2,3G-07A 9/17/1990 4.0 IPERF 180 deg.phasing;4 1/2" Csg Gun Mandrel Inserts !i. St €€ at1 SLEEVE-C;7,875.2, _ on Top(ND) Valve Latch Port Size TRO Run C NIPPLE;7,875.3 [42,1: No Top(ftKB) (kKB) Make Model OD(in) Sery Type Type (!n) (psi) Run Date m 1 2,690.5 2,401.6 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,296.0 8/30/2009 2 4,290.1 3,419.1 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,288.0 8/30/2009 SEAL ASSY,7,684.9 = 3 4,909.4 3,810.5 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 8/30/2009 I. 4 5,531.9 4,197.8 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,278.0 8/30/2009 PACKER;7,886.8 5 6,151.2 4,598.8 MERLA TMPD 1 GAS LIFT GLV BK 0.188 1,302.0 8/30/2009 6 6,710.4 5,007.2 MERLA TMPD 1 GAS LIFT OV BK 0.250 0.0 5/19/2013 SBE;7,8906 7 7,239.0 5,401.6 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 8/29/2009 8 7,680.7 5,734.6 CAMCO MMG-2 11/2'GAS LIFT Patch 10/24/2013 9 7,759.9 5,796.0 CAMCO MMG-W 11/2 PROD DMY RK 0.000 0.0 3/12/1999 IPERF;7.9050-7,926.0- Notes:General&Safety End Date Annotation IPERF;7,942.07,9620-- 1/27/1997 NOTE:TUBING CUT @ 7885';TTL PUSHED DOWNHOLE 2/4/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 FISH,8,357.0 FISH;8,370.0 FISH;8,375.0 FISH;6376.0 PRODUCTION,35 0-8,502.7 . • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 12, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~~_ o~,s ~~~ 07~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped February 15~" 2009. The corrosion inhibitor/sealant was pumped March 10~` and 11 ~', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ~~ F r M.J. Ioveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off I~_ Report of Sundry Operations (10-404) Kuparuk Field Date 3/12/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3G-02 190-137 SF NA 16" NA 1.7 3/11/2009 3G-03 196-122 SF NA 16" NA 1.7 3/11/2009 3G-05 190-075 12'6" 1.80 19" 2/15/2009 4.25 3/10/2009 3G-06 190-069 8'4" 1.20 18" 2/15/2009 3.5 3/10/2009 3G-07A 190-085 25'6" 3.40 18" 2/15/2009 3.4 3/10/2009 3G-11 190-076 22" NA 22" NA 4.25 3/10/2009 3G-14A 197-251 SF NA 17" NA 3.4 3/10/2009 3G-17 190-122 5' 0.80 16" 2/15/2009 2.55 3/10/2009 3G-18 190-125 18" NA 18" NA 4.25 3/10/2009 3G-19A 201-106 18" NA 18" NA 2.55 3/10/2009 3G-21A 198-052 21' 2.80 2'10" 2/15!2009 12.75 3/10/2009 3G-25X 196-136 SF NA 7" NA 2.55 3/10/2009 Schlumberger -DCS 2525 Gambell Street, Suite 400 ,,, Anchorage, AK 99503-2838 ATTN: Beth ~,~,`~~~ ~~~ ~. ~D~ s Well Job # Log Description NO. 5063 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 02/09/09 1 L-13 11978475 PRODUCTION PROFILE ~ ~- L `j 08/16/08 1 1 2A-26 AZJZ-00010 USIT ~- ~j 01/16/09 1 1 iD-141A ANHY-00041 FLOWING BHP -Q 01/21/09 1 1 3K-15 B04C-00004 INJECTION PROFILE ' l 01/21/09 1 1 1E-105 AZED-00019 INJECTION PROFILE 01/23/09 1 1 1 E-119 AYS4-00023 INJECTION PROFILE J 01/23/09 1 1 3J-01 AYS4-00024 INJECTION PROFILE , -r 01/24/09 1 1 2V-06 AZED-00022 INJECTION PROFILE J$~- 1 01/26/09 1 1 2K-22 AZED-00024 LDL "~ r'~-,~ J 01/28/09 1 1 2L-301 AZED-00025 SBHP SURVEY 01/29/09 1 1 1 R-03A ANHY-00045 INJECTION PROFILE T ~'} $- 02/09/09 1 1 2B-11 AZED-00028 INJECTION PROFILE 02/01/09 1 1 2F-16 AZED-00029 INJECTION PROFILE U 02/02/09 1 1 3J-05 AZED-00030 INJECTION PROFILE 02/03/09 1 1 3G-07A AYS4-00033 PRODUCTION PROFILE ( 02/04/09 1 1 1 D-03 ANHY-00042 LDL ~ - ' - 02/05/09 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~~...f THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 27, 2000 P M C:LOP,.~M~LM.DOC E E L E W A T E R IA L U N D ER TH IS M A.R K ER · ~,,.~ STATE OF ALASKA "~-~. ALASKA OIL AND GAS CONSERVATION COMMISSION 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 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 2538' FNL, 220' FWL, Sec. 24, T12N, R8E, UM At top of productive interval 1067' FSL, 1955' FEL, Sec. 13, T12N, At effective depth 1141' FSL, 1818' FEL, Sec. 13, T12N, At total depth 1219' FSL, 1818' FEL, Sec. 13, T12N, R8E, UM R8E, UM R8E, UM 12. Present well condition summary Total Depth: measured 8 7 6 7 fe et true vertical 6650 feet 6. Datum elevation (DF or KB) RKB 89 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3G-07A 9.~Permit n umber~~al_..~~ (~ 10. APl number 5o-103-20127-01 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) Original 3G-07 P&A and 3G-07A sidetracked off of cement plug @ 5600' Effective depth: measured 841 6 feet Junk (measured) None true vertical 6346 feet Casing Length Size Cemented Structural Conductor 8 0' 1 6" 225 Sx AS I Surface 3 61 2' 9 - 5 / 8" 755 Sx AS III & Intermediate 525 Sx Class G Production 8467' 7" 225 Sx Class G & Liner 171 Sx Class G tail Perforation depth: measured 7788'-7848', 7906'-7.926', 7942'-7962' true vertical 5818'-5865', 5911'-5927', 5940'-5956' Tubing (size, grade, and measured depth) Measureddepth True ve~icaldepth 115' 115' 3649' 3006' 8502' 6423' ORIGINAL 3.5", 9.3#/ft., J-55 @ 6976', 3.5", 9.3#/ft., L-80 @ 7871', 2.875". 6.5#/ft., J-55 @ 7893' Packers and SSSV (type and measured depth) i? Packers: Baker HB @ 7731' & Baker D @ 7874'; SSSV: Camco TRDP-1A-SSA @ 1835' ~:~' 13. Stimulation or cement squeeze summary Fracture Stimulate 'A' Sands on 3/14/97 .... ~ · ........ Intervals treated (measured) ~ 7906'-7926' 7942'-7962' !,...~ ~)i~ ! .... :: ~.~-~ '~ ~ ' ~ ~ .......... ~, ..... . ' ,;:;7'., _,{ °,~ Treatment description including volumes used and final pressure : . Pumped 145.9 Mlbs of 20/40 and 12/18 of ceramic proppant into formation, fp was 4339 psi 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2 5 0 140 310 1019 174 Subsequent to operation 799 940 747 1031 180 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best'of my knowledge. Signed ~~~ ~'~(5')z¢¢i Form 10-4~0'4 R~8 Title Wells Superintendent Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT '' WELL SERVICE REPORT ~ K1 (G-07A(W4-6)) WELL JOB SCOPE JOB NUMBER 3G-07A FRAC, FRAC SUPPORT 0303972118.2 DATE DAILY WORK UNIT NUMBER 03/14/97 FRAC A SANDS , DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 5 (~) Yes ('~) NoI ® Yes O No DS-GALLEGOS JORDAN FIELD AFC# CC~ DAILY COST ACCUM COST Signed ESTIMATE KD1675 230DS36G L $78,600 $92,614 Initial Tb.q Press Final Tbq Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 1 600 PSI 0 PSI 700 PSI 0 PSII 1 00 PSII 0 PSI DALLY SUMMARY PUMPED A SAND FRAC TO COMPLETION. 145909 LBS PROPPANT IN PERFS W/727 LBS PROPPANT IN PIPE AFTER FLUSH. TIME 07:00 11:30 11:38 12:27 13:59 17:00 LOG ENTRY MIRUDOWELLFRACUNIT. SBFORSNOW REMOVAL. SBFORVALVESERVICETOLOCKEDUP WKM VALVE. TGSM. SET TREE SAVER AND PT SURFACE EQUIP TO 8840 PSI. PUMP BREAKDOWN STAGE. ISIP 1940 PSI. SD AND MONITOR PRESSURE. PUMP DATA FRAC STAGE. ISlP 2190 PSI. ADD 15 BBL TO PAD. PUMP A SAND FRAC AS DESIGNED. ADD PROPPANT TO LAST STAGE, TO FLUSH. TOTAL PROPPANT PUMPED 146636 LBS. 6035 LBS #20/40; 140601 LBS #12/18 RDMO SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $1,668.00 APC $5,200.00 $6,700.00 DOWE LL $68,400.00 $68,400.00 HALLIBURTON $0.00 $7,302.00 LI~-FLE RED $5,000.00 $8,545.00 TOTAL FIELD ESTIMATE $78,600.00 $92,615.00 ~" ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Operation Shutdown __ Stimulate X Plugging_ Pull tubing __ Alter casing ~ Repair well ,. 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service Perforate Other 6. Datum elevation (DF or KB) X RKB 89 _ 7. Unit or Property name _ Kuparuk River Unit 8. Well number 3G-07A 9. Permit number/approval number 10. APl number 50-103-20127-01 11, Field/Pool Kuparuk River Oil Pool Plugs (measured) Original 3G-07 P&A and 3G-07A sidetracked off of cement plug @ 5600' Junk(measured) None 4. Location of well at surface 2538' FNL, 220' FWL, Sec. 24, T12N, R8E, UM At top of productive interval 1067' FSL, 1955' FEL, Sec. 13, T12N, At effective depth 1141' FSL, 1818' FEL, Sec. 13, T12N, At total depth 1219' FSL~ 1818° FEL~ Sec. 13, T12N~ 12. Present well condition summary Total Depth: measured 8 7 true vertical 66 R8E, UM R8E, UM R8E, UM 67' feet 50' feet Effective depth: measured 841 6' feet true vertical 6346' feet feet ,, Casing Length Size Structural Conductor 8 0' 1 6" Surface 3 61 2' 9 - 5 / 8" Intermediate Production 8467' 7" Liner Cemented 755 Sx AS III & 525 Sx Class G 225 Sx Class G & 171 Sx Class G Tail Perforation depth: measured 7788'-7848', 7906'-7926', 7942'-7962' true vertical 5818'-5865', 5911'-5927', 5940'-5956' Tubing (size, grade, and measured depth) 3-1/2" 9.2#, EUE, ABMOD, IPC, w/Tail @ 7893' Packers and SSSV (type and measured depth) SSSV: Camco TRDP-1A-SSA (1835')~ Packer: 13. Stimulation or cement squeeze summary C Sand Nitrogen Stimulation Intervals treated (measured) 7788'- 7848' Treatment description including volumes used and final pressure Pumped 66 MSCF N2. Beat out plug @ 6700 psi WHTP. 14. Reoresentative Daily Average Production or In!ection Data C Sand Only OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Measured depth True vertical depth 115' 115' 3649' 3006' SEP2 7) 1994 N~ska 0ii & Gas Cons. Commission Anch0ra~e Baker HB (7731')~ Packer: Baker Model 'D' (7874') Tubing Pressure 15. Prior to well operation (C Sand only) Subsequent to operation {C Sand only/) Attachments Copies of Logs and Surveys run m Daily Report of Well Operations X 0 0 0 600 163 475x/x 396 322 480 159 16. Status of well classification as: Water Injector__ Oil X Gas ~ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,4~ ~/F~. /~- ~ Title Wells Superintendent Fnrm ln.,tn,~ nn,, I"IO/19/Bt~ Date ~1 IRI~IIT Ikl 1'311DI I~Z~TI: ARCO/~iaska, inc. KUPARUK RIVER UNIT WELL SERVICE REPORT WELL DATE DAY Y TIME DESCRIPTION OF WORK OPERATIO~ AT REPORT TIM~ [~OMPLETE I--] INCOMPLETE . q FIELD EST: .~. $ /~,,Tq/~ AFC/CC ~ ACCUMULATED COST LOG ENTRY PAGE 1 OF I Gas Cons. commission I-~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather [Temp. I Chill Factor t Visibility I Wind Vel' Report oF °F miles knots AR3B-7031 298-3481; WELL COMPLETION OR RI:COMPLETION RI:PORT AND LOG I Status of Well Classification of Service Well OIL [] GAS ~ SUSPENDED r-~ ABANDONED E~ SERVICE r'-'] 2 Name of Operator 7 Permit Number c~O.. ARCO Alaska, Inc 'e9-6,4~1~-,,~/C 3 Address 8 APl Number P.O. Box 100360, Anchora~le, AK 99510-0360 ~i~:i'~-~i~i~-~ . ~ 50-103-20127 i . 4 Location of well at surface i~,/~ ;~-''~ ~/~ [.(~'F~ON~ 9 Unit or Lease Name 2538' FNL, 220' FWL, SEC 24, T12N, R8E, UM ~ /~//;~ ~. ~. ~.~.__ ~ VEEIJ:~ KUPARUK RIVER At Top Producing Interval ~ ,,~j~.j J~ E[~ ~ ,~3~,q~m~ 10 Well Number 938' FSL, 2072' FEL, SEC 13, T12N, R8E, UM ~~ I~. ~ ~ 3G-7A At Total Depth ~ 11 Field and Pool 1196' FSL, 1767' FEL, SEC 13, T12N, R8E, UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 89', PAD 54' GLJ ADL 25547 ALK 2661 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. I 15 Water Depth, if offshore 116 No. of Completions 7/02/90. 7/09/90. "9~,, I ,.°/09.J NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey ]2o Depth where SSSV set I 21 Thickness of permafrost 8550' M D, 6459' TVD 8416' MD, 6346' TVD YES ~-~ NO E]I 1848' feet MDI 1600' APPROX 22 Type Electric or Other Logs Run EWR/CN/S FD/CET/DGR/CBL/GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP DO'FI'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 225 SX AS 1 9-5/8" 36# J-55 SURF 3649' 12-1/4" 755 SX ASIII, 525 SX CLASS G 7" 26# J-55 SURF 8502' 8-1/2" 572 SX CLASS G, 171 SX CLASS G TAIL 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) 3-1/2" 7906' 7744', 7887" 7788'-7848' @ 10 SPF MD, 5818'-5865' TVD 7906'-7926' @ 4 SPF MD 5911'-5927' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 7942'-7962' @ 4 SPF MD 5940'-5956' TVD DEPTH INTERVAL (MD) J AMOUNT & KIND OF MATERIAL USED SEE AI-I'ACHED ADDENDUM 27 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 ] GAS-OIL RATIO I TEST PERIOD ,~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL ;OILGRAVITY-API (corr) Press. 24-HOUR RATE ~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ' ORIGINAL 3G-7 ( P & A ) & 3G-7A SIDETRACKED OFF OF CEMENT PLUG @ 5600'J E( EIVED AU G 1 9 1991 Alaska 0il & Gas Cons. C0mn |sS|l nchorage GEOLOGIC MARKERS FORMATION TESTS , , NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 7786' 5816' NA KUPARUK C BOTTOM 7849' 5865' KUPARUK A TOP 788g' 5897' KUPARUK A BOTTOM .8042' 6022' 31~. LIST 0F ATTACHMENTS GYRO, FRAC, & REPORT OF OPERATIONS 32-. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title AREA DRILLING ENGINEER Date ~//~'/~'// ~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam 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 Injectioni'Shut-in, Other-explain. Item 28: If no cores taken, indicate "none',. Form 10-407 ADDENDUM WELL: 6/25/91 3G-07A Frac KRU "A" sand peals from 7906'-7926', 7942'-7962' @ 4spf in 10 stages as follows: Stage 1. Pmp 45 bbls YF240D XL GW @ 25 bpm 7700-6650 psi Stage 2 Pmp 75 bbls YF240D Non XL GW @ 25 bpm 6650-4362 psi ISIP: 1789 FRAC GRAD: .74 PERF FRIC: 205 Pmp 40 bbls YF240D XL GW @ 5 bpm 2740-3290 psi Pmp 80 bbls YF240D XL GW @ 25 bpm 3290-5000-4765 psi Pmp 15 bbls Yf240D XL GW w/2ppg 16/20 Carbolite @ 25 bpm 4765- 4715 psI Pmp15 bbls YF240D XL GW w/4ppg 16/20 Carbolite @ 25 bpm 4715- 4573 ps~ Pmp 15 bbls YF240D XL GW w/6ppg 16/20 Carbolite @ 25 bpm 4573- 4348 psI Pmp 20 bbls YF240D XL GW w/7ppg 16/20 Carbolite @ 25 bpm 4348- 4252 ps~ Pmp 10 bbls YF240D XL GW w/8ppg 16/20 Carbolite @ 25 bpm 4252- 4243 ps~ Pmpl 6 bbls YF240D XL GW w/10ppg 16/20 Carbolite @ 25 bpm 4243- 4300 ps~ Pmp 22 bbls FLUSH 4300-7683 psi 22bbls into flush 5.4# @ peals Stage 3 Stage 4 Stage 5 Stage 6 Stage 7 Stage 8 Stage 9 *Stage 10 * Screened out Average Pressure: Fluid to recover: Sand in zone: Sand in casing: 4500psi 302 H20, 24 Diesel 4,250# 16/20 Carbolite 10,352# 16/20 Carbolite D~illing s~erintendent ~ R£'C£1VED AUG 1 9 1991 Alaska 0il & Gas Cons. ~,urnmissien Anchorage AR~ ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: LEASE: API: PERMIT APPROVAL: AFE: WI: 3G-07A NORTH SLOPE KUPARUK RIVER UNIT ADL 25547 ALK 2661 50-029-22111 90-64 AK4940 55.252072 ACCEPT: 09/17/90 RELEASE: 09/18/90 OPERATION: COMPLETION RIG: NORDIC 09/17/90 (18) TD: 0 PB: 0 SUPV:DEB 09/18/90 (19) TD: 0 PB: 0 SUPV:DEB TESTING BOPE 9-5/8"@ 3649'- MW:10.9 NaCl MOVE RIG TO 3G-07, Nil BOPE DAILY:S16,018 CUM:$1,447,708 ETD:S1,447,708 EFC:$1,800,000 . RUNNING 3-1/2" COMP 9-5/8"@ 3649' MW:10.9 NaCl FINISH BOP TEST, RU HLS FOR PERFING, PERF 7942'-7962', 7906'-7926' (4SPF), 7848'-7808' (10 SPF), RUN 5.98" GAUGE RING AND JUNK BASKET, RUN PERM PACKER AND TUBING TAIL, POH, RD HLS E-LINE, RUN 3-1/2" SELECTIVE SINGLE OCMPLETION DAILY:S73,550 CUM:$1,521,258 ETD:S1,521,258 EFC:$1,800,000 09/19/90 (20) TD: 0 PB: 0 SUPV:DEB RIG RELEASED 9-5/8"@ 3649' MW:10.9 NaC1 RUN 3-1/2" COMP ASSBY, STAB INTO LOWER PKR, SPACE OUT 1', RILDS, SET RET. PKR, BOLDS, PU TO ll0K# TO SHEAR PBR (NO SHEAR), SLACKOFF TO 60K# AND PRESS UP, SHEARED PBR AT 1700 PSI, VERIFY PBR IS SHEARED, RELAND TBG, RILDS, TST SSSV, SET BPV, ND STACK, NU WKM 3-1/8" 5KSI TREE, PULL BPV, SET TP, TEST TREE AND PKF TO 5000 PSI, TEST CL AND REOPEN SSSV, SHEAR SOS AT 3600 PSI, REVERSE CIRC 12 BBLS DIESEL CAP INTO ANNULUS, INJECT 4 BBLS DIESEL CAP INTO TBG, CHECK VALVE HELD SHUT-IN AND SECURE WELL DAILY:S191,611 CUM:$1,712,869 ETD:S1,712,869 EFC:$1,800,000 SIGNATURE: RECEIVED AUG 1 9 1991 Alaska 0/I & Gas Cons. Commisslen Anchorage DATE: :REAT LAND DIRECTIONAL DRILLING, INC. llient .... : ARCO ALASKA, INC. 'ield ..... : KUPARUK RIVER ~ell ...... : KRU 3G-7~ lection at: N,41.78,E :urveyor..: M. NAIRN MEAS INCLN DEPTH ANGLE iqlCI OFILMED ORI61NA[ 08/29/90 Computation...: RADIUS OF CURVATURE Survey Date...: 08/12/90 RKB Elevation.: 89.00 ft API Number .... : 50-103-20127-01 Job Number .... : AK0890G238 VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE BEARING FROM-WELL-HEAD CLOSURE DL ( DISTNCE BEARING /100 100 0.13 200 0.13 300 0.24 400 0.32 500 0.35 600 0.47 700 0.62 800 0.72 900 0.99 1000 3.94 100.0 11.0 0.0 N 46.44 W 0.1 N 0.0 W 200.0' 111.0 0.0 N 68.18 W 0.2 N 0.2 W 300.0 211.0 -0.1 N 51.72 W 0.4 N 0.5 W 400.0 311.0 -0.0 N 32.76 W 0.7 N 0.8 W 500.0 411.0 0.2 N 18.77 W 1.3 N 1.1 W 600.0 511.0 0.7 N 2.31 E 2.0 N 1.2 W 700.0 611.0 1.5 N 11.45 E 2.9 N 1.1 W 800.0 711.0 2.4 N 8.16 E 4.1 N 0.9 W 900.0 811.0 3.7 N 13.86 E 5.5 N 0.6'W 999.9 910.9 7.9 N 41.39 E 9.3 N 1.4 E 0.1 N 23.22 W 0.13 0.3 N 46.27 W 0.00 0.6 N 53.10 W 0.11 1.1 N 48.41 W 0.08 1.7 N 40.71 W 0.03 2.3 N 31.17 W 0.12 3.1 N 20.32 W 0.15 4.2 N 12.22 W 0.10 5.6 N 6.15 W 0.27 9.4 N 8.42 E 2.95 1100 9.82 1200 11.11 1300 12.84 1400 14.45 1500 15.59 1099.1 1010.1 19.7 N 56.03 E 17.2 N 10.4 E 1197.4 1108.4 37.3 N 55.22 E 27.4 N 25.3. E 1295.3 1206.3 57.6 N 53.35 E 39.6 N 42.2 E 1392.4 1303.4 80.8 N 51.18 E 54.0 N ' 60.8 E 1489.0 1400.0 106.4 N 49.04 E 70.6 N 80.7 E 20.1 N 31.'06 E 5.90 37.4N 42.72 E 1.29 57.8 N 46.85 E 1.73 81.3 N 48.42 E 1.62 107.2 N 48.82 E 1.15 ' 1600 17.92 ' 1700 23.76 ' 1800 27.92 ' 1900 34 .'99 ' 2000 38.29 1584.8 1495.8~ 135.1 N 46.20 E 90.0 N 102.0 E 1678.2 1589.2 170.6 N 43.13 E 115.3 N 127.0 E 1768.2 1679.2 214.2 N 38.94 E 148.2 N 155.6 E 1853.4 1764.4 266.3 N 40.39 E 188.3 N 188.9 E 1933.6 1844.6 326.0 N 40.88 E 233.6 N 227.8 E 136.1 N 48.57 E 2.35 171.6 N 47.76 E 5.86 214.9 N 46.40 E 4.26 266.7 N 45.09 E 7.09 326.3 N '44.27 E 3.31 2100 43.36 2009.3 1920.3 391.3 N 41.69 E 282.7 N 270.9 E 391.5 N 4'3.77 E 5.08 'Survey Codes: 7/GYRO KRU3G7) [RU 3G- 7~ MEAS INCLN DEPTH ANGLE 2200 46.20 2300 48.05 2400 50.06 2500 49.38 2600 48.95 2700 52.14 2800 52.13 2900 51.53 3000 51.20 3100 50.89 3200 50.86 3300 50.24 3400 49.46 3500 50.72 3600 50.33 3700 50.71 3800 50.39 3900 50.46 4000 49.47 4100 49.05 4200 48.98 4300 50.64 4400 50.97 4500 51.02 4600 51.06 4700 50.75 Survey Codes: VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 2080.3 1991.3 461.7 2148.3 2059.3 535.0 2213.8 2124.8 610,5 2278.5 2189.5 686.8 2343.9 2254.9 762.5 2407.4 2318.4 839.7 2468.8 2379.8 918.6 2530.6 2441.6 997.1 2593.0 2504.0 1075.2 2655.9 2566.9 1153.0 2719.0 2630.0 1230.5 2782.5 2693.5 1307.8 2847.0 2758.0 1384.2 2911.2 2822.2 1460.9 2974.7 2885.7 1538.0 3038.3 2949.3 1615.1 3101.9 3012.9 1692.2 3165.6 3076.6 1769.1 3229.9 3140.9 1845.5 3295.2 3206.2 1921.3 3360.7 3271.7 1996.7 3425.3 3336.3 2073.0 3488.5 3399.5 2150.3 3551.4 3462.4 2227.9 3614.3 3525.3 2305.6 3677.4 3588.4 2383.1 RECORD OF SURVEY 7/GYRO DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD N 42.63 E 334.9 N 318.2 E N 42.29 E 389.0 N 367.6 E N 40.80 E 445.5 N 417.7 E N 41.20 E 503.1 N 467.8 E N 41.57 E 559.9 N 517.8 E N 39.94 E 618.3 N 568.2 E N 39.83 E 678.9 N 618.8 E N 40.03 E 739.2 N 669.3 E N 40.43 E 798.8 N 719.7 E N 40.79 E 857.9 N 770.3 E N 41.42 E 916.3. N 821.3 E N 41.82 E 974.1 N 872.6 E N 41.65 E 1031.1 N 923.5 E N 43.57 E 1087.5 N 975.4 E N 43.99 E 1143.3 N 1028.8 E N 45.57 E N 45.60 E N 45.44 E N 44.15 E N. 43.52 E N 44.30 E N 45.12 E N 45.21 E N 44.59 E N 44.61 E 1198.1 N 1252.1 N 1306.1 N 1360.4 N 1415.1 N Page 2 08/29/90 CLOSURE DISTNCE BEARING DL /lOO N 43.78 E 1744.5 N 1624.4 E 1469.5 N 1352.1 E 1996.9 N 42.62 E 0.45 1523.8 N 1405.9 E 2073.2 N 42.70 E 1.73 1578.4 N 1460.8 E 2150.7 N 42.78 E 0.33 1633.5 N 1515.7 E 2228.3 N 42.86 E 0.38 1688.8 N 1570.3 E 2306.0 N 42.92 E 0.04 1083,2 E 1615.1 N 42.12 E 1.02 1138.4 E 1692.2 N 42.28 E 0.32 1193.4 E 1769.2 N 42.42 E 0.12 1247.3 E 1845.7 N 42.52 E 1.24 1299.8 E 1921.4 N 42.57 E 0.55 839.7 N 42.58 E 3.35 918.6 N 42.35 E 0.07 997.2 N 42.16 E 0.61 1075.2 N 42.02 E 0.41 1153.0 N 41.92 E' 0.38 1230.6 N 41.87 E 0.38 1307.8 N 41.86 E 0.66 1384.2 N 41.85 E 0.79 1460.9 N 41.89 E 1.71 1538.0 N 41.98 E 0.46 2383.6 N 42.96 E 0.59 462.0 N 43.53 E 2.88 535.2 N 43.38 E 1.86 610.7 N 43.15 E 2.19 687.0 N 42.92 E 0.72 762.6 N 42.76 E 0.48 RU 3G-7Zl Page 3 08/29/90 RECORD OF SURVEY MEAS INCLN DEPTH ANGLE VERTICAL-DEPTHS BKB SUB-SEA 4800 50.51 3740.8 3651.8 4900 50.39 3804.5 3715.5 5000 51,07 3867.8 3778,8 5100 51.61 3930.2 3841,2 5200 51.49 3992.4 3903,4 5300 51,31 4054,8 3965,8 5400 52,18 4116,7. 4027,7 5500 51.99 4178.2 4089.2 5600 52,57 4239,3 4150.3 5700 52.43 4300.2 4211.2 5800 50,57 4362.5 4273,5 5900 49.27 4426.9 4337.9 6000 47,86 4493.0 4404,0 6100 44.69 4562,1 4473,1 6200 43,65 4633,9 4544,9 6300 43.50 4706.3 4617.3 6400 43.50 4778.9 4689.9 6500 43,56 4851.4 4762,4 6600 41.79 4924,9 4835,9 6700 41.80 4999.4 4910.4 6800 41,98 5073,9 4984,9 6900 41.16 5148.7 5059.7 7000 42,37 5223,3 5134,3 7100 41,81 5297,5 5208,5 7200 41.42 5372.2 5283.2 7300 41.02 5447,5 5358,5 'Survey Codes: 7/GYRO SECTION DISTNCE 2460.4 2537.4 2614.8 2692.9 2771.1 2849,3 2927,8 3006.7 3085,8 3165,1 3243,3 3319,7 3394.2 3465.8 3534,6 3602,7 3670,8 3738,8 3806.0 3872.2 3938,7 4004.9 4071.4 4138,1 4204,1 4269.4 DIRECTION BEARING N 44.06 E N 43,85 E N 43,87 E N 43.40 E N 43.04 E RELATIVE-COORDINATES FROM-WELL-HEAD 1800.1 N 1855.7 N 1911.5 N 1968.0 N 2025.1 N CLOSURE DISTNCE BEARING DL /loo 1678.0 E 2460.9 N 42.99 E 0.29 1731.5 E 2538.0 N 43.02 E 0.17 1785.2 E 2615.4 N 43.04 E 0.68 1839.0 E' 2693.5 N 43.06 E 0.61 1892.7 E 2771.8 N 43.06 E 0.25 N 42.74 ,E 2082.3 N 1945.9 E N 43.04 E 2139.9 N 1999.3 E N 42.39 E 2197.8 N 2052.8 E N 42.27 E 2256.3 N 2106.1 E N 41.86 E 2315.2 N 2159.2 E N 39.07 E 2374.7 N 2210.0 E N 37.04 E 2435.0 N 2257.2 E N 34,61 E 2495,7 N 2301,1 E N 32.65 E 2555.9 N 2341,1 E N 33,02 E 2614,5 N 2378,9 E N 33.37 E 2672.1 N 2416,6 E N 32,98 E 2729,8 N 2454,3 E N 32,67 E 2787,6 N 2491,6 E N 35,39 E 2843,8 N 2529,5 E N 34.95 E 2898.3 N 2567,9 E N 38,72 E 2951,7 N 2607,9 E N 38.08 E 3003.7 N 2649,2 E N 36,90 E 3056,6 N 2689,7 E N 35,53 E 3110,6 N 2729,3 E N 34.96 E 3164.9 N 2767,6 E 2850,0 N 43,06 E 2928,5 N 43,06 E 3007.4 N 43,05 E 3086,5 N 43,03 E 3165,8 N 43,00 E 3244.0 N 42.94 E 3320.2 N 42.83 E 3394.7 N 42.68 E 3466.0 N 42.49 E 3534.7 N 42.30 E 3602.8 N 42,13 E 3670.8 N 41,96 E 3738,8 N 41,79 E 3806,0 N 41,65 E 3872,2 N 41,54 E 3938.8 N 41.46 E 4005.0 N 41.41 E 4071'.5 N 41.'35 E 4138.2 N 41.26 E 4204.3 N 41.17 E 4269.7 N 41.06 E N 33,41 E 3219,4 N 2804,6 E 0.26 0.89 0.45 0.58 0.29 2.50 1.75 1.94 3.31 1.05 0.22 0.18 0.16 2.14 0.20 1,70 0.87 1,32 0,83 0,46 0,78 [RU 3G-7A Page 4 08/29/90 RECORD OF SURVEY MEAS INCLN DEPTH ANGLE 7400 41.30 7500 41.55 7600 40.83 7700 39.44 7800 38.18 VERTICAL-DEPTHS BKB SUB-SEA 5522.7 5433.7 5597.7 5508.7 5673.0 5584.0 5749.4 5660.4 5827.4 5738.4 SECTION DIRECTION DISTNCE BEARING .m RELATIVE-COORDINATES FROM-WELL-HEAD 4334.6 N 34.66 E 3273.9 N 2841.5 E 4400.3 N 34.79 E 3328.3 N 2879.2 E 4465.5 N 33.81 E 3382.7 N 29'16.3 E 4529.6 N 37.21 E 3435.2 N 2953.7 E 4592.2 N 42.20 E 3483.4 N 2993.7 E 7900 37.34 5906.4 5817.4 8000 35.18 5987.0 5898.0 8100 32.23 6070.2 5981.2 8200 30.07 6155.8 6066.8 8300 28.69 6242.9 6153.9 4653.5 N 42.39 E 4712.6 N 42.01 E 4768.1 N 44.78 E 4819.4 N 51.94 E 4867.1 N 58.07 E 3528.7 N 3034.9 E 3572.5 N 3074.7 E 3612.8 N 3112.8 E 3647.1 N 3151.4 E 3675.3 N 3191.6 E 8400 26.35 6331.6 6242.6 8767 26.35 6660.5 6571.5 4910.1 N 67.97 E 5056.3 N 67.97 E 3696.2 N 3232.7 E 3757.3 N 3383.7 E 'Survey Codes: 7/GYRO X/EXTRAPOLATED CLOSURE DISTNCE BEARING 4335.0 N 40.96 E 4400.8 N 40.86 E 4466.2 N 40.77 E 4530.4 N 40.69 E 4593.1 N 40.68 E 4654.3 N 40.70 E 4713.4 N 40.72 E 4768.8 N 40.75 E 4820.1 N 40.83 E 4867.6 N 40.97 E 4910.4 N 41.17 E 5056.4 N 42.01 E DL /lOO 0.61 0.26 0.83 1.95 2.29 0.84 2.16 3.05 2.81 1.97 3.05 0.00 [RU 3G-7~ Page 5 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 08/29/90 ~UBSEA MEAS INCLN )EPTH DEPTH ANGLE 0 89 0.12 100 189 0.13 200 289 0.23 300 389 0.31 400 489 0.35 TVD BKB 89 189 289 389 489 500 589 0.46 589 600 689 0.60 689 700 789 0.71 789 800 889 0.96 889 900 989 3.~62 989 1000 1090 9.22 1089 1100 1191 11.00' 1189 1200 1294 12.73 1289 1300 1396 14.39 1389 1400 1500 15.59 1489 1500 1604 18.18 1589 1600 1712 24.25 1689 1700 1824 29.60 1789 1800 1944 36.44 1889 1900 2072 41.96 1989 2000 2213 46.43 2089 2100 2362 49.29 2189 2200 2516 49.31 2289 2300 2670 51.19 2389 2400 2833 51.93 2489 2500 2994 51.22 2589 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 0 0 N 46.44 W 0.08 N 0.03 W 0 0 N 65.79 W 0.21 N 0.21 W 0 0 N 53.53 W 0.36 N 0.48 W 0 0 N 34.85 W 0.69 N 0.80 W 0 0 N 20.31 W 1.21 N 1.07 W 0 0 N 0.01 W 1.89 N 1.19 W 0 0 N 10.45 E 2.80 N 1.10 W 0 0 N 8.52 E 3.93 N 0.90 W 0 0 N 13.23 E 5.35 N 0.64 W 0 0 N 38.39 E 8.73 N 0.97 E 1 1 N 54.53 E 16.18 N 9.00 E 2 2 N 55.29 E 26.50 N 23.99 E 5 2 N 53.47 E 38.71 N 41.05 E 7 3 N 51.26 E 53.44 N 60.15 E 11 4 N 49.04 E 70.61 N 80.72 E 15 4 N 46.06 E 90.99 N 103.01 E 23 7 N 42.63 E 118.86 N 130.29 E 35 12 N 39.28 E 157.06 N 162.83 E 55 20 N 40.60 E 207.79 N 205.51 E 83 29 N 41.47 E 268.73 N 258.48 E 124 40 N 42.59 E 341.66 N 324.35 E 173 49 N 41.37 E 423.48 N 398.49 E 227 55 N 41.26 E 512.31 N 475.84 E 281 54 N 40.42 E 600.56 N 553.15 E 3441 63 N 39.90 E 698.80 N 635.40 E 405 61 N 40.40 E 795.03 N 716.47 E RU 3G- 7/~ Page 6 08/29/90 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL UBSEA MEAS INCLN 'EpTH DEPTH ANGLE TVD BKB MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 2600 3152 50.87 2689 2700 3310 50.16 2789 2800 3465 50.28 2889 2900 3622 50.41 2989 3000 3780 50.45 3089 463 59 N 41.12 E 888.62 N 797,02 E 521 58 N 41.80 E 979.84 N 877.79 E 576 55 N 42.90 E 1067.95 N 957.01 E 633 57 N 44.34 E 1155.62 N 1040,83 E 691 57 N 45.59 E 1241.21 N 1127.24 E 3100 3937 50.10 3189 3200 4091 49.09 3289 3300 4243 49.70 3389 3400 4401 50.97 3489 3500 4560 51.04 3589 748 57 N 44.97 E 1325.97 N 1213.36 E 802 54 N 43.58 E 1409.94 N 1294.88 E 854 53 N 44.66 E 1492.95 N 1375.17 E 912 57 N 45.20 E 1578.86 N 1461.28 E 971 59 N 44.60 E 1666.54 N 1548.30 E 3600 4718 50.71 3689 3700 4876 50.42 3789 3800 '5034 51.25 3889 3900 5195 51.50 3989 4000 5355 51.79 4089 1029 59 N 43.83 E 1754.74 N 1634.24 E 1087 57 N 43.90 E 1842.18 N 1718.56 E 1145 58 N 43.71 E 1930.52 N 1803.42 E 1206 61 N 43.06 E 2021.93 N 1889.75 E 1266 60 N 42.91 E 2113.91 N 1975.14 E 4100 5518 52.09 4189 4200 5682 52.46 4289 4300 5842 50.03 4389 4400 5994 47.94 4489 4500 6138 44.30 4589 1329 63 N 42.37 E 2208.08 N 2062.19 E 1393 64 N 41.94 E 2304.33 N 2149.50 E 1453 60 N 38.23 E 2399.68 N 2229.99 E 1505 52 N 34.76 E 2492.08 N 2298.53 E 1549 44 N 32.79 E 2578.11 N 2355.35 E 4600 6276 43.54 4689 4700 6414 43.51 4789 4800 6552 42.65 4889 4900 6686 41.80 4989 5000 6820 41.81 5089 1587 38 N 33.29 E 2658.40 N 2407.57 E 1625 38 N 32.94 E 2737.83 N 2459.51 E 1663 38 N 34.07 E 2817.05 N 2510.98 E 1697 34 N 35.01 E 2890.64 N 2562.58 E 1731 34 N 3,8.59 E 2962.31 N 2616.42 E 5100 6954 41.81 5189 1765 33 N 37.44 E 3031.89 N 2670.99 E RU 3G-7~ Page DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 7 08/29/90 ~BSEA MEAS INCLN EPTH DEPTH ANGLE TVD BKB 5200 7089 41.87 5289 5300 7222 41.33 5389 5400 7355 41.17 5489 5500 7488 41.52 5589 5600 7621 40.54 5689 5700 7751 38.80 5789 5800 7878 37.52 5889 5900 8002 35.11 5989 6000 8122 31.75 6089 6100 8238 29.54 6189 6200 8352 27.47 6289 6300 8464 26.35 6389 6400 8576 26.35 6489 6500 8687 26.35 6589 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 1800 35 N 35.69 E 3104.46 N 2724.88 E 1833 34 N 34.61 E 3177.00 N 2776.04 E 1866 33 N 34.10 E 3249.51 N 2824.78 E 1899 33 N 34.77 E 3321.95 N 2874.76 E 1932 33 N 34.53 E 3394.10 N 2924.02 E 1962 30 N 39.76 E 3460.35 N 2973.74 E 1989 27 N 42.35 E 3518.82 N 3025.97 E 2013 24 N 42.08 E 3573.50 N 3075.60 E 2033 20 N 46.37 E 3621.00 N 3121.17 E 2049 16 N 54.29 E 3658.55 N 3166.63 E 2063 14 N 63.24 E 3687.30 N 3213.01 E 2075 12 N 67.97 E 3706.85 N 3259.06 E 2087 12 N 67.97 E 3725.43 N 330.4.98 E 2098 12 N 67.97 E 3744.01 N 3350.89 E RU 3G- 7/~ Page 8 08/29/90 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD DIST BEARING 1000 3.94 1000 911 8 N 41.39 E 9 N 2000 38.29 1934 1845 326 N 40.88 E 234 N 3000 51.20 2593 2504 1075 N 40.43 E 799 N 4000 49.47 3230 3141 1846 N 44.15 E 1360 N 5000 51.07 3868 3779 2615 N 43.87 E 1911 N 6000 47.86 4493 440~ 3394 N 34.61 E 2496 N 7000 42.37 5223 5134 4071 N 36.90 E 3057 N 8000 35.18 5987 5898 4713.N 42.01 E 3572 N 100 1 E 9 N 8.42 E 3.0 228 E 326 N 44.27 E 3.3 720 E 1075 N 42.02 E 0.4 1247 E 1846 N 42.52 E 1.2 1785 E 2615 N 43.04 E 0.7 2301 E 3395 N 42.68 E 1.9 2690 E 4071 N 41.35 E 1.3 3075 E 4713 N 40.72 E 2.2 <KB>O 500 LO00 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 500 VERTICAL SECTION VIEW ARCO ALASKA, INC. .......... KRU 36-7A . Section at: N 4~.78 E TVD Scale.' ! Inch = iO00 feet Dap Scale.' ! Inch = tO00 feet .... Drawn ..... · 08/30/90 .~ ' AjHankerKB Identification ~0 TVDo SECTNo ....... B} ~5/8' CASING 3649 3006 ~576 C} TOP KUPAR~ C 8079 6053 4757 D} BASE KUPARUK C 8i56 6t18 4797 B TOP K~ARUK A 82i4 6i68 4826 - ~ ~'- ...... F} BASE KUPA~ A 8339 6277 4885 G} 7' LINER 8502 6423 495! ......... ~ ~ TD ~~ GG~ ~ ~ ~,,~ .... t · .I _[ INCLN 0.00 .52 .85 .02 29. BB 27.78 26.35 26--.-.-.-.-.-~5 0 500 iooo tsoo ;,000 2500 3000 3500 4000 4500 5000 Section Deparbure Grsat Land Dirs£tionaI Drilling, Znc. A) KB 0 ON OE ~) BASE KUPARUK A 8339 3684N 3~08E ;) 7" LINER 8502 37i3N 32752 H) TD ~ ~ ~ PLAN VIEW ARCO ALASKA. ZNC. KRU 3G-7,,A CLOSURE · §0§§ ft N 42.01E DECLiNATiON · 0.00 E SCALE. · ! inch = 700 feet DRAWN ' 0B/30/90 455O 4200 3850 3500 3i50 2BO0 ~450 2t00 i750 t400 t050 700 350 350 350 0 350 <- NEST' EAST -> 700 tO50 t400 t750 2t00 2450 2800 3t50 3500 3850 AOGCC GEOLOGICAL MATEniALS iNYENTOn¥' LiST PERivilT # ?~ - ~ WELL NAiviE /~/t COMPLETION DATE Z ~ /~ ~ ~ CO. CONTACT .... check off or Ii'st data aS' it is rcccivcd.~list received date for 407. if not required list as NR cored ~nte~als core analysis j~~ d~ ditch intc~als j "digital data mm ~ m mm 7] lO] 11] 14] 15] 17) ! i , ~ STATE OF ALASKA '~...~ ALASKA OIL AND GAS CONSERVATION CC~/IMISSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Pull tubing 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2538' FNL, 220' FWL, Sec. 24, T12N, R8E, UM At top of productive interval 1067' FSL, 1955' FEL, Sec. 13, T12N, R8E, UM At effective depth 1141' FSL, 1818' FEL, Sec. 13, T12N, R8E, UM At total depth 1219' FSL~ 1818' FEL~ Sec. 13, T12N, R8E, UM Operation Shutdown Stimulate X Alter casing Repair well 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 8767' feet 6650' feet 12. Present well condition summary Total Depth: measured true vertical Plugging Perforate _ Other 6. Datum elevation (DF or KB) RKB 89 feet 7. Unit or Property name _ Kuparuk River Unit 8. Well number 3(;;i-07A 9. Permit number/approval number -eve-84 ciO- 85 10. APl number 5o-103-20127-01 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) Original 3G-07 P&A and 3G-07A sidetracked off of cement plug @ 5600' Effective depth: measured 8416' feet Junk (measured) true vertical 6346' feet None Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' 1 6" 1 I 5' 1 1 5' Surface 3 61 2' 9 - 5 / 8" 755 Sx AS III & 3 649' 3 0 0 6' Intermediate 525 Sx Class G Production 8467' 7" 225 Sx Class G 8502' 6423' Liner & 171 Sx Class G Tail i!~'"'~ ~;~ ..~ ~-~" ~ ~. ~ ~ ~. Perforation depth: measured ~%~ ~ii ~ '~ E ~ 7788'-7848', 7906'-7926', 7942'-7962' true vertical 581 8'-5865', 5911'-5927', 5940'-5956' Tubing (size, grade, and measured depth) 3-1/2" 9.2#, EUE, ABMOD, IPC, w/Tail @ 7893' Packers and SSSV (type and measured depth) SSSV: Camco TRDP-1A-SSA (1835'), Packer: 13. Stimulation or cement squeeze summary C Sand Acid Stimulation Intervals treated (measured) 7788'-7848' Treatment description including volumes used and final pressure Baker HB (7731'), Packer: Baker Model 'D' (7874') Pumped 120 BBLS of Nitrified12% HCL Acid, 224 BBLS Diesel w/20% Xylene, 25 bbls of OSR diverting agent in gelled water @ 0.2 ppg concentration. Final BHP = 4900 psi. 14. Reoresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 350 175 0- 500 100 Subsequent to operation 1 8 0 0 9 0 0 1 5 0 5 0 0 15. Attachments ~16. Status of well classification as: Copies of Logs and Surveys run ~ I Water Injector Daily Report of Well Operations X Oil X Gas Suspended 17. I here_by certify that the foregoing is true and correct to the best of my knowledge. Si,ned ~~)~~. ~ Title ~"~¢1~- ~)~~.5 ~t~.¢~ =orm 10-404 Rev 09/12/90 120 Service Date SUBMIT IN DUPLICATE ARCO AlaSka, Inr <~ WELL SERVICE REPORT Subaldla~/of Atlantic Richfield Com~= WELL 36-7 CONT,~ACTOR .EMARKS / / ifoo .. CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK W"tl~' ITlmP'Report 'F Chill Factor ] VlllbllltY. F ,ARCO Alaska, Inc Subsidiary of Atlantic Rtcl~field Compai-~. CONTRACTOR OT~ g - ~,~£/~, s r~EMARKS FIELD- DISTRICT- STATE WELL SERVICE REPORT IDAYS DATE 0930 O ~r.7 o 05 ~-rs'" Io00 I 01 ..T" ~o3~" ilOo 'T"',,~6.. '7ool. u.,'c t-, O, ~'o,,,,.~ po,,A.~ '[-'-o I--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Report °F "F miles knots ,ARCO Alaska, Inr <> Subsidiary of Atlantic Richfield Compat..,~.~ WELL SERVICE REPORT WELL ~~7 HEMARKS IPBDT DAYS DATE //-/¢-~ ~.~.f .~ r---I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. I Chill Factor Visibility I Wind Vel. Report °Ft °F mil®s I iSigned knots STATE OF ALASKA ALA~;~ OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown X Re-enter suspended well _ _ PLugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARGO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2538' FNL, 220' FWL, Sec. 24, T12N, RSE, UM At top of productive interval 1250' FNL, 1675' FEL, Sec. 13, T12N, R8E, UM At effective depth NA At total depth 1576' FSL, 1384' FEL, Sec. 13, T12N, R8E, UM 5. Type of Well: Development Exploratory Stratigraphic Service (approx) (approx) 12. Present well condition summary Total Depth: measured 8550 feet (approx) true vertical 6132' feet Effective depth: measured NA feet (approx) true vertical NA feet 6. Datum elevation (DF or KB) RKB 89 7. Unit or Property name Kuparuk River Unit feet 8. Well Number 3G-7A 9. Permit number 10. APl number 50-103-20127 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Plugs (measured) Original 3G-7 P&A & 3G-7A sidetracked off of cement plug @ 5600' Junk (measured) None Casing Length Size Structural Conductor 8 0' 1 6" Surface 3612' 9 5/8" Intermediate Production 8467' 7" Liner Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None Cemented Measured depth 755 Sx AS III & 525 Sx Class G 572 Sx Class G & 171 Sx Class G tail True vertical depth (approx) 115' 115' 3649 3019' 8502' 6101' 13. Attachments Description summary of proposal _ Detailed operation program BOP sketch 14. Estimated date for commencing operation November, 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as:, Oil X Gas __ Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~Ined ,~,/~, ~I~ Title Area Drilling Engineer / FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test__ Subsequent form require 10- Approved by the order of the Commission Commissioner Form 10-403 Rev 06/15/88 ORIGINAL SlSNE§ LONNIE C. SMITH Approved Copy Re,turned IApproval No. SUBMIT IN TRIPLICATE ARCO Oil and Gas Company Well History - Initial Report - Daily Instrucllona: Prepare and submit the "lflillal Rel~Ol't" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. Field ICounty, parish or borough NORTH SLOPE Lease or Unit ADL: 25547 Title DRILLING State AK KUPARUK RIVER Auth. or W.O. no. AK4940 ALK: 2661 I Well no. K~J 3G-07A Operator ARCO Spudded or W.O, begun SPUD Date and depth as of 8;00 a.m. 07/02/90 ( 1) TD: 0'( 0) SUPV:JMM 07/03/90 (2) TD: 2779' (2779) SUPV:JMM 07/04/90 (3) TD: 3670' ( 891) SUPV:JMM 07/05/90 (4) TD: 4027' ( 357) SUPV:JMM 07/06/90 (5) TD: 4217' ( 190) SUPV:JMM 07/07/90 (6) TD: 5738'(1521) SUPV:JMM Date07/02/90 Complete record for each day repoAed DOYON 14 ARCO W.I, I 55. 3477 IHour 07:00 I Prior status if a W.O. PREP TO SPUD MW: 0.0 VIS: 0 PREPARING TO SPUD WELL DAILY:S59,879 CUM:$59,879 ETD:S59,879 EFC:$1,800,000 DRLG MW: 9.1 VIS: 46 TEST DIVERTER SYSTEM, SPUD 02-JUL-90 07:00,DRLD TO 2779' DAILY:S54,783 CUM:$114,662 ETD:S114,662 EFC:$1,800,000 CMT 9-5/8" CSG 9-5/8"@ 3649' MW: 9.6 VIS: 48 DRLG FROM 2719'-3670' CIRC AND CONDITION HOLE, WIPER TRIP TO 900', RIH, CIRC AND COND HOLE. DROP SS SURVEY, POOH, LD BHA. RUN 9-5/8" CSG, 94 JTS 38#,J-55 BUTTRESS. CIRC, RU DOWELL, PREP TO CEMENT 9-5/8" CASING. DAILY:S125,011 CUM:$239,673 ETD:S239,673 EFC:$1,800,000 DRLG @ 4027' 9-5/8"@ 3649' MW: 9.1 VIS: 38 CEMENT 9-5/8" CSG WITM 80 BBLS WATER, 295 BBLS ARCTIC SET III, 108 BBLS CLASS G. BUMP PLUG TO 2000 PSI, FLOATS HELD OK. ND CMT MEAD, DIVERTER. INSTALL WKM SPEEDMEAD, NU BOPE. TEST BOPE. RIM WITH BHA #2, DRILL FLOAT COLLAR AT 3569', TST CSG OK TO 2000 PSI. DRILL FLOAT SHOE AND 10' OF NEW FORMATION TO 3680'. DIPLACE WITH 9.2 PPG ML~. TEST FORMATION TO 12.5 EMW, NO LEAKOFF. DRLG FROM 3680'-4027'. ADT-$.2 HRS. DAILY:S110,209 LOGGING COLVILLE CUM:$349,882 ETD:S349,882 EFC:$1,800,000 9-5/8"@ 3649' MW: 9.5 VIS: 38 DAILY:S56,822 CUM:$406,704 ETD:S406,704 EFC:$1,800,000 DRLG WITH TURBINE 9-5/8"@ 3649' MW: 9.7 VIS: 40 MLS SHOT 48 SIDEWALL CORES, 4 MISFIRES, 4 COREMEADS LEFT IN WELL, 40 CORES RETRIEVED. RIH WITH JUNK BIT TO DRILL UP COREHEADS. DRILL FROM 4217' TO 4332 CIRC MOLE CLEAN, POOH TO CHANGE TO NEYFOR TURBINE AND PDC BIT. DRILL FROM 4332' TO 5738', ADT-5.5 HRS, AST=0.5 HRS. DAILY:S49,036 CUM:$455,740 ETD:S455,740 EFC:$1,800,000 DRLG @ 7625' 9-5/8"@ 3649' MW: 9.8 VIS: 38 ~<~XI~-~-c~i'~'5<'J~'''~ ~"~2'-~~'TH"NEYRFOR TURBINE. 1887', ADT'14.6 HRS, AST=i.8 DAILY:S50,440 CUM:$506,180 ETD:S506,180 EFC:$1,800,000 07/08/90 (7) TD: 7625'.( The above Is/ .... t DrHlinQ, Paoes 86 and 87. Number all daily welt history forms consecutively as they are prepared for each well. iPaga no. ARCO Oil an~"~as Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number aH drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lnlerim" sheets when filled out but not less frequently than every 30 days, or on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District County or Parish I State I ARCO ALASKA INC. I NORTH SLOPE Field ILease or Unit KUPARUK RIVER I KRU 3G-07~ Date and depth as of 8:00 a.m. 07/09/90 ( 8) TD: 7885' ( 26( SUPV:JMM 07/10/90 ( 9) TD: 8767' ( 88: SUPV:JMM 07/11/90 (10) TD: 8767'( SUPV:JMM 07/12/90 (11) TD: 8767'( SUPV:RWS o) Complete record for each day while drilling or workover in progress DO¥ON 1 4 AK RIH TO 7885' TO DRILL 9-5/8"@ 3649' MW:10.2 VIS: 44 DRILL FROM 7625' TO 7885' INCREASE MUD WT FROM 9.8 TO 10.1 DUE TO CONNECTION GAS. POOH TO 9-5/8" SHOE. PERFORM FORMATION LEAKOFF TEST TO 10.75 PPG EMW. POOH, LD TURBINE, RIH WITH ROTARY ASSY TO 7885'. SPOT LCM PILL IN OPEN HOLE, 15 PPB KWIK SEAL MED. POOH TO 9-5/8" SHOE. SLIP AND CUT DRILL LINE. CIRC MUD AND PERFORM SECOND FORMATION LEAKOFF TEST, PUMP 60 BBLS OF LCM MUD INTO FORMATION AND LOT IMPROVED TO 11.1 EMW. RIH TO 7885' TO RESUME DRILLING. DAILY:S72,650 CUM:$578,830 ETD:S578,830 EFC:$1,800,000 WIPER TRIP TO 9-5/8" 9-5/8"@ 3649' MW:10.8 VIS: 42 CIRC OUT LCM, DRILL WITH ROITARY ASY FROM 7885' TO 8767' TD. ADT=iS.7 HRS. CIRC AND CONDITION HOLE, POOH FOR SHORT TRIP TO 9-5/8' SHOE. HOLE TIGHT, PULLING 100K AND SWABBING, WORKING THRU TIGHT SPOTS. DAILY:S82,463 CUM:$661,293 ETD:S661,293 EFC:$1,800,000 OPEN HOLE LOGGING 9-5/8"@ 3649' MW:10.9 VIS: 44 POOH TO 9-5/8" SHOE, TIGHT HOLE, SWABBED. RIH FOR WIPER TRIP BEFORE LOGGING. CIRC BU, 4000 UNITS GAS ON BOTTOM. WT UP TO 10.9 PPG, DROP SS SURVEY. SPOT DIESEL PILL ON BOTTOM, POOH TO LOG. LOGGING RUN #I-HRI,SDL,DSN, CAL, HD. LOGGING RUN #2 IN PROGRESS- MICROLOG. FAULT HAS CUT OUT MOST OF "A" PAY, EVALUATING SIDETRACK POSSIBILITY. DAILY:S55,777 CUM:$717,070 ETD:S717,070 EFC:$1,800,000 SET CMT KICKOFF PLUG 9-5/8"@ 3649' MW:10.9 VIS: 43 RIG DOWN HLS LOGGERS. RIH WITH BIT FOR CONDITIONING TRIP. MAX GAS 760 UNITS~ SHORT TRIP TO SHOE, POOH TO SET CEMENT PLUGS. RIH WITH 26 JTS 2-7/8" TBG AND DP. SPOT 16 PPG PILL FROM TD (8767') TO 8400' POOH 4 STANDS, MIX AND PUMP 41 BBL, 200 SX CLASS G CF/ViENT PLUG WITH .25% D-65,.1% D-133. SPOT BALANCED CEMENT PLUG (15.8 PPG) FROM 8400' TO 7972' POOH 7 STANDS SLOWLY. PUMP 100 BBL VISCOUS LCM PILL. PUMP 279 SX, 55 BBL CLASS G CEMENT WITH NO ADDITIVES 15.8 PPG, SET BALANCED PLUG FROM 5825' TO 6200' FOR SIDETRACK KICKOFF. DAILY:$109,518 CUM:$826,588 ETD:$826,S88 EFC:$1,800,000 ATTEMPTING SIDETRACK 9-5/8"@ 3649' MW:10.4 VIS: 46 CIRC AND CONDITION MUD ABOVE CEMENT PLUGS. POOH, LD 26 JTS 2-7/8" TBG. TEST BOPE. RIH, TAG CEMENT AT 5600', DRILL FIRM CEMENT FROM 5600' DAILY:S92,374 CUM:$918,962 ETD:S918,962 EFC:$1,800,000 Well no. The above is correct For form preparationF"l~ (~istribution ,~ see Procedures Man%/.~l Section 10, Drilling, Pages 86 aha 87 AR3B-459-2-B Number all daily well history forms consecutively as they are prepared for each well. Page no. ARCO Oil an,~,..~s Company Daily Well History--Interim Instruclions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District KUPARUK RIVER Date and deptll as of 8:00 a.m, I County or Parish ARCO ALASKA INC. J NORTH SLOPE I l_ease or Unit J KRU 3G-07A Complete record for each day while drilling or workover in progress DOYON 14 07/14/90 (13) TD: 6980' ( 1274 SUPV:RWS/KSP 07/15/90 (14) TD: 7758' ( 77 SUPV:RWS/KSP 07/16/90 (15) TD: 8550'( 7 SUPV:KSP 07/17/90 (16) TD: 8550'( SUPV:KSP IState AK DRLG @ 6980' 9-5/8"@ 3649' MW:10.0 VIS: 41 DRILLING SIDETRACK HOLE WITH 1-3/4 DEGREES BENT SUB, 5769'-6149' CIRC HOLE DROP SS SURVEY. POOH, CHANGE BHA TO TURBINE. TIH AND DRILL FROM 6149' TO 6980', ADT=7.9 HRS. DAILY:S56,597 CUM:$975,559 ETD:S975,559 EFC:$1,800,000 DRLG @ 7758' 9-5/8"@ 3649' MW:10.8 VIS: 45 DRLG W/ TURBINE FROM 6980' TO 7614'. POOH TO 9-5/8" SHOE. TEST FORMATION TO 11.2 PPG EMW, HELD OK, STARTED TAKING FLUID AT 11.3 PPG EMW. POOH, LD TURBINE RIH WITH ROLLER BIT, REAM FROM 7510' TO 7614', DRILL FROM 7614' TO 7758' ADT= 3.7 HRS. DAILY:S61,741 CUM:$1,037,300 ETD:S1,037,300 EFC:$1,800,000 POOH TO LOG 9-5/8"@ 3649' MW:10.8 VIS: 40 DRLG FROM 7758' TO 8550'. CIRC HOLE, WIPER TRIP TO 5300', PULLED TIGHT THRU SAND, RETURN TO BOTTOM WITH NO PROBLEM. CIRC WITH 800 UNITS TRIP GAS. POOH TO LOG. DAILY:S82,340 CUM:$1,119,640 ETD:Si,II9,640 EFC:$1,800,000 POOH LDDP 9-5/8"@ 3649' MW:10.8 VIS: 40 POOH, RU HLS LOGGERS. TIH AND LOG WITH GR/CNL/HRI/CDL/MICROLOG, BOTH "A" AND "C" SANDS PRESENT ON SIDETRACK HOLE. POOH WITH LOGGING TOOLS. RIH WITH ROLLER BIT, REAM FROM 8510' TO 8550'. WIPER TRIP TO 5400', HOLE PACKING OFF SOME ~ VERY TIGHT THROUGH SAND. SPOT DIESEL PILL ON BOTTOM, POOH LD DP. DAILY:S103,736 CUM:$1,223,376 ETD:S1,223,376 EFC:$1,800,000 IWell no. The above is correct Signaturo~, For form preparation,/fl'-r~ di'stribution see Procedures ManckafSection 10, Drilling, Pages 86 and 87 AR3B-459-2-B lNumber all daily well history forms consecutively as they are prepared for each well. IPage no. ARCO Oil and Gas Company ~. Daily Well History-Final Report Instructions: Prepare and submit the "Fillal~ R~rt" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also wherl ol)erations are suspended for an indefinite or appreciable length of time, On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District County or Parish ARCO ALASKA INC. NORTH SLOPE Field JLease or Unit KUPARUK RIVER I ADL: 25547 i Auth. or W.O, no. ~Tit~e AK4940 I DRILLING IAccounting cost center code State AK ALK: 2661 I Wett no. K~U 3G-07 A Operator A.R.Co. W.I. ARCO 55.3477 Spudded or W.O. begun Date SPUD 07/02/90 Iotal number of wells (active or inactive) on this pst center prior to plugging and I bandonment of this well our I Prior status if a W.O, 07:00 I Date and depth as' of 8:00 a.m. 07/18/90 (17) TD: 8550'( SUPV:KSP Complete record for each day repoRed DOYON 14 0) RIG RELEASE 9-5/8"@ 3649' MW:10.9 VIS: 0 POOH & LDDP. RUN 124 JTS 7" 26# CSG, BUT J55 & 78 JTS 7" 26# AB MOD BUT J55. SET SHOE @ 8502' BOTTOM GOT TIGHT. CIR 2 CSG VOLUMES. PUMPED 10 BBL PREFLUSH, 35 BBL 12 PPG SPACER, 214 BBL 12.5 PPG LEAD CMT, 36 BBL 15.8 PPG TAIL CMT. DISPLACE WITH 327 BBL 10.9 PPG NACL. BUMP PLUG AT 3000 PSI, HELD OK. PUI~P 40 BBL MUD DOWN ANN. ND BOPS, SET SLIPS, INSTALL WELLHEAD & TREE. TEST TREE TO 3,00 PSI. RELEASE RIG AT 05:00 7-18-90. PREP TO MOVE TO 3G-11. DAILY:S208,314 CUM:$1,431,690 ETD:S1,431,690 EFC:$1,800,000 Old TD Released rig tNew Date PB Depth IK nd of rig Classifications (oil, gas, etc.) Producing method Potential test data IType completion (single, dual, etc.) Official reservoir name(s) Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected ,The above, i,~, orrect I Date . ' Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively I Page no. as they are prepared for each well. DiVision of AtlantlcRIchfleldCompany ARCO Alaska, Inc. Date: July 27, 1990 Transmittal #: 7828 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3G-07A High Resolution Induction DFL 5" 7-1 6-90 7550-8523 3G-07A High Resolution Induction DFL 2" 7-1 6-90 7550-8523 3G-07A Spectral Density DSN II Raw Data 7-1 6-90 7550-8496 3G-07A Spectral Density DSN II Porosity 7-1 6-90 7550-8496 3G-07A High Resolution Induction Raw X & R 7-16-90 7550-8523 Receipt Acknowledged: DISTRIBUTION: Date: .......... D&M Drilling Franzen Vendor Package(Johnston) NSK State of Alaska(+Sepia) ARCO Alaska, Inc. Date: July 27, 1990 Transmittal #: 7826 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. ,~-3'G-07A LIS Tape and Listing Please acknowledge receipt and return 7- 16-90 HRI, SDL/DSN Receipt Acknowledged: DISTRIBUTION: ............................. Date: Lynn Goettinger State of Alaska July 12, 1990 Telecopy.. (907)276-7542 P. J. Archey Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Kuparuk River Unit 3G-07A AP. CO Alaska, Inc. Permit No, 90-85 Sur. Loc. 2538'F~tL, 220'FWL, Sec. 24, T12N, RSE, UM. Btmhole Loc. 1257'FSL, 1940'FEL, Sec. 13, T12N, RSE, U~4. Dear Mr. Archey ~ Enclosed is the approved application for permit to redrill the above referenced Well. The permit to redrilI does not exempt you from obtaining additional pe~its required by law from other governmental agencies, and does not authorize conducting redrtlling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. Very. truly I>- . . C~a~ertdn Chair~n of -Alaska Oil and Gas Consa~ation Co~tsston BY O~ER OF THE CO~{ISSION dlf Enclosure cc~ Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. · STATE OF ALASKA A~,.,,.~ OIL AND GAS CONSERVATION COMtV~...~iON PERMIT TO DRILL 20 AAC 25.005 Jla. Type of Work Drill ~ Redrill _~_ I lb. Type of Well Exploratory~ Stratigraphic Test _ Development Oil .~X Re-Entry _ Deepen --I Service _ Development Gas ~ Single Zone ~ Multiple Zone _ 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool AF{QO Alaska. Inc. RKB 89', Pad 53' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25547 ALK 2661 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2538' FNL, 220' FWL, Sec. 24, T12N, R8E, UM Kuoaruk River Unit At top of productive interval (TARGET) 8, Well number Number 1005' FSL, 2100' FEL, Sec. 13 , T12N, R8E, UM 3G-07A #U630610 At total depth 9. Approximate spud date Amount 1257' FSL, 1940' FEL, Sec 13, T12N, R8E, UM 07-12-90 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3G-09 8312' MD 1384' ~ TD feet 10' at 1040 feet 2560 6212' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 900 feet Maximum hole an~lle 51° Maximum surface 1800 psi~ At total depth (TVD) 5900' '3200 ps~ 18. Casing program Setting Depth . size Specification Top B~ottom Quantity of cement Hole Casing Weight Grade Coupling Length IVD 'I'VD' lVD TVD linclude sta~le datat 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +_200 Cu. Ft. 12.25 9.625 36.0# J-55 BTC 3614 35' 35' 3649 3040 1300Cu. Ft. AS III & HF-ERW 600 Cu. Ft. Class G 8.5 7" 26.0# J-55 BTC 8277' 35' 35' 8312' 6213' 215Cu. Ft. ClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 8767 feet Plugs (measured) 7972'-8400' and 5825'-6200' true vertical 6388 feet 5773'-6103' and 4395'-4624' Effective depth: measured feet Junk (measured true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 80' 16' 200 Cu. Ft. 115' 115'R~;' ~ ~ ~~'\ i,~ ~V~D Surface 3614' 9.625" 1900 Cu. Ft. 3649' 301_~ _ ~. ,,~ Intermediate Production Liner JUL 1. 2 Perforation depth: measured true ve.~ca~ '~.~'~:a 0ii & ~as 20. Attachments Filing fee~ Property plat ~ BOP Sketch ~ Diverter Sketch ...X_ Drilling program Drilling fluid program ~ Time vs depth plot ~ Refraction analysis _ Seabed report _20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Si~ned ~ .~'~~'~ Title Area Drilling Engineer Date ~/~/~,~ Commission Use Only Permit Number I APInumber I Approval date 07/12/901 See cover letter for ?0-~:~6 S0-,/'OJ "' .~'(::2) /2_ ~'--' (~ / other requirements C0nc~itions of approval Samples required __Y e s ~ N o Mud log require~d . __ Y e s ~Z~ N o Hydrogen sulfide measures__ Yes ~ N o Directional survey required .,~es __ N o Required working pressu~re for BOPE /~'~M~ ~3M;... __ SM; __ 10M' __ 15M Other: //F~/y~~.. ~~ by order of Approved by[_ '__ "~' · ~,__.~/~~~6~,F, Commissioner the commission Date Form 10-401 ~_~_~_~_~_~_~_~-24-89 in triplicate DRILLING FLUID PROGRAM (3G-07A) Spud to 9-5/8" Drill out to surface casing weight up Density 8.6-10.0 8.6-9.3 PV ' 15'-35 5-15 YP 15-35 5-8 Viscosity 50-100' 30-40 Initial Gel 5-15 2-4 10 Minute Gel 15-40 4-8 APl Filtrate 10-1 2 8-10 pH 9-10 8.5-9 % Solids 10 +/- 4- 7 Weight up 11.0 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 10-12 Drillin(~ Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators N(~tes: - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. - Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1880 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. - The nearest well to 3G-07A is 3G-08. As designed, the minimum distance between the two wells would be 10' at 1040' MD. The wells would diverge from that point. - Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 to drill gravel beds. ARCO ALASKA, Inc. l s--T~+-~.~-FTad-~-~- -~E-~.' -gX (~D-~F~-C-K) / Field : Kuparuk Field Location : Kuparuk River Unit] ~o,~,. ~oo.oo East i i i i i i i i i i i i ~ i i i I i i i I om~,N~ ~oLE I TARGE~ DIRECTION N ,.32 DEG 28 MINE TARGET ANGLE 40 DEG 33 MIN KICK-O~F POINT 5874 MD 52.5 DEG N41.2E 51.1~ 47. tl ~ of ~ 4o.~ [TARGET / TOP C ZONE] J 1¥D-5863 J TMD=7853 L__ . DEP--_4614 _ ~oo i i [ , , , i i i ~ i i , i , i i I i , , , , , , i i , , i [ i i i i , , , ~colt 1 ' ~0.~ ~iCO] ~cTion on ~.~7 o~i~ufh with ~c~ ~.~ ~, ARCO ALASKA, !no,?.~..~.· f Prod 3G. Well ot R vitae Kuparuk FI · Id Nor, h SI ope Propoeml Aleeke 0 . RKB EL~AT[ON~ 90' I-- rtl "0 1000 _ 2000 _ ;3000. 4000. 5000 _ 6000. ?000 ,,, KOP TVD-900 TrlD-900 DEP-O BUILD 3 OEO PER 100 FT B/ PERHAFROST T/ UONU SNDS 3.3 39 4,5 TVD- 1 605 THD- 1622 DEP- 1:35 TVD- 1 81 0 TI'ID- 1 849 DEP-231 T/ W SAK SNDS TVD-2370 TND-2578 DEP-691 EOC TVD-2394 TI"ID-2616 DEP-720 B/ W SAK SNDS TVD-2840 TIqD-3:332 DEP-1280 9 5/8" CSG PT TVD-3040 THD-3653 DEP-1532 K-lO TVD-3330 TIID-4118 DEP-1 896 AVERAGE ANGLE 51 DEG 29 MIN .~ ~ -~....~ ~.~.,.. K-5 TVD-4930 ' JUL 1 ~- 1~0 Abska Oi~ & Ga~ I I I I 1000 2000 3000 4000 VERTICAL SECT[ON I I 5000 . 6000 1 O0 50 0 50 1 O0 1 50 200 250 500 150 100 5O 5O 100 150 100 "' .~zoo 500 ZOO '~el~O0 / / 1 300 / / /110 300 1 500 5O / / / 500 O0 17'OO ! / / "1 ?00 / / .1 O0 150 ;0o i , M J I ! 200 250 :500 1 50 lO0 5O lO0 150 HORIZON ' PROJECTION SCALE I'~-~'.N. - 1000 FEET z C3 ARCO ALASKA. I ao · Ped 30. Well Ne. Z~ Revl,ed Pre e,ei Kupmruk Field. N=r~h Slope. AlmP, ke 5000 4000 _ 3000 _ 2000 . 1000 _ a 1000 _ WEST-EAST 1 000 0 1 000 2000 I I I TARGET TVD-58~3 DE:P- #ORTH 3S'43 EAST ~lbO TARGET LOCATION, 104~5" FSL. ZlO0' FEL eJEC. !3. T!2Jl. RSE ;~000 4000 ,I , I TD LOCATIONs !'~5'7' FSL. lq40' FEI. SEC. !3. TI21#. RSE b~URFACE LOCAT 2538' FNL. 220' FUt. 9EO. 24. T laN. N 4.1 DEG 47 MI N E 5080' (TO TARG;ET) k PARUK RIVER 20" DIVERTER SCHEMATIC I I HCR I 5 3 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANC.,E ~, OPERATION . . . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN TH E EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNULAR PREVENTER SRE 2/6/90 7 ,6 , 13 5/8" 5000BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLYAND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACKAND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TESTALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTORAND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOTA FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMSAND CLOSE BO'i-I'OM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE 8/22/89 DOYON 14 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 3G PAD 10. 11. 12. 13. 14. 15. 16. 17, 18. 19. 20. 21. Move in and rig up Doyon 14. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or RLL as needed. Run and cement 7" casing. (Isolation of the Colville sands will be performed if there is hydrocarbon presence.) Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel Shut in and secure well. Clean location and release rig. Fracture stimulate well. Reperforate and add additional perfs. ADDENDUM TO GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD WELL 3G-7A SIDETRACK PROCEDURE Due to a fault intersecting the wellbore and the resulting absence of Kuparuk "A" sand pay in well 3G-7, it is proposed to sidetrack the well to a new bottom hole location. The new target location at the top of the Kuparuk pay will be 200' south and 425' west of the original target location for 3G-7. The following sidetrack procedure will be performed between steps #8 and #9 of the general procedure. 8a. Set two cement plugs in the 3G-7 open hole wellbore: 1. Plug #1 from 7972' to 8400' MD (Kuparuk oil bearing interval in 3G-7 is 8072'-8338' MD). 2. Plug #2 from 5825' to 6200' MD. 8b. WOC, kick-off from top cement plug at 5874' and sidetrack to new 3G-7A bottom hole location. Continue with general procedure at step #9. Company CHECK LIST FOR NEW WELL PERMITS (1) Fe----~ ~e< ?~.//~2 1. Is the pe~: fee attached .......................................... (2 thru 8) (8) (3) Admin~9~5' ?/~_/~ 9. hru 13) 10. ~. ,'M.~z~. 7-/z- ~ ii. (10 amd 13) 12. 13. Lease & Well No. YES NO 2. Is well t~ be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is we!lbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... 14. 15. Does operator have a bond in force .................................. is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... Is cdnductor string provided ........................................ Wi!i surface casing protect all zones reasonably expected to sez~e as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. (4) Casg' 7- z- (14 thru 22) 16. 17. 18. 19. (23 thru 28) (6) OTHER ,~(?_~9~ ~~_~ ' thru 31) (6) Add: Geology: DWJ ~.~,' En$ineering: rev: 01/30/89 6.011. · -zR. LMARK$ /' 20. 21. 22. 23. 24. 25 26. 27. 28. For 29. 30. 31. Is this well to be kicked off from an existing we!lbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate weilbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate~ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~g)gp~ psig .. Does the choke manifold comply w/AP1 RP-53 (May 84) .................. Is the presence of H2S gas probable ............................. ~--- exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented 32. Additional requirements ............................................. INITIAL GE0. UNIT ON / OFF POOL CLASS STATUS AREA NO. SHORE , , , Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. ~H~~£1~UI~TOH ~ ~L O~IH~ $~1~V1~$, Iht~. DIRECT DIGITAL LOGGING COMPUTER PROCESSED ANALYSIS MICROFILMED LLLLLLLLLL LLLLLLLLLL IIIIIIIIII SSSSSSSS IIIIIIIIII 2SS$$SSSSS II SS S2 II SS II SS II SSSSSSSSS II SSSSSS~SS IIIIIiilii S~SSSSSSSS IIIIIIIIII SSSSSSSS DDDDDDDDD UU UU DDDDDDDDDD UU UU DD DD UU UU DD DD UU UU DD DD 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 HH MN PPPPPPPPPF' HHH HHH PPPPPPPPF'P HHNH HHHH PP HH MN NM HH PP MH HHMM HH PP HH MM HH PPPPPPPPPF'i HH NH PPPPPPPPPP: MM MM PP MN HH PP MM HH PP MN NH PP NH HH PP ill t1'11 11 I1 11 11 il llliIllll :222222222 '.2222222222 22 22 22 22 22 22 22 :2222222222 '.2222222222 00000000 0000000000 O0 O0 0.0 O0 O0 0'0 O0 O0 ,00 O0 O0 O0 0'0 O0 O0 O0 0000000000 000.00000 00000000 0000000000 0:0 0 00 0 · 00 0 '00 0 '00 0 00 0 00 0 O0 '0 0000000000 00000000 JJ JJ 0 .J,J 0 .J.J 0 .JJ 0 .d.J 0 JJ 0 JJ 0 JJ 0 .JJ JJ JJJJJJJJJJJJ JJJJJJJJJJ 00000000 0000000000 O0 O0 O0 O0 O0 O0 O0 O0 0.0 00 :00 O0 O0 00 ..00 O0 0000000000 00000000 UU UU UU UU UU UU UU UU UU UU UU UU UU UU UU UU UU UU UU UU UUUUUUUUUUUU UUUUUUUUUU 5'55555555555 555555555555 55 55 55 555555555 5555555555 55 55 55 555555555555 55555555555 LL LL LL LL LL LL LL LL LL LL LLLLLLLLLLLL LLLLLLLLLLLL YY YY YY YY YY Y¥ YY YYYY YY YY YY YY YY YY YY YY YY AA HH AAAA HHH H AA AA HHHH AA AA HH HH HH AA AA MM MHHH AA AA MN HH AAAAAAAAAAAA NH AAAAAAAAAAAA HH AA AA MM AA AA MM AA AA HH AA AA HH 9999999999 O0000000 999999999999 000000000 99 99 O0 99 99 O0 99 99 O0 999999999999 O0 999999999999 O0 99 O0 99 O0 99 99 O0 999999999999 000000000 9999999999 00000000 REEL HEADER **** Service name: &GSFO1 Previous reel: Date: 90/07/20 Comments: HEADER Origin: RECORDS Reel name: 491799 Continuation Page #: Ol TAPE'HEADER **** ********************** Service name: &G5F.O1 Previous ~ape: Date: 907~07/20 Comments: Origin: Tape name: 491799 Continuation #: 01 FILE. HEADER **** File name: .001 Haximum length: '1024 Service name: File type: 'LO Version Previous ?ile: Date: MNEM CH WN FN COUN STAT CTRY APIN LATI LONG SECT TOWN RANG EKIB EDF EGL PD LHF DMF RUN TIME DATE LCC SON LUN FL LUL ENGI WITN DD DL CBD1 CBLi TLI BLI TCS TLAB BHT MAT HT HSS DFD MV IS DFPH DFL RI,I RI'IF MFST MFS~ RH£: INFORMATION RECORDS CONTENTS UNIT ARCO ALASKA INC. . 3G-?~ APl NUH: 50-'1 03-20127-01. KUPARUK DATE LOGGED.: 07-16-90. NORTH SLOPE ..................... ALASKA ..................... USA ..................... 20J27,000 ................................ 0 Deg. 0 Hin. O, 0 Sec, N ......... · 0 Deg. 0 Nih, O, O Sec, W ......... 24 .............. 12N ............ 0SE ............ 89. 000 ......... 88 . 000 ......... 53.0 O0 ............... KB ................... 700, O00 ................ 1 ~/ 7/90 ............... ~ ..................... ~91.?~ ............. W-51 9~ ............. ~ORTH SLOP~ ,,, ~O~TH SLOPE ,,., HcKAY ,, , SEAL , . . 8550. 000.. 85~ , 000, . . 3649. 000, ~640,000., 7550,000.. , 8496.000... 700. 000 ~430. 000 ............... ~ 6~, 000 ~. 000 LSND .... C,I RCULATED ~ O. 8 O0.. , 45,000 .................. lO.O00 5,400 ; , ~5.0 ................... 7~, 000 ..... , ~ ~ 5~-0 ................... i ItIt4, i i· · , It It41Itii · mIt.· .41· ItI i i I I, It I · I II It41:I t! I· i· i i · I I i It i II · I It I ItI It I Ii i· i· i . I i I i ii It i I I It41I i ,I II · I·I · i · i· m I ·· I mi i , .,ii It i imt m· I , , I , i It I i I i , . I 41 , i I , It i · , · · IlIlIIlll! lllIIIIIl. IllllllllI tii1·1141II IIIlItIIIltII IltIIlttllIII · , iii ill II ii ii it i · · m , ii 141 ii IIlllllllIt IlllIlIItlI IlI·lllllI IlllitlllII IllIIIllll IlIItIIIIIII IIIIIIIIIIP I'IIItlIIlIII IIIIIIIIIII I$IlIIlIIII IIIIll141III IIIIIIIIII· IIIIIIIItII 11Ill141flll IIIIIIIllIlI Iflllt·lIll 41IIIIIIIill lIIIIll ItllIll till|el IIIllII Illllll IIIIIII II Ia lite It II II · I · ! · t t Ill IlllIlII lllllIIl TYPE CATG SIZE CODE 0 0 40 65 0 0 40 65 0 0 40 65 0 0 20 65 0 0 20 65 0 '0 20 65 0 0 4 68 0 0 34 65 0 0 34 65 0 0 2 65 0 0 3 65 0 0 3 65 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 0 3 2 65 0 3 2 65 0 3 2 65 0 '0 2 79 0 0 4 68 0 0 8 65 0 0 2 79 0 0 10 65 0 O 10 65 0 :0 20 65 0 9 20 65 0 0 20 65 0 '0 20 65 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 HR 0 ~ 4 68 HR 0 4 4 68 DEaF 0 1 4 68 DEGF 0 I. 4 68 0 2 20 65 0 2 20 65 LB/G 0 2 4 68 CP 0 2 4 68 0 2 4 68 0 2 4 68 OHHH 0 2 4 68 OHHH 0 2 4 68 DEGF 0 2 4 68 0 2 12 65 OHHH 0 2 4 68 ERROR MHEM NCST MCSS CS I, NFORMAT ION RECORDS CONTENTS UHIT 64,000 .................................................. MEAS ............................................. 9.625 ................................................... 8.500 ................................................... DEGF TYPE CATG SIZE 4 12 4 4 CODE 65 ~8 Page ERROR ~ell ~ell ~ell ~ell ~ell COMMENT Loca%ion Comment 1: SURFACE: 2538' Location Comment 2: Location Comment 3: Location Comment 4: File Comment l: CHLORIDES = 1800 PPM. FNL & 220" FWL RECORDS IN COMBINATION. HRI, SDL/DSN II RUN Well File Comment 2: DATA PRESENTED USING CONDUCTIVITY X OFFSET VALUES OF: Well File Comment 3:(-17 MMHOS FOR DEEP X) AND (7 MMHOS FOR MEDIUM Well Fil.e Comment 4: most closely match LIS tape written by: ANCHORAGE COMPUTING CENTER All curve and tool mnemonics used are those which Halliburton curve and tool mnemonics, HALL'ISURTON TO SCHLUMBERGER TOP BOTTOM MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT 3960,00 8580.00 GR SDL GAPI GR SDL GAPI 3964,25 8571.75 FDSN DSN2 Cps FDSN DSN2 CPS 3964.25 8571.75 ND~N DSN2 CPS NDSN DSN2 CPS 3964 25 8571 75 NPHI DSN2 DECP NPHI DSN2 DECP 3964,25 857~,75 NEAT DSN2 C/C NRAT DSN2 C/C 3964.25 8571.75 DPE SDL DPE SDL 3964,25 8571,75 DPHI SDL DECP DPHI SDL DECP 3964,25 857~,75 DRHO SDL G/C3 DRHO SDL G/C3 3964,25 8571,75 FSDL SDL CPS FSDL SDL CPS 3964,25 8571,75 Page NSDL PE PI=LC QL QS QPE RHOB CALl HDR HDX HMR HMX HDRS HI'IRS HDCN HHCH DFL SP TENS DLOD SDL SDL SDL SDL SDL SDL SDL SDL HRI HRI HRI HRI HRI HRI HRI HRI HRI HRI SDL SDL SDL CPS G?C3 IN OHHH OHHH HHHO HHNO OHHH LBS LBS GAPI HSDL PE PELC QS QPE RHOB CALl HDR HDX HDRS HHRS HDCN HHCN DFL SP TENS DLOD GE SDL SDL SDL SDL SDL SDL SDL SDL HRI HRI HRI HRI HRI HRI HRI HRI HRI HRI SDL SDL SDL CPS G/C3 IN ONHH OHHH HHHO HHHO ONHH LBS LBS GAPI 3964,25 3964,25 3964.25 3964.25 3964,25 3964,25 3964,25 3964.25 3964,25 3964.25 3964.25 3964,25 3964.25 3964,25 3964,25 3964,25 3964,25 3964,25 3964.25 3964,25 3964,25 8571.75 e57i.75 8571.75 8571.75 8571.75 8571.75 857~,75 8571,75 8571,75 8571.75 8571,75 8571.75 8571.75 8571.75 8571.75 857t.75 857'1,75 e57'1,75 e57~,75 C~L]I HDRI HDXI HNR1 HMX! HDRS'I HMRSl HDCNI HMCH1 DFLI ?ENS1 DLOD! SDL HRI HRI HRI HRI HRI HRI HRI HRI HRI HRI SDL SDL IN OH~H OHNM NNHO MHHO MV LBS LBS COMMEN CALI SDL HDR HRI HDX HRI HHR HRI HMX HRI HDRS HRI HMRS HRI HDCN HRI HMCN HRI DFL HRI SP HRI TENS SDL DLOD SDL T RECORDS IN 3964.25 3964.25 3964,25 3964,25 3964,25 OHNH 3964.25 OHHH 3964.25 NRHO 3964,25 NMHO 3964,25 OHNH 3964,25 NV 3964.25 LBS 3964.25 LBS 3964,25 8571.75 8571.75 8571.75 857'1,75 8571,75 8571,75 8571.75 8571.75 8571.75 8571.75 8571,75 8571.75 8571.75 DATA FORMA ENTRY BLOCKS ENTRY TYPE T SPECIFICA ENTRY BLOCK LEQEND m~mm TYPE DESCRIPTION 16 Datum spmci~ication block sub-type 0 Terminator ( no more entries ) ~SIZE CODE 16 1 66 TIONS Page DATA F 0 R M A T SPECIFICATIONS Pagm DATUM SPECIFICATION BLOOKS ************************************* MNEH SERVICE SERVICE API AP1 AP1 APl FILE ID ORDER # UNIT LOG TYPE CLASS MOD PRC # SIZE LVL SMPL RC PROCESS INDIOATORS DEPT 491799 8R SDL 491799 FDSN DSM2 · 491799 NDSN DStq2 491799 NPHI DSN2 4'91799 NRAT DSN2 491799 bPE SDL 491799 DPHI SDL 491799 bRHO SDL 491799 FSDL SDL 491799 NSDL SDL 491799 PE SDL 491799 PELC SDL 491799 QL SDL, 491799 QS SDL 491799 QPE SDL 491799 RHOB SOL 491799 CALl SDL 491799 HDR HRI 491799 HDX HRI 491799 HHR HRI 491799 'HMX HRI 491799 HDRS HRI 491799 HMRS HRI 491799 HDCN HRI 491799 HHCN HRI 491799 DFL HRI 491799 SP ~HRI 491799 TENS SDL 491799 DLOD SDL 491799 GR SDL 491799 CALl SDL 491799 HDR HRI 491799 HDX HRI 491799 HMR HRI 491799 HMX HRI 491799 HDRS HRI 491799 H~RS HRI 491799 NDCN HRI 491799 HMCN HRI 491799 DFL HRI 491799 FT 0 0 0 0 GAPI 94 O 0 1 0 CPS 94 0 0 1 0 CPS 94 0 0 I 0 DECP 94 0 0 I 0 C/C 94 0 0 1 0 94 0 0 1 0 DECP 94 -0 0 i 0 G/C3 94 0 0 '1 0 CPS 94 O 0 I 0 CPS 94 0 0 I 0 94 0 0 '1 0 94 0 '0 1 0 94 0 0 i 0 94 !0 0 '1 0 94 :0 0 I O G/C3 94 .0 ~0 i 0 IN 94 .0 :0 I 0 94 0 0 'l 0 94 ~0 0 1 0 94 0 0 'I 0 94 0 O '1 0 OHHH 94 0 0 1 0 OHMM 94 :0 0 'I 0 MMHO 94 :0 O I 0 HMHO 94 :0 0 'I 0 OHMH 94 0 0 1 0 HV 94 :0 0 1 0 LBS 94 '0 0 1 O LBS 94 0 0 'I 0 GAPI 94 ~ 0 I 0 IN 94 0 0 1 0 94 0 0 'I 0 94' 0 0 "I 0 94 :0 0 '1 0 94 0 .0 1 0 OHHH 94 0 0 '1 0 OHHM 94 0 0 1 0 HHHO 94 0 .,0 1. 0 HMHO 94 0 0 'I 0 OHMH 94 :0 0 I O 4 0 1 68 4 0 1 $8 4 0 1 ~8 4 0 1 68 4 0 1 68 4 0 I ~8 4 0 1 68 4 0 1 &8 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 t 68 4 0 .1 68 4 0 1 68 4 0 I 68 4 0 1 68 4 0 I 68 4 0 '1 68 4 0 t 68 4 0 '1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 t 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 .t 68 4 0 t 68 4 0 .1 68 4 0 1 68 4 0 1 68 4 0 '1 68 4 0 I 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 000000 000000 000000 000000 000000 000000 000000 0000~00 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 OOO000 000000 000000 O00OO0 000000 O0000O 000000 000000 000000 000000 000000 '000000 O00000 000000 000000 000000 000000 000000 000000 000000 000000 0.0.0000 000000 000000 O00000 000000 000000 000~000 000000 000000 O00000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 OOOO00 000000 000000 O00000 000000 000000 00000.0 OOO000 000000 000000 O0000O 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O00000 000000 000000 0.00000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 DA'TA FORM.AT DATUM SPECIFICATION BLOCKS ************************************* SPEC I F I CAT IONS Page SERVICE SERVICE API API MNEM ID ORDER # UNIT LOG TYPE API CLASS APl MOD FILE # PRC SIZE LVL SMPL RC PROCESS INDICATORS SP HRI 491799 MV 94 0 TENS SDL 491799 LBS 94 0 DLOD SDL 491799 LBS 94 0 4 0 1 68 4 0 1 G8 4 0 1 60 000000 000000 000000 000000 000000 .O00OO0 000000 000000 000000 DEPT DRHO RHOB HDCN HDR DFL 8571 -- 1 -12345 -999 -999 .75.0 .069 .931 .000 ,250 .250 8500,000 -.071 1 .~J1 508.045 -999.250 -999.250 8400.0.00 .055 2.365 356.27.7 -999.250 -999.250 8~0.000 .053 2.421 38! ,397 -999,250 .-999,250 82O0. O00 .062. 2,449 250,323 -999.250 -999.25'0 DATA RECORDS GR FSDL CALI HHCN HD~ SP FDSN NSDL HDR DFL HMR TENS NDSN PE HDX SP HHX DLOD NPH I PELC HHR TENS HDRS NRAT QL HMX DLOD HHRS 97.894 13005.217 8.400 -i2345,000 -999,250 -999,250 I 02,838 12975,328 7,254 519,652 -999,250 -999,250 98,289 7604,438 8.689 370,484 -999,25,0 -999,250 1.0.0,992 6867,217 8,732 390,288 -999,250 -999,250 93,345 6682.327 8.691 252,541 -999,250 -999.250 1452.829 16030,883 0,00'0 2,085 -999,250 -999,250 1488.002 15975.520 354,156 2,237 -999,258 -999.250 157.0,592 16680,246 275.474 3,194 -999,250 -999,250 17:02,454 1634.0,701 290,559 2.776 -999,250 -999,250 '1900.979 16364,520 198.492 4,189 -999.250 -999.250 13852.803 11.242 0.000 I23450000, -999.250 -999,250 13711.072 10,85@ 1 06. 287 281 ,405 -999,250 -999,250 'i4247,387 5,.044 73.920 290,~03 -999,250 -999,250 't4589,527 4,5i9 74,8'12 294,'117 -999,250 -999,250 15141,951 4,001 45.535 294.141 -999,250 -999,250 ,484 14.640 O,O00 6390,102 -999,250 .486 14.942 444· .057 5924.309 -999,25.0 .452 7.633 327,472 5764,192 -999,250 .42:0 6,594 353.314 5676, 855 -999,250 .380 5.186 225. 755 5735.08 0 -999.250 10,117 .007 0.000 -29,000 -999.250 9. 776 -,019 56,55? 1435.000 -999,250 9,625 .008 39.043 1495,000 -999,250 9, O92 ,0.05 37,250 1483,000 -999,250 8,451 · 009 24. 528 1551 .000 -999.250 DPE QS HDRS GR HDCN DPHI QPE HMRS CALl HHCN 0.000 ,0i4 -i2345.000 -999,25.0 -999,250 .436 -1,OOO -12345,000 -999,250 -999,250 0,000 ,.024 1,968 -999,250 -999,250 .436 -1.000 1.924 -999.250 -999,250 0,000 -, 033 2,807 -999,250 -999,258 ,173 -1.000 2,699 -999,250 -999,250 0,000 ,002 2.622 -999.250 -999,250 ,139 -1.000 2,562 -999,250 -999,250 '0,000 -,.021 3,995 -999,250 -999.250 ,122 -1 .000 3.960 -999.250 -999,250 Page DATA RECORDS D£PT ~R FDSN NDSN NPH! NRAT DP£ DPHI DRHO F~DL NSDL PE PELC ~L ~S ~PE RHOB ~ALI HDR HDX HHR HHX HDRS HHRS HDCN HHCN DFL SP TENS DLOD GR CALl HDR HDX HHR HHX HDRS HHRS HDCN HHCN DFL SP TENS DLOD Page 8100,000 99.146 1548.669 .~092 7867,772 17264,066 2.381 8.784 269,905 353,279 362.393 3,244 -999,250 -999,250 -999,250 -999,258 -999,25.0 -999,250 800.0..000 91,499 196.0.661 ,064 7743,661 16859,793 2,365 8,803 154.9'06 186,143 190.817 5.887 -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 7900.000 92,884 1999,215 ,047 7306.66! 16467,793 2.384 8,894 148,104 192,438 '186.343 6,349 '-999,250 -999,250 -999,250 -999,250 -999,250 -999.250 7800.'000 67,965 1751.. 865 -, 027 4569,438 14011 ,338 2,575 8,801 20. 056 17,229 13,580 252.994 -999,250 -999.230 -999.250 -999.250 -999,250 -999,250 7700.000 174.758 1420.887 ,060 9:024,328 172.71,062 2,270 8,958 263,262 328,649 354.653 3.794 -999,250 -999,250 -999,250 -999,250 -999.250 -999.250 13889.414 ,446 9,516 0.000 .163 3.980 5.324 -.013 ,008 -1.000 69.524 321,676 36,158 2,831 2.759 295.797 5211.063 1467.000 -999.250 -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,25O 14995.313 ,366 8.114 O,O00 ,173 3,468 4.563 -,.043 ,036 -I,000 29,566 170.861 16.260 5.372 5,241 285.780 5152.838 I123,000 -999.250 -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 '15416,535 ,363 8,182 0.000 .161 3,305 4,470 -,019 -.057 -1,000 29,231 154,538 13,943 5.196 5,366 282,389 4759.825 1147.'000 .-999,250 -999.250 -999,250 -999,250 -999,250 -999,25'0 -999,250 -999,250 14934,697 ,417 9,045 0,000 ,045 6.775 8,157 ,034 ..002 -1,0'00 8.087 8.815 8,708 58.043 73.638 273,510 5342,066 1535,'000 -999,250 -999.250 -999,250 -999,250 -999,250 -999,25,0 -999,250 -999,2S0 13554,855 .474 10,121 0,'000 ,230 3.8t4 4,365 .857 ,009 -1.000 80.17i 307,282 36,281 3,043 2,820 302.346 4919.941 1355.000 -999,250 -999.250 -999.250 -999,250 -999,250 -999.250 -999,250 -999,250 DATA RECORDS DEPT GR FDSN NDSN NPHI NEAT DPE DPHI DRHO FSDL NSDL PE PELC QL QS QPE RHOB C~LI HDR HDX HHR HHX HDRS HHRS HDCN HMCN DFL SP TENS DLOD GR CALl HDR HDX HHR HMX HDRS HHRS HDON HHON DFL SP TENS DLOD 7600.000 118 ,039 8259 2.308 $I 390.358 418 -999,250 -999 -999,250 -999 ,066 1312,966 13218.777 ,474 ,771 16757,426 3,443 3,922 ,756 283,314 68,532 353,843 ,133 2,614 298,354 5080,058 ,250 -999,250 -999.250 -999,250 ,250 -999,250 -999,250 7500,'000 376 -999,250 -999 -999,250 9 397,240 439 -999,250 -999 -999,250 -999 ,017 -999,250 -999,250 -999.250 ,250 -999,250 -999,250 -999,250 ,456 297,287 22,436 359.396 ,245 2,922 307,3.04 4672,488 ,250 -999,250 .-999,250 -999.250 ,25.0 -999,250 -999,250 7400,000 13.9,622 -999,250 -999,250 -999,250 10,.090 260.674 266,167 -999.250 -999,250 -999,250 -999,258 730'0,000 -999,230 -999,250 .-939,250 -999,250 -999,250 -999,250 -999,250 0,'000 :0.'000 5,023 12345~'0.00, 7200,~000 -999,25~0 -999,250 -999,250 -999.250 .-999.250 -999.25'0 -99'9.250 180.709 41.956 4,239 292,153 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 2-06,468 42.,994 244,509 4,385 294,631 4526,929 -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 0.000 O.OOO -12345,.000 4337,7.00 523, -999,250 -999,250 -999,250 -999.250 -999,250 -999,250 -999,250 -999,250 -999.250 -999,250 -999.250 -999,250 2.03.278 23,729 4,390 4876.273 1167.000 10.682 -,044 29,750 1147,-000 -999,250 -999,250 -999,250 32,995 1111,"008 -999,250 -999,250 -999,250 19,586 1 091 ,O00 -999,250 -999,250 -999,250 -999,258 -999,250 -12345,008 -999,250 -999,250 -999.250 -999,250 4.196 Page 0.000 ,030 2.562 -999,250 -999.250 .207 -'i . 000 2.392 -999.250 -999,250 -999,250 -999,250 2,517 -999.250 -999,250 -999,250 -999,250 2.277 -999.250 -999,250 -999,2,50 -999,250 3,836 -999,250 -999,250 -999,250 -999.250 3.757 -999,250 -999,250 -999,250 -999,250 -999,250 150,104 -t 2345. 000 -999.250 -999,250 -999,250 8. 400 -12:345,000 -999,250 -999,258 -999.250 102.376 227,769 -999,250 -999,250 -999.250 9,993 238,326 11 DATA DEPT ~R FDSN NDSN DRHO FSDL NSDL PE RHOB CALI HDR HDX HDCN HMCN DFL SP HDR HDX HM~ HMX DFL .~P TEHS DLOD 7100.000 -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 -999,250 229,457 54.241 27.0.708 26.513 3,490 292,980 4294.031 1099,000 7000.000 -999,25.0 -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 -99'9,250 197,993 40,001 232.970 17.465 3,899 291,175 4366,812 1187,800 6900,~000 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999.25,0 -999,250 -999,25'0 · -999,250 -999,25.0 -999,250 -999,250 184,239 30,223 214,323 17,945 4.520 292,402 4279,476 991.000 68.00,000 -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 -999.250 171.052 3.1.851 199.833 14,533 4,468 274.650 4279.476 1011,000 6700.000 -999,250 -999.250 -999,250 -999.250 -999,250 -999.250 -999,250 -999,250 -999.25.0 -999.250 -999.280 -999,250 -999.250 -999.250 -999,250 201,542 41,900 245.677 19.420 3,608 291.644 4075,691 1083.0i00 RECORDS NPHI NRAT DPE DPHI PELC QL QS QPE HMR HMX HDRS HHRS TENS DLOD GR CALI HDRS HMRS HDCN HHCN Page 12 -999,250 -999,250 -999.250 -999,250 -999,250 -999,250 -999.250 -999.250 -999.250 -999,250 -999,25'0 -999,250 -999.250 -999.250 118.857 10,446 3.503 3,389 205,452 295.048 -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 -999,250 105,277 10, 093 4,089 3,942 244,546 253,692 -999,250 -999,250 -999,25.0 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999. 250 -999.250 -999. 250 -999.250 -999,250 1 14.242 1 0,231 4 . 453 4,245 224,582 235 , 5'33 -999.250 -999.250 -999.258 -999.250 -999,250 -999,250 -999.250 -999,250 -999.250 -999,250 -999.250 -999.250 -999.250 -999,250 79,106 8.987 4,638 4,467 215,596 223..850 -999,250 -999,250 -999,250 -999 , 2.50 -999,250 -999. 250 -999,250 -999,250 -999.250 -999,250 -999.250 -999,250 -999,250 -999,250 115,758 1 O, 145 3. 800 3,508 263. 138 278,692 DEPT DP, HO RNOB HDCN HDR DFL FSDL CALi HHCN NDX FDSN NSDL HDR DFL NHR TENS 6600.000 -999.250 -999 -999.250 -999.250 -999 -999.250 -999.250 -999 -999.25'0 -999.250 -999 185.459 40,241 214 3.964 293.208 3857 6500.0'00 -999,250 -999 -999,250 -999,25.0 -999 -999,250 -999.250 -999 -999,250 -999,250 -999 223.696 51.174 271 3,168 298,400 3871 640~0.000 -999,250 -999 -999.250 -999.250 -999 -999.250 -999.250 -999 · -999,250 -999,250 -999 210.169 48.941 249 3.632 294.399 3959 6300,0'00 -999.25:0 -999 -999,250 -999,250 -999 -999.250 -999,25'0 -999 -999.250 -999.250 -999 225.070 50.175 273 3.172 295.670 4.032 620.0. iOOO -999. 280 -999 -999. 250 -999.25.0 -999 -999. 250 -999. 250 -999 -999. 250 -999. 250 -999 245. 569 .58. 384 3'04 2,761 301 ,53.0 3828 .250 ,250 .250 °250 ,110 ,350 .250 ,250 ,250 ,250 .252 .9'06 ,250 ,250 .250 .250 ,280 .243 ,250 ,25.0 .250 .250 .438 , .023 ,250 ,250 .250 ,250 ,207 ,238 DATA NDSN PE HDX SP HMX DLOD -999.250 -999,250 -999.250 -999,250 19,148 1019.~.00 -999.250 -999.250 -999.250 -999.250 24.595 1059.~8.00 -999,250 -999,250 -999,258 -999,250 22.863 1071.900 -999,250 -999,250 -999.250 -999.250 22,680 1051.000 -999,250 -999,250 -99'9,250 -999,250 27,272 '1.051,~00 RECORDS NPHI PELC HHR TENS HDRS NRAT QL HHX bLOb HHRS DPE QS HDES HDCN DPHI QPE HHRS CALI HHCN -999.25 0 -999.250 -999.250 -999.25 0 4.505 -999.250 -999.250 -999.250 -999.250 4.383 -999.250 -999.250 -999.250 99,937 221.959 -999.250 -999.250 -999.250 10.987 228.175 -999.250 -999.250 -999,250 -999,250 3,501 -999.250 -999.250 -999.250 -999.250 3.342 -999. 250 -999.250 -999.250 I 15.495 285.638 -999.250 -999.250 -999.250 t 1.3,95 299.222 -999. 250 -999.250 -999.250 -999.250 3.943 -999.250 -999.250 -999.250 -999..250 3.772 -999.250 -999.250 -999.250 107.510 253.62'1 -999.250 -999.250 -999.250 11.213 265.099 -999.250 -999.250 -999.250 -999.250 3.551 -999.250 -999.250 -999.250 -999.250 3.372 -999.25:0 -999.250 -999.250 125.779 281 .630 -999.250 -999.250 -999.250 1 0. 653 296 ..530 -999.250 -99'9.250 -999.250 -999.250 3.035 -999.250 -999.250 -999.250 -999.250 2.711 -999.250 -999,250 -999,25.0 129,602 329,448 -999.250 -999.250 -999.250 9.795 368.802 Page DEPT DRHO RNOB HDCN NDR DFL FSDL CALI HHCN HDX SP FDSN NSDL HDR DFL HHR TENS DiATA NDSN PE HDX SP HHX DLOD RECORDS NPHI PELC HHR TENS HDRS NRAT QL HMX DLOD HMRS DPE QS HDRS HDCN DPHI QPE HHRS CALI HHCN Page 14 6100,000 -999,25'0 -999,250 -999,250 190,886 3.643 6000,000 -999.2S0 -999,250 -999,250 332.156 1,992 5900. 000 -999,250 -999,250 -999.250 203. 020 4 ,.229 550.0,~000 -999,250 -999,250 -999.250 323,553 1.517 570.0,000 -999.250 -999,250 -999,250 316,3J3 1.956 -999.250 -999,250 -999,250 -999.25,0 36.968 2~?.972 -999,250 -999,250 -999,25-0 -999,250 86,549 306,273 -999,250 -999,250 -999,25,0 -999,258 49,718 2.95,792 -999.250 -999,25,0 -999,25,0 -999,250 81 .779 299,723 -999,250 -999,250 -999,250 -999,250 9.0,995 299,974 -999,250 -999,250 -999,250 -999,250 231.638 3711.790 -999,250 -999,258 -999.250 -999,250 441.577 3682.678 -999,250 -999.250 -999,250 -999.250 230,333 3668,122 -999,250 -999.250 -999,250 -999.250 453.574 3406.113 '999.250 -999,250 -999,250 -999,250 424.849 34~06,113 -999,250 -999,250 -999,250 -999,250 14.60'0 1011.900 -999,250 -999.250 -999.250 -999,250 41.874 1063,000 -999,250 -999,250 -999,250 -999,250 21,645 -999.250 -999.250 -999,250 -999,250 42.872 947.960 -999.250 -999.250 -999,250 -999,250 45.172 943.000 -999,250 -999.250 -999,250 -999.250 4.224 -999.250 -999.250 -999.250 -999,250 2.069 -999,25'0 -999,250 -999,25,0 -999.250 4.237 -999. 250 -999,250 -999.250 -999,250 2, ~003 -999. 250 -999,250 -99'9.250 -999,250 2,281 -999,250 -999,250 -999,250 -999.250 3.960 -999,250 -999,250 -999.250 -999,250 1 .819 -999,250 -999,258 -999,25,0 -999,250 4.234 -999,25.0 -999,250 -999,250 -999,250 1,694 -999,250 -999.,250 -999.250 -999,250 2.865 -999.250 -999,250 -999,250 117.472 236,759 -999.250 -999.250 -999.250 '159.992 483,322 -99'9,250 -999,250 -999,250 204.489 236. 039 -999.25.0 -999.250 -999.250 139.952 499,374 -999,25'0 -999,250 -999,250 133,755 438.354 -999,250 -999,250 -999,250 13.194 252.506 -999.250 -999,250 -999.250 10.t48 549.679 -999.250 -999,250 -999,250 10,174 236,205 -999,250 -999,250 -999,250 10,462 590..479 -999.250 -999,250 -999,250 14.21 494.216 DEPT DRHO RHOB HDCN HDR DFL ~R FSDL CALI HMCN HDX ~P FDSN NSDL HDR DFL TENS DATA NDSN PE HDX SP HMX DLOD RECORDS NPHI PELC HHR TENS HDRS NRAT QL HHX DLOD HMR$ DPE QS HDRS ~R HDCN DPHI QPE HHRS CALI HMCN Pag~ 15 -999 -999 -999 303 SSO0 -999 -999 -999 282 2 S40.0 -999 -999 .--999 240 2 5300 -999 -999 -999 303 5200 -999 -999 -999 225 2 .000 ,250 ,250 .250 .602 ,970 ,000 .250 ,250 ,250 .985 ,308 .000 ,250 ,250 ,250 ,390 ,0 O0 ,250 .250 ,250 ,200 .941 , O00 ,250 ,25 0 ,250 ,340 ,926 -999,250 -999.250 -999.250 -999,250 8t.224 298.883 -999.250 -999,250 -999.250 -999.250 24.460 294.'199 -999,25.0 -999.250 -999,250 -999,250 57.394 294,243 -999,250 -999,2S0 -999.250 -999.250 80.064 293,2..07 -999,250 -999.250 -999.25i0 -999,250 5t,77! 286,936 -999 -999 -999 -999 404 3333 -999 -999 -999 -999 359 3493 -999 -999 -999 -999 309 3435 -999 -999 -999 -999 414 3289 -999 -999 -999 -999 281 3289 ,250 ,250 ,250 ,250 ,335 ,333 ,250 ,250 ,250 .250 ,927 ,449 ,250 ,250 ,250 ,250 ,772 .225 .250 ,2SO .2SO ,250 ,212 ,665 ,250 ,250 ,250 ,250 ,352 -999,250 -999.250 -999,250 -999,250 40,529 1087, ..000 -999.250 -999.250 -999..,250 -999,250 36.799 979,000 -999,250 -999.250 -999,250 -999.250 28.747 979.00~0 -999,250 -999.250 -999.250 -999,250 42.,67~ 1059.~080 -999.250 -999,250 -999.25'0 -999,250 24,.656 987,~000 -999,250 -999.250 -999.250 -999,250 2.421 -999.250 -999,25 0 -999.250 -999,250 2,798 -999,25'0 -999,250 -999,250 -999.250 3,146 -999,250 -999,250, -999.250 -999,25'0 2,405 -999,25'0 -999.250 -999,250 -999.250 J °4?3 -999,250 -999.250 -999.250 -999,250 2.212 -999,25.0 -999,250 -999,250 -999.250 2.606 -999,250 -999,250 -999,250 -999,250 2,882 -999,25.0 -999.25.0 -999.250 -999,250 2.129 -999.250 -999.250 -999.250 -999,250 3.2.09 -999,250 -999.250 -999.250 131.448 413,135 -99'9. 250 -999.250 -999,250 117,934 357.369 -999.250 -999,250 -999.250 I 1 0. 485 31 7,911 -999,25.0 -999,250 -999.250 95,520 415.720 -999,250 -999.250 -999.25,0 131 , 250 287,963 -999.250 -999.250 -999.250 14,049 452.148 -999.250 -999.250 -999.250 i3.2i7 383,796 -999,250 -999.250 -999,250 11,344 346.984 -999,,250 -999.250 -999.250 11.308 469,.802 -999,250 -999,250 -999,250 11,532 3 ! 1,653 DEPT DRNO RHOB HDCN NDR DFL GR FSDL CALI HHCN NDX SP FDSN NSDL HDR DFL HHR T£NS DATA NDSN PE HDX SP HHX DLOD RECORDS NPHI PELC HMR TENS HDRS NRAT QL HHX DLOD HMRS DP£ QS HDRS GR HDCN DPHI QPE HHRS CALI HMCN Page 16 5100.'000 -999,250 -999,250 -999,250 248.773 2,350 50.00.000 -999,250 -999,250 -999,250 242.001 2,512 4900,~00 -999,250 -999,250 -999,250 239,394 2,596 4800,000 -999,250 -999,250 -999,250 225,880 2.700 4700.000 -999,250 -999,250 -999,250 2't8,964 2,686 -999.25-0 -999,250 -999,250 -999.25.0 62,771 289,'127 -999.250 -999.250 -999,250 -999.25~0 57,959 290,236 -999,250 -999.,250 -999,250 -999,250 57.552 287,862 -999,25:0 -999,250 -999,250 .-999,2.50 53.6i4 292.113 -999,250 -999,250 -.999,250 -999,250 46,787 289,7.73 -999 -999 -999 -999 324 3202 -999 -999 -999 -999 3t8 .3289 -999 -999 -999 -999 310 3'1~0'0 -999 -999 -999 -999 295 3095 -999 -999 -999 -999 289 3129 .250 ,250 .250 ,250 .592 .329 ,250 ,250 ,250 ,250 .562 ,665 .250 ,25.0 ,250 ,250 .089 ,436 .250 ,250 ,250 ,250 .893 .880 ,250 .250 ,250 ,250 .173 ,548 -999.250 -999,250 -999.250 -999.250 32,483 125'1.9.00 -999,250 -999,250 -999,250 -999,250 31 ,425 11.19.000 -999,250 -999,250 -999,250 -999,250 29,81.0 1.087 .~00 -999.2,5'O -999,250 -999.250 -999.250 28,278 '1007,:000 -999,250 -999,250 -999,250 -999.250 26.225 1163.000 -999.250 -999,250 -999.250 -999.250 3,075 -999,250 -999,250 -999.250 -999,250 3,164 -999.25'0 -999,250 -999,250 -999,250 3,152 -999,250 -999.250 -999,250 -999,250 3,443 -999,250 -999,250 -999,250 -999,25 0 3, ?24 -999.250 -999,250 -999.250 -999.250 2.693 -999,250 -999.250 -999,250 -999,250 2,823 -999,250 -999,250 -999.250 -999,250 2,851 -999,250 -999,250 -999,250 -999.250 3. 023 -999,250 -999.250 -999.250 -999,250 3,224 -999.250 -999,250 -999,25'0 99,674 325,195 -999,250 -999,250 -999.250 115.824 316,, 012 -999,25-0 -999.250 -999,25.0 113.71.5 317,292 .-999.250 -999,250 -999,25~0 98. 355 290.414 -999,250 -999.250 -999.250 94.664 268,514 -999.250 -999.250 -999.250 10,517 371,279 -999.250 -999.250 -999.250 10,455 354.229 -999,250 -999,250 -999.250 11,644 350.733 -999,250 -999.250 -999,250 I I . 947 330.797 -999.250 -999.250 -999,250 10,839 310,128 DEPT DRHO RHOB HDCH HDR DFL GR FSDL CALI HHCN- SP FDSN NSDL NDR DFL HMR TEHS ,DATA HDSN PE ND~ SP HHX DLOD RECORDS NPHI PELC HHR TENS HDRS NRAT QL HHX DLOD HI'IRS DPE HDRS HDCN DPHI QPE HHRS CALI HMCN Pag~ 4600 -999 -999 -999 200 3 4500 -999 -999 -999 194 440.0 -999 -999 · -999 191 3 4300 -999 -999 -999 212 420:0 -999 -999 -999 193 2 ,000 ,250 ,250 ,250 ,902 ,0tl ,-000 ,250 .250 ,250 ,748 ,237 ,000 ,250 ,250 .250 ,253 ,15! 000 ,250 250 ,250 16,0 022 000 ,250 ,250 ,250 225 945 -999.250 -999,250 -999.250 -999,25'0 44,486 29t,255 -999,250 -999,250 -999,250 -999,250 42.028 291,8tl -999.25O -999,250 -999.250 -999.250 41,107 291,368 -999.250 -999,250 -999,250 -999,250 44,26.0 290,549 -999,250 -999,250 -999~'250 -999,250 38,972 291,724 -999,250 -999.250 -999,250 -999.250 256.669 2954.876 -999.250 -999.250 -999.250 -999.250 247.822 2882.096 -999,250 -999.250 -999.250 -999.250 25,0,084 2882..~096 -999,250 -999.250 -999,250 -999,250 278,374 3333.333 .-999,250 -999,250 -999,250 -999.250 257.682 2838,427 -999,250 -999.250 -999.250 -999.250 23,273 -999,250 -999.250 -999,250 -999,250 2~0, .765 1027, -999,250 -999.,250 -999,250 -999,250 22.466 -999,250 -999,250 -999,250 -999,250 23.105 1.079,'000 '-999,250 -999,250 -999,250 -999,250 21,139 963,88:0 -999.250 -999,250 -999.250 -999.250 3,9'14 -999.250 -999.250 -999.250 -999,250 4,191 -999,25 0 -999.250 -999,250 -999.250 4,2O6 -999.250 -999,250 -999,250 -999,250 3. 736 -999..,250 -999.250 -999,250 -999.250 4,055 -999,250 -999.250 -999,250 -999,250 3.510 -999,250 -999.250 -999. 250 -999,250 3,739 -999,250 -999,250 -999,250 -999,250 3,676 -999,250 -999.250 -999.250 -999.250 3.26'I -999,250 -999,250 -999,250 -999.250 3,492 -999,250 -999.250 -999,25.0 110,946 255.493 -999.250 -999,250 -999,250 ! 08,705 238.620 -999,250 -999,250 -999,250 1.01 . 849 237.734 -999,250 -999,25.0 -999,250 JO3,563 267,652 -999.250 -999,25,0 -999,250 95,191 246,591 -999,250 -999,250 -999.250 t1.076 284,921 -999.250 -999,250 -999,250 I 1 , 666 267.440 -999.250 -999,250 -999,250 11,823 272.071 -999,250 -999,250 -999,250 I J, 239 306 ,.647 -999.250 -999,250 -999.250 286.393 DiATA RECORDS DEPT GR FDSN NDSN NPHI NRAT DPE DPHI DRHO FSDL NSDL PE PELC QL QS QPE RHOB CALI HDR HDX HHR HMX HDRS HHRS NDCN HMCN DFL SP TENS DLOD GR CALl HDR HDX HNR HMX HDRS HHRS HDCN HMCN DFL SP TENS DLOD 4100.000 -999,250 -999,250 -999,250 111,970- 6,527 -999,25-0 -999,250 -999,250 -999.25.0 22,355 289.808 -999,250 -999,250 -999,250 -999,250 29'1,5'18 4000,~00 -999,250 -999,250 -999,250 201.422 2,784 -999,250 -999,250 -999.25'0 -999,250 -999,250 -999,250 -999.250 -99'9,250 -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 96,3?7 13,334 125,943 9.868 8.174 7.953 122.346 125.737 2852.983 983.8;00 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,256 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,258 -999.250 80,293 12,545 266,1'13 16.441 3.950 3.4t3 253.!89 293.000 2954.876 1'387.~00 Page FILE TRAILER File name; &GSFO! Maximum leng%h: 1024 TRA I LER RECORDS ~ePvice name: Verzion #: File type: LO Next ~ile: Date: Page *** FILE HEADER ********************** Fi, le name: ,002 Maximum length: 1024 ice name: File type: LO Version #: Date: Previouz f'ile: MNEH CH kin FN COUN STAT CTRY APtN LATI LONG SECT TOWN RANG EKB EDF EGL PD LMF DHF ~UN DATE LCC SON LUN FL' LUL ENGI W I TN DD DL CBDI CBL1 TLI BLI TCS TLAB BHT HRT HT riSS DFD MVIS DFPH DFL RM RMF NFST NFSS AMC I NFORMAT I ON RECORDS CONTENTS UNIT TYPE CATG SIZE CODE ARCO~ALASKA INC ................. 3G-? API NUM: 5:0-103-20i27-0! ................ KUPARUK DATE LOGGED.: ..07-I6-90 ................ NORTH SLOPE .................................... ALASKA .................................... USA .................................... 2.0127.900 ............................................... i !. ! ............... ! ........ 0 Deg , . c ....................... 24,, ,i,,, , ,, ,,, .,, , ,, , ..... ,,, ,,,, ...... , ,, , ,, .................... , .......................... .OeE,..: ........ :..: ............ : ..... .: ....... : ........... 89. O:OO .................................................. FT 88 0'00 FT 53~ 000 ......................................... MSItlllIIIIlIIIIIIIIIIIIIIIItlIIIlIIIIIIIIIIIIIIIIII~III ~ I I I 66 ~ I I : I I I: I I ............. : ....................... :II O0 · ' I II III IllllllllIlllll IlIIIIllll141111111111II II 16~ 7~901.. .............................................. 491.799 .............................................. W-51.939 .. ........................................... NORTH SLOP~ $lmIIllllltIlI'llIlIlIIlIllllllIllIII NORTH SLOPE .................................... McKAY .................................... BEAL ...... . .............................. 855'0.000, ......................... .. ~ ..................... FT 8532,00'0 ................................................ FT 3649,000 ........................ , ....................... FT 3640,000 .......................... ,., .................... FT 755~0 000 FT 8496 000 I Itlll Illlll 141 II IIi ilIl.ll 11411111 $1 IlItlll : : : : I, ,,.41.. ... ,...........,....... ... HR ' HR II IIIllt Ill IIlIIlIll141qlIIlIlll lei 162 t 0:0 0 ...... · I · ..................... · .......... DEGF 162.,~00 ....................................... DEGF LSND ............... ........... ClRCULATEb .......................... 1 O, 800 ......... , .............................. LB?G 45,000 ........................................ CP 1'0. 000 ........................... ......... .... 5.4 0'0 .............................. ,. .......... '1, ~5'0 ..................................... , .... I 340 72,0-00 .................................... NE~S .... · ............................... 2,52:0 ........................................ , It It Ii II i ~ II i I tI II I I ii I i~Ii Ii i 41 i i I I iI i i i ii OHMH OHHH DEGF OHMM o 0 o · 0 0 o 0 · 0 0 0 0 .0 0 0 0 o o 0 o :0 0 0 ~0 0 3 0 0 3 0 0 0 0 0 0 0 0 .0 t3 0 0 0 0 0 0 ~0 0 0 0 3 0 0 0 0 3 0 3 ,0 2. 0 4 0 0 1. .0 .0 0 .0 0 2 -0 2 0 0 2 ;0 2 40 40 40 20 20 20 4 34 34 3 3 4 4 4 2 2 2 2 4 2 1 0 10 20 20 20 20 4 4 4 4 4 4 4 4 4 4 20 20 4 4 4 4 4 4 4 4 65 65 65 65 65 65 65 65 65 65 65 79 65 79 65 65 65 65 65 68 68 65 Page ERROR 2 0 MNEM mmmm MCST MCSS INFORMATION RECORDS CONTENTS 64 0'00 MEA$ .............................................. g 625 .............................................. UNIT DEGF TYPE CATG 2 2 3 3 SIZE 4 12 4 4 CODE 68 68 68 Page ERROR 21 COMMENT RECORDS Well Location Comment i: Well Location Comment 2: Well Location Comment 3: Watt Location Comment'4: Well File Comment l: ~ell File Comment 2: Well File Comment 3: SURFACE: 2538' FNL & 2~.0' FWL CHLORIDES = 18~0 PPM. HRIj SDL/DSN II RUN DATA PRESENTED USING CONDUCTIVITY X OFFSET (-I? MMHOS FOR DEEP X) AND (? MMHOS FOR IN COMBINATION, VALUES OF.: MEDIUM X). Well Fil~'Comment 4: ******************************************************************************** ******************************************************************************** ** LIS tape wpi~ten'b~: ANCHORAGE COMPUTING CENTER ** All curve .and ~ooI mnemonics used are those which most closel~ .match .** Halliburton cupve and tool mnemonics. ********************************************************************************* ******************************************************************************** HALLIBURTON TO SCHLUMBERGER TOP BOTTOM MHEM SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT 3960,00 'eseo,o'o GR2 SDL GAPI GR SOL GAPI 7550,00 8576.75 FDSN2 DSN2 Cps FDSN DSN2 CPS 7550,00 8576,75 NDSN2 DSN2 CPS NDSN DSN2 CPS ,7550,"00 ~576.75 NPHI2 DSH2 DECP NPHI DSN2 DECP .7550,00 8576,75 NRAT2 DSN2 C/C NRAT DSN2 C/C 7550,:00 857~,75 OPE2 SDL OPE SDL 7550,'0:0 857.6,75 DPHI2 SDL DECP DPHI SDL DECP ?550,-00 8576,75 DRH02 SDL G?C3 DRHO SDL G?C3 7550,00 8576,75 FSDL2 SDL CPS FSD.L SDL CPS 7550,~00 8576.75 Page 22 NSDL2 'PE2 ' PELC2 GL2 GPE2 RHOB2 CALl2 HDR2 HDN2 HHR2 HHX2 HDRS2 HNRS2 HDCH2 HHCN2 DFL2 SP2 TENS2 DLOD2 SDL SDL SDL SDL SDL SDL SDL SDL HRI HRI HRI HRI HRI HR:[ HRI HR! HRI SDL SDL CPS G?C3 IN OHMfl OHMN NHHO NNHO OH~N LBS LBS NSDL PE PELC QL QPE RHOB CALI HDR HDX HNR HDRS HMRS HDCN HNCN DFL SP TEHS DLOD SDL SDL SDL SDL SDL SDL SDL SDL HRI HRI HRI HRI HRI HRI HRI HRI HRI SDL SDL CPS G?C3 OHHH OHNN HNHO NNHO OHHN MY LBS LBS 755 O. ~00 755 O. O0 755 0.00 755 0. '00 7550. O0 7550. O0 755 O. O0 755 O. O0 7550. O0 7550 7550.00 755 O..00 7550. 755 O, ~00 7550.00 7550. O0 755 O. 0'0 7550. ~00 755 O, O0 7550..00 8576, ?'5 8576.7.5 8576,75 8576.75 8576, ?5 8576.75 8576.75 8576.75 8576.75 8576.75 8576.75 8576.75 8576.75 8576.75 8576.7~ 8576.7~ 8~76.75 8576.75 DATA ENTRY BLOCKS ENTRY .F 0 R.H A T TYPE 16 :0 SIZE SPECIFICATIONS CODE 66 Page ***************************** ENTRY BLOCK LEGEND ***************************** TYPE DESCRIPTION 16 Datum specification block sub-type 0 Tepminatop, ( no mope entpies ) DATA FORMAT SPEC I F I CAT I OHS Page 24 DATUM SPECIFICATION BLOCKS MNEH SERVICE SERVICE APl APl APl API FILE ID ORDER # UNIT LO~ TYPE CLASS MOD PRC # SIZE LVL SMPL RC PROCESS INDICATORS DEPT GR SDL FDSN DSM2 NDSN DSM2 flPHI DSM2 NRAT DSN2 DPE SDL DPHI SDL DRHO SDL FSDL SDL NSDL SDL PE SDL PELC SDL QL SDL aS SDL aPE SDL RHOB SDL CALI SDL HDR HRI HDX HRI HMR HRI NMX HRI HDRS HRI HMRS HRI HDCH HRI HMCN HRI DFL HRI SP HRI TENS SDL DLOD SDL 491799 FT 0 '0 0 .0 2 49'1799 GAPI 94 0 0 491799 CPS 94 0 0 3 491799 CPS 94 0 0 3 491799 OECP 94 O 0 3 491799 C/C 94' ~ 0 3 1 491799 94 0 0 3 491799 DECP 94 491799 G/C3 94 ~O .0 3 1 49'1799 CPS 94 0 0 3 49'1799 CPS 94 ;0 0 3 1 49'1799 94 O '0 3 1 491799 94 0 O 491799 94 0 0 3 1 49t799 94 0 0 3 491799 94 0 0 3 1 49'1799 G/C3 94 491.799 IN 94 0 0 J 1 4.9'1799 94 :0 0 3 1 491799 94 0 0 3 1 491799 94 0 0 3 491799 94. 0 0 3 1 491799 OHMM 94 0 '0 3 1 491799 OHMH 94 ;0 0 3 1 491799 flHHO 94 O O 3 1 491799 NMHO 94 0 0 J 1 49'1,799 OHMM 94 ~0 0 3 1 491799 NV 94 :0 :0 3 1 491,799 LB8 94 0 0 3 1 491799 LBS 94 '0 ,0 3 4 0 1 68 4 0 I 68 4 0 1 61:3 4 0 'l 68 4 0 I 68 4 0 I 60 4 0 I 68 4 0 I 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 I 68 4 0 1 68 4 0 I 68 4 0 I 68 4 0 1 68 4 0 I 68 4 0 I 60 4 0 ,1 60 4 0 1 68 4 0 1 60 4 0 1 68 4 0 I 68 4 0 1 6~ 4 0 I 68 4 0 1 68 4 0 I 68 4 0 1. 60 4 0 I 68 4 O t 68 00000:0 O00000 000000 000000 OOO00O 000000 000000 00000'0 000000 000000 000000 000000 000000 O000OO 000000 000000 O00000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O0000O 000000 O00OO0 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O00O.O0 O000OO 0000.00 000000 000000 000000 000000 000000 000000 800000 000000 000000 000000 000000 000000 0'00000 000000 000000 000000 000000 000000 000000 000000 0~00000 000000 000000 000000 000000 000000 DATA RECORDS DEPT GR FDSH NDSH NPHI NRAT DPE DPHI DRHO FSDL HSDL PE PELC QL QS QPE RHOB CALI HDR HDX HHR HMX HDRS HHRS HDCN HHCH DFL SP TENS DLOD 8576.750 -.146 '1,739 2345. '000 850t) .000 -.119 I .774 496.432 e400 .~000 .0'56 2,410 335. 562 8300.000 .046 2. 456 303. 756 '820 O, 0 0 0 .032 2.453 24'5. ~05~ 8.! OO. O00 .054 2,439 336,832 8000,000 · 030 2,383 183,792 7900.000 .045 2,425 188. 130 1.02. 047 1389.995 13683,906 ,504 1 0,445 O. 000 ,552 15818.217 15245,883 11,542 15.761 -,667 1.000 -I.000 8,40~0 0.000 O,OOO O.O00 0.00:0 -12345.000 -12345'.000 -1.2345, ~000 200:0'0,000 ~23450000. 6302.766 -4'3.t)00 1~05. 277 1398.9! 7 13.677,1)! 6 ,556 10. 373 O. O00 .531 15664.662 15636. 338 11 ,9:0! 14,5'I 0 .027 -, 004 -I. 000 5.834 355. 220 104,7.09 445.71'0 5'5. 904 2,014 I ,946 513,983 2, t96 290,069 5599.520 2567,.000 95,916 1631 .248 144,51 ,381 ,430 9.399 0.000 . 145 7075. 550 16465,883 3,547 4,261 -. 001 ,026 -1 . 000 9,163 269. 720 72,589 320.578 38. 957 2,980 2.882 346.987 3,396 300,348 5545,852 1427.000 102.179 1.849.799 '14787,.,590 ,384 8,482 0,000 .118 6434,884 16089,428 3,381 3,772 -,009 -, 009 -! . 000 9. 006. 291 . 265 73,793 354,932 36. 484 2,606 2,592 385. 768 2,621 286,71 0 5269,286 ! 331 ,~000 96,:048 21'6'9,428 15712.1)94 ,346 .7,684 .0. 000 , 119 6356,105 15880.975 3,.:002 3.226 -,013 -, 013 -I . OOO 8,806 1.93,8.03 43,167 222,275 21 .790 4,081 4,057 246.500 4,.578 301 ,400 5123,727 1299,000 93. 741 1742.417 14603,031 ,408 8,892 O.OOO . 128 &68~ ,550 16243°428 3,6'13 3,949 ,:015 -.002 -1 , 000 8,992 262.648 68.5t9 311 .e59 36.562 2,969 2 ..977 335.863 4,.052 293,953 5065.502 1311 ,:OOO 98.355 22'14. 081 15837,~0'57 .340 7.589 0.'000 .162 7206,772 16339,793 2,863 3,19.0 -.019 -,026 -1,000 8,806 153.32! 2.7,5't 7 169,40! !4.795 5,441 5,299 188.697 6. ;073 299,6.21 4818. 049 I 035.'000 · 96.312 232.1 . 229 15966,752 ,323 7,2cj8 O. 000 , 136 .6'8'03,66:1 16225,064 2,9,92 3,'135 -,:007 .006 -I . O00 8.932 144,652 27,808 151 ,940 13,417 5,31'5 5,792 172.637 6.244 257, 1'17 4832,605 1211 ,'000 Pag~ 25 DATA R E C 0 R D S DEPT GR FDSN NDSN NPH I NEAT DPE DPH I DRNO FSI)L NSDL PE PELC QL QS QPE EHOB CALI fIDE HDX HHR HHX HDRS HHRS HDCN HMCN DFL SP TENS DLOD 2800, ~000 -.~008 2.69:3 1 4. 266 23.305 3916.661 8,878 2 ! 7. 541 8242,55 ! 9,259 28t:,422 '1 '! 2, S26 18298. 439 1 'l , ~020 384,316 '1941,106 139S9,064 21,2:35 213,048 384.39 ! 16720,336 244,222 4, .7.03 1345,979 , 16841,:066 274,914 3 ..'058 7.700, :000 ,035 2,303 279,252 15142,887 .377 6,292 7,S92 i2,1.79 e,443 265,373 4992,722 't341:3,554 ,478 3.1 85 3,842 72.47.0 267,565 281 ,248 4701 ,601 13332,988 .472 3.623 3,83S 65,728 340,338 279,1 9! 4730,7! 3 7600.'000 · 048 2.317 368,984, Pag~ 8.277 ,008 14,082 '1 0.280 .0 OS 29,291 295,00.0 1 0.5'09 -, 008 26,125 155,80.0 O. '000 .016 70. 098 0,000 -,019 :3,581 0,000 ,0,06 2,710 -, 026 -! ,000 112,634 ,211 -1 .000 3.553 ,202 -1,000 2,602 26 FILE TRAILER *********************** File name: &GSF01..O02 Haximum leng%h=. '1024 TRAILER RECORDS Service name: Version File %ppe: LO Ne~t 'file: Date: Page 27 *********************** REEL TRAILER *********************** Service name: &GSF.O! "Date: 90/'07/20 Origin: Next reel: Comments: Reel name: 4.91.799 Continuation #: .01 *********************** TAPE"TRAILER *********************** ~ervice name,: &GSF01 Next tape:: Date: 90/9?/2.0 Opigin: Comments: Tape name: 49'1799 Continuation #: O~