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190-076
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, September 20, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3G-11 KUPARUK RIV UNIT 3G-11 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/20/2023 3G-11 50-103-20133-00-00 190-076-0 W SPT 5673 1900760 1500 2675 2675 2675 2675 150 150 150 150 4YRTST P Adam Earl 8/1/2023 MIT IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3G-11 Inspection Date: Tubing OA Packer Depth 480 1810 1750 1740IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230802193106 BBL Pumped:1.3 BBL Returned:1.3 Wednesday, September 20, 2023 Page 1 of 1 Originated: Schlumberger PTS- PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: n +�6 AT >> ATN: Natural Resources Technician 11 Alaska Oil & Gas Conservation Commision .333 W. 7th Ave, Suite 100 Anchorage, AK 99501 X11 07 1 TRANSMITTAL DATE TRANSMITTAL # . WELL NAME API 4 ORDERSERVICE 9 FIELD NAME DESCRIPTION DELIVERABLE DESCRIPTION DATA DATE LOGGED Prints CD's 1H-114 1H-111 1H-105 1H-113 1H-116 50-029.23584-00 50.029-23581-00 50-029.20727-01 SO -029-23588.00 50-029-23594.00 EOSH-00071 EA18-00022 E118-00075 E118-00076 E118-00077 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL WL WL IPROF IPROF-WFL IPROF-WFL (PROF-WFL IPROF•WFL FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 15 -Jul -19 17 -Jul -19 19Jul-19 20 -Jul -19 21 -Jul -19 1 1 1 1 1 3M-19 50-629�21737-00 18-00078 KUPARUK RIVER WL Caliper FINAL FIELD 22 -Jul -19 1 3G -07A 50.103-20127-01 E118-00079 KUPARUK RIVER WL PPROF FINAL FIELD 23Jul-19 1 3G-11 50-103-20133.00 E118-00081 KUPARUK RIVER WL (PROF FINAL FIELD 25 -Jul -19 1 3M-13 50-029-21720-00 E118.00084 KUPARUK RIVER WL Caliper FINAL FIELD 28 -Jul -19 1 1B-16AL1 50-029.22457-60 EDEA -00009 KUPARUK RIVER Memory PPROF FINAL FIELD 28 -Jul -19 1 1A-17 50-029-22102-00 E118.00085 KUPARUK RIVER WL LDL FINAL FIELD 29 -Jul -19 1 1C-121 3N -14A 3G-08 50-029-23015.00 50-029.21589-01 50.103.20128-00 E118-00086 EOSH-00074 EOSH-00075 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL (PROF LDL,Caliper LDL,Caliper FINAL FIELD FINAL FIELD FINAL FIELD 1 -Aug -19 2 -Aug -19 3 -Aug -19 1 1 1 2N-317 50-103-20266.00 EOSH-00076 KUPARUK RIVER WL LDL FINAL FIELD 4 -Aug -19 1 AQGGG Tr s i tal Receip A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the X package have been verified to match the media noted above. The Pr t ame Sign toe Date specific content of the CDs and/or hardcopy prints may or may SCANNEDSchlumberger-Private AUG 0 7 2019 MEMORANDUM TO: Jim Regg -7y 6I t(15 P.l. Supervisor }`� L FROM: Adam Earl Petroleum Inspector Well Name KUPARUK RIV UNIT 30-11 Insp Num: mitAGE190805105904 Rel Insp Num: State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, August 6, 2019 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3G-11 KUPARUK RIV UNIT 3G-11 Sre: Inspector Reviewed By;-:��, �� P.1, Suprv] - I --tri `( NON -CONFIDENTIAL Comm API Well Number 50-103-20133-00-00 Inspector Name: Adam Earl Permit Number: 190-076-0 Inspection Date: 8/32019 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3c-li Typelnj w TVD y 5673 Tubing -790 2790 2790 3790 PTD 900 60 Type Test SPT Test psi' 150-0 IA 690 1 1 I - 111_5 BBL Pumpe I -I BBL Returned: _ I OA -'tio za0 zao X10" Interval 4vRTST P/F P Notes: MITAA Tuesday, August 6, 2019 Page 1 of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,January 22,2018 TO: Jim Regg ' i) P.I.Supervisor elCl (( 10 SUBJECT: Mechanical Integrity Tests l CONOCOPHILLIPS ALASKA,INC. 3G-11 FROM: Guy Cook KUPARUK RIV UNIT 3G-11 Petroleum Inspector Src: Inspector Reviewed By: • P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3G-11 API Well Number 50-103-20133-00-00 Inspector Name: Guy Cook Permit Number: 190-076-0 Inspection Date: 1/21/2018 Insp Num: mitGDC180121162146 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3G-11 -'Type Inj W 'TVD 5673 Tubing 2690 " 2690 2690- 2690 ' PTD 1900760 Type Test SPT Test psi 1500 IA 325 2000 - 1930 - 1930 - BBL Pumped: 1.6 BBL Returned: 1.5 OA 250 250 250- 250 Interval 1 INITAL P/F P — Notes: Initial MIT-IA per Sundry 317-254 for conversion from producer to injector. Little Red Services pump truck used for testing. • SCANNED MAR, 0 .8 j,r` Monday,January 22,2018 Page 1 of 1 STATE OF ALASKA AL,OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations H Fracture Stimulate ❑ Pull Tubing H Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ ,erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: _PROD to WINJ_ 0 2.Operator 4.Well Class Before Work: 15.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development 2 Exploratory ❑ 190-076 3.Address: P. O. Box 100360,Anchorage, Alaska Stratigraphic❑ Service ❑ 6.API Number: 99510 50-103-20133-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 3G-11 ADL 25547 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 6,900 feet Plugs measured None feet true vertical 6,150 feet Junk measured None feet Effective Depth measured 6,884 feet Packer measured 6416 feet true vertical 6,134 feet true vertical 5673 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 79 16 115 « .,,, "°�"""" Surface 3,316 12 3,352 REC; . . ' .,.;,,J Intermediate Production 6,849 7 6,884 Q 14 t;. Liner x' �3 Perforation depth Measured depth 6,571 feet A0(51' CC True Vertical depth 5,825 feet Tubing(size,grade,measured and true vertical depth) 3.5 J-55 6449 5705 Packers and SSSV(type,measured and true vertical depth) Baker HB PKR 6416'MD/5673'TVD CAMCO TDRP SSSV 1807'MD/1798'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED JAN 1 7 ?Old 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: 0 0 0 475 2395 Subsequent to operation: 5665 650 1978 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory❑ Development❑ Service ❑� Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑., WAG ❑ GINJ H SUSP❑ SPLUG H 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: 317-254 Lynn Aleshire Contact Name: Lynn Aleshire Authorized Name: Y Petroleum Engineer Contact Email: Lynn.Aleshire@conocophillips.com m Authorized Title: 0.•/.9 Authorized Signature: 1 6064144;.t Date: + I 7.11V Contact Phone: (907)265-6525 YL ity //Ki Form 10-404 Revised 4/2017 4 [4/s, EMS 0-/!:',!! - 8 7 J1 Submit Original Only ConocoPhillips ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 January 2, 2018 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, Enclosed you will find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. regarding 3G-11 (PTD# 190-076-0). If you have any questions regarding this matter, please contact me at 907-265-6525. Sincerely, Lt/I-' Lynn Aleshire Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry Report Description of Work Completed Schematic 1 • 3G-11 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/29/17 Piping modifications complete. Placed well on water injection service. KUP ABOD 3G-11 Con©coPhillips Well Attribultir Max Ang MD TD AlaskiInc, Wellbore API/UWI Field Name Wellbore Status Inc!r) MD(ftKB) Act Olin If1KB) Ccxwco Nrr8rps'i: 501032013300 KUPARUK RIVER UNIT PROD 44.26 2,900.00 6,900.0 ,- ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3G-11.113/20186:13:16 AM SSSV:TRDP 130 3/15/2014 Last WO: 36.01 7/290990 Vertical schematic((actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:RKB 6,596.0 5/4/2017 Rev Reason:TAG pproven 5/11/2017 HANGER;30.6 11111 Casing Strings Mallt:ii.alCasing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen g...Grade Top Thread SURFACE 95/8 8.921 36.1 3,352.0 3,020.0 36.00 J-55 BUTT Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len p...Grade Top Thread , ,,;,;PRODUCTION 7 6.276 35.0 6,884.4 6,134.5 26.00 J-55 BTCABMOD t� ' Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING 1 3 1/21 2992 30.81 6,450.01 5,706.11 9.301 J-55 1EUE8rdABMOD ^Completion Details CONDUCTOR;36.0-115.0 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(') Item Des Com (in) 30.8 30.8 0.07 HANGER WKM GEN IV HANGER 3.500 I1,807.2 1,798.3 17.81 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.812 '-- 6,402.7 5,659.7 11.49 PBR BAKER 10'STROKE PBR 3.000 SAFETY VLV;1,907.2 *II%: w 6,416.3 5,673.1. 11.29 PACKER BAKER HB RETRIEVABLE PACKER 2.890 6,437.7 5,694.0 10.97 NIPPLE CAMCO D NIPPLE NO GO 2.750 . 6,449.2 5,705.4 10.80 SOS BAKER SHEAR OUT SUB 2.992 GAS LIFT;2,516.9 Perforations&Slots Shot Dens Top(TVD) Bin](ND) (shoal Top(ftKB) Btm(MB) (ftKB) (ttKB) Zone Date ft) Type Com 6,531.0 6,542.0 5,785.8 5,796.7 C-4,UNIT B, 7/9/2011 6.0 RPERF 2.5"HSC,60 Deg,11.1 3G-11 Gram DP Millenium HMX Charge 6,571.0 6,584.0 5,825.2 5,838.0 A-3,3G-11 8/17/1991 8.0 IPERF 2 1/8"Dyna Strip Gun; 90 deg.phasing SURFACE 36 1-R352 0- 6.594.0 6,614.0 5,847.9 5,867.6 A-2,3G-11 1/13/1991 4.0 APERF 4 1/2"Expendable;180 17E1,11'1.i deg.phasing Mandrel Inserts St ab on Top(ND) Valve Latch Port Size TRO Run GAS LIFT;4,620.8 N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,516.9 2,405.8 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 5/9/2017 2 4,620.8 4,014.8 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 5/9/2017 3 6,355.8 5,613.8 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/9/2017 Notes:General&Safety End Date Annotation GAS LIFT;6,355.8 8/30/2010 NOTE:View Schematic w/Alaska Schematic9.0 I PBR,6,402.6 r PACKER;6,416.3 NIPPLE;6,437.7 Its SOS;6,449.2li RPERF;6,531.0-6,542.0-_. .--. (PERF;6,571.0-6,584.0-,.... APERF,6,594.0-6,614.0--es-. PRODUCTION;35.0-6,881.4 • • • SOF Ti evw\� Iy/ s� THE STATE Alaska Oil and Gas of e T e c 1A Conservation Commission Witt_= 333 West Seventh Avenue c GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Lynn Aleshire Petroleum Engineer ConocoPhillips Alaska,Inc. P.O. Box 100360 SCANNED j , a 2 C 17, Anchorage,AK 99510 Re: Kuparuk River Field,Kuparuk River Oil Pool, KRU 3G-11 Permit to Drill Number: 190-076 Sundry Number: 317-254 Dear Ms. Aleshire: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this - day of June, 2017: RBDMS I, JUN 2 7 2017 111 111 RECEIVED STATE OF ALASKA JUN 14 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations H Fracture Stimulate LJ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casingt ❑ PROD to WINJ Other: ❑ - 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhilliDs Alaska, Inc. Exploratory ❑ Development 0• 190-076 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20133-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require a spacing exception? Yes ❑ No E / KRU 3G-11 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25547 , Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 6,900' 6,150' Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 16" 115' 115' Surface 3,316' 12" 3,352' 3,020' Intermediate Production 6,849' 7" 6,884' 6,134' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6571-6584',6531-6542' 5825-5838',5786-5797' 3.500" J-55 6,449' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER HB RETRIEVABLE PACKER v MD=6416 TVD=5673 SAFETY VLV-CAMCO TRDP-1A-SSA SAFMY VALVE Q • MD=1807 TVD=1798 12.Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service E. 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations: 8/1/2017 OIL ❑ WINJ ❑✓ • WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned Ei 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Lynn Aleshire Contact Name: Lynn Aleshire Authorized Title: Petroleum Engineer Contact Email: Lynn.Aleshire@conocophillips.com C,, , .< 41,31a 1I`2 Contact Phone: (907)265-6525 Authorized Signature: � `3 Date: IOJ 7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 311- 25`f Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test er Location Clearance ❑ 4-6 co 12-b I,"i'C Other: � Post Initial Injection MIT Req'd? Yes [] No ❑ Spacing Exception Required? Yes H No UCJ Subsequent Form Required: /0 —Q0 4- RBDMS t. L. JUN 2 7 2017 Zr>/--------eAPPROVED BY I.7 Approved by COMMISSIONER �TrHE COMMISSION Date: ,#<8. 0/1//� D N1AL V/1- 6/z 1 �f' .y. O I Submit form and Form 10-403 Revised 4/2017 , ` dI valid for 12 months from the date of approval. Attachments in Duplicate ConocoPhillips ConocoPhillips Alaska, Inc. RECEIVED 700 G St. JUN 14 2017 Anchorage, AK 99501-3448 June 12, 2017 AOGCC AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit Well 3G-11 from Oil Production to Water Injection service. Enclosed you will find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 3G-11 (PTD# 190-076). If you have any questions regarding this matter, please contact me at 907-265-6525. Sincerely, <Y- 04114w Lynn i - Lynn Aleshire Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry application Proposal Summary AOR Detail Area Map Well Schematic 1 • • • 3G-11 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kuparuk River Unit Well 3G-11 (PTD# 190-076) from Oil Production service to Water Injection service. Area of Review: KRU Well 3G-11 was completed as a producer 1/14/91. To add injection support to 3G-07A and 3G-26 this well will be converted to injection service. The top of the C sand is at 6531' MD/5786' TVD. Area Map with 1/4 mile radius around target injection zone (see attached): � The map attached shows that, with the exception of the offset injector 3G-10 and producers 3G-05, 3G-07A and 3G-26 there are no additional production or injection wells within a 1/4 mile radius of the 3G-11 penetrations of the Kuparuk interval. Mechanical Condition of Well to be Converted: /5/9/17 MITIA passed to 3000 psi; 2/21/16 TIFL passed; OA shoe appears to have failed and well receives regular FL-OA monitoring. Last FL-OA was 2/22/16 T/I/O= SI 2900/825/430 and OA FL @ 990' CBL and interpretation of the cement quality: See attached AOR Detail. The 16"conductor was cemented with 220 sx ASI The 9-5/8"surface casing was cemented with 700 sx ASIII and 470 sx class G The 7" prodution casing was cemented with 415 sx classG and 200 sx class G tail Calico r• l pie fokiec' wcl/ is (col piodeari C dve tv /sock r/-o(400 , co,(t''rI ty.. rztc -ef( 772 /44 ecr'bi ferv✓C1 I(c v(o' 11", ✓� /e cpy2i�, -,o, f �i'/r�� ac j�e foe/. 64117 • . /( t\( ) • . / 67 ))j /e ;3f _ /§J» ! _ f ; = &OE '-::1 k f/3§{ \§±f §/) $ ! \\/\ }22 }§ ° ) \\E \\ glueA -\ 0L< ,\\ E �\ �\ �\ \}\ a s e !E. \\cc \\ - - / {) .. () w.4 \\ \\ \\ \\ 42 RI 4z' g El § I 7 ] . 7 1 \ ) \ \ \ \o � y\\ : §� do CO \� \\ //� \ / 0. \I , , , \ . . \\ \\ \ \\ } } } g 42 72 \ )j \ r':= • • / c oC\P / NJ ti� T12NR8E 01 Oa ADL025547 ADL025632 �/ 3G.05 3G Well Pad Top A Form Picks(ATDB) • Producer:Oil hd INJ:MWAG P+A N ConocoPhillips Well Trajectory Alaska,Inc. Open Interval Open Interval Quarter Mile Radius 3G-11 Other Active Wells 0 0.2 Injection Sundry CPAI Leases iiiiiiiiii Miles AUi, 4/13/2017 • KUP PROD 3G-11 COnOCOP'UIIips ='* Wen Atbibutes Max Angie&MD TO Alaska,Inc, Wellbore API/UWI Field Name Wellbore Status ncl(°t MD(ftKB) Act Btm(ftKB) w...vwnips 501032013300 KUPARUK RIVER UNIT PROD 44.26 2,900.00 6,900.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 30-11.5111/2017 10 40:25 AM SSSV:TRDP 130 3/15/2014 Last WO: 36.01 7/29/1990 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:RKB 6,596.0 5/4/2017 Rev Reason.TAG,GLV C/O pproven 5/11/2017 HANGER;30.8 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(...Grade Top Thread SURFACE 95/8 8.921 36.1 3,352.0 3,020.0 36.00 J-55 BUTT Casing Description OD(In) ID(in) Top(kKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 'mmenuelleuguamememmal : PRODUCTION 7 6.276 35.0 6,884.4 6.134.5 26.00 J-55 BTCABMOD Tubing Strings 1 Tubing Description String Ma ID lin) Top(KKR) Set Depth(ft...Bet Depth(TVD)(...Wt(lblft) Grade Top Connection TUBING 3 1/2 2.992 30.8 6.450.0 5,706.1 9.30 3-55 EUEUrdABMOD Completion Details CONDUCTOR 36.0-1150- u Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(1) Item Des Corn (in) 30.8 30.8 0.07 HANGER WKM GEN IV HANGER 3.500 1,807.2 1,798.3 17.81 SAFETY VLV CAMCO TRDP-IA-SSA SAFETY VALVE 2.812 6,402.7 5,659.7 11.49 PBR BAKER 10'STROKE PBR 3.000 SAFETY VLV;1807.2 6,416.3 5,673.1 11.29 PACKER BAKER HB RETRIEVABLE PACKER 2.890 r_• 6,437.7 5,694.0 10.97 NIPPLE CAMCO D NIPPLE NO GO 2.750 6,449.2 5,705.4 10.80 SOS BAKER SHEAR OUT SUB 2.992 GAS LIFT,2.516.9 Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shotslf Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 6,531.0 6,542.0 5,785.8 5,796.7 C-4,UNIT B, 7/9/2011 6.0 RPERF 2.5"HSC,60 Deg,11.1 3G-11 Gram DP Millenium HMX Charge 6,571.0 6,584.0 5,825.2 5,838.0 A-3,3G-11 8/17/1991 8.0 IPERF 2 1/8"Dyna Strip Gun; 90 deg.phasing SURFACE',36.1-3.352.0-+ 6,594.0 6,614.0 5,847.9 5,867.6 A-2,3G-11 1/13/1991 4.0 APERF 4 1/2"Expendable;180 deg.phasing Mandrel Inserts st ati N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn GAS LIFT,4,6208 k 1 2,516.9 2,405.8 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 5/9/2017 2 4,620.8 4,014.8 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 5/9/2017 3 6,355.8 5,613.8 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/9/2017 Notes:General&Safety End Date Annotation 8/30/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT;6,355 8 - FOR;6.402.6 T • ra=;r PACKER;6.416.3 torr NIPPLE;6.437.7 • SOS,6.449.2 RPERF.6,531 0-6,542.0 (PERF;6,571 0-6,5840- - APERF',6,594.06,614.0--+ PRODUCTION,35.0-6,884.4 • • Roby, David S (DOA) From: Aleshire, Lynn <Lynn.Aleshire@conocophillips.com> Sent Wednesday,June 14, 2017 2:20 PM To: Roby, David S (DOA) Subject RE: [EXTERNAL] Sundry application for KRU 3G-11 (PTD 190-076) Dave, The well has been shut in because it produces rocks.Since it was shut in the liquid production from 3G-07A has significantly increased. Injection will add much needed pressure support and further increase throughput. Regards, Lynn From:Roby, David S(DOA) [mailto:dave.roby@alaska.gov] Sent:Wednesday,June 14,2017 2:14 PM To:Aleshire,Lynn<Lynn.Aleshire@conocophiltips.com> Cc:Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>; Bettis,Patricia K(DOA)<patricia.bettis@alaska.gov> Subject: [EXTERNAL]Sundry application for KRU 3G-11(PTD 190-076) Lynn, I was review the sundry app to convert the subject well from a producer to an injector and had a quick question for you. When the well last produced it was producing a few hundred barrels per day with a water cut well below the field average, but with a GOR about twice the field average. Would it be safe to assume the reason the well was shut in was due to this high GOR and it not being a competitive producer,or is there another reason the well has been offline for the past couple of years? Thanks in advance, Dave Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907) 793-1232 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Dave Roby at(907)793-1232 or dave.roby@alaska.00v. 1 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 13, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 3G -11 Run Date: 7/9/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3G-11 Digital Data in LAS format, Digital Log Image file 1 3 ( 1 CD Rom 50 -103- 20133 -00 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: Signed: 1Z—.0_ 06/03/09 ~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~~~ ~ ~ ~~Q~ ~-- ._t ssd(a~ ~~ C~iT~Si'~w~ e r~~t~~ Log Description NO. 5261 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 2U-15 AZCM-00012 GLS - 03/28/09 1 1 3G-12 B04C-00047 INJECTION PROFILE - `-~- J/ 05/10/09 1 1 iC-172A 604C-00049 GLS 05/11/09 1 1 3G-11 604C-00050 PRODUCTION PROFILE 05/12/09 1 1 2A-06 B14B-00048 DDL - 05/15/09 1 1 2A-16 B14B-00047 LDL = 05/15/09 1 1 3G-16 B14B-00049 INJECTION PROFILE p _. 05/16/09 1 1 3G-18 6146-00050 PRODUCTION PROFILE 05/17/09 1 1 2D-05 AYS4-00072 INJECTION PROFILE - 05/21/09 1 1 1 E-15 6148-00058 LDL - 05/24/09 1 1 3H-33 B04C-00006 CH EDIT (PEX,SONIC SCANNER,CHFR) 02/09/09 4 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. r • ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 12, 2009 .~ ~. a ..~.~- , ... Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~~ ~~ ,,V=r~ iY -a:. ®(~ d~~. "~~( "~'~'' ~~~~i® ~~~~~° ~~ r~~®~~ a,~~~ ~ ~~,~,~ ~~ 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, ~~ ~ ~ ,. . ,~~. ,~___.o ~` ~, /' M.J. I;oveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off 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 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 3024 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 10/31/03 Field: Kuparuk Well Job # Log Description Date BL Color CD 1Y-t9 I ~'¥-'1<~'~ PRODUCTION PROFILE/DEFT 10109103 ~ 3^-0~ ~_'_~?~_ ,NJEC~O. P.OF,LE ~0~/03 ~ 3B-03 ~ ~~(~,IPRODUCTION PROFILE/DEFT ~ 0/13~03 ~ 3B-0S ~.~-~~.ODUCT~ON P.OF,LE ~0/~4/03 ~ 3A-0S l~-~l PRODUCTION PROFILE ~0/~S/03 ~ 39-0S ~ ~'O~ P.ODUCT~ON P.OF~LE ~0/~S/03~ 3B-04 PRODUCTION PROFILE/DEFT 10118103 ~ 1E-20 ~ ~ SBHP SURVEy ~0/20103 ~ "' 3~-~ }~?-O~5 LEAK DETECT~ON LO~ ~0/~S/03 ~ 3G-09 ~O-~o~'PRODUCTION PROFILE 10125103 ~ 3G-~ t R~~ PRODUCTION PROFILE ~0/=7/03 ~ .......,., ~ B-20 ~-'~ I PERF RECORD/STATIC SURVEY 10/30/03 1 ,,, ,,, ,,, SIGNE .. , ~ 0_~~'"-,....C,- ~-,,,.--~ DATE: - . Please sign and return one copy of this transmiffal t0 Beth at the above address or fax to (907) 56~-8317. Thank you. STATE OF ALASKA AI_~,,~,'A OIL AND GAS CONSERVATION COMMIS~,,,..,',I REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate X, Plugging Perforate Repair well Other ~ 2. Name of Operator ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2538' FNL, 120' FWL, Sec. 24, T12N, R8E, UM At top of productive interval 715' FNL, 1806' FWL, Sec. 24, T12N, R8E, UM At effective depth 695' FNL, 1833' FWL, Sec. 24, T12N, R8E, UM At total depth 685' FNL~ 1847' FWL~ Sec. 24~ T12N1 R8E~ UM 12. Present well condition summary Total Depth: measured 6900 feet true vertical 6 1 5 0 feet 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 6. Datum elevation (DF or KB) RKB 89 7. Unit or Property name Kuparuk River Unit 8. Well number 3G-11 9. Permit number/approval number 90-76 10. APl number 50-103-20133-00 11. Field/Pool Kupar. uk River Field/Oil Pool Plugs (measured) None Effective depth: measured 6 7 9 0 feet true vertical 6041 feet Junk (measured) None Casing Length Size Structural Conductor 8 0' Surface 331 6' Intermediate Production 6841' Liner Perforation depth: measured Cemented Measured depth True vertical depth 220 Sx AS I 1 1 5' 11 5' 700 Sx AS III & 3352' 3020' 470 Sx Class G 415 Sx Class G & 6876' 61 26' 200 Sx Class G tail 1 6" 9-5/8" 7" 6531'-6542',6571'-6584',6594'-6614' true vertical 5786'-5797',5825'-5838',5848'-5868' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 6450' Packers and SSSV (type and measured depth) Pkr: Baker HB @ 6403'; SSSV: Camco TRDP-1A-SSA @ 1807' 13. Stimulation or cement squeeze summary Fracture stimulate 'A' Sand on 9/3/97. Intervals treated (measured) 6571 '-6584',6594'-661 4' Treatment description including volumes used and final pressure Pumped 267.5 Mlbs of 20/40 and 12/14 ceramic proppant into the formation~ fp was 7300 psi. 14. Representative Daily Average ProdLlction or InjectiQn OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 3 5 4 114 415 850 186 Subsequent to operation 961 539 556 850 176 Attachments Copies of Logs and Surveys run Daily Report of Well Operations ,,,,Z 16. Status of well classification as: Oil X Gas Suspended Service 17. I he re ~,y,,j,',~}rtify that the foregoing is true and correct to the best of my knowledge. / / Signed Title Wells Superintendent Date Form ~,,,1~-~'04~ ~'~'~~' """ ~'.:'-'~ :::': ':~"'~'- ~ ~..~: ~ i§UBIVI~'T ~,1 ~UP'I_.I(~ATE ARCO Alaska, Inc. ~'~ ~-~ KUPARUK RIVER UNIT VELL SERVICE REPORT ' ~' K1(3G-11(W4-6)) WELL JOB SCO~E JOB NUMBER 3G-11 FRAC, FRAC SUPPORT 0829972318.8 -- DATE DAILY WORK UNIT NUMBER 09/03/97 "A" SAND REFRAC .,. DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 (~) Yes O NoI (~) Yes O No DS-GALLEGOS CHANEY FIELD AFC~ CC# DAILY COST ACCUM COST Signed .:'- ESTIMATE KDl170 23ODS36GL $151,741 $158,204 Initial Tbq Press Final Tbq Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 1 000 PSI 1 800 PSI 400 PSI 500 PSII 1 00 PSII 100 PSI DAILY SUMMARY "A" SAND REFRAC COMPLETED THRU FLUSH. INJECTED 267471 LBS OF PROP IN THE FORMATION W/144f PPA OF #12/18 @ THE PERF'S. FREEZE PROTECTED TBG DOWN TO 3100' W/27 BBLS OF DIESEL. MAXIMUM PRESSURE 7300 PSI & F.G. (.79) TIME LOG ENTRY 07:00 MIRU DOWELL FRAC EQUIP, APC VAC TRUCK, AND LRS HOT OIL TRUCK. HELD SAFETY MEETING (18 ON LOCATION. 09:30 PT'D BACKSIDE LINES AND EQUIP TO 4000 PSI, RAISED THE INNER CSG PRESSURE AS REQUIRED. SET THE TREESAVER AND PT'D HIGH PRESSURE LINES TO 8600 PSI. 09:45 11:05 12:35 14:40 14:55 15:55 16:55 PUMP BREA!t:,.r)o'¢~N WI 50# DELAYED XL GW @ 25 BPM TO 15 BPM. VOLL~tL: !;i, :i,: :"::',~': 3t,'.:: ~]BLS. USED 5677 LBS OF #20140 PROP tOR CONDITIONING. MAXIMUM PRESSURE 6000 PSI ANd -L;~D;;4G PHLJSSURE 2300 PSI. STEPPED RATE DOWN TO FROM 15 BPM TO 5 BPM AT END OF BD. S/D AND OBTAINED ISlP OF 1996 PSI W/F.G. @ (.79). STOOD-BY AND MONITORED WHTP. PULSED FOR CLOSURE. DETERMINED CLOSURE TIME +-32 MINS @ 1800 PSI. PUMP DATAFRAC W/50# DELAYED XL GW @ 5 BPM TO 15 BPM. VOLUME PUMPED 171 BBLS. MAXIMUM PRESSURE 3700 PSI AND ENDING PRESSURE 2500 PSI. STEPPED RATE DOWN FROM 15 BPM TO 5 BPM ATTHE END OF THE DATAFRAC. S/D AND OBTAINED ISIP OF 2136 PSI AND F.G. @ (.81). STOOD-BY AND MONITORED WHTP FOR CLOSURE. DETERMINED CLOSURE TIME +-16 MINS @ 1840 PSI. PUMP FRAC W/50# DELAYED XL GW @' 5 BPM & 15 BPM. PAD .....> 4400 PSI --> @ 15 BPM. 430 BBLS 2# PPA --> 4300 PSI --> @ 15 BPM. #20/40 4# PPA --> 4300 PSI --> @ 15 BPM. #12/18 6# PPA --> 4200 PSI --> @ 15 BPM. #12/18 8# PPA --> 4100 PSI --> @ 15 BPM. #12/18 10# PPA --> 4150 PSI --> @ 15 BPM. #12/18, WHTP BUILT UP TO 4450 PSI. 12# PPA --> 4500 PSI --> @ 15 BPM. #12/18 14# PPA --> 4600 PSI --> @ 15 BPM. #12/18 FLUSH --> 4000 PSI --> @ 15 BPM. FRAC COMPLETED THRU FLUSH. PUMPED 268562 LBS OF PROP (21509 LBS OF #20/40 & 247053 LBS OF #12/18). INJECTED 267471 LBS OF PROP IN THE FORMATION W/14# PPA OF #12/18 @ THE PERF'S. LEFT 1091 LBS OF PROP IN THE WELLBORE. FREEZE PROTECTED TBG DOWN TO 3100' W/27 BBLS OF DIESEL. STARTED R/D. DEPRESSURED THE INNER CSG TO 500 PSI AND R/D LRS TRUCK. REMOVED TREESAVER (ALL CUPS RETURNED) CONTINUED R/D. R/D COMPLETE AND DOWELL LEAVING LOCATION. WELL SECURED AND NOTIFIED DSO OF STATUS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $1,040.00 , APC $5,200.00 $6,250.00 DIESEL $400.00 $400.00 DOWELL $143,941.00 $143,941.00 HALLIBURTON $0.00 $4,373.00 LITTLE RED $2,200.00 $2,200.00 ..TOTAL FIELD ESTIMATE $151,741.00 $158,204.00 ARCO Alaska, Inc. .'~-~-, Post Office Bo~ ,360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 TO: STATE OF ALASKA OIL & GAS CONSERVATION COMM. 3001 PORCUPINE DR. ANCHORAGE, AK. 99501 ATTN: ROBERT CRANDALL DATE: 1-8-91 AIRBILL: AIRLAND #510121 AFE #0-0 1-08--~.~ OPERATOR: ARCO SAMPLE TYPE: CORE CHIPS SAMPLES SENT: NAME: KRU3G-11 NUMBER OF BOXES: 2 BOX#1 6534'-6580' BOX#2 6581'-6634' SENT BY: DAN PRZYWOJSKI UPON RECEIPT OF THESE SAMPLES PLEASE NOTE ANY DISCREPANCIES AND SEND A SIGNED COPY OF THIS TRANSMITTAL TO'. RECEIVED BY: ARCO ALASKA, INC. BAYVIEW GEOLOGIC FACILITY P. O. BOX 100360 ANCHORAGE, AK. 99510-0360 ATTN: T. A. GORUP P. Jl & Gas Cons. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfleldCompany AR3B.6003.C e '-" STATE OF ALASKA 0 ~ ALASKA OIL AND GAS CONSERVATION COMMISo, ON REPORT OF SUNDRY WELL OPERATIONS Perforate Operation Performed: Pull tubing Name of Operator L Address P. O. Box 100360, Anchorage, AK Operation Shutdown ,. Stimulate ~ Alter casing ~ Repair well 5. Type of Well: Development ~ Exploratory _ I Stratigraphic 99510 Service Plugging Other 6. Datum elevation (DF or KB) 89' RKB 7. Unit or Property name _~paruk River Unit feet Location of well at surface 2538' FNL, 120' FWL, Sec. 24, T12N, R8E, UM At top of productive interval 721' FNL, 1799' FWL, Sec. 24, T12N, R8E, UM At effective depth 721' FNL, 1799' FWL, Sec. 24, T12N, R8E, UM At total depth 685' FNL, 1847' FWL, Sec. 24, T12N, R8E UM 2. Present well condition summary Total Depth: measured 6 9 0 0' feet true vertical 61 50' feet $. Well number 3G-11 9. Permit number/approval number 90-76 10. APl number _5o-1 03-201 33 11. Field/Pool ~ruk River Oil Pool Plugs (measured) None Effective depth: measured 6 5 3 1 ' feet true vertical 5786' feet Casing Length Size Structural Conductor 11 5' 1 6" Surface 335 2' 9 - 5 / 8" Intermediate Production 6876' 7" Liner Perforation depth: measured 6571 '-6584', true vertical 5825'-5838', Junk (measured) None Cemented 220 Sx AS I 700 Sx AS III & 470 Sx Class G 415 Sx Class G & 200 Sx Class G Tail 6531'-6542' 5786'-5797' Tubing (size, grade, and measured depth) 3-1/2" 9.3#, EUE, ABMOD, @6450' Packers and SSSV (type and measured depth) SSSV: Camco TRDP-1A-SSA (1807'), Packer: 3. Stimulation or cement squeeze summary Perforate 5786'-6584' Intervals treated (measured) Treatment description including volumes used and final pressure Measured depth True vertical depth Prior to well operation Subse¢ ~eration 5. Attachments Copies of Logs and Surveys run 115' 3352' 6876' 115' 3O20' 6126' RECEIVED JAN 2 8 1992 Alaska Oil & Gas Cons. L;ornrniss~or~ Anchorage BakerHB (6403') Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water- Bbl Casing Pressure -1151- -856- -91 - -20- -1 634:J-779- -277- -400- 16. Status of well classification as: __ Water Injector __ Daily Report of Well Operations X Oil X. Gas Suspended I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Tubing Pressure -178- -162- Form 10-404 Rev 09/12/90 Title Operations Engineer Date '/~/~2.. SUBMIT IN DUPLICA iE ARCO Alaska, SuDs~d~ary of Atlantic Ricnfieid ComDany WELL SERVICE REPORT WELL .?~- // '4TRACTOR REMARKS PBDT ' ~IELD - DISTRICT - STATE 'DAYS DATE - ' OPERA-~ON AT R~:POR~'TIME - .___ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. Chill Factor Visibility Report °F °F miles Wind Vel. DIST: ORIG - NSK KOE FILES DSENG KO~ FILES DS FOREMN~ NSK CENT FILES KUPARUK OPERATIONS ENGINEERING PERFORATION RECORD WELL NAME: ~ ~ - ~! DATED ~''?/o/z/'~ ENG REP: /'~ ~',,~/_.~ TIED IN WI~:~LSDIL, & ~%CB~CET, DATED COMPLETION DETAILS: ~/~' ~ ;~ ~ ~_ . .... GUN INFO: ~'/~'~ ~~ ~ ~ ~ ~ 8PF: ...... ~.~ ~ ~, P~SING: -~- ~ , ORIENTATION: ~- G~M~:~,~ ~.H~ES~E ~,~ ~o.~,' A~ ~~, m mmmmm~m m m mmm m mmm mmmmmm! GUN PROPOSED PROPOSED GUN CCL CCL DATE: 8ERV. CO'& EgG: ../.,¢~ ,/"~p~) ~,~_~ PERF INTERVAL: SAND ~ INT ~-:~ ( __ /,,,.S-c-I.L_ SAND,,, SAND INT TIME RUN PERFORATIONS PERFORATIONS LENGTH TO TOP SETTING NO. (md- D I L) (md-C ET) ( It ) SHOT DEPTH COMMENTS GUN SHOT STATE OF ALASKA ALA,SKA OIL AND GAS CONSERVATION COtv,,viISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL F~ GAS r--] SUSPENDED [~] ABANDONED r'~ SERVICE r'-] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-76 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20133 4 Location of well at surface 9 Unit or Lease Name 2538' FEE, 120' FWL, SEC 24, m12N, R8E, UM KUP ARUK RIVER AtTop Producing Interval~,/~[~'i~/~/ ~ i ¥~PiFJ.~, ' 10 Well Number 721' FNL, 1799' FWL, SEC 24, T12N, R8E, UM ~ //~7//;~"~Z~! '~', n~..~ 3G-11 685' FNL, 1847' FWL, SEC 24, T12N, R8E, UM ........... ~~ KUPARUK RIVER FIELD $ Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 89'I ADL 25547, ALK 2661 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 116 No. of Completions 7/18/90. 7/27/90. --14..1.~.I NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 6900' MD, 6150' TVD 6790' MD, 6070' TVD YES I~l NO r-] 1807, feet MD 1600' APPROX 22 Type Electric or Other Logs Run EWR, CN, SFD, DGR, CET, CBL, GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 220 SX AS I 9-5/8" 36~ J-55 SURF 3352' 12-1/4" 700 SX AS III, 470 SX CLASS G 7" 26~ J-55 SURF 6876' 8-1/2" 415 SX CLASS G, 200 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" 6450' 6416' 6594'-6614' W/4-1/2" CSG GUN @ 4SPF 5848'-5868' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production JMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD .~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. , Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS FORM,. ,,..~/TESTS NNVE Include interval tested, pressure data, all fluids recoverd and gravity, ...... MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ,,, ,,, ,,, KUPARUK C TOP 6531' 5786' NA KUPARUK C BOTTOM 6541' 5796' KUPARUK A TOP 6557' 5811' KUPARUK A BOTTOM 6676' 5929' 3i. LIST OF ATTACHMENTS .. GYRO. 32. i '~ereby certify that the' foregoing' is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion repod and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ORIGINAL Western Atlas International :~, ~1or, O~esser ~,3moan¥ CORE LABORATORIES ARCO ALASKA, INC. CORE ANALYSIS REPORT KRU 3G-11 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA CL FILE NO. BP-3-1394 Performed by: Core Laboratories 8005 Schoon St. Anchorage, AK 99518 (907) 349-3541 Final Report Presented Sept. 22, 1990 ?, iCiiOFiLi4ED These analysis, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgement of Core Laboratories (all errors and omissions excepted); but Core Laboratories and it's officers and employees assume no responsibility and make no warranty of representation as to the productivity, proper operations, profitability of any oil, gas or other mineral well or formation in connection with which such report is used or relied upon. 8005 Schoon Street, Anchorage, Alaska 99518-3045, (907) 349-3541. Fax (907) 344-2823 INTRODUCTION Core Laboratories was requested to perform a core analysis study on behalf of Arco Alaska, Inc. for samples recovered from the Kuparuk 3G-11 well, North Slope, Alaska. Core was recovered from 6534.0 to 6634.7 feet, for a total of 100.7 feet recovered. Presented herein are the results of this study. Conventional cores cut with a bland mud were submitted. A service description with methodology is presented in section 1. The core analysis results, core statistical data, and surface core gamma log are presented in sections 2 and 3. section 4 contains shipping transmittals. Appendices are provided in Section 5. In conjunction with the report, the tabular results of the analysis are supplied on an IBM PC compatible diskette. Four sets of visible spectrum flash and three sets of ultraviolet light photographs are provided in separate binders. We sincerely appreciate this opportunity to be of service and hope these data prove beneficial in your exploration efforts. TABLE OF CONTENTS Section CONVENTIONAL CORE ANALYSIS, SERVICE DESCRIPTION AND METHODOLOGY DEAN-STARK CORE ANALYSIS, TABULAR RESULTS CONVENTIONAL CORE STATISTICAL DATA AND SURFACE CORE GAMMA LOG TRANSMITTALS APPENDICES DATA DISKETTE SECTION 1 CONVENTIONAL CORE Field Procedures Conventional coring equipment, in conjunction with a bland based drilling fluid was used to extract four inch diameter core samples from the KRU 3G-11 well during July of 1990. There were two Core Lab personnel assigned to the wellsite during the coring operation. Eighty-five one inch plugs were drilled at the wellsite with diesel and were dry trimmed into right cylinders. The trimmed wellsite plugs were preserved in bottles of diesel. Special 1.5 inch plugs were cut on-site by Arco personnel from Plano, Texas. The special plugs were cut in anaerobic crude, stored, and shipped by said Arco personnel. Ends from the special plugs were sealed in ProtectCore as they were cut at the wellsite. See appendix for detailed procedures. Two, 2 inch whole core tracer samples were dry cut from the core, wrapped in saran wrap, and sealed in ProtecCore. See appendix for detailed procedures. The 1.0 inch wellsite plugs, along with 100.7 ft. plugged core was shipped to Core Laboratories' Anchorage facility. The whole cores was preserved for shipment in three feet long fiberglass barrels sealed with rubber caps and clamps. Core Processing Sample Preparation Dean-Stark Plug Samples Wellsite plugs were drilled with diesel. Plugs were taken from the center of each section and parallel to the bedding strike. The plug samples were dry trimmed into right cylinders and stored in diesel until analyzed. surface core Gamma Log 'A surface core gamma log was performed on the recovered core samples upon arrival at the Anchorage Laboratory. The gamma response is graphically presented in Section 3. When the gamma log was completed the core was extruded from the fiberglass barrels and placed onto tables in preparation for slabbing. Slabbing At Core Laboratories, in Anchorage the whole core was slabbed in one-third and two-third sections using water as a blade coolant. Appropriate depths were marked on the slabbed faces of both slabbed sections, along with orientation lines. The one- third sections were put in protective plastic sleeve material and placed in boxes. The two-third sections were prepared for photography and later packed in core boxes with the one-third sections. State Chips One set of state chips were taken to represent every foot of core. The chips were marked and boxed according to depth. Analysis Techniques Dean-Stark Fluid Saturation Measurements Water was extracted from the plug samples by Dean-Stark technique using toluene. Samples were left in Dean-Stark for 24 hours. Recovered waters were measured and the samples were removed. The samples were then placed in a toluene centrifuge for hydrocarbon extraction a minimum of two days, or until no fluorescence was visible. Extracted samples were dried in a oven at 220 degrees F. for a minimum of 24 hours, and cooled in a desiccator to room temperature before porosity and permeability was measured. Saturations by Dean-Stark methods were calculated using Equations 1 and 2. Where: So = [ ((Wl - W2 - H20)/Do)/Vp] x 100 Sw = [H20/Vp] x 100 (2) So = Oil Saturations, Percent Sw = Water Saturation, Percent Wi = Natural Weight W2 = Extracted and Dried Weight H20 = Extracted Water, Density Assumed 1.0 gm/cc Do = Density of Oil Vp = Pore Volume Grain Density Grain volume determinations were performed according to Boyle's Law utilizing the Heise Gauge Helium Porosimeter. Grain density was calculated using Equation 3. Dg = Mg/Vg (3) Where' Dg = Grain Density Vg = Grain Volume Mg = Grain Mass Atmospheric Porosity The samples were measured for bulk volume by mercury displacement at ambient conditions. Porosity was calculated using Equation 4. P = [(Vb-Vg) / Vb) ] x 100 (4) Where'. P = Porosity, Percent Vb = Bulk Volume Vg = Grain Volume Atmospheric Permeability to Air Samples were loaded into a Hassler type core holder at a confining pressure of 400 psig. Permeability calculations were performed as defined by Darcy's Equation for compressible fluids, Equation 6. Pa × v x 1000 K--- t~m (Pl - P2) (Pl +P2) Qa x L x L x (6) Vb Where: K = Permeability v = Gas Viscosity P1 - P2 = Differential Pressure P1 + P2 = Mean Pressure Pa = Atmospheric Pressure Qa = Flow Rate L = Length Vb = Bulk Volume Core Photographs The two-thirds slabbed section of each core was photographed. Approximately 15 feet of core appears in each photograph. Four sets of visible spectrum flash light photographs and three sets of ultraviolet light photographs are provided in separate binders. Sample Disposition Both core slabs of KRU 3G-11; and state chips were shipped to the Arco storage facility in Anchorage. All plug ends from the standard plugs and all plugs, excluding five destroyed for Bromide concentration tests, were shipped to ARCO Plano. DEAN-~~ ANALYSIS RESULTS :ompanY ~el'l : ARCO ALASKA, !NC. : KRU 3G-11 ANALYTICAL PRO CORE LABORATORTES Field : KUPARUK RIVER UNIT Formation : KUPARUK FORMATION EDURES AND QUAL ITY A File No.: BP-3-1394 Date.- 2g-Aug-lggO SSURANCE HAIIDLIN6 8, CLEANIll6 ANALYSIS Core Transportation Solvent Extraction Equipment Extraction Time Drying Equipment Drying Time Drying Temperature : AIR FRIEGHT : TOLUENE : DEAN STARK : 24 HOURS : CONVECTION OVEN : 24 HOURS : 220 DEG. F. Grain volume measured by Boyle's Law in a matrix cup using He Bulk volume by Archimedes Principle Water saturations by Dean Stark Oil saturations by weight difference in Dean Stark Permeabilities measured on I in. diameter drilled plugs Core Ganmm Composite Dean Stark grain densities clean, dry solid mineral phase are measured CORE LABORATORIES Company : ARCO ALASKA, /NC. Ne11 : KRU 3G- 1! Location : 24-12N-8E UN, Fr NH cot 606'S 1927'E(BHL) Co,State : NORTH SLOPE, ALASKA Field : KUPARUK RIVER UNIT Formation : KUPARUK FORMATION Coring Fluid : BLAND MUD Elevation : CORE ANALYSIS RESULTS File No.: BP-3-1394 Date : 2g-Aug-lg90 APl No. : Analysts: PLB SATURATION SAMPLE DEPTH PERMEABILITY POROSITY GRAIN DESCRIPTION NUMBER (HORIZONTAL) (HELIUM) (PORE VOLUME) DENSITY Kmir OIL WATER ft mci % % % gm/cc CORE Z 6535.0 - 6571.7 FEET 2 1 6538.5 19.4 19.6 72.4 22.7 3.23 SS-brngy,vf-mgr,pred vfgr,mod srtd,sb-wrnd,wcmt,qtz,glau,vc cly clast,broken 2 2 6539.0 137. 28.6 76.1 17.6 2.80 SS-dkgrngy,f-vcgr,pred mgr,mod srtd,rnd-wrnd,mod fri,qtz,glau,brn carb cmt 2 3 6539.5 <.01 1.3 32.3 64.9 3.22 SS-brngy,vf-cgr,pred mgr,mod srtd,rnd-wrnd,vwcmt,qtz,wt carb cmt 2 4 6540.0 68.9 5.0 26.7 70.7 3.23 SS-brngy,f-cgr,pred mgr,wsrtd,rnd-wrnd,vwcmt,qtz,glau,sid cmt,broken 2 5 6540.6 0.03 7.1 31.7 58.3 3.27 SS-ltbrngy,f-cgr,pred mgr,wsrtd,rnd,vwcmt,qtz,glau,sid cmt,open frac 2 6 6541.3 38.6 22.9 45.5 50.3 2.69 SS-mgy,fgr,r cgr,vwsrtd,rnd,sl fri,qtz,glau 2 7 6542.0 83.2 26.4 47.7 42.2 2.74 SS-mgy,fgr,r cgr,vwsrtd,rnd,sl fri,qtz,glau 2 8 6542.4 2.41 17.4 39.9 57.3 2.70 SS-mgy,fgr,r cgr,vwsrtd,rnd,sl fri,qtz,glau 2 9 6543.0 17.1 22.9 45.3 46.3 2.72 SS-mgy,fgr,r cgr,vwsrtd,rnd,sl fri,qtz,glau 2 10 6543.5 0.61 20.1 36.6 58.8 2.69 SS-mgy,fgr,r cgr,vwsrtd,rnd,sl fri,qtz,glau 2 11 6544.0 0.81 17.5 47.4 49.9 2.69 SS-ltbrngy,f-mgr,pred fgr,vwsrtd,rnd,sli fri,qtz,glau 2 12 6544.5 <.01 0.9 54.4 39.6 3.17 SS-ltbrngy,vf-cgr,pred fgr,mod srtd,sbang-rnd,vwcnrc,qtz,glau,wt carb cmt 2 13 6545.0 0.09 18.9 53.9 40.7 3.00 SS-dkyelbrn,f-nKjr,pred fgr,wsrtd,rnd,vwcmt,qtz glau,sid c~ 2 14 6545.5 <.01 2.4 35.0 52.7 3.11 SS-ltbrngy,vf-cgr,pred fgr,wsrtd,sbang-rnd,vwcmt,qtz,glau,wt carb cmt 2 15 6546.2 1.04 21.0 55.8 38.5 2.95 SS-brngy,vf-cgr,pred fgr,mod srtd,sbang-sbrnd,vwcmt,qtz,glau,occ calc 2 16 6546.6 30.9 21.6 50.6 43.8 3.05 SS-ltbrngy,vf-cgr,pred vfgr,mod srtd,sbang-sbrnd,vwcmt,qtz,glau,occ calc 2 17 6547.0 1.45 24.5 60.8 34.1 3.02 SS-brngy,vf-cgr,pred fgr,mod srtd,sbang-rnd,vwcmt,qtz,glau, lt tn cmt,tr calc 2 18 6547.3 0.67 18.0 34.5 63.8 2.71 SS-dkgngy,f-~r,wsrtd,sbang-sbrnd,sl fri,qtz,glau,frac 2 19 6548.3 0.95 12.9 20.0 75.8 2.67 SLTST-dkgy,bnd/yelbrn vfgr s$,wsrtd,w cmt,qtz,tr pyr,frac CORE 3 6572.0 - 6634.7 FEET 3 I 6575.5 1344. 13.6 18.1 77.2 2.68 SS-gybrn,vf-fgr,pred vfgr,lam,wsrtd,sl fri,qtz,dkbrn cly,dis pyr,broken 3 2 6576.5 16.3 12.9 25.9 73.1 2.66 SS-gybrn,vf-fgr,pred vfgr,lam,wsrtd,sl fri,qtz,dkbrn cly,broken 3 3 6579.8 8.08 12.6 34.4 61.9 2.67 SLTST-dkbrngy,bnd/ltgy vf ss,wsrtd,wcmKc,qtz,dkbrn cly,frac 1 - 1 Company : ARCO ALASKA, INC. Wel 1 : KRU 3G- 11 CORE CORE LABORATORIES Field : KUPARUK RIVER UNIT Formation : KUPARUK FORFIATION ANALYSIS RESULTS File No.: BP-3-1394 Date : 2g-Aug- 1990 SATURATION SAMPLE DEPTH PERMEABILITY POROSITY GRAIN DESCRIPTION NUMBER (HORIZONTAL) (HELIUM) (PORE VOLUME) DENSITY Kair OIL WATER ft md % % % gm/cc 3 4 6581.9 259. 27.1 83.0 8.1 2.67 SS-ltbrngy,vf-fgr,pred vfg~,vwsrtd,sbang-sband,wcmt,qtz 3 5 6582.8 415. 28.0 85.1 5.6 2.66 SS-ltbrngy,vf-fgr,pred vfgr,vwsrtd,sbang-sbrnd,wcmt,qtz,tr pyr 3 6 6583.2 217. 24.4 75.7 15.9 2.65 SS-ltbrngy,fgr,cly lam, vwsrtd,sbang-sbrnd,wcmt,qtz,brn cly 3 7 6583.6 364. 27.7 87.6 3.7 2.66 SS-ltbrngy, vf-fgr,pred vfgr,vwsrtd,sbang-sbrnd,sl fri,qtz,tr glau 3 8 6584.0 260. 25.8 78.4 14.1 2.66 SS-ltbrngy,vf-fgr,pred vfgr,cly bnd,vwsrtd,sbang-sbrnd,sl fri,qtz,brn cly 3 9 6584.5 334. 27.7 85.7 5.6 2.67 SS-ltbrngy,vr-fgr,pred vfgr,vwsrtd,sbang-sbrnd,sl fri,qtz,tr glau 3 10 6585.0 17.0 17.5 51.7 44.3 2.74 SS-ltbrngy,vfgr,cly bnd,vwsrtd,sbang,sl fri,qtz,brn cly,tr glau,sml frac 3 11 6585.5 4.89 17.6 64.9 30.5 2.67 SS-ltbrngy,vfgr,cly bnd,vwsrtd,sbang,sl fri,qtz,brn cly 3 12 6586.0 7.73 17.2 60.6 35.9 2.68 SS-ltbrngy,vfgr,cly bnd,vwsrtd,sbang,sl fri,qtz,brn cly 3 13 6586.5 142. 26.7 86.3 5.8 2.67 SS-ltbrngy,vfgr,cly bnd,vwsrtd,sbang,sl fri,qtz,brn cly,tr glau,frac 3 14 6587.0 52.2 18.8 67.3 24.3 2.70 SS-ltbrngy,vfgr,cly bnd,vwsrtd,$bang,sl fri,qtz,brn cly,tr glau,frac 3 15 6587.5 186. 26.2 87.8 3.0 2.66 SS-ltbrngy,vfgr,wk lam, vwsrtd,sbang,sl fri,qtz,tr brn cly 3 16 6588.1 1.08 16.4 51.2 42.9 2.69 SS-ltbrngy,vfgr,cly bnd,vwsrtd,sbang,sl fri,qtz,brn cly,tr pyr 3 17 6588.5 28.4 21.8 53.8 36.6 2.67 SS-ltbrngy,vfgr,vwsrtd,sbang,sl fri,qtz,occ musc,frac 3 18 6589.0 105. 25.9 82.4 9.5 2.68 SS-ltbrngy,vfgr,vwsrtd,sbang,sl fri,qtz,r musc,frac 3 19 6589.5 111. 26.1 65.8 24.7 2.66 SS-ltbrngy,vfgr,vwsrtd,sbang,sl fri,qtz,r musc,tr glau 3 20 6590.0 59.9 25.3 87.7 5.1 2.67 SS-ltbrngy,vfgr,wk cly lam, vwsrtd,sbang,sl fri,qtz,occ brn cly,tr musc 3 21 6590.8 56.8 25.3 88.0 4.1 2.65 SS-ltbrngy,vfgr,wk cly lam, vwsrtd,sbang,sl fri,qtz,brn cly,tr musc,glau 3 22 6591.1 14.5 16.9 38.5 51.9 2.77 SS-ltbrngy, vfgr,cly bnd,vwsrtd,sbang,sl fri,qtz,brn cly,occ pyr,frac 3 23 6591.5 99.1 19.7 60.5 34.3 2.66 SS-ltbrngy,vfgr,cly bnd,vwsrtd,sbang,sl fri,qtz,gy cly,occ musc,broken 3 24 6592.0 135. 25.6 83.6 6.8 2.68 SS-ltbrngy,vfgr,vwsrtd,sbang,sl fri,qtz,occ musc 3 25 6592.5 55.5 25.4 82.9 8.1 2.70 SS-ltbrngy,vfgr,wk gy cly lam,vwsrtd,sbang,sl fri,qtz,gy cly,occ musc 3 26 6593.0 55.8 23.3 79.0 13.7 2.65 SS-ltbrngy,vfgr,wk gy cly lam, vwsrtd,sbang,sl fri,qtz,gy cly,occ musc,frac 3 27 6593.5 15.9 23.1 81.5 12.2 2.67 SS-ltbrngy,vfgr,wk gy cly lam,vwsrtd,sbang,sl fri,qtz,gy cly,occ musc 3 28 6594.0 6.09 19.8 68.7 25.4 2.66 SS-ltbrngy,vfgr,cly bnd,vwsrtd,sbang,sl fri,qtz,dkbrn cly 3 29 6594.5 1.62 18.8 72.1 22.4 2.69 SS-mltgy,vfgr,cly bnd,vwsrtd,sbang,sl fri,qtz,dkgy cly,occ musc 3 30 6595.0 0.83 15.3 54.6 39.9 2.66 SS-mltgy,vfgr,wk cly lam, vwsrtd,sbang,wcmt,qtz,dkgy cly,occ pyr 3 31 6595.5 1.13 17.8 66.7 26.6 2.66 SS-mltgy,vfgr/r vcgr,wk cly lam, vwsrtd,sbang,wcmt,qtz,occ pyr 3 32 6596.0 34.6 15.4 74.3 25.0 2.66 SS-mltgy,vfgr,bnd,vwsrtd,sbang,wcmt,qtz,dkgy cly,occ musc,tr pyr,broken 1 -2 company : ARCO ALASKA, INC. gel 1 : KRU 36-11 CORE CORE LABORATORTES Field : KUPARUK RIVER UNIT Formation : KUPARUK FORMATION ANALYSIS RESULTS File No.: BP-3-1394 Date : 29-Aug-1990 SATURATION SAMPLE DEPTH PERMEABILITY! POROSITY GRAIN DESCRIPTION NUMBER (HORIZONTAL) (HELIUM) (PORE VOLUME) DENSITY Kair OIL WATER ft md % % % gm/cc 3 33 6596.5 0.71 16.7 64.9 31.4 2.67 SS-mltgy,vfgr,bnd,vwsrtd,sbang,wcmt,qtz,dkgy cly,occ musc,r yel cly clas 3 34 6608.8 1.32 14.9 65.2 31.3 2.67 SS-mltgy,vfgr,cly lam,vwsrtd,sbang,sl fri,qtz,dkgy cly,occ musc 3 35 6609.2 174. 25.0 87.5 4.2 2.66 SS-mltgy,vfgr,vwsrtd,sbang-rnd,wcmt,qtz,occ musc 3 36 6609.6 2.12 17.1 76.7 18.2 2.67 SS-mltgy,vfgr,cly bnd,vwsrtd,sbang,wcmt,qtz,dkgy cly,tr pyr 3 37 6610.0 56.3 24.1 83.7 7.5 2.68 SS-mltgy,vfgr,wk lam,vwsrtd,sbrnd,wcmt,qtz,dkgy cly,tr pyr 3 38 6610.5 9.67 20.3 74.6 17.9 2.66 SS-mltgy,vfgr,lam,vwsrtd,sbrnd,wcmt,qtz,dkgy cly,tr pyr 3 39 6611.0 127. 27.8 85.5 5.7 2.67 SS-ltbrngy,vfgr,vwsrtd,sbrnd,sl fri,qtz 3 40 6612.0 115. 20.3 58.8 36.4 2.69 SS-ltbrngy,vfgr,cly bnd,vwsrtd,sbrnd-rnd,wcmt,qtz,dkgy cly,tr pyr,frac 3 41 6613.0 80.9 25.5 85.5 6.2 2.67 SS-ltbrngy,vfgr,wk lam, vwsrtd,sbang,wcmt,qtz,occ dkgy cly 3 42 6613.6 56.5 22.0 82.7 8.3 2.70 SS-mltgy,vfgr,occ cly bnd,vwsrtd,sbang,wcmt,qtz,occ dkbrn cly,tr pyr 3 43 6614.5 5.73 16.2 50.4 45.6 2.65 MOST-dkgy bnd/m]tgy vfgr ss,vwsrtd,wcmt 3 44 6615.0 7.38 16.4 79.7 15.5 2.67 SS-mltgy,vfgr,c]y lam,vwsrtd,sbrnd,wcmt,qtz,dkgy c]y,tr pyr 3 45 6616.6 2.38 19.4 81.4 12.3 2.67 SS-mltgy,vfgr,wk lam, vwsrtd,sbrnd,wcmt,qtz,dkgy cly 3 46 6617.5 8.89 22.1 84.7 7.3 2.68 SS-mltgy,vfgr,wk lam, vwsrtd,sbrnd,wcmt,qtz,dkgy cly,tr pyr 3 47 6618.5 7.42 20.1 76.7 17.8 2.65 SS-mltgy,vfgr,wk ]am, vwsrtd,sbrnd,wcmt,qtz,dkgy cly,tr pyr 3 48 6620.0 11.7 21.2 81.6 11.0 2.68 SS-mltgy,vfgr,lam,vwsrtd,sbrnd,wcmt,qtz,dkgy cly 3 49 6620.5 5.14 16.9 72.2 24.6 2.66 SS-m]tgy,vfgr,bnd,vwsrtd,sbrnd,wcmt,qtz,dkgy cly,tr pyr 3 50 6621.0 70.1 22.5 89.8 2.3 2.68 SS-m]tgy,vfgr,vwsrtd,sbrnd,wcmt,qtz,tr pyr 3 51 6621.5 45.3 22.2 87.0 4.4 2.67 SS-mltgy,vfgr,vwsrtd,sbrnd,wcmt,qtz 3 52 6622.0 27.9 22.3 87.8 5.3 2.66 SS-m]tgy,vfgr,vwsrtd,sbrnd,wcmt,qtz 3 53 6622.6 13.9 20.9 82.8 10.6 2.68 SS-mltgy,vfgr,vwsrtd,sbrnd,wcmt,qtz,tr pyr 3 54 6623.0 9.47 20.4 83.5 9.7 2.72 5S-mltgy,vfgr,wk lam,vwsrtd,sbrnd,wcmt,qtz,occ dkgy c]y,occ pyr 3 55 6623.6 5.30 19.1 73.6 19.7 2.68 SS-mltgy,vfgr,wk lam,vwsrtd,sbrnd,wcmt,qtz,occ dkgy cly,occ pyr 3 56 6624.6 17.5 17.4 62.2 30.4 2.65 SS-mltgy,vfgr,cly bnd,vwsrtd,sbrnd,wcmt,qtz,dkgy cly,tr pyr,frac 3 57 6625.6 5.26 17.4 69.1 26.6 2.65 SS-mltgy,vf-fgr,pred vfgr,cly lam,vwsrtd,sbrnd-rnd,wcmt,qtz,dkbrn cly,occ pyr 3 58 6626.6 7.30 13.6 37.8 52.4 2.66 SS-mltgy,vf-fgr,pred vfgr,cly lam,vwsrtd,sbrnd-rnd,wcmt,qtz,dkbrn cly,pyr,frac 3 59 6627.6 3.99 17.8 64.0 29.4 2.66 SS-mltgy,vfgr,cly bnd,vwsrtd,sbrnd,wcmt,qtz,dkgy cly,tr pyr 3 60 6628.6 8.62 18.1 67.2 24.1 2.66 SS-mltgy,vfgr,cly bnd,vwsrtd,sbrnd,wcn~c,qtz,dkgy cly,tr pyr,frac 3 61 6629.6 2.19 15.4 40.9 48.2 2.68 SS-mltgy,vfgr,cly bnd,vwsrtd,sbrnd,wcmt,qtz,dkgy cly,tr pyr,frac 1 -3 Company : ARCO ALASKA, INC. Well : KRU 3G-11 CORE CORE LABORATORTES Field : KUPARUK RIVER UNIT Formation : KUPARUK FORMATION ANALYSIS RESULTS F~le No.: BP-3-1394 Date : 29-Aug- 1990 SATURATION SAMPLE DEPTH PERMEABILITY POROSITY GRAIN OESCRIPTION NUMBER (HORIZONTAL) (HELIUM) (poRE VOLUME) DENSITY Kair OIL WATER ft md ~ ~ ~ gm/cc 3 62 6630.5 0.63 19.7 76.1 18.4 2.66 SS-mltgy,vfgr,wk lam,vwsrtd,sbrnd,vwcmt,qtz,occ dkgy cly 3 63 6631.7 2.47 20.7 78.7 15.2 2.66 SS-mltgy,vfgr,vwsrtd,sbrnd,vwcmt,qtz,tr dkgy cly,tr pyr 3 64 6632.5 5.78 20.9 82.9 9.9 2.66 SS-mltgy,vfgr,vwsrtd,sbrnd,vwcmt,qtz 3 65 6633.6 2.95 20.4 79.1 14.2 2.68 SS-mltgy,vfgr,cly bnd,vwsrtd,sbrnd,wcmt,qtz,dkgy cly,tr pyr 3 66 6634.4 2.74 18.2 17.1 6.5 2.66 SS-mltgy,vfgr,cly bnd,vwsrtd,sbrnd,vwcmt,qtz,dkgy cly,occ musc I -4 STAT]:ST~CAL DATA AfD StJRFA(:E C(~ ~q~ I_~ Company Wel 1 : ARCO ALASKA, INC. : KRU 3G- 11 CORE LABORATORIES Field : KUPARUK RIVER UNIT Formation : KUPARUK FORMATION File No.: BP-3-1394 Date : 2g-Aug- 1990 TABLE I SUMMARY OF CORE DATA ZONE AND CUTOFF DATA CHARACTERISTICS REMAINING AFTER CUTOFFS ZONE: Identification ......... NOT SPECIFIED Top Depth 6534.0 ft Bottom Depth 6634.7 ft Number of Samples 85 DATA TYPE: Porosity (HELIUM) Permeability (HORIZONTAL) Kair CUTOFFS: Porosity (Minimum) Porosity (Maximum) ....... Permeability (Minimum) --- Permeability (Maximum) --- Water Saturation (Maximum) Oil Saturation (Minimum) - Grain Density (Minimum) -- Grain Density (Maximum) -- Lithology Excluded 0.0 100.0 0.0000 100000. 100.0 0.0 2.00 3.50 NONE % % md md % % gm/cc gm/cc ZONE: Number of Samples Thickness Represented - POROSITY: Storage Capacity Arithmetic Average Minimum Maximum Median Standard Deviation GRAIN DENSITY: Arithmetic Average Minimum Maximum Median Standard Deviation 85 85.0 ft 1668.2 ~-ft 19.6 % 0.9% 28.6 % 20.1% +5.7 % 2.73 gm/cc 2.65 gm/cc 3.27 gm/cc 2.67 gm/cc .+0.15 gm/cc PERMEABILITY: Flow Capacity Arithmetic Average Geometric Average Harmonic Average Minimum Maximum Median Standard Oev. (Geom) -- 5716.2 md-ft 67.2 md 10.00 md 0.07 md 0.00 md 1344. md 11.7 md K.10±1'119 md HETEROGENEITY (Permeability): Oykstra-Parsons Var. -- Lorenz Coefficient 0.912 0.713 AVERAGE SATURATIONS (Pore Volume): Oil Water 68.8 % 23.7 % Stat 1 - 1 iO000. Permeabilihy vs. Porosity 0 N tO00.0 tO0.0 iO.O i.O O.Oi O.OOi - 0.0 .+ · 1' + 9' 4- + + i2.0 iO.O Helium Porosity' 24.0 +~. + + :SO. 0 KRU ~$-it KUPARUK RIVER UNIT 6534-6635 Feet - I. EBEND - to0 ?0 ~0 4O 3o Porosity Histogram , · · lo .0 t~.O te.O / / , I / / I too eO ?0 eO 40 30 0 30.0 Helium Porosity: ARGO ALASKA. lNG. KIqU KUPAI4UK RZVL~4 UNZT 6534-663S Feet ....... Med &eft Ye ............ ~" t,~,h. Average . ~m~e~&ve ~f. equefloy I~ eeml~&ee ~00 7o ~0 0 .00~ Permeability Histogram Horizontal Permeability (Air) · md ARCO ALASKA. KI:IU KUPARUK RXVER UNZT 65~4-6635 Feet ii, ---lledSan Value ............ hOB. AveraOe ItO.O0) - -C~mUlltSye Frlqulfl~y t00 gO O0 7O o0 ~0 4O 3o ~0 ~0 0 Grain a.7o Density HiStogram gO I0 70 40 30 aO 10 0 3.30 Grain Oens~ty: gm/cc ARCO ALASKA. XNC. KAU KUPARUK ICl~:VEICl UN~:T --- #mdiln Vllum (~.07! Iff Corl LlJOrl~Or~ll ll-#p-l#O KRU ~G-1 1 KUPARUK R]~VER UNliT KUPARUK FORMAT]CON (8534.0 - 8634.? feet) Core Laboratories 1S-8ep-1990 Vertical Scale $.00 In - 100.0 ft - Llthology Legend - Slltltone ~'L4d'4d--rd~ Mudet one I0.,, lOg Ho-r~ Ka l,r~ O. 1. md. 1,000 Depth Helium Porolity ~ 1_o. x ! I 6SOO 3( Cum. CtJrve Water Sat: X Ol I So t: ~ F' ' 8 8 I Grain Den lOOL2.eo gm/cc 3.30 PLIJ~ TRACER PREPARAT~ DATA Arco Alaska, Inc. KRU 3G-11 North Slope, Alaska DEPTH FEET SMPL. # CORE LABORATORI E S I NC . Date : 12-0ct-90 File No : BP-3-1394 Formation : Kuparuk Laboratory : Anchorage Drig Fld : Bland Mud Analysts : PLB, DKS Location : 24-12N-8E,Fr NW cor 606'S 1927'E(BHL) TRACER ANALYSIS DATA SHEET: DEAN STARK PLUG SAMPLES CRUSHED EMPTY WEIGHT DRY WEIGHT FLASK WT. FLSK/H20 WEIGHT GRAMS GRAMS GRAMS GRAMS FRESH WATER WEIGHT OUT GV PV GRAMS CC's CC's CC's 6582.8 3-5 6587.0 3-14 6609.2 3-35 6610.0 3-37 6618.5 3-47 36.745 122.080 34.594 120.470 38.308 119.093 39.094 125.070 40.762 124.886 CORE 3 222.000 36.809 219.910 34.700 219.173 38.345 225.240 39.129 223.656 40.842 41.220 0.30 13.851 5.378 37.214 0.72 12.851 2.966 42.310 0.20 14.401 4.792 42.970 0.35 14.601 4.644 44.199 0.69 15.391 3.871 International CORE LABORATORIES TRANSMITTAL AND ACKNOWLEDGEMENT OF RECEIPT TO' Materials received via:_ ~.."~'4~,/':~ ~..~.~ . Items received ~-~-<~ ~_~ > ~ i~', * PLEASE RETURN ONE COPY Shipped by: ~/_~ ~ for Core Lab Date: ~--/~'¢~ Received by: ~ for Date: · ** Please note that the ~tems listed above are inventoried, shipped and received in g~od faith, but are subject to minor adjustments because of possible unintentional human error. In such a case, both shipper ~nd~receiver agree to make a timely and bona fide effort to correct any observed discrepancies. ~ .e,,~.l.v,v,~ .C~I'rL~N~f. An~"~m~. Alllskl19951~~ (907) 349-,3541 lr~t;~.~r-r]O~iOr~L~', LAgO~qATOF~IES · )~ ") CO~ L ~C',. ~ 0 ~::::~ ATO R I ES l COPE LASOiqATOFIIES CORE LABORATORIES / I CORE LASOF-~ATORIES CORE Western Atlas International CORE LABORATORIES TRANSMITTAL AND ACKNOWLEDGEMENT OF RECEIPT TO: AR CO ALASKA, INC. 2300 W. PLANO PARKWAY PLANO, TEXAS 75075 A TTN: SHINIGHI SAKURAI MATERIAI_,S RECEIVED VIA: FEDERAL EXPRESS ITEMS RECEIVED- ONE PA CKA GE CONTAINING 78 PLUG SAMPLES FRO3I E .~ U vG-I 1 (SEE A T., ACHED LNVENTOR Y) PLEASE RETURN ONE COPY SHIPPED BY: DA VID SUMPTER FOR CORE LAB DATE' 19-SEP-90 RECEIVED BY' FOR ARCO DATE' Please note that the items listed above are inventoried, shipped and received in good tkdth, but are subject to minor adjustments because of possible human error. In such case both shipper and receiver agree to make a timely and bona fide effort to correct any observed discrepancies. 8005 Schoon Street. Anchorage. Alaska 99518-3045, (907) 349-3541. Fax (907) 344-2823 PLUG SAMPI,E INVENTORY COMPANY ARCO ALASKA. INC. WEI.I. KRU 3(}-11 6538.5 .{.77c _ /'~A o_>,0.0 5540.6 dS~ i ~ 0~.0 F 545 c~ :~546.6 (5575.5 6576.5 ,:,o ;9.8 558:.9 o384. q ¢5S5.0 S5S5.5 6587.5 '55'd8.5 4589.O 65?;9.5 6590. S 5591.~ ,5592.0 ~592.5 4593.0 .5593.5 ,55 94. u 5~04.5 't596.0 ,'5596.5 ,- ~ . . .- , .~ ., .. . 6L 7.5 ~620.0 I) J-{txl'~ l 6d20.5 662 !.0 5,,521.5 6622.0 662° 6 6623.0 6623.6 6625.6 6626.6 6627. {5 6628.6 6620.6 d~q30.5 .:632.5 MATERIAL AND SITE PREPARATION Upon arrival at the wellsite, the required preservation materials should be set up in the core trailer by Service Company Personnel. The melting pot should be filled with Core Seal and turned on. The temperature should be adjusted for the length of time before the core is recovered, place on low (180 deg. F.) if more than 48 hours is anticipated. It is recommended that the melting pot be checked at regular intervals when turned on and never exceed the recommended dipping temperature for Core Seal (320 - 330 deg. F). Sampling equipment will be set up and tested. All personnel need to familiarize themselves with the areas on the wellsite that they will be working in while retrieving the core, such as the rig floor, pipe shed, and core trailer location. Also all personnel should be aware of their areas of responsibility for the preservation operation. One core trailer will be used for this operation. Figure 2 shows the preservation trailers~ work areas. Upon completing the above preparations, the core boxes should be put together and marked with client, well name, core number and box number. CORE HANDLING AND PRESERVATION CATCH'r NG CORE The Service Company Lab representative should be present on the rig floor when the core barrel is being disconnected. He should have all materials that will be needed to prepare the core for movement to the core trailer on the rig floor or in the pipe shed. Also he should have a rock hammer, markers, and plastic sample bags with him on the rig floor. It is important that the core is maintained in the proper orientation until fully marked. Both a steel and fiberglass inner barrel will be used. Both core catching methods are discussed bel ow. fiberglass inner barrel Fiberglass liner or inner barrel is laid down in work area. Clean exterior of fiberglass tube and mark orientation lines down the entire length with a waterproof/non-erasable ink. Markette brand markers seem to be best suited for this. Orientation lines shall be marked with black on the left and red on the right. We have found that taping the red and black markers together allows this to be done in a minimum amount of time. Mark each foot with a depth and foot line. Cut plastic tubes into three foot sections on the foot line with an electric skill saw. We use a masonry blade for cutting, available at most hardware stores. Generally it is the responsibility of the coring company to provide an appropriate saw with blades. Both ends of the three foot sections are sealed with caps and hose clamps provided by the coring company. Number each tube from the top down in consecutive order by depth. The core is loaded onto a forklift and moved over to the core trailer. At the core trailer the core is pushed out and treated just like core from a steel inner barrel. steel inner barrel Core boxes or core trays will be used to carry the core, once it is removed from the inner barrel. The wooden core boxes will be lined with oil sorbent material and Barex plastic. Personnel will cover the core with another layer of Saran Wrap as core is placed in the boxes to minimize exposure to the atmosphere. As boxes are filled on the rig floor, they will be closed and set aside until moved to the pipe shed. When all core is off the rig floor it is transported to the core trailer. Care must be taken to ensure all core boxes are numbered and labeled with top and bottom. CORE LAY-OUT 'tN TRA'rLER The core should be laid out on the counter in five to ten foot intervals by an AAI Coring Geologist. Core pieces are fit together, oriented with the apparent up-dip at the top, depth marked and double striped for orientation. Depths shall be marked below the corresponding foot line and orientation lines marked with white on the right and yellow on the left, if using waterproof markers. It is recommended that lumber crayons be used for marking the core surface and markers for foil wrapped core. While core is marked, chip samples and core descriptions may be performed providing the exposure of core is kept to a minimum. Sampling intervals will be identified by an AAI Coring Geologist. Three types of samples will be identified with markings both on the core piece itself and on the foil wrapping. They are: SC - Service Company analysis, 3" of whole core, 1 or 2 per foot in the sands. TR - Tracer analysis, 2" or whole core, minimum of ! per sand interval. No designation - Core pieces preserved only. Samples are dry cut on Service Company Person on rock saw and replaced in the core at the appropriate depth. This operation requires a dust mask. The samples are removed and are replaced with spacer containing the appropriate depth and sample marking. These samples are immediately wrapped in Saran (6 layers) and foil (3 layers). SC samples are plugged. TR samples are sawed into segments. Depth and orientation lines are to appear on both the core itself and foil wrapping. Priority for sample selection will be as follows: · SC, 1" Service Company plugs for routine saturation measurements. TR, Tracer sample. The SC plugs will be selected as near the foot marker as possible. TR samples should be selected from better the rock and should never be selected at a break in the core. The core is placed with the top facing the same direction for all personnel in the trailer. This will help insure that the proper core orientation is maintained. CORE PRESERVATION This process should begin as soon as possible following sample identification and separation by AAI and Service Company Personnel. The core is then wrapped a minimum of six full wraps of Saran Wrap, then wrapped with a minimum of three full wraps of aluminum foil, and marked. Wrapped core will be marked wi th depth and orientation lines. Glass strapping tape is placed on the foil under the wire to prevent puncture of the foil. The core is wrapped tightly around the center with wire to facilitate the dipping of the samples in Core Seal. The core should be completely submerged in the dip tank for 10 to 15 seconds and them hung on the cooling rack. After the Core Seal has cooled (3-5 min.) the sample should be redipped to insure a proper seal and to help protect the core from damage during shipment. After the second dip, the wire is cut at a point just above the preserved piece, and a small amount of Core Seal should be placed over the enclosed wire to eliminate a whicking effect. The preserved core is then placed in core boxes and the boxes left open for final quality control inspection. Once all the core has been preserved and placed in the open core boxes, it should be checked for proper preservation and markings. Occasionally the Core Seal will be too thick to read the markings, and if possible a marker should be used to mark the appropriate designations on the Core Seal. Waterproof marker seem to be best suited for writing on Core Seal. The core depths are then placed on the core boxes and the boxes packed and sealed for shipment. A wellsite inventory shall be completed for each core, and the boxes then placed in shiPping crates. The core trailer should be cleaned and prepared for the next core to be preserved. TRACER CUTT'rNG TRACER AND PLUG SAMPLING At least two TR samples will be taken from each sandstone interval. The TR samples must be cut into 13 segments by Service Company Person. The segments are shown in figure 3. This is done with the dry saw used for cutting whole core samples from the core. The segments must be identified by segment number and depth on the rock. This numbering must be done before sawing to avoid sample confusion. Use a template to mark core segments on the rock. Preserve these segments in Saran Wrap immediately and tape closed. Mark depth and segment number on tape. The 13 wrapped pieces from one tracer are then sealed in a strip of ProtecCore. Each strip should have 13 pockets pre-made. CORE PLUGGZNG One inch diameter plugs are drilled from selected samples by Service Company Person. Drill plugs as samples are available. Samples will be depth marked, oriented, identified SC and wrapped. All plugs to be drilled to maximum length and parallel to bedding strike. Drilling fluid will be recirculated mineral oil. Unwrap sample only immediately prior to plugging. Upon completion of plugging, the plug is trimmed as shown in figure 4. Remnant whole core will be represerved in six layers of Saran, two layers of foil, marked for depth and orientation and placed back in position with the rest of the core. The plug will be immediately immersed in containers prefilled with Isopar. Teflon spacer washer should be fit on the core plug at top and bottom to prevent breakage of glass container or plug during shipping. The container is opened, the core plug inserted with Isopar overflow. The container is capped immediately, squeezing out excess Isopar, so the container is liquid-filled. Hydrocarbon gas in core plug will provide thermal expansion space. Bottle cap is labeled with plug depth before core is plugged. The caps of these containers will be coated in Core Seal to prevent leakage due to the cap coming loose while in transit. Plug end pieces are placed in Ziplock bags marked with depth, well name, and company. PACKAGING FOR SHIPPING CORE BOXES The preserved whole core will be placed in standard core boxes, approximately three feet to the box and taped closed. Mark boxes to indicate core interval, core number, and well name. These boxes will be placed in wooden crates and shipped to Anchorage. Core should be kept from freezing. These boxes will be shipped to Service Company Lab for further sampling. TRACER SAMPLES The tracer samples will be placed in heavy corrugated boxes with packing material to prevent damage. Do nos fold or crease ProtecCore laminate. These will be shipped to Service Company Laboratory for analysis. ROUTTNE CORE PLUGS (SC PLUGS) The glass containers will be placed in holes cut in foam plastic inside a trunk. Foam plastic will be placed between each layer. These samples will be shipped by air to the Service Company Lab for routine water saturation, porosity, and air permeability. The plugs will then be analyzed for tracer. ROUT/NE CORE PLUG ENDS (FROH SC PLUGS) These plug end pieces will be placed in corrugated boxes with packaging materials and shipped to the Service Company Lab and await further instructions from ~u~I. RECOMMENDED TOOLS AND MATERIALS The following tools and materials will be supplied by the Service Company Lab: Core Seal Preservative (estimate one pound per foot of core) ProtecCore Laminate Small Melting Pot Saran Wrap Plastic Wrap Aluminum Foil Plastic Sample Bags Tape Measure Waterproof Markers (black and red) Lumber Crayons (yellow and white) Wi re For Dipping Core Boxes Strapping Tape Stapler Rock Hammer Large Chisel Screwdrivers and Nutdrivers Wi re Cutters Pliers Skill Saw For Cutting Fiberglass Inner Barrel Cut-Off Saw For Core Trailer Drill Press And Pump For Isopar Trim Saw For Plugs Plastic Tubing For Unpreserved Sections Heat Sealer For ProtecCore Rubber Gloves Hardhat Ziplock Bags For Plug Ends Safety Boots And Glasses Coveralls Cold Weather Clothing Isopar For Bit Lubricant And Plug Sample Preservation The following materials will be supplied by ARCO' Rags Six Foot Wooden Core Boxes Trunk With Foam Packaging Material Glass Sample Jars With Lids Teflon Washers And Teflon Disks ADDITIONAL INFORMATION Please provide Service Company Lab with the following information: Rig Name and Number Rig Phone Number Company Man's Name And Phone Number AFE Number - For shipping materials to the slope. Materials are usually shipped to the rig at least one week prior to the core date and are sent via ARCO Freight Terminal. It is preferred that Service Company Personnel arrive at the wellsite 24 hours prior to con~nencement of coring for site preparation. Upon arrival at Prudhoe Bay Service Company Personnel will require transportation to the wellsite and prefer to stay at the wellsite during the entire coring operation. FIGURE 1 - CORE TRAILER LAYOUT isEAEER:! FIGURE 2 - SERVICE COMPANY SAMPLE FIGURE 3 - CORE TRACER SAMPLE SEGMENTS , DATA DTSi~...i Ii:, ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" 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 KUPARUK RIVER UNIT Auth. or W.O. no. AK5067 tCounty, parish or borough NORTH SLOPE Lease or Unit itle ADL:25547 ALK:2661 COMPLETION IState Ai~ J Wetl no. 3G~%l Operator ARCO Spudded or W.O. begun ARCO W L 55.252072 IHour Prior status if a W.O. 15:00 SPUD Date and depth as of 8:00 a.m. IDate 07/18/90 01/13/91 (13) TD: 0 PB: 6790 SUPV:GB/SK Complete record for each day reported NORDIC 1 LEVEL RIG MW:10.6 NaC1/Br MOVE RIG FROM 3G-2 TO 3G-4, LOCATION TO UNLEVEL TO SPOT RIG DUE TO ADJACENT WELL HOUSE, MOVE RIG FROM 3G-4 TO 3G-11, PREPARE SITE, STEAJ~ HEAT WELL SEAL FLANGE AND VALVE, BRING IN UPPER TREE, LEVEL RIG 2 HRS WHILE NU BOPE, CHANGE PIPE PJ%MS FROM 2-7/8" TO 3-1/2", TEST BOPE, RELEVEL RIG AND CENTER ON HOLE DUE TO COLLAPSED CRIBING DAILY:S21,036 CUM:$1,096,424 ETD:S1,096,424 EFC:$1,600,000 The above is correct Signature Drilling, Pages 86 and 87. Date , I Title D,iiilng 8upi AR3B-459-1-D INumber ail daily well histo~ forms consecutively as they are prepared for each well. jPage no l ARCO Om, and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length ot 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. Accounting cost center code District ARCO ALASKA INC. NORTH SLOPE Field Lease or Unit ell no. KUPARUK RIVER UNIT ADL:25547 ALK:2661 3G~ll Auth. or W.O. no. Title AK5067 COMP LETI ON Slate OperatorARCO A.RCo. W.I. Spudded or W.O. begun IDate SPUD J 07/18/90 Date and depth as of 8:00 a.m. 01/14/91 (14) TD: 0 PB: 6790 SUPV:GB/SK Iotal number of wells (active or inactive) on this, ost center prior to plugging and aS~W,O2 bandonment of this well 52072 our I Prior status if . 15:00 Complete record for each day reported NORDIC 1 RIG REALEASED MW:10.6 NaCl/Br RU HLS E-LINE, PERFORATE "A" SAND: 6594'-6614' (ONE GUN), POH AND RD HLS, LOAD PIPE SHED WITH 3-1/2" TUBING, RIH W/ COMP ASSY, MU SSSV AND TEST CONTROL LINE TO 5000 PSI (OK), DROP BALL, MU TBG HNGR, TEST TO 5000 PSI (OK), DRAIN STACK AND LAND TBG, RILDS, PRESS TBG TO 2500 PSI AND SET PACKER, PRESS ANN TO 1000 PSI (OK), BLEED OFF ANN AND TBG TO 1200 PSI, PU AND SHEAR PBR, BLEED OFF PRESS AND RELAND TBG, RILDS PRESS TBG TO 1000 PSI, CLOSE SSSV, BLEED TBG TO 500 PSI AND TEST SSSV (OK) EQUALIZE PRESS, OPEN SSSV, PULL LANDING JOINT SET BPV, ND BOPE, NU TREE, TEST TREE (OK), SHEAR SOS, DISPLACE WELL W/ 450' DIESEL, RELEASE RIG DAILY:S143,879 CUM:$1,240,303 ETD:S1,240,303 EFC:$1,600,000 Old TD New TD Released rig Date IPB Depth Kind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effec' .... corrected The above is correct For form preparati .... d distr'~ion: see Procedures Manual, Seoti~.~0, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. DIvlllon of Alla~h, ~'~ .... Vl Cl/VIT ~ I'°~ ~ MI, ~ 5~988~8~0.~0 498,~4. Y0 ?O°~R' 4Y.~" 150°Off~O.e~8" ? ~~ ~0.47 4 PS~.~O ?O°~R~ 4?. 9R~" 1~O~O0'40. P~O" ~ ~,90~, ~0,~? mgo,~m~, yl ?~ ~'~?. ~R~" I~O~OO'4R.~O* /~ ~ ~00, ~0.~ 4 ~0~ 4?4. ~ ~0~' 4~.~4" /~00'~4.~4~ ~ /3 ~00,~0.4~ 4~, ~04.~ ?0~' 4~.~" 18 ~, 900~600. 81 4~0~ 334.00 ?~ee' 4?.9R8" 1~0~00'~8.?~8" 16 8,~00,~60.8~ ~0~0~.0~ ?O°RR' 4?,~R~'' 1~0°00'4~. / ? 8, OOO~ 860. ~0 40O, RO~. ?O ZO° RR' 4?. 9R8" 180~'~0. R04" 18 ~,988, 8eO.~ 498~ R89.8~ ?O°RR'dZ. gR~' I~'80. 19 8, ~OO~ ~60.84 4~0~ R34.~0 ZOneR' 47. 9R~' 1~'~1.6 ?1" · 0 8,988, ~0.88 49~ R09.~8 ?~ RR'4?.~R8' I~0~'~e.397' /0 ~. N.L... FW.L. 0,$. ~&O · ~88' ~$$' 48.9 85.9 R855" ~48' 48.? 84,0 ~$8'~ ~0' ~8.4 3~.0 Z~8'~ 19~' 48.~ 84.0 ~38'~ I?0' 47.8 R~8'~ 14~' 47.~ ~8'~ /~0' 46.~ ~.~ R~o' ' 9~' 46.9 18~'~ 8' ~.~ ~.~. ~,~, ~. ~.~. R838'~ ~0' 4?.8 8S, I ~8'~ ~0' 4~.~ ~.1 e~3O'-- 9~' 46.0 ~3.0 ~8'~ /~0' 46,8 ~38'~ /4~' 4~.~ ~3.0 2~' /9~' 4~.3 ~.0 _ I H~Ea~ C~RTIFY ~Ar I AM ~81ST~R~D AND LlCgNS~D ~ P~ACTIC~ ~NO SU~V~YIN~ IN THE ~FAr~ O~ ANO ~A? ?HIS PLA? ~[~EN~ ( ~ T~T ALL OI~NSl~ AND ~?~ILS A~[ CO;~? ~ Og ~PRlL ~6, 1990. N$DK. $$00. C~A .03GX.6~0708 OfU& L $1 ?'~ $' $ CONDUC TOt~ $ AS OUI£ ? LOCATION ORIGINAL -7/ 08/31/90 by GREAT LAND DIRECTIONAL DRILLING, INC. for Gyrodata Services, Inc. Client .... : ARCO ALASKA, INC. Field ..... : KUPARUK RIVER Well ...... : KRU 3G-11 Section at: N,43.08,E Surveyor..: M.NAIRN Computation...: RADIUS OF CURVATURE Survey Date...: 08/12/90 RKB Elevation.: 89.00 ft API Number .... : 50-103-20133 Job Number .... : AK0890G240 INTERPOLATED MARKERS REPORT Surface Location: 2538 SNL 120 EWL S24 T12N RSE MARKER IDENTIFICATION KB 9-5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A 7" LINER TD MEAS INCLN DEPTH ANGLE 0 0.00 3352 42.55 6531 9.99 6541 9.97 6557 9.94 6676 9.39 6876 9.05 6900 9.05 VERT-DEPTHS SECT BKB SUB-S DIST DIRECTION REL-COORDINATES BEARING FROM-WELLHEAD 0 -89 3020 2931 5786 5697 5796 5707 5811 5722 0 N 0.00 E 996 N 41.48 E 2474 N 52.90 E 2476 N 53.03 E 2478 N 53.23 E ON 0 E 727 N 681 E 1817 N 1679 E 1818 N 1680 E 1820 N 1683 E 5929 5840 6126 6037 6150 6061 2498 N 53.40 E 2529 N 53.39 E 2533 N 53.39 E 1832 N 1699 E 1851 N 1724 E 1853 N 1727 E Oate ~ GREAT LAND Client · Field ..... : Well ...... : Section at: Surveyor..: S MEAS C DEPTH 7 100 7 200 7 300 7 400 7 500 DIRECTIONAL DRILLING, 600 700 800 900 1000 ARCO ALASKA, INC. KUPARUK RIVER KRU 3G-11 N,43.08,E M.NAIRN 7 1100 7 1200 7 1300 7 1400 7 1500 INCLN ANGLE VERTICAL-DEPTHS BKB SUB-SEA 0.22 100.0 11.0 0.36 200.0 111.0 0.24 300.0 211.0 0.15 400.0 311.0 0.29 500.0 411.0 0.34 600.0 511.0 0.32 700.0 611.0 0.36 800.0 711.0 0.40 900.0 811.0 0.36 1000.0 911.0 0.52 1100.0 1011.0 0.27 1200.0 1111.0 1.43 1300.0 1211.0 3.78 1399.9 1310.9 6.71 1499.4 1410.4 7 1600 11.03 7 1700 15.40 7 1800 17.54 7 1900 21.25 7 2000 24.15 7 2100 30.27 1598.2 1509.2 1695.5 1606.5 1791.4 1702.4 1885.7 1796.7 1978.0 1889.0 2066.9 1977.9 INC. RECORD OF SURVEY SECTION DIRECTION DISTNCE BEARING 0.1 N 56.46 W -0.3 S 57.78 W -0,8 S 51.12 W -1.1 S 81.90 W -1.3 N 55.81 W -1.6 S 69.65 W -2.1 S 51.32 W -2.7 S 22.21 W -3.3 S 26.75 W -4.0 S 28.24 W -4.7 S 39.03 W -5.4 S 77.85 W -5.4 N 9.06 E -1.3 N 25.27 E 7.6 N 39.35 E 23.0 N 53.35 E 45.5 N 52.98 E 73.5 N 50.27 E 106.5 N 50.61 E 144.8 N 48.96 E 190.4 N 45.88 E 08/30/90 Computation.... · Survey Date...: RKB Elevation.: API Number .... : Job Number .... : RADIUS OF CURVATURE 08/12/90 89.00 ft 50-103-20133 AK0890G240 RELATIVE-COORDINATES FROM-WELL-HEAD 0.2N 0.1W 0.2N 0.6W 0.18 1.0W 0.3S 1.3W 0.2S 1.7W 0.1S 2.2W 0.4S 2.7W 0.9S 3.0W 1.5S 3.3W 2.1S 3.6W 2.7S 4.0W 3.1S 4.6W 2.2S 5.5W 2.1N 4.2W 9.8N 0.7E 20.5N ll.SE 34.2N 30.1E 51.8N 52.3E 72.9N 77.9E 97.8 N 107.4 E 128.7 N 141.0 E CLOSURE DL DISTNCE BEARING /100 0.2 N 28.23 W 0.22 0.6 N 73.48 W 0.14 1.0 S 82.17 W 0.12 1.3 S 78.25 W 0.09 1.7 S 83.64 W 0.14 2.2 S 86.82 W 0.05 2.7 S 81.45 W 0.02 3.2 S 73.96 W 0.04 3.6 S 65.98 W 0.04 4.2 S 60.30 W 0.04 4.9 S 56.24 W 5.5 S 56.51 W 6.0 S 68.42 W 4.7 N 63.05 W 9.9 N 3.90 E 23.6 N 29.97 E 45.5 N 41.38 E 73.6 N 45.31 E 106.7 N 46.90 E 145.2 N 47.67 E 190.9 N 47.61 E 0.16 0.25 1.16 2.35 2.94 4.35 4.37 2.15 3.71 2.91 6.17 'Survey Codes: 7/GYRO KRU 3G-11 S MEAS INCLN C DEPTH ANGLE 7 2200 31.45 7 2300 35.41 7 2400 37.97 7 2500 41.67 7 2600 42.18 7 2700 41.41 7 2800 41.80 7 2900 44.26 7 3000 43.52 7 3100 42.85 7 3200 42.96 7 3300 42.57 7 3400 42.53 7 3500 42.56 7 3600 41.87 7 3700 41.36 7 3800 40.31 7 3900 39.41 7 4000 38.70 7 4100 38.68 7 4200 38.28 7 4300 37.08 7 4400 33.26 7 4500 30.36 7 4600 29.72 7 4700 27.94 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 2152.7 2063.7 241.6 2236.2 2147.2 296.6 2316.3 2227.3 356.2 2393.1 2304.1 420.2 2467.5 2378.5 487.0 2542.1 2453.1 553.6 2616.9 2527.9 620.0 2689.9 2600.9 688.1 2762.0 2673.0 756.9 2834.9 2745.9 825.2 2908.2 2819.2 893.2 2981.6 2892.6 961.0 3055.3 2966.3 1028.6 3128.9 3039.9 1096.2 3203.0 3114.0 1163.4 RECORD OF DIRECTION BEARING SURVEY RELATIVE-COORDINATES FROM-WELL-HEAD N 44.83 E 164.8 N 177.5 E N 46.22 E 203.4 N 216.8 E N 47.71 E 244.1 N 260.5 E N 44.35 E 288.6 N 306.6 E N 42.46 E 337.1 N 352.5 E N 42.77 E 386.2 N 397.6 E N 41.57 E 435.4 N 442.2 E N 36.51 E 488.4 N 485.1 E N 36.79 E 544.0 N 526.5 E N 40.17 E 597.5 N 569.1 E N 40.66 E N 41.35 E N 41.60 E N 41.29 E N 41.21 E 3277.8 3188.8 1229.8 N 44.07 E 3353.4 3264.4 1295.1 N 42.82 E 3430.2 3341.2 1359.2 N 46.25 E 3507.8 3418.8 1422.1 N 46.32 E 3585.9 3496.9 1484.5 N 46.85 E 649.4 N 613.2 E 700.6 N 657.8 E 751.3 N 702.6 E 802.0 N 747.3 E 852.5 N 791.6 E 901.3 N 836.6 E 948.8 N 881.6 E 994.5 N 926.5 E 1038.0 N 972.1 E 1081.0 N 1017.5 E 3664.2 3575.2 1546.6 N 46.00 E 1123.9 N 1062.5 E 3743.3 3654.3 1607.7 N 45.00 E 1166.7 N 1106.1 E 3825.0 3736.0 1665.3 N 41.63 E 1208.6 N 1145.6 E 3910.0 3821.0 1717.9 N 40.62 E 1248.3 N 1180.3 E 3996.6 3907.6 1768.0 N 41.15 E 1286.2 N 1213.1 E 4084.2 3995.2 1816.1 N 39.72 E 1322.9 N 1244.3 E Page 2 o8/3o/9o CLOSURE DISTNCE BEARING 242.2 N 47.13 E 297.3 N 46.83 E 357.0 N 46.86 E 421.0 N 46.73 E 487.7 N 46.27 E DL /lOO 1.21 3.99 2.62 3.99 0.99 554.3 N 45.84 E 0.78 620.5 N 45.44 E 0.66 688.4 N 44.81 E 3.48 757.1 N 44.07 E 0.75 825.2 N 43.60 E 1.70 893.2 N 43.36 E 961.0 N 43.19 E 1028.6 N 43.08 E 1096.2 N 42.98 E 1163.4 N 42.88 E 1229.8 N 42.87 E 1295.1 N 42.90 E 1359.2 N 42.97 E 1422.1 N 43.12 E 1484.5 N 43.27 E 1546.6 N 43.39 E 1607.7 N 43.47 E 1665.3 N 43.47 E 1718.0 N 43.40 E 1768.0 N 43.32 E 1816.1 N 43.25 E 0.25 0.50 0.12 0.14 0.69 1.35 1.17 1.65 0.71 0.21 0.52 1.25 3.95 2.91 0.65 1.81 'Survey Codes: 7/GYRO KRU 3G-11 S MEAS INCLN C DEPTH ANGLE 7 4800 27.41 7 4900 25.15 7 5000 25.23 7 5100 25.47 7 5200 25.12 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 4172.7 4083.7 1862.5 4262.4 4173.4 1906.8 4352.9 4263.9 1949.3 4443.3 4354.3 1992.0 4533.7 4444.7 2034.7 7 5300 25.01 4624.3 4535.3 7 5400 24.74 4715.0 4626.0 7 5500 22.97 4806.4 4717.4 7 5600 22.28 4898.7 4809.7 7 5700 21.01 4991.7 4902.7 7 5800 20.30 5085.3 4996.3 7 5900 19.09 5179.4 5090.4 7 6000 18.87 5274.0 5185.0 7 6100 18.90 5368.6 5279.6 7 6200 18.23 5463.4 5374.4 7 6300 13.98 5559.4 5470.4 7 6400 11.53 5657.0 5568.0 7 6500 10.04 5755.2 5666.2 7 6600 9.87 5853.7 5764.7 7 6700 9.24 5952.3 5863.3 7 6790 9.05 6041.1 5952.1 X 6900 9.05 6149.8 6060.8 2077.0 2119.1 2159.5 2198.0 2234.8 2270.1 2303.8 2336.2 2368.6 2400.4 2428.1 2450.1 2468.7 2485.7 2502.0 2516.1 2533.1 RECORD OF SURVEY DIRECTION RELATIVE-COORDINATES BEARING FROM-WELL-HEAD Page 3 CLOSURE DISTNCE BEARING N 41.32 E 1358.2 N 1274.5 E 1862.5 N 43.18 E N 39.88 E 1391.8 N 1303.3 E 1906.8 N 43.12 E N 40.20 E 1424.4 N 1330.7 E 1949.3 N 43.05 E N 39.90 E 1457.1 N 1358.3 E 1992.0 N 42.99 E N 39.75 E 1490.0 N 1385.6 E 2034.7 N 42.92 E N 42.62 E 1521.8 N 1413.5 E N 42.25 E 1552.9 N 1441.9 E N 41.78 E 1582.9 N 1469.0 E N 41.88 E 1611.6 N 1494.6 E N 41.46 E 1639.2 N 1519.1 E N 40.71 E 1665.7 N 1542.3 E N 40.80 E 1691.3 N 1564.3 E N 39.47 E 1716.1 N 1585.3 E N 40.23 E 1741.0 N 1606.0 E N 39.91 E 1765.3 N 1626.5 E N 42.47 E 1786.2 N 1644.8 E N 47.52 E 1801.8 N 1660.4 E N 52.52 E 1813.8 N 1674.7 E N 53.76 E 1824.2 N 1688.6 E N 53.28 E 1834.1 N 1701.9 E 08/30/90 N 53.39 E 1842.6 N 1713.4 E N 53.39 E 1852.9 N 1727.3 E 2077.0 N 42.89 E 2119.1 N 42.88 E 2159.5 N 42.86 E 2198.0 N 42.84 E 2234.9 N 42.82 E 2270.1 N 42.80 E 2303.8 N 42.77 E 2336.3 N 42.73 E 2368.6 N 42.69 E 2400.4 N 42.66 E 2428.1 N 42.64 E 2450.2 N 42.66 E 2468.7 N 42.72 E 2485.8 N 42.79 E 2502.1 N 42.86 E 2516.1 N 42.92 E 2533.1 N 42.99 E DL /lOO 0.63 2.27 0.10 0.25 0.35 0.52 0.28 1.77 0.69 1.27 0.72 1.21 0.26 0.09 0.67 4.25 2.46 1.50 0.17 0.63 0.21 0.00 ASurvey Codes: 7/GYRO X/EXTRAPOLATED KRU 3G-11 Page DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 4 08/30/90 SUBSEA DEPTH 0 100 200 300 400 5OO 600 700 8O0 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 MEAS DEPTH 89 189 289 389 489 589 689 789 889 989 1089 1189 1289 1389 1490 1591 1693 1797 1904 2012 2126 2243 2366 2494 2629 INCLN TVD MD-TVD VERT DIRECTION ANGLE BKB DIFF CRRT BEARING 0.20 89 0 0 N 56.46 W 0.34 189 0 0 S 65.01 W 0.25 289 0 0 S 51.85 W 0.16 389 0 0 S 78.52 W 0.27 489 0 0 N 60.46 W 0.33 589 0 0 S 75.65 W 0.32 689 0 0 S 53.33 W 0.36 789 0 0 S 25.41 W 0.40 889 0 0 S 26.25 W 0.36 989 0 0 S 28.08 W 0.50 1089 0 0.30 1189 0 1.30 1289 0 3.52 1389 0 6.40 1489 1 10.62 1589 2 15.10 1689 4 17.49 1789 8 21.35 1889 15 24.89 1989 23 30.57 2089 37 33.15 2189 54 37.09 2289 77 41.47 2389 105 41.96 2489 140 0 S 37.84 W 0 S 73.59 W 0 N 3.14 W 0 N 23.51 E 0 N 37.87 E 1 N 52.04 E 3 N 53.01 E 4 N 50.34 E 6 N 50.55 E 9 N 48.59 E 14 N 45.61 E 17 N 45.43 E 23 N 47.20 E 29 N 44.54 E 34 N 42.55 E RELATIVE COORDINATES FROM WELL HEAD 0.13 N 0.07 W 0.19 N 0.51 W 0.11 S 0.96 W 0.27 S 1.27 W 0.21 S 1.62 W 0.10 S 2.13 W 0.37 S 2.64 W 0.81 S 3.01 W 1.41 S 3.28 W 2.01 S 3.59 W 2.63 S 3.99 W 3.05 S 4.57 W 2.41 S 5.48 W 1.50 N 4.46 W 8.89 N 0.05 W 19.36 N 10.42 E 33.09 N 28.67 E 51.27 N 51.72 E 73.71 N 78.89 E 101.13 N 111.16 E 137.80 N 150.33 E 180.96 N 193.77 E 229.94 N 245.02 E 285.97 N 304.00 E 351.41 N 365.56 E 2500 2763 41.65 2589 174 34 N 42.02 E 416.86 N 425.61 E KRU 3G-11 Page 5 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 08/30/90 SUBSEA MEAS INCLN DEPTH DEPTH ANGLE 2600 2899 44.23 2700 3037 43.27 2800 3174 42.93 2900 3310 42.57 3000 3446 42.54 3100 3581 42.00 3200 3715 41.20 3300 3847 39.89 3400 3976 38.87 3500 4104 38.66 3600 4232 37.90 3700 4356 34.92 3800 4476 31.07 3900 4591 29.78 4000 4705 27.91 4100 4818 27.00 4200 4929 25.17 4300 5040 25.33 4400 5151 25.29 4500 5261 25.05 4600 5371 24.82 4700 5481 23.31 4800 5589 22.35 4900 5697 21.05 5000 5804 20.25 TVD BKB DIFF CRRT BEARING MD-TVD VERT DIRECTION RELATIVE COORDINATES FROM WELL HEAD 2689 210 36 N 36.58 E 487.62 N 2789 248 38 N 38.05 E 564.25 N 2889 285 37 N 40.53 E 635.83 N 2989 321 36 N 41.38 E 705.73 N 3089 357 36 N 41.46 E 774.46 N 3189 392 35 N 41.23 E 843.03 N 3289 426 34 N 43.88 E 908.44 N 3389 458 32 N 44.42 E 970.50 N 3489 487 29 N 46.30 E 1027.58 N 3589 515 28 N 46.82 E 1082.70 N 3689 543 28 N 45.68 E 1137.44 N 3789 567 25 N 43.10 E 1190.58 N 3889 587 19 N 40.87 E 1238.86 N 3989 602 16 N 41.10 E 1282.91 N 4089 616 14 N 39.81 E 1324.83 N 4189 629 13 N 41.06 E 1364.46 N 4289 640 11 N 39.97 E 1401.37 N 4389 651 11 N 40.08 E 1437.41 N 4489 662 11 N 39.82 E 1473.81 N 4589 672 10 N 41.50 E 1509.62 N 4689 682 10 N 42.36 E 1544.02 N 4789 692 10 N 41.87 E 1577.38 N 4889 700 8 N 41.87 E 1608.62 N 4989 708 8 N 41.47 E 1638.38 N 5089 715 7 N 40.71 E 1666.79 N 484.58 E 542.02 E 601.61 E 662.28 E 723.09 E 783.34 E 843.46 E 902.24 E 961.11 E 1019.28 E 1076.50 E 1129.21 E 1172.16 E 1210.22 E 1245.97 E 1280.02 E 1311.35 E 1341.70 E 1372.17 E 1402.49 E 1433.83 E 1464.00 E 1491.96 E 1518.46 E 1543.23 E 5100 5910 19.07 5189 721 6 N 40.66 E 1693.78 N 1566.49 E KRU 3G-11 Page 6 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 08/30/90 SUBSEA MEAS INCLN DEPTH DEPTH ANGLE TVD BKB 5200 6016 18.87 5289 5300 6122 18.76 5389 5400 6227 17.09 5489 5500 6330 13.23 5589 5600 6433 11.04 5689 5700 6534 9.98 5789 5800 6636 9.64 5889 5900 6737 9.16 5989 6000 6838 9.05 6089 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 727 6 N 39.59 E 1720.10 N 1588.56 E 733 6 N 40.16 E 1746.30 N 1610.52 E 738 5 N 40.60 E 1771.57 N 1631.80 E 741 4 N 44.01 E 1791.43 N 1649.69 E 744 2 N 49.15 E 1806.07 N 1665.17 E 745 2 N 52.95 E 1817.45 N 1679.48 E 747 2 N 53.59 E 1827.81 N 1693.45 E 748 1 N 53.33 E 1837.63 N 1706.67 E 749 1 N 53.39 E 1847.16 N 1719.50 E KRU 3G-11 Page 7 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL 08/30/90 MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD DIST BEARING DL/ 100 1000 0.36 1000 911 -4 S 28.24 W 2 S 2000 24.15 1978 1889 145 N 48.96 E 98 N 3000 43.52 2762 2673 757 N 36.79 E 544 N 4000 38.70 3508 3419 1422 N 46.32 E 1038 N 5000 25.23 4353 4264 1949 N 40.20 E 1424 N 4 W 4 S 60.30 W 0.0 107 E 145 N 47.67 E 2.9 527 E 757 N 44.07 E 0.8 972 E 1422 N 43.12 E 0.7 1331 E 1949 N 43.05 E 0.1 6000 18.87 5274 5185 2336 N 39.47 E 1716 N 1585 E 2336 N 42.73 E 0.3 Land Directional Orilling~ Inc. <KB>O [ ....... z .............. ] .................................................. t 350 700 ~ .............. i050 ........ VERTICAL SECTION ViEW ARCO ALASKA, INC. i KRU 3G-~ I Section at: N 43.08 E TVD Scale.: ! inch = 700 feet Dep Scale.: 1 inch ~ 700 feet Drawn ..... : 08/31/90 Harker Iden[if[cation HD TVD SECTN INCLN BASE KUPARUK C 654! 5798 TOP KUPARUK A 6557 58ii 7 LINER 6876 6t26 ~u ~, 6900 6~5o t4oo 1750 2100 2450 2800 3500 3850 4200 4550 ......... 4900 5600 ................................ l ............. I 6300 350 0 350 700 t050 A) KB 0 0 0 0.00 .............. ~B] 9-5/8" CASING 3352 3020 996 42.55 ' ~ C] TOP KUPARUK C 853t 5786 2474 9.99 2478 9.97 2478 9.94 2498 g.3g 2529 9.05 2533 9.05 i400 t750 2i00 Section Departure 2450 2800 3i50 3500 A t Sreeb Lend Olre~'t_/~neI Drillln~ i'nc. Marker Identification MD NIS A) KB 0 0 N 0 E B) 9-518' CASING 3352 727 N 68! E C) TOP KUPARUK C 653t !8!7 N 1679 E D) BASE KUPARUK C 6541 18!8 N t680 E E) TOP KUPARUK A 6557 t820 N 1683 E F) BASE KUPARUK A 6676 1B32 N 1699 E $) 7' LINER 6876 t85! N ~724 E H) TD 6900 IB53 N J727 E PLAN VIEW ARCO ALASKA, INC. KRU 3G-l! CLOSURE .....: 2533 ft N 42.99 E DECLINATION.: 0.00 E SCALE · ! inch = 400 feet DRA~N '08/31/§0 2600 2400 2200 2000 1800 1600 !400 t200 !000 800 6OO 400 2OO 200 200 0 200 400 600 <- NEST ' EAST -> 800 !000 !200 t400 t600 ~800 2000 2200 PERMIT At ,~o - ~r COMPLETION DATE .... cf~eck off Or list data' .... ~. ~" ! ''~ ~/.~"~'h/' cored intervals ~,.'-<- ~'%- ~. ~1, , ?g" WELL NAiviE .,/ /,/~ t ,~/ CO. CONTACT AOGCC GEOLOGICAL ivlATERiALS iNVENTORY' LiST as it is rece'ived.*lis~ i i drillinQ history' I,~/ core analysis ~"' ir receiv,.ed date for 407. if not r~'quired list as NR . survcv l / ] Well tests,I !core d~scriptio~ ~ ....... d~/~i'tch i'nt'ervals vt'. '..j di~it,a,"i data ~--' , n,- 'r~n= i nnUN NO. ,kll'rcnt.'A .o ,,., ~_rx.~Lo SCALE (to,the nearest foot ........................ ......................... ,, .~ ~ 2,= ..... [~.~? / ! 33..~ 9....- · AOGCC GEOLOGICAL MATERIALS iNVENTORY LiST PERIvi,¥# ... ,~o - ~'O/ LOG TYPE ' RUN INTERVALS SCALE · . NO. [.t.o the nearest foot~ [incht100'] 1,,~", ~~/~~~, , .... I / I - ,. I ,... c~T / ~/~.- ~~ ! r, ,, ,,.,, { ............. , , , . -i,'''~' ....... I '38] , , ,, , , , , , , , ,, I, , , , , ,,, ,, ,36] {,,, , , 38l ~i ' ' , , ARCO Alaska, Inc. Date: December 7 1990 Transmittal #: 7956 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. 3G-11 Formation Evaluation Log Please acknowledge receipt and return 7-18-90 110-8900 Receipt Acknowledged' D ri II in g Franzen D&M State of Alaska Chevron BP Unocal Mobil ARCO Alaska, Inc. Date: December 7 1990 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. 3G- 1 1 Core Analysis Transmittal #: 7955 Please acknowledge receipt and return 9-22-90 6534- 6634.7 Receipt Acknowledged: D r i I ling Franzen D&M Date: State of Alaska Kup. Reservoir Eng. Chevron BP Unocal Mobil ARCO Alaska, Inc. Date: September 14, 1990 Transmittal #: 7888 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. · 3 G- 11 Pulse Echo Cement Evaluation(PET) 9 - 7 - 9 0 2 9 4 0 - 6 7 8 4 · 3 G- 1 0 Pulse Echo Cement Evaluation(PET) 8 - 1 2 - 9 0 3 6 0 0 - 81 3 8 · 3G-07 Pulse Echo Cement Evaluation(PET) 8-1 I -90 3600-8408 · 3 G- 11 Acoustic Cement Bond Log 9 - 7 - 9 0 2 9 8 0 - 6 7 9 6 ' 3G-10 Acoustic Cement Bond Log 8-1 2-90 3600-8140 · 3 G- 0 7 . Acoustic Cement Bond Log 8 - 1 I - 9 0 3 5 7 3 - 8 4 0 8 Receipt Acknowledged: DISTRIBUTION: RECEIVED Date: S E P 1 7 1990 Alaska 0il & Gas Cons. C0mm'tssiou Anchorage Drilling NSK · 'Sta{6'~(~j Alask'~(+se'Pia) ' i,~.£ STATE OF ALASKA 0 ,~, ALASKA 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 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, 120' FWL, Sec. 24, T12N, R8E, UM At top of productive interval 640' FNL, 1895' FWL, Sec. 24, T12N, RSE, UM At effective depth NA At total depth 606' FNL, 1927' FWL, Sec. 24, T12N, R8E, UM Re-enter suspended well _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) (approx) Plugs (measured) None Junk (measured) None RKB 9o' 7. Unit or Property name Kuparuk River Unit feet 8. Well Number 3G-11 9. Permit number 90-76 10. APl number 50-103-20133 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool (approx) 12. Present well condition summary Total Depth: measured 6900' feet (approx) true vertical 6132' feet Effective depth: measured NA feet (approx) true vertical NA feet Cemented 700 Sx AS III & 470 Sx Class G 415 Sx Class (3 & 200 Sx Class (3 tail Measured depth True vertical depth (approx) 115' 115' 3350' 3008' 6876' 6108' Casing Length Size Structural Conductor 8 0' 1 6" Surface 3313' 9 5/8" Intermediate Production 6841 ' 7" Liner Perforation depth: measured None true vertical None Detailed operation program X BOP sketch -- Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None 15. Status of well classification as:, Oil X Gas 13. Attachments Description summary of proposal_ Date Suspended _ IApproval No. / ' / 14. Estimated date for commencing operation November, 1990 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed //~~/. ~ ~ Tit, e Area Drilling Engineer I FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require 10-z~ Commissioner Date ~'- ';/..- ?~ SUBMIT IN TRIPLICATE Approved Copy Rf~turr~ed , qi {q.o_ Approved by the order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SI(~NED BY LONNIE C. SMITH ARCO Oil =,,d Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" 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 1County, parish or borough IState ARCO ALASKA INC. I NORTH SLOPE I AK Field ILease or Unit KUPARUK J ADL: 25547 ALK: 2661 Auth. or W.O. no. ITitle AK5067 J DRILLING W~ell no, Operator IARCO W I ARCO I I I55.2521 Spudded or W.O. begun IDate JHour Prior status if a W,O. SPUD 07/18/90 15:00 Date and depth as of 8:00 a.m, 07/19/90 (1) TD: 1573' ( 1573 SUPV:KSP 07/20/90 (2) TD: 3382' ( 18~09) SUPV:KSP 07/21/90 ( 3) TD: 3382' ( 0) SUPV:KSP 07/22/90 (4) TD: 3927'( 545) SUPV:KSP 07/23/90 (5) TD: 5447'(1520) SUPV:KSP 07/24/90 ( 6) TD: 6200' ( 753) Complete record for each day reported DOYON 14 DRLG @ 1573 MW: 9.2 VIS: 58 MIRU, ACCEPT RIG 08:00 18-JUL-90. RU BHA. SPUD 15:00 18-JUL-90, DRLG TO 1390'. RUN SS SURVEY TO CHECK MWD. DRLG TO 1485'. TRIP TO CHANGE OUT BHA. DRILL TO 1573. THE FIRST MWD AND SS SURVEY SHOWED LESS THAN 1 DEGREE, THE SECOND MWD TOOL SHOWED 4.6 DEGREE AT 1517' DAILY:S83,441 CUM:$83,441 ETD:S83,441 EFC:$1,600,000 CIRC & WO LOGGING UNIT MW: 9.8 VIS: 49 DRLG 1573'-2015'. TRIP TO CHANGE BHA, TIGHT HOLE 1865'-2015', REAM AND WASH TIGHT SPOT. DRLG 2015'-3382', CIRC HOLE A.ND SHORT TRIP TO HWT DP, NO DRAG. CIRC AND WORK PIPE WHILE WAITING ON LOGGING TRUCK. DAILY:S60,598 CUM:$144,039 ETD:S144,039 EFC:$1,600,000 RUNNING 9-5/8" CASING MW: 9.8 VIS: 45 DROP SS SURVEY, POOH, TIH WITH HOLE OPENER. CIRC WHILE WAITING FOR LOGGING UNIT. POOH TO LOG, RU SCHLUMBERGER, RUN DHE/DIL/GR ON THE FIRST PULL, RUN LDT/CHL/GR ON THE SECOND. RD LOGGERS, TIN, CIRC AND CLEJ%N HOLE. POOH, RU AND RUN 9-5/8" CSG, 45 JTS IN AT REPORT TIME. DAILY:S56,247 CUM:$200,286 ETD:S200,286 EFC:$1,600,000 DRLG MW: 9.5 VIS: 38 FINISH RUNNING 9-5/8", 36#, J55 BUTT CSG~ SHOE AT 3350..93 KB, FC AT 3268.82 KB CMT CSG WITH 700 SX AS III AND 470 SX CLASS-G, PLUG HELD OK, DID NOT GET CMT TO SURFACE. CMT TOP WITH 105 SX GLASS-G. NU BOP, PU BHA, TIH TO FC 3268'. DRILL PLUG-FC AND CMT TO 3335', TEST CSG TO 2000 PSI, HELD OK. DRLG SHOE AND 10' OF FORMATION, XO MUD, TEST FORMATION TO 12.5 EMW. DRLG TO 3927'. DAILY:S201,904 CUM:$402,190 ETD:S402,190 EFC:$1,600,000 DRLG MW: 9.5 VIS: 39 DRLG TO 3998'. POOH FOR BHA, TIH, DRILL 3988' TO 4032' TROUBLE WITH TELCO TOOL. POOH TO CHG OUT TELCO TOOL. TIH, DRLG 4032' TO 5447'. 9.6ADT. DAILY:S93,563 CUM:$495,753 ETD:S495,753 EFC:$1,600,000 TIH MW:10.2 VIS: 39 DRLG 5447'-6200', DRLG WITH TURBINE AND PDC BIT, LAST 300' DRLG SLOW. TEST FORMATION TO 11.3 EMW AT 5445' TVD, HELD OK. CIRC B.U., TRIP T~ LU T~u~xNE ANu ~C ~lT, C*~%N~ ~*~A, TIH. DAILY:S84,381 CUM:$580,134 ETD:S580,134 EFC:$1,600,000 The above is correct For form preparatioj~j~nd di~tribution,~) see Procedures M~[fl~l, Section 10, Drilling, Pages 86 a'~d 87. JDate / AR3B-459-1-D INumber all dally well history forms consecutively as they are prepared for each well. Page no. ARCO Oil an,. Gas 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 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 Field County or Parish Slate ARCO ALASKA INC. I NORTH SLOPE I Lease or Unit KUPARUK I 3G-11 AK JWell no. Date and deptll as of 8:00 a.m. 07/25/90 ( 7) TD: 6535'( 33~ SUPV:KSP 07/26/90 ( 8) TD: 6572' ( 3; SUPV:JMM 07/27/90 (9) TD: 6720'( 14~ SUPV:JMM 07/28/90 (10) TD: 6900'( 18' SUPV:JMM 07/29/90 (11) TD: 6900'( SUPV:JMM Complete record for each day while drilling or workover in progress DOYEN 14 POOH FOR NEW CORE BIT MW:10.8 VIS: 49 TIH TO 6110', REAM 6110'-6200'. DRLG 6200'-6534'. CIRC BTM'S UP. POOH LOOKING FOR WASH OUT IN 23 STD. CHANGE OUT BHA, PU CORE BBLS AND BIT, TIH, WASH 20' TO BTM. ATTEMPT TO CORE, CUT 1 FT IN 5 HOURS. POOH TO CHANGE CORE BIT. DAILY:S62,691 CUM:$642,825 ETD:S642,825 EFC:$1,600,000 MU #2 CORE BBL. ASSY. MW:10.7 VIS: 43 FINISH POOH, CHANGE CORE HEAD, RIH. CORE 6535'-6572' (37') ACT=13.5. LOST 200 PSI, POOH FOR WASHOUT AT 29 STD, FINISH POOH. SURVICE CORE BBL MU #2. DAILY:S51,853 CUM:$694,678 ETD:S694,678 EFC:$1,600,000 DRLG 8-1/2 @6720' MW:10.7 VIS: 43 RIH W/ CORE BBL RUN #3. CORE 6572'-6632'. POOH, CHANGE BHA, RIH. REAM 6497'- 6540'. LOST 600 PSI, POOH FOR WASHOUT IN 16TH STD, RIH. PRESS STILL LOW, POOH FOR 2ND WASHOUT IN 29TH STD, RIH. LOG WITH RLL WHILE REAMING 6507'-6632'. DRLG 6632'-6720' DAILY:S79,896 CUM:$774,574 ETD:S774,574 EFC:$1,600,000 LOGGING MW:10.7 VIS: 43 DRLG FROM 6720' TO 6900'. CIRC HOLE CLEAN, WIPER TRIP TO 9-5/8" SHOE, TRIP TO BOTTOM, DROP SS SURVEY, SPOT DIESEL PILL, POOH TO LOG. RU HLS, RUN LOG #1: SDL/DSN II/ML/HRI/GR/CAL/SP. RUN LOG #2: GR/FW SONIC/DILL/SG. RUN LOG #3: ARCO SHEAR WAVE TOOL. DAILY:S107,946 CUM:$882,520 ETD:S882,520 EFC:$1,600,000 RUNNING 7" CASING MW:].0.8 VIS: 40 FINISH LOGGING WITH ARCO SHEAR WAVE, RD HLS. RIH FOR WIPER TRIP, SPOT DIESEL PILL ON BOTTOM, POOH. RUN 7" CASING, HIT TIGHT SPOT AT 6820', MU CIRC HEAD AND PUMP CASING DOWN HOLE. DAILY:S157,951 CUM:$1,040,471 ETD:S1,040,471 EFC:$1,600,000 The above is co~rrect For [orm IJreparation/~ ~istdbutioe ,~ see Procedures Madl, l~ll Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B Number all daily well history forms conseculively as hey are prepared for each well JPage no ARCO ~.... and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also whan operations are suspended for an indefinite or appreciabre 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. IAccounting cost center code State District County or Parish ARCO ALASKA INC. NORTH SLOPE lease or un}t KUPARUK I ADL: 25547 ALK: 2661 Auth. Or W~O. no. ITitle AK5067 I DRILLING %ell no. Operator A.R.Co. W.l. ARCO 55. 2521 Spudded or W.O. begun Date SPUD 07/18/90 Date and depth as of 8:00 a.m. 07/30/90 (12) TD: 6900'( SUPV:JMM 0) Complete record for each day reported DOYON 14 I otal number of wells (active or inactive) on this pst center prior to plugging and bandonment of this well our I Prior status if a W.O. I 15:00 RR @ 1600 HRS, 7/29/90 MW:10.8 VIS: 0 FINISH RIH WITH 7" CASING, CIRC. CEMENT WITH 10 BBL PREFLUSH, 35 BBL SPACER, 156 BBL LEAD CEMENT AT 12.5 PPG, 42 BBL TAIL CEMENT AT 15.8 PPG. DISPLACE WITH 259 BBL 10.8 PPG BRINE, BUMP PLUG TO 3500 PSI, FLOATS OK. SET SLIPS, INSTALL TREE, TEST TO 3000 PSI. INJECT 100 BBL MUD AND 65 BBL DIESEL DOWN iM~TNULUS. RELEASE RIG AT 1600 HRS ON JULY, 29,1990. DAILY:S34,917 CUM:$1,075,388 ETD:S1,075,388 EFC:$1,600,000 Old TD Released rig Classifications (oil, gas, etc.) Producing method JNew TD Date PB Depth J Kind of rig Type completion (single, dual, etc.) Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production O 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 is correct Sig.atu~.~ ~__ -- -- Date / For form prepar~ and distributio~ see Procedures~anual, Section 10, Drilling, Pages 86 and 8L AR3B-459-3-C INumber all daily well history forms consecutively as they are prepared for each well. iPage no. DlvtNon of AtlantlcRIchfieldCompan¥ KUPARUK ENGINEERING TRANSMITTAL #1390 TO: John Bolye AOGCC DATE: August 20, 1990 FROM: K.W. Griffin/P. S. Baxter WELL NAME: 3G- 11 Kuparuk CONFIDENTIAL TRANSMITTED HEREWITH ARE THE FOLLOWING: One each blueline and sepia: 3G-11 3G-11 ~/3G-11 11 BHC Sonic - GR Compensated Neutron- Litho Density raw data 5" Dual Induction - SFL Compensated Neutron- Litho Density porosity 2" Dual Induction - SFL run 1 run ! run 1 run 1 7/20/90 7/20/90 7/20/90 7/20/90 7/20/90 PLEASE RETURN RECEIPT TO: ARCO Alaska, Inc. ATTN: P. S. Baxter, ATO-1269 P. O. Box 100360 Anchorage, Alaska RECEIPT ACKNOWLEDGED: ._~~~ DATE: 99510 RECEIVED S Fa P - 4 1990 Alaska Oil & Gas Cons. L;ommisS'tOtl. _ ;Anchorage. KUPARUK ENGINEERING TRANSMITTAL #1386 TO: John Bolye AOGCC DATE: August 20, 1990 FROM: K. W. Griffin/l:'. S. Baxter WELL NAME: 3G- 10 (Colville) CONFIDENTIAL TRANSMITTED HEREWITH ARE THE FOLLOWING: One each blueline and sepia: 3G-10 3G-10 3G-10 3G-10 Spectral Density DSN II Log Gamma Ray Tie-In For Sidewall Cores Microlog High Resolution InductiOn DFL run 1 run 1 run 1 run 1 3G-11 3G-11 3G-11 Micro Log High Resolution Induction DFL Log Spectral Density DSN II Log run 1 run 1 run 1 One each of tape and listing: 3G-10 HRI; ML:SDL/DSN Top 3750.00 3G-11 HRI, SDL/DSN, ML Top 3327.00 Bottom 4401.00 Bottom 3810.00 8/5/90 8/5/90 8/5/90 8/5/90 7/27/90 7/27/90 7/27/90 Date logged: 8/5/90 Date loged: 7/27/90 PLEASE RETURN RECEIPT TO: ARCO Alaska, Inc. ATTN: P. S. Baxter, ATO-1269 P. O. Box 100360 Anchorage, Alaska RECEIPT ACKNOWLEDGED :~ Jh0~X~000~ DATE: 99 10RE EIVED SEP - 4 1990 Alaska Oil & Gas Cons. GommiSs'ton ARCO Alaska, Inc. Post Office Bo× ,00360 Ar~chora~e~ A~aska 995i0.=0360 Telephone 907 27~ 1215 SAMPLE TRANSMITTAL TO' State of Alaska Oil & Gas Conservation Comm. 3001 Porcupine Dr. Anchorage, Ak. 99501 Attn: Robert Crandall OPERATOR: Arco DATE: 08-30-90 AIRBILL #: ALT 484472 AFT#: 0-08-30- CHARGE CODE# J-35879 NAME: KRU3G-11 SAMPLE TYPE: dry ditch NUMBER OF BOXES' 5 SAMPLES SENT: Dried samples in five boxes starting at 115' to 6900' SENT BY: D.L. Przywojski UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: RECEIVED ArcoAlaska, Inc. P. O. Box 100360 Anchorage, AK. 99510 Attn' ABV-100 BY' DATE: RECEIVED SEP - 4 1990 Alaska 0il & Gas Cons, ~0.mmissi0n cfiorage ARCO Alaska, thC. is a Subsidiary of AtlanticRichfieidCompany /,,l~:ll~ ~;~)~):~ (; ARCO Alaska, Inc. Date: August 24, 1990 Transmittal #: 7860 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 cased hole items. Please acknowledge receipt and return one signed copy of this transmittal. ,/3G-11 Pulse Echo Cement Evaluation(PET) 8-1 1 -90 31 00-6798 ,~/3G-05 Pulse Echo Cement Evaluation(PET) 7- 5 - 9 0 6 289-7736 3 G - 11 Acoustic Cement Bond Log 8- 1 2 - 9 0 3 2 9 5 - 6 8 0 0 Receipt Acknowledged: DISTRIBUTION: RECEIVED Date: Alaska Oil & Gas Cons. Commission Anchorage Drilling NSK State of Alaska(+Sepia) ARCO Alaska, Inc. Date: August 17, 1990 Transmittal #: 7856 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-10 High Resolution Induction DFL 5" 8-5-90 3790-8241 3 G- 10 High Resolution Induction DFL 2" 8 - 5 - 9 0 3 79 0- 8 241 3 G- 10 Spectral Density DSN II Raw Data 8 - 5 - 9 0 3 790 - 8 21 4 3G-10 Spectral Density DSN II Porosity 8-5-90 200-8213 3 G- 10 High Resolution Induction Raw X & R 8-5-90 3 790- 8241 3G-10 Microlog 8-5-90 3790-8214 3G-11 ' Full Wave Sonic Delta-T Log 7-28-90 6300-6870 3 G - 11 Dual Gamma Ray Compensated 7 - 2 7 - 9 0 6503 - 6 9 0 0 Neutron Porosity Simultaneous Formation Density 3 G - 11 Dual Gamma Ray Electrmagnetic 7 - 2 7 - 9 0 65 03 - 6 9 0 0 Receipt DISTRIBUTION: Acknowledged: Wave Resistivity ~ EE E IV E P ~~~---~D~T ....... ---- .... ~U~ 2 I 19~0 Alaska 0il & Gas Co,Is. ~0.mmissi0.n Anchorage D&M Drilling Franzen Vendor Package(Johnston) NSK ~~t AiaSk~(+SePia) ARCO Alaska, Inc. Date: August 17, 1990 Transmittal #: 7855 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-1 1 7- 2 8- 9 0 HRI,ML /"'~5~ 0 3G-10 ~5 q J Receipt LIS Tape and Listing SDL/DSN LIS Tape and Listing 8 - 5 - 9 0 HRI,ML SDL/DSN LIS Tape and Listing ..~7 8,-/1 6- 9 0 AKRB900728 Acknowle Date: DISTRIBUTION: Lynn Goettinger State of Alaska ARCO Alaska, Inc. Date: August 10, 1990 Transmittal #: 7844 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. 3G-11 Please acknowledge receipt and return LIS Tape and Listing 7 - 2 7 - 9 0 LIS Tape and Listing 7 - 1 8 - 9 0 Acknowledged: ~/~~~-''-~ 3G-11 Receipt DISTRIBUTION: HRI,ML, ~-~-~ ~' SDL/DSN 770TAK ~ z../ Date' Lynn Goettinger State of Alaska ARCO Alaska, Inc. Date' August 10, 1990 Transmittal #: 7842 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-11 ,4~gh Resolution Induction DFL 5" 7-27-90 3327-6884 3G-11 .,High Resolution Induction DFL 2" 7-27-90 3327-6884 3G-11 .~,,Spectral Density DSN II Raw Data 7-27-90 3327-6860 3G-11 i/Spectral Density DSN II Porosity 7-27-90 3327-6860 3G-11 ~High Resolution Induction Raw X & R 7-27-90 6300-6884 3G- 11 ,-'~Dual Induction Short Guard 7 - 2 8 - 9 0 6298 - 6884 3G-! 1 ~-'l~icrolog 7-27-90 3327-6860 3G-11 ,.,,'Resistivity Gamma Directional 7-1 8-90 0-6534 1:240 _,~:~esistivity Gamma Di,~ctional/ ,, 7- 1 8- 9 0 Acknowledged. ~--~~--~-----, 3G-11 Receipt Date' DISTRIBUTION: 0-6534 D&M Drilling Franzen Vendor Package(Johnston) NSK State of Alaska(+Sepia) TO: THRU: FROM: MEMORA, UUM Slate of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Lormie C.' smi~~'' CommiSsioner ~ '~3 DATE: FILE NO: July 30, 1990 JT.BF. 730.2 TELEPHONE NO: SUBJECT: RIG/BOPE Inspection AAI KRU 3G-11 Permit No. 90-26 Kuparuk Oil Pool Bobby D. Petroleum Inspe~[- Tuesday,~: i went to Doyon rig 14 and made a walk thru in~e~dt~i~~ing Ken Price, AAI rep. I checked the AIDC report and found that the BOPE had been tested on 7/21/90 and was logged properly. 02-00lA (Rev. 6/89) 20/ll/MEMO1.PM3 July 10, 1990 Telecopy: (907)276-7542 Mr. Patrick J Archey Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re:KuPa~ak:~Riv. er Unit 3G-11 Revised ~gO~ Alaska, Inc. Permit No. 90- 76 Sur. Loc. 2538'F}~, 120'FWL, Sec. 24, T12N, RSE, UM. Btnuhole Loc. 606'FNL, 1927'FWL, Sec. 24, T12N, R8E, UM. Dear Mr. Archey~ Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the cover letter, dated June 28, 1990, accompanying the original approved permit are in effect for this revision. Very__t~ly you=s, Chai~an of Alaska Oil and Gas Conservation Co~ission BY ORDER OF T~HE COmmiSSION 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 COMfy. ,ON PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill ;~ Redrill ~ I lb. Type of Well Exploratory~ Stratigraphic Test _ Development Oil 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 ARCO ^h3sk~. Inq, RKB 89'. Pad 53' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100560, Anchoracje, 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, 120 ' FWL, Sec. 24, T12N, R8E, UM KuDaruk River Unit At top of productive interval (TARGET) 8. Well number Number 640' FNL, 1895 'FWL, Sec. 24 , T12N, R8E, UM 3G-11 #U630610 At total depth 9. Approximate spud date Amount 606 ' FNL, 1927 ' FWL, Sec 24, T12N, R8E, UM 07-1 0-90 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 3roperty line ' 3G-12 6901 MD 3353 '@ TD feet 25' at surface feet 2560 6088 VD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 1~00 feet Maximum hole angle & 2° Maximum surface 1600 psi9 At total depth (TVD) 5800' 3500 psi~l 18. Casing program Setting Depth size Specification Top Bottom 'Quantity of cement Hole Casin(j Wekjht Grade Coupling Lencjth IVD 'I'VD IVD TVD (include stage dataI 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' ±200 tM.Ft. 12.25 9.625 36.0# J-55 BTC 3308' 35' 35' 3343' 3030' 1380 Cu. Ft. AS III & HF-ERW 540 Cu. Ft. Class G 8.5 7" 26.0# J-55 BTC 6866' 35' 35' 6901' 6088' 200Cu. 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 feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor ~'~ ~ Surface ., "" ~' ~' '~, ~ Intermediate,~i"<~ ~.'%"~ %` ~ Production Liner , ,~ ,~ ,~j Perforation depth: measured true vertical 20. Attachments Filing fee X Properly plat ~ BOP Sketch ~ Diverter Sketch ~ Drillih{~.~program .A... Drilling fluid program X 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 Signed .~t~ J ~"~~ Title Area Drillin~ l::n~ineer Date Commission Use Only Perm,/, .,mbe., ~;.q_ 50-/"("~ , --' Z d~ / .$73 other requirements Conditions of approval Samples required ~ e s __ N o Mud log requited ,~ Ye s __ N o Hydrogen sulfide measures__ Yes '~ N o Directional survey required ,z~'~;es __ N o Other:Required working/~.~~pre~ure for BO~ · ' · 5 M' ~ I OM' ~ 1 by5 Morder of 7j~Oj~ Approved by rL ~ ,g , Commissioner the commission Date Form 10-401 Rev. 7-24-89 in triplicate DRILLING FLUID PROGRAM (3G-11) Spud to 9-5/8" Drill out to surface casin(] weioht 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 to TD 11.0 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 10-12 Drilling 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 Notes: - 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-11 is 3G-12. As designed, the minimum distance between the two wells would be 25' at surface. 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. HOR~"~ONTAL PROJECT ION ,,~ALE 1 !N. = 1000 FEET ARCO ALASKA. lne. Pad ~O, Well No~ Il Revl~ecl Pr'opo~el Kuparuk Field. North Slope. Ala,k, '~~7 3000 2000 _ z cz) , 1000 _ c) 0 SURFACE LOCAT I ON, 2538' FNL. 120' FWL SEC. 24. T12~iN. RSE 1000 _ WEST-EAST 1000 0 1000 2000 3000 I I I I / SUR~ TD LOCAT [ ON ' 606' FNL. 1927' FWL SEC. 24. T I2N. R8E TARGET CENTER TVD=$822 TI"ID=6~I DEP=2599 NORTH 1898 EAST 1775 TARGET LOCATION, 640' FNL, 1895' FWL SEC. 24. TI2N. RSE N 43 DEG 5 2599' [TO TARGET) GENERAL DRILLING/CORING PROCEDURE KUPARUK RIVER FIELD 3G PAD . 2, 1 = . . m = , 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 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 open hole logs through surface hole per well 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 core point according to well plan. Core Kuparuk sands as specified in well plan. With coring complete, continue drilling the 8.5" hole to logging point (TD). 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. 24. Reperforate and add additional perfs. ARCO ALASKA, !no. Pad 3G. Yel I No, !1 Nevlaed Proposal Kuparuk Field. North Slope. Alaska 0 . RKB ELEVAT[ON~ 90' CZ m m ~o m 1000_ 2000_ 3000_ 4000_ 5000_ 6000_ ZOO0_ I'iAX I HUM AN OLE 4'2 DEO 1 HIN KOP TVD=1200 TMD=1200 DEP=O BUILD 3 DEG PER I00 FT ~ g B/ PERMAFROST TVD=1605 TMD=1608 DEP=43 ~':, T/ UGNU SNDS TVD-I795 THD=1805 DEP=95 ~~~ T/ W SAK SNDS TVD=23ZO TMD=2459 DEP=400 '~,,,,,,~' LOC TVD'2478 THD'2600 DEP=49! ~ B/ "SAK SNDS TVD=2830 TMD=3074 DEP=808 ~'~g 5/8' CSO PT TVD=3030 TMD=3343 DEP=gB8 '~ K-lO TYD=3330 THD=3747 DEP=1258 ~ BEGIN=ANGLE DR~P 3~~ TVD 3760 TMD 4325 DEP 1645 ~R I~DROP ~ D~ 2) ~Ft- -;8 '; ~ END ANOLE DROP TVD-5653 THD-645g DEP-256g . , . T/ ZONE C TVD-5753 THD-6561DEP-2586 J I I 1000 2000 3000 VERTICAL SECTION TARGET ANGLE 10 DEO 2OO 150 100 50 0 5O 100 100 50 0 50 1 O0 1 50 20O I I I I I ! ,I, / / / · ' 1200 / / / / / '"2000 / / / ~ ~oo, e / ,,, / ~1800 / ? ~ 1 400 ./ /, ~800 /, }soo / 200 / / / I / / .,.' 14o~ s o ~ / t' ,,oo ~.oo ° 400 '-,,.,.,.'"~oo~'4oo 1 600 ~uu 1 200 __, ......... .... __ ,/ 600 000 O0 I 200 / / / / / 100 50 0 50 100 150 250 I / / / '" 1 800 2OO )0 i 250 300 I 300 200 _ 150 .100 _ 50 _0 _ 50 100 7 6 5 4 13 5/8" 5000 I',.,I BOP 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 SIMULTANEOUSLY AND 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. TESTAS IN STEP 4. DO NOT PRESSURE TESTANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMSAND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF 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 ..JPARUK RIVER UNI', 20" DIVERTER SCHEMATIC I I 3 r--'O ( DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & 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 THE 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 CHECK LEST FOR NEW WELL PERMITS ITEM APPROVE DATE (2 thru 8)' (8) ' ~9--thru 13)' '- 10. (10 and 13) 12. 13. (4) ca~g ~z~.~, >~.~ (14 thru 22) thru 28) 14. 15. 16. 17. 18. 19. 20. 21. 22. Company Is the permit fee attached .......................................... 2. Is well td be located in a defined pool ............................. 3. Es 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 ...................... 23. 24. 25. 26. 27. 28. Lease & Well No. YES NO - ,£ Does operator have a bond in force .................................. Es a conservation order needed ...................................... Es administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor 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.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ...................................... Is the drilling fluid program schematic and list of equipment adequate,F-~' Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. ; _ th~u '31) (6) Add: Geolo$~. DWJ ~ Enging. ering rev: 01/30/89 6.011 For 29. 30. 31. 32. IN IT'IAL GEO. UNIT ON / OFF POOL CLASS STATUS AREA NO. SHORE / o 0 2- '/ /?o ///6'o o ,O ,,, 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 ,, Additional requirements ............................................. Additional Remarks: I / June 28, 1990 Telecopy.. (907)276-7542 P. J. Archey Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kupa~ak River Unit 3G- 11 ARCO Alaska, Inc. Permit' No. 90-76 Sur. Loc. 2538'FNL, 120'FWL, Sec. 24, T12N, RSE, UM. Btmhole Loc. 1369'FNL, 1407'F%~L, Sec. 24, T12N, RSE, UM. Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced well. %~he permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until al! other required permitting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. Ve~y... tru/ly y-~rs, Chai~an ~ f Alaska 0~1 and Gas Conse~ation Co~ission BY ORDER OF THE COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o enc!. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALA~r~ OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ! la. Type of Work Drill X 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 ARCO Alaska, Inc. RKB 89', Pad 53' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchora~]e, 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, 120 ' FWL, Sec. 24, T12N, R8E, UM KuDaruk River Unit At top of productive interval (TARGET) 8. Well number Number 1385 ' F~L, 1390' FWL, Sec. 24, T12N, RSE, UM 3(3-11 #U630610 At total depths. ~.~, ,~, 7.-~,d?/~;m~/~.~, ,,~,~. 9. Approximate spud date Amount 1369 ' F~L, 1407 ' FWL, Sec 24, T12N, R8E, UM 07-1 0-90 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed deplh (MD and TVD) 3roperty line 3G-12 6498 MD 1369 ' @ TD feet 25' at surface feet 2560 6090 VD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 1 600 feet Maximum hole angle 32° Maximum surface 1 600 psig At total depth (TVD) 5800' 3500 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length IVD TVD IVD TVD (include stage data1 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' _+200 Cu. Ft. 12.25 9.625 36.0# J-55 BTC 3125' 35' 35' 3160' 3030 1335 Cu. Ft. AS III & ~-~.Rw 500 Cu. Ft. Class G 8.5 7" 26.0# J-55 BTC 6463' 35' 35' 6498' 6090' 200Cu. Ft. ClassG H~-~.RW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured true vertical feet Casing Length Size Cemented Measured depth True Vertical deplh Structural Conductor iSn~refraCjediate J~ E ~ ElM E Production Liner ~ ..... "~': ~-"' Perforation depth: measured ~,n~,hnra~ 20. Attachments Filing fee X~ Property plat ~ BOP Sketch ~ Diverter Sketch ~ Drilling program X Drilling fluid progran~ X_~._ Time vs depth plot ~ Refraction analysis _ Seabed report _20 AAC 25.050 requirements ~ 21.1 hereby~at.the~~_ 1 foregoingiSrtrUe:!i:!!i!~and corroct to the best of my knowledge Sign/pd ~ Title Area Drillincj En~]ineer Date G'"o~7 ~'O / / ~'~(~-J'~_ Commission Use Only I I {~ See cover letter for Permit Num"~l~er ~ Approval date 0 6 / 2 8 / 9 ~:~-- ~" 50- /~ ~'- ~_.O/x'~,~ other re(:{uirements Conditi(~ns of approval Samples required ~e s~ N o Mud log required ~Ye s ~ N o Hydrogen sulfide measures~ Yes .,~ N o Directional survey required ,~ Yes ~ N o Required working pressure_.,[~ BOPE ~2M; X 3M; ~ 5M; ~ 10M' ~ 15M by order of Approved by ~ - Commissioner the commission Date Form 10-401 Rev. 7-24-89 ~it in triplicate 100 50 0 50 100 150 200 250 300 " 200 150 lO0 5O 5O 100 / 2300 / / / / /'"2500 / 700 I / "' 1500 "2100 / ~"1 /, .~ ;300 / , //1 900 / ~'"''~ 100 ~~ 'soo h ~,o%soo ' ~~oo ' ~~oo X~oo X,~oo ~ ' ...... . , ~x~o .... ~o ........... ~ ~/ 2OO _ 150 _ 100 _ 5O _0 _ 5O _ 100 100 50 0 50 100 150 200 250 :300 ARCO ALASKA, !nec Ped 30, Well No' 1! Kuperuk Field, North Propoeed Slope, Aleeke 0 . RKB ELEVAT[ON~ 90' 1000_ 2000 _ ~000 _ 4000 5000 _ 6000 _ ?000 _ KOP TVD=1600 TMD=1600 DEP=O B/ PERHAFROST TVD=1605 THD=1605 DEP=O T/ UONU SNDS TVD=l?95 T~D=1?95 DEP=IO 9 BUELD 3 DEO 15 PER 100 FT 2t T/ W SAK SNDS TVD=2370 THD=2393 DEP=162 ~r EOC'~ TVD=2613 TMD=2668 DEP=291 ~, B/ W SAK SNOS TVD=2830 TMD=2924 DEP=427 -- ~9 5/8 CSO=PT TVD=~030 TMD=~160 DEP=552 ~K-IO TVD 3330 TMD 3514 DEP 739 ~ AVERAGE ANGLE ~ 32 DEG 2 HIN ~'~. BEGIN ANGLE DROP 30 '~ TVD=3960 THD=4257 DEP=l134 K-5 TVD=4770 TMD=5155 DEP=I516 D~p? hSDEO ~s ~ PER I00 FT I~ t _6t t END AHGLE DROP TVD-5653 TMD=6059 DEP=ITO! : , .TI ZONE C TVD-5753 THD=6159 DEP=1709 ~ ~ 'T/ ZOHE A TVD-ST?4 THD-6180 DEP=1711 [ TARGET CHTR TVD-5822 T~D-6228 DEP-I?15 B! KUP SHDS TVD-589! THD-6298 DEP=1721 TD (LOG PT) TVD=6090 THD=6498 DEP=1?39 I i ! 000 2000 TARGET -ANGLE 5 DEG VERTICAL SECTION HOIq I ZONT AL~-P~OJECT I ON SCALE 1 Ih = 1000 FEET ARCO ALASKA, !ne. Pad 3G, Well No~ 11 Propoeed Kuparuk Flelcl. North SI ope. Alaeka z 3000 2000 1000 1000 WEST-EAST 1000 0 1000 2000 I I I SURFACE' SURFACE LOCAT [ ON ~ 25.38' FNL, 120' FWL ~C. 24, T I2N. R~ 3000 I TD LOCAT [ ON ~ 1369' FNL. 144:)7' FWL SEC. 24, TI2N, R~ TAROET ~NTER TVD"$822 Tt'ID-6228 DEP-I715 NORTH 1153 EAST 1270 T AROET LOCAT [ ON ~ 1385' FNL. 13gO' FWL SEC- 24. T I2N, RSE N 47 DE[; 46 MI N E 1715' (TO TARGET) DRILLING FLUID PROGRAM (3G-11) 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- 1 0 pH 9- 10 8.5-9 % Solids 10 +/- 4- 7 Weight up to TD 11.0 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 10-12 Drilling 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 Notes: - 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-11 is 3G-12. As designed, the minimum distance between the two wells would be 25' at surface. 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. 13 5/8" 5000 I-,.51 BOP STACK 7 6 5 4 I I ACCUMULATOR CAPACITY TEST 1. CHECKAND FILLACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 15(X) PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH 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 STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THATALL HOLD-DOWN SCREWSARE 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 PREVENTOR AND MANUAL KILL AND 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 NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE Bo'FrOM PIPE RAMS. TEST BO'F1-OM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULLOUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMS AND 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 ,.JPARUK RIVER UNI' 20" DIVERTER SCHEMATIC I I 3 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENAN(~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 THE 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 GENERAL DRILLING/CORING PROCEDURE KUPARUK RIVER FIELD 3G PAD · , · . · , = , . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19 20 21 22 23 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 open hole logs through surface hole per well 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 core point according to well plan. Core Kuparuk sands as specified in well plan. With coring complete, continue drilling the 8.5" hole to logging point (TD). 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. 24 Reperforate and add additional perfs. (2) Loc __~ i- FOR NEW WELL PERMITS Company _ '/~Fc-,-~ Lease & Well No. APPROVE DATE YES NO .... RE~.S 1. Is the permit fee attached .......................................... (2 ~hru 8) (8) (3) Admin '~'~'f<'(9 thru' ~ (10 and 13) (14 thru 22) (23 thru 28) 2. Is well td be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... ,, 10. 11. 12. 13. 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 ......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor 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.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate~ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~QOO psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. .. I (6) Add: Geology!: DWJ ~ rev: 01/30/89 6.011 · For 29. 30. 31. 32. 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 Additional requirements ............................................. ...... iNiTiaL GEO. U~IT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particulady 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. DIRECT DIGITAL LOGGING COMPUTER PROCESSED ANALYSIS ,! ~ IiIIIIIIII ~'~'~'~' .-' IIIIIIiIiI SSS$SSSSSS .'~' Ii SS SS ' II SS II SS II SSSSSSSSS II SSSSSSSSS II SS II ii SS SS LLLLLLLLLL IiIlIIIIII SSSSSSSSSS i...LLLLLLLLL IIIIIilIlI S~'~ ooSSSSS 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 MM MM MHM HHM HMHM HMHM MM MM MN MM MM MHHH MM MM MM MM MM MM MM MM MM MM MM NM PPPPPPPPPPi PPPPPPPPPPI PP I PP I PP I PPPPPPPPPPI PPPPPPPPPPI PP PP PP PP 9999999999 999999999999 99 99 99 99 99 99 999999999999 999999999999 99 99 99 99 999999999999 9999999999 333333333333 444 4444 44 44 44 44 44 44 44444444444 444444444444 44 44 44 44 44 UU UU UU UU Ui.J UU UU Ui.J UU UU UU UU UU UU UU UU UU UU UU UU UUUUUUUUUUUU UUUUUUUUUU 9999999999 999999999999 99 99 99 99 99 99 999999999999 999999999999 99 99 99 99 999999999999 9999999999 GG~GGGGGGG AA AAAA AA AA AA AA AA AA. AA AA AAAAAAAAAAAA AAAAAAAAAAAA AA AA AA AA AA AA AA AA 9999999999 999999999999 99 99 99 99 99 99 999999999999 999999999999 99 99 99 99 999999999999 9999999999 MM i HMH 'MI MHMM MMI MM MM MM MM HMMM MM MM MM MM MH MM O00OO000 000000000 O0 O0 O0 O0 O0 O0 O0 O0 000000000 00000000 REEL HEADER **** Pr. mvious r. mel: Date: 90708703 Comments: HEADER Origin: RECORDS Reel name: Page Continuation #: Oi Sar. vice name: &GSFO! Previous tape: Date: 90?08/0:3 Commmn'ts: Origin: Tape name: Continuation #: O1 Servic~ name: Version Date: Maximum length: 1024 File type: LO Previous f'ile: M N E M CN WN FN COLIN STAT CTRY AP iN LATi LONG SECT T 0 bJ !',t RANG E i< B EDF EGL LMF ' DHF RUN TIME DATE LCC SON LUN FL LUL ENG i WI TN DD DL CBDi COLi TLI 8LI TCS TLA8 8HT MR T MT MSS DFD M :! I S DFPH DFL ~'i RMF MFST MFSS RMC INFORMAT I ON RECORDS CONTENTS ARCO ALASKA INC. 36-11 KUPARUK RIVER NORTH SLOPE ................ ALASKA ................ USA ................ 201:33, O00 ........................... 0 ~mg. 0 Min. O, O Smc, N O umg. 0 W 12N ....... 08E ....... 89, OOO .... 88. 000... , 53, OOO .... lis .... KB ........ 2100.000.. 277 7/90.. 30 ........ 367697 5.t 939 NORTH SLOPE NORTH SLOPE ADDISON LOWEN 6980 , 880 ..... G89~, 00 S~54. O O0 S~45,000 ~27. O 00 6884. 1Goo.goo 21 00. 000 117.000. ~17.000. LSN~ ClRCULATEB 10.800... 48. OOO, .. 8,000 .... 5,700 .... 1 .730 .... I ,300 ..... 77,000 .... ME~S. . 2,270 ........ API NUM: 5.0-103-2 0133 .... DATE LOGGED: 07-27-90 .... I i I · w I I Min. O, 0 Sec IIIIIIIllIIIIll ~ a a m m ililll iIllIi iiiili m m m I · i i i · m m · I I I I m m w I m m m i · m I · I m Ill ,mil l&l mImm ill illl IIi I Itl · ii i i Ii I ii II I ii ii i · ii I i ii ii i ilil ii m mill i i llli i i llii IliIi ilIliii ItiliI iiilli iIiiii Iillii i s m m · i .III IIIImI tilt IImI IIleI lIll IIIII mmlmmm~lm~ Ii iii i II Ill · II III · ii ill · ~l I , i ii i i ii i I ii i i I ii I i i i ii ii i · Ill I I I I t II m I i i ! I i ii i i m m · I i I i J I I I t I I i · I illlelill i ieiiIiiiI i IlllltI~I IiIlIiI I IiIlllI IlllIll I IIIlilI I iIllIiI I imli iii iii iii iii ill · i · · · i · i m I i m · · I m i i I i m I m i · i I I I m m amm I f m m I m m m m m i · m m m m m I I I · 1 I I I I I I I I · , I I I i I i I ~ I ~r I ~ i i · · I , i m m ~ m m i UNIT FT FT FT FT FT FT FT FT FT HR HR DEGF DEGF L8/6 CP OHMM OHMM DEGF OHMM TYPE 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 .0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 CATG 0 0 0 0 .0 0 0 0 0 0 0 0 3 3 0 0 0 0 0 0 0 .0 0 0 3' 3 1 SIZE 40 40 40 20 20 . # 4 34 34 2 4 4 4 2 2 2 2 4 2 tO 10 20 20 20 20 4 4 4 4 4 4 4 4 4 4 20 20 4 4 4 4 4 4 4 12 4 CODE 65 65 65 65 65 68 65 65 65 65 65 68 68 68 65 ~5 65 79 68 65 65 65 65 65 65 G8 68 68 68 68 68 68 68 65 65 68 68 68 68 68 68 68 65 68 Pagm ERROR MNEM MCST HCSS CS I NFORMAT I ON RECORDS CONTENTS 77. cl~JO .................................................. MEAS ............................................. 9,625 ................................................... 8.500 ................................................... UNIT DECF TYPE CflTG SIZE 4 12 4 4 CODE 68 65 68 68 Page ERROR COMMEN T RECORDS 11 Location Comment 1: SURFACE: 2538' FNL & 11 Location Comment 2: ll Location Comment 3: ll Loca%ion Comment 4: Il File Comment l: CHLORIDES = 2?00 PPM. ll File 11 File Comment J: 120 ' FWL HRI~ML,SDL?DSN RUN IN COMBINATION. Comment 2: THIS L.I.S. TAPE CONTAINS COLVILLE DISTRIBUTION DATA ONLY. Well File Comment 4: LIS tape written by: ANCHORAGE COMPUTING CENTER All curve and tool mnemonics used are those which Halliburton curve and tool mnemonics. most closely match HALLIBURTON TO SCHLUMBERGER TOP BOTTOM MNEM SERVICE UNIT MNEM SERVICE DEPTH DEPTH I UNIT DEPTH FT DEPT FT 3325,00 GR SDL GAPI GR SDL GAPI 3327,0'0 FDSN DSN2 CPS FDSN DSN2 CPS. 3327.00 NDSN DSN2 CPS NDSN DSN2 CPS 3327,00 NPHI OSN2 DECP HPHI DSN2 DECP 3327.00 NEAT DSN2 C/C NEAT DSN2 C:/C 3327.00 DPE SDL DPE SDL 3327.00 DPHI SDL DECP DPHI SDL DECP 3327.00 DRHO SDL G./C3 DRHO SDL G/C3 3327.00 FSDL SDL CPS FSDL SDL CPS 3327.00 6910,00 3810,00 3810.00 3810.00 JCl0 O0 3810 O0 3810 O0 3810 O0 3810 O0 3810 O0 Pagm NSDL PE PELC QL QS QPE RHOB MNOR CAI_I HDR HDX HNR HMX HDRS HHRS HDCN HMCN DFL SP TENS SDL SDL SDL SDL SDL SDL SDL ML ML SDL HRI HRI. HR! HRI HRI HRI HRI HRI HRI HRI SDL CPS G?C3 OHNM OHMM IN OHMM MMHO MMHO OHMM M~ LBS NSDL PE PELC QL QPE RHOB MIN9 MNOR CALI HDR HDX HMR HMX HDRS HMRS HDCN HMCH DFL SP TENS SDL SDL SDL SDL SDL SDL SDL ML ML SDL HRI HRI HRI HRI HR I HR! HRI HR! HRI SDL CPS 6?03 OHMM OHMM IN OHMM OHMM MMHO MMHO OHMM MY LBS 3327, O0 3327. O0 3327. O0 3327, O0 3327.00 3327, O0 3327, :00 3327,0:0 3327, O0 3327, '00 3327, :80 3327, O0 3327,08 3327. '08 3327', O0 3327.08 3327,08 3:327, O0 3327, O0 3327. '0 .O 3327 ,OO 3e i 381 381 381 381 381 381 3et 381 381 3el 381 381 3e! 0.00 O,O0 0,00. 0,00 '0 O0 0 O0 0 O0 0 O0 0 O0 · 0O0 '0 O0 0 O0 0 O0 0 O0 ~0 O0 0 O0 0 O0 0 O0 :0 O0 0,00 O, O.O C 0 M M E N T RECORDS Pagm DLOD SDL LBS DLOD SDL LBS ENTRY DATA FORMAT TYPE 16 0 SIZE 'SPEC I f I CAT I OHS CODE Page ENTRY BLOCK LEGEND TYPE DESCRIPTION 16 Datum s~ec'.i.?ication 0 Terminator ('no more block zub-t~,pm entries ) DA TA F 0 RiM T DATUM SPECIFICATION BLOCKS SPECIFICA T IONS Page HNEM SERVICE SERVICE API API API API FILE iD ORDER # UNiT LOG TYPE CLASS MOD PRC # SIZE LVL SMPL RC II PROCESS INDiCaTORS DEPT 367697 FT 0 0 0 GR SDL 367697 GAPI 94 0 0 i O FDSN DSN2 367697 CPS 94 0 0 i O NDSN DSN2 367697 CPS 94 0 0 1 0 NPHi DSN2 367697 DECP 94 0 0 i 0 NR~T DSH2 36?697 C?C 94 0 0 ! 0 DPE SDL 36?69?' 94 0 0 i DPHI SDL 367697 DECP 94 0 0 1 DRHO SDL 367697 G/C3 94 ~0 0 1 0 FSDL SDL 367.697 CPS 94 0 0 1 0 NSDL SDL 367697 CPS 94 0 0 1 0 RE SDL 367697 94 .0 0 1 0 PELC SDL 367697 94 0 0 1 0 QL SDL 367697 94 0 .0 1 O OS SDL 367697 94 0 0 i O QPE SDL 367697 94 0 0 1 0 RHOB SDL 367697 G/C3 94 ,0 0 i 0 MiNV ML 367697 OHMM 94 0 0 1 0 MHOR HL ~67697 OHMH 94 0 0 I 0 CALI SDL 367697 IN 94 0 0 I 0 HDR HRI 367697 94 0 0 i O HDX HRI 36769? 94 O 0 1 O HMR HRI 367697 94 0 0 i 0 HHX HRI 367697 94 O 0 1 .0 HDRS HRi 3GTG97 OHHM 94 '0 0 1 O HHRS HRI 367697 OHMM 94 0 0 i 0 HDCN HRI 367697 MMHO 94 0 0 1 0 HMCH HRI 36?697 MHHO 94 0 O 'l 0 DFL HRI 367697 OHMM 94 0 O '1 0 SP HRI 367697 MV 94 0 0 1 0 TENS SDL 367697 LBS 94 0 0 1 0 DLOD SDL. 367697 LBS 94 0 0 '1 0 4 0 1 6g 4 0 1 Ge 4 0 1 Ge 4 0 1 68 4 0 1 Ge 4 0 1 G8 4 0 1 GS 4 0 1 Ge 4 0 1 6~ 4 0 1 6e 4 0 J 68 4 0 1 68 4 0 1 68 4 0 i 60 4 0 ~ 68 4 0 1 68 4 0 1 68 4 0 I 6~ 4 0 I 68 4 0 i 68 4 0 ~ 68 4 0 1 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 t 68 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 00'00.00 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O00'O00 000000 000000 000000 000000 000000 O00~OOO 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 0.00'000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 0.00000 000000 000000 000000 000000 000000 000000 000000 000000 00000'0 000000 DEPT DRHO RHOB HD~ ~R F~DL HINV HHRS DATA 3810,000 2.217 4.523 ~800. 000 ,02~ 2, 4,409 · 3700. 000 ,024 2,133 5,208 3600,000 ,054 2,269 8,243 3500,000 ,058 2,220 5.746 3400,0'00 .012 2.106 3,487 '36,250 i 0099,217 3,230 4,178 ! 04. 429 036 O, 551 2,285 3.972 102.069 1'0827,439 2,622 4,464 74,145 8989,994 2,285 6,366 I 07,378 9892. 994 2,816 4.830 71,919 11372.105 1.238 3,047 RECORDS FDSN NDSN NPHI NRRT DPE DPHI NSDL PE PELC QL Q9 QPE HNOR CALI HDR HDX HMR NHX HDCN HHCH DFL SP TENS DLOD 1601, 17783, 3, 221, 1592, 17331. 2, 226, 1456, 17451, 2. 192, 1699, 17202. 2, 121 , 1618, 17599, 2, 174. 1426, 17461 , 1. 286. Page 714 14507,439 ,426 9.634 O.O00 ,260 883 3,207 3,114 ,026 -,016 -1,000 027 10,849 190,196 36,248 232,423 16,512 880 239,339 3,743 330,365 2896,652 1230,420 065 14267,771 ,418 9,532 0,000 ,294 699 2.657 2, ei 7 -, 082 , Ol 2 -1 , 008 473 11 , 025 190,677 35, i38 244,558 15,383 790 25i ,777 3,607 327,172 2969,432 1306,206 838 '139~94.3'I 2 .457 10,2i0 0.000 ,311 246 2,559 2. 802 -. 004 .046 -I. 000 562 11 .'O13 165. 226 26,084 2i 5. 347 1 O. 240 029 224. :032 3,655 320. 585 2663. 755 1168. 007 806 14544,504 ,402 9,101 .O,O00 ,228 156 3,071 3,557 ,823 ,021 -1,000 418 10.288 92.216 12.529 125,278 4,421 310 157,084 5.121 313,184 2547,307 1154.633 3?5 14455,699 ,407 9,501 0.000 ,259 063 3,2i$ 3,200 -,016 -,025 -l,OOO 839 11,992 147.542 21.418 191.757 13.882 031 207,048 4,260 299,883 2547,307 1087,763 839 14529,984 ,479 10,832 0,000 ,328 062 2,883 2.316 ,025 ,030 -1.000 276 11,088 207,853 32,'081 266,177 13,183 745 328,192 2.158 308,366 2576,419 1217.046 FILE TRAILER Film name: &GSF01. Maximum length: 1024 TRAILER RECORDS Service File type: LO Version Hext ~ile: Date Page REEL TRAILER Service name: &GSF01 Next rem 1: Date: 90/'08/03 Comment~: Origins: Reel name: 367697 Continuation #: 01 :~:~ TAPE TRAILER mmm,m :+: :~ ~:~ ~ :~ ~:~ ~:~ :~ ~ :~:~ ~:~ ~:~ Service name: &GSF01 Nmxt tape: Date: 90/08/03 Comments: Origin: Tape name 367697 Continuation #: 01 (NOTE: **** LIS READ **** MAXIMUM RECORD LENGTH - 8192 BYTES) ** REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SSDS DATE: 90/08/10 ORIGIN OF DATA: RLL REEL NAME: ARCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: RLL DATE: 90/08/10 ORIGIN OF DATA: 3Gll TAPE NAME: KUPARUK CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE (EOF # 1) ********** ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: 3G22.MWD SERVICE NAME: RLL VERSION #: V 2.40 DATE: 90/08/10 MAX. RECORD LENGTH: 1024 FILE TYPE: E0 PREVIOUS FILE NAME: ** COMMENTS ** COMPANY: ARCO ALASKA INC.// WELL: 3G-11// FIELD: KUPARUK// DATE: 27 JULY 90 API#: 50-103-20133// LOCATION: 2538' FNL & 120' FWL, SEC. 24, TWP. 12N, RANGE 8E, NORTH SLOPE BOROUGH, ALASKA, USA// CO. REP: McCAULEY & SALAT// RIG: DOYON RLL ENG.: GALVIN & WESLEY// COMMENTS: ***> HOLE WIPED FROM 6503' - 6630' MD. HOLE LOGGED WHILE DRILLING FROM 6630'- 6899'MD. HOLE CORED FROM 6532'- 6630'MD NEUTRON & DENSITY LOGS ARE CALIPER CORRECTED AND PROCESSED USING SFD-K AND CNO-C ALGORITHMS. ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID DEPT EWR MWD ROP MWD TEMF MWD NF0 MWD NFl MWD NN0 MWD NN1 MWD GRC MWD FXE MWD CAL MWD DRHO MWD NPSC MWD RHOB MWD ORDER# LOG TYP CLS MOD NO. LVL CODE FT 0 0 0 0 1 4 0 1 68 OHMM 0 0 0 0 1 4 0 1 68 FT/H 0 0 0 0 1 4 0 1 68 DEGR 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 API 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 P.U. 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 ** DATA FORMAT SPECIFICATION ** TYPE SIZE REP CODE 4 1 66 0 1 66 ENTRY BLOCKS ENTRY DESCRIPTION 255 LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID DEPT EWR MWD ROP MWD TEMF MWD NF0 MWD NFl MWD NN0 MWD NN1 MWD GRC MWD FXE MWD CAL MWD DRHO MWD NPSC MWD RHOB MWD ORDER# LOG TYP CLS MOD NO. FT 0 0 0 0 1 OHMM 0 0 0 0 1 FT/H 0 0 0 0 1 DEGR 0 0 0 0 1 CTS 0 0 0 0 1 CTS 0 0 0 0 1 CTS 0 0 0 0 1 CTS 0 0 0 0 1 API 0 0 0 0 1 HOUR 0 0 0 0 1 0 0 0 0 1 G/C3 0 0 0 0 1 P.U. 0 0 0 0 1 G/C3 0 0 0 0 1 4 4 4 4 4 4 4 4 4 4 4 4 4 4 LVL 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 1 1 1 1 1 1 1 1 1 1 1 1 1 CODE 68 68 68 68 68 68 68 68 68 68 68 68 68 68 DEPT NN1 6400.000 -999.250 6450.000 -999.250 6500.000 2024.000 6550.000 2666.212 6600.000 2644.087 6650.000 2700.064 6700.000 2497.794 6750.000 2471.021 6800.000 2671.521 6850.000 2507.296 6900.000 -999.250 6950 -999 .000 .250 ** DATA VERIFICATION EWR GRC -999.250 -999.250 -999.250 -999.250 1.624 88.785 4.097 82.354 4.846 76.709 4.561 73.862 2.770 91.240 2.693 89.576 2.803 86.032 2.148 95.888 -999.250 -999.250 -999.250 -999.250 ROP FXE -999.250 -999.250 -999.250 -999.250 (every 50 FT) ** -999.250 -999.250 TEMF CAL 92.864 -999.250 -999.250 -999.250 67.212 -999.250 -999.250 -999.250 60.674 .674 101.072 -999.250 41.437 .843 102.830 8.790 49.561 .764 106.346 8.850 48.294 .718 109.861 8.730 31.400 1.026 115.135 8.640 -999.250 -999.250 118.650 8.750 120.408 8.840 123.924 8.790 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** 62 DATA RECORDS ** FROM ** FILE TRAILER** FILE NAME: 3G22.MWD SERVICE NAME: RLL VERSION #: V 2.40 DATE: 90/08/10 MAX. RECORD LENGTH: FILE TYPE: E0 NEXT FILE NAME: 1024 NFO DRHO -999.250 -999.250 -999.250 -999.250 422.000 -999.250 565.553 -.002 567.401 .025 588.795 .001 567.973 -.087 516.960 .000 564.933 .001 538.203 .000 -999.250 -999.250 -999.250 -999.250 6400.00 TO NFl NPSC -999.250 -999.250 -999.250 -999.250 441.000 -999.250 545.212 38.346 591.106 31.804 586.802 34.580 541.146 41.723 518.814 45.538 560.380 37.315 531.435 44.014 -999.250 -999.250 -999.250 -999.250 6950.00 FT NN0 RHOB -999.250 -999.250 -999.250 -999.250 2040.000 -999.250 2698.547 2.386 2769.079 2.396 2739.815 2.392 2489.358 2.405 2434.243 2.403 2629.592 2.372 2489.296 2.423 -999.250 -999.250 -999.250 -999.250 ********** END OF FILE (EOF # 2) ********** ** TAPE TRAILER** SERVICE NAME: RLL DATE: 90/08/10 ORIGIN OF DATA: 3Gll TAPE NAME: KUPARUK CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** REEL TRAILER ** SERVICE NAME: SSDS DATE: 90/08/10 ORIGIN OF DATA: RLL REEL NAME: ARCO CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT DIREOT DIGITAL LOGGING OOMPUTER PROCESSED ANALYSIS I..LLLLLLLL LLLLLLLLL tlIilIIIII SSSSSSSS ilIIIIiliI SSSSSSSSSS Ii SS SS II SS II BB Ii SSSSSSSSB ii SSSSSSSSS II ~S Ii SS Ii SS SS iilililiii SSs~ss~ss Iiliiiiiii SSSSSSSg 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 MM MM MMN MHM NMHM MHNN NH MM MM NH MM MMMM MM MM NM MM MM NM MM NH MH MM MM HM MM HM MN him PPPPPPPPPPP PPPPPPPPPPP PP P PP P PP P PPPPPPPPPPP PPPPPPPPPPP PP PP PP PP PP 11 111 illl I1 11 11 I1 11 11 ii illl 1111 11 iii 1111 ii ii li ii ii li ii iiii iiil Ili1 Illl 1ill 1111 2222222222 222222222222 22 22 22 22 22 22 22 22 22 222222222222 222222222222 3333333333 333333333333 33 33 33 3333 33 33 33 333333333333 3333333333 i ~ AAAA AA AA AA AA AA AA AA AA AAAAAAAAAAAA AAAAAAAAAAAA AA AA AA AA AA AA AA AA 3333333333 333333333333 33 33 33 3333 3333 33 33 33 33 333333333333 3333333333 UU UU UU UU UU UU UU UU UU UU UU UU UlJ UU UU UU UU UU UU UU UUUUUUUUUUUU UUUUUUUUUU 777777777777 77777777777 77 77 77 77 77 77 77 77 77 77 77 CC GCGGG GGGGGGGGGGGG GGGGGGGCGG PPPPPPPPPPP PPPPPPPPPPPP PP PP PP PP PP PP PPPPPPPPPPPP PPPPPPPPPPPP PP PP PP PP PP 9999999999 999999999999 99 99 99 99 99 99 999999999999 999999999999 99 99 99 .99 999999999999 9999999999 MM M MMM MH MMHM HHH NM MM MM H NM MMHH H MM MM H MM H MM H NM hi MM H MH H MM H 00000000 0000000000 ~0 0 O0 0 O0 0 O0 0 ~0 0 O0 0 O0 0 ~0 0 0000000000 00000000 S~r.',/ice name~ HLS Pr.~viou~ reel: Date: 90/08/08 Comments: HEADER RECORDS Page Origin: PLS Reel name: HgO41G4 Continuation #: HLS FORMATIOtl EVALUATION SYSTEMS -- HEADQUARTERS S~r. vice name: HLS Previous tape: Date: 90/07/28 Comments: Origin: PLS Tape name: H904164 Continuation #: ** FILE HEADER *~** Film r, ame: HLS,.O01 ,.,.mm Haximum length: 974. File type: LO Version #: Previous ~ile: SFM6 Date: 89/01/04 H N E H bin FH C 0 Lt i,i STAT ~ U ;-t DATE A P I N L U N L UL Wi TN HR T RH HS'f · RHF HFST RHC HCST EKB EDF L HF ~SD i BSD2 BSD3 CS~ CSD i C S D 2 BL[ TL.~ INFORMATION RECORDS CONTENTS ARCO ALASKA, INC. SG-11 KUPARUK RIVER UNIT N. SLOPE ....... ~67697 ........... ONE o?x2 .> 61 ' i ' i' i .... 50'i032013300 .. , 519~9 ...... H. SLO6 ..... J. ADDISON A, LOWEN t 19 .... i .7~ ,..-. 77 .... I .~0 ... , . 77 .... 2.27 .... 77 .... 89 .... 88 .... 5~ .... KB . 6900 ,,. 6, 3 0 0,0 0 0 i · i i m · · I II··tllI IlleIII I*l|IlI ·Il· IIII II iIii IlJI mi·t ii .i··· ii, IIllt III IIIIl III IIIII III IlllI III IIItI III IIdlI III · I IIII aI .I IIII II I II a · · I I I · I I I I II IleII IIIII ,IIII I I a · i · . I 4, · . i . . I · i m iiIiiIIiiIIiiiI IIlIIIII ii ii i, ti ,I iii,Iii iilIIii . . · i ! i i . i ! · i i · · . a . · i i ii · .i i m ·· i i· · mi m .i I ·I · · a . im · i · i i. i · . · · . iiJililIIii tdl|I|ilIli i·Ii|iitlii · · · I · · I · amal. miami imIal lima· iii·· .Imm. mm4.·l I.m.m .I ·i ·I ii ii i· lie IalI IlmI IIII Imlm ·mml UNIT DEGF OHMH DEGF OHHM DEGF OHMH .DEGF FT FT ,FT IN FT IN FT IN FT IN FT I N FT IN FT FT FT TYPE CATG 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 3 0 ,3 0 3 0 3 0 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 0 3 SIZE 26 28 28 12 2 8 4 8 i6 32 40 40 4 4 4 4 ,4 4 4 4 4 CODE 65 65 65 65 65 65 65 65 65 65 ~5 65 65 65 ~5 ~5 ~5 ~5 65 65 ~5 ~5 65 ~5 ~5 ~8 Page ERROR COMMENT RECORDS Page Tills IS THE MAIN SECTION FOR FULL WIqVE SONIC LOC,. ** ENTRY' BLOCKS Ei-tTRY DATA FORMAT SPEC I F I CAT I.ONS TYPE SIZE CODE Page iiiiIIiiiiii1~ · i~llilllllllll · i 1 I 6G 4 1 gg 0 4 ?~ 11 1 Gg 1G 1 gg -~*:*: ENTP, Y BLOCK LEGEND TYPE DESCRIPTION 1 Data record type ( logical record t~/pe number ) 2 Datum speci?ication block Dmt. m ~rame size ( b~tez ) 4 Up / Down ~lag ( 1 = up, 255 = dOwn, O = nmither 5 Optical log de~th scale ( '1 = Ceet, 25~ = meters 8 Frame spacing. depth di?~ermnce 9 Unit~ o? ?tame spacing 11 Maximum Cremes per record 16 Datum speci£ication block sub-t,~pe 0 Terminator ( no more entries ) ) 0 = time DATA FORMAT DATUM SPECIFICATION BLOCKS SPECIFICATIONS Pag~ M N E M SERVICE SERVICE APl AP1 APl AP1 FILE ID ORDER # UNIT LOG TYPE CLASS MOD # PRC # SIZE LVL SMPL RC PROCESS INDICATORS DEPT FWS CALl FWS GR FWS G4GI FWS SCAE FWS TD i C FWS ALT FWS SCF 1 FWS SCF3 FWS SDCS FWS Gi FWS 367697 FT 62 0 0 i 1 367697 iN 62 280 i i 1 367697 GAPi 62 3i0 i i i 367697 DB 62 980 21 1 1 367697 US/F 62 970 70 I i ~67697 US 62 52 4 1 1 B67697. 62 988 1 ~G?G97 UB/F ,G2 50 ~ 1 1 367697 US/F 62 50 3 -1 1 367697 62 SO 3 1 1 367697 DB 62 98e 22 i i 4 0 1 68 4 0 i 68 4 0 i 68 4 0 1 68 4 0 1 68 4 0 i G8 4 0 1 68 4 0 1 G8 4 0 1 68 4 0 i 68 4 o 1 6,8 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O00OO0 000000 · 000000 000000 000000 000000 000000 000000 000000 OOOO00 000000 000000 000'000 000000 000000 000000 000000 000000 000000 000000 DEPT SCF~ CALl DATA RECORDS SCAE TDIC ALT SCFi Pmgm 6870.000 0.000 6800.000 -999.250 6700.000 -999.250 6600.000 89,668 6500,000 i50,460 6400,000 148,405 6300,000 -999,250 8.849 -~,z50 8.982 -999,250 9.102 -999,250 8.982 ,117 I4.717 12,007 '11,570 i2.488 9,474 -999.250 1 04.4~3 O. 000 87. 743 43.1 ~? 99.464 4~,5oo G5,525 47.500 99. 671 51. 000 1 O?. 847 49.667 238,912 49, O 0:0 0.000 :3,500 4,833 4.000 -1 . 66.7 -3.667 0, .000 33,553 89,097 105.680 89.91:3 11,3.902 112. 879 -999,250 0.000 O. '000 O. 0.~000 O. 00'O 0. O. 'O O0 -999.250 .226 -.276 -. 003 -,342 -.290 -.336 0,000 89, 097 1 04. 758 89.326 116.500 113,083 1 06,876 Film name: HLS.O01 Maximum length: 974, TRA I LER RECORDS name: Version File type: LO Next ~i le: HLS. 002 Date: 89/0J?04 Page Film name: HLS.O02 Haximum length: · 9?4. Service name: File .type: LO Ver.~ion Previous ?ile: #: SFM6 Date: HLS.O01 89/01 / 04 H H E H C: H td H FH C 0 tJ i4 STAT SON RUN DATE AP IH LUN LUL EHG I ~d i T N i'IR T RH HST. ~HF HFST H C S T EKB EDF E&L LNF ~SD1 B~D2 C:SD 1 CSD2 CS2 CSD3 TLi COHTENTS ARCO ALASKA, INC. ~G-11 KUPARUK RIVER UNIT N, SLOPE ......... AK ................... ............. ............. o7/ 6 o ...... :,, :... ..... ~, SLO~k ............. d. ~DDISOH ~. LO,EH ii9 ................. 1 .73 .................. 77 ................ 1 .30 ................. 77 ................ ~ .27 ................ 77 ................ e9 ............... 8e ............... 52 ................ 8 1/2 .... ~gOO .... · ..... . , 3354 .... il·riel lelileI Iwlwaii iii·Ill iiIilIi IIi·iii IIlIlII IiIliii INFORMATION RECORDS UNIT alii iIll Ifil IleIIl IIllll lIllll lei·lB telll llelltli illeellI i·tllelil Iiiilllt iiii illll Ilell illillIlllmllllIIllillii iiliilllliiiIiliilliiIi · i I I m I I I I Il i m m iiii il IIll II ilii lmllll Iiii lei ell iiiI III la mil lmm me i Iii·mill·emi Iai Illl II i i &III I IeIiei &Iii i ilii i IlIlil iiii I iIii I IiiiIi ! m iIImIilI I i IlmlIlll I I IIIIIlII I I IIlmmlmmi ! m · m I · m I I m m DEGF OHHM DEGF OHMH DEGF OHMH DEGF FT FT FT IN FT iN FT iN FT I N FT IN FT IN FT FT FT TYPE CATG SIZE 0 0 26 0 0 28 0 0 12 0 0 0 -0 0 0 4 0 0 0 0 16 0 0 32 0 '0 40 0 :0 4 0 0 1 4 0 2 4 0 2 4 0 2 0 P 4 0 2 4 0 2 4 0 3 6 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 '0 3 0 2 .0 3 4 0 3 4 CODE 65 65 &5 65. 65 65 &5 &5 &5 .65 ~5 ~5 ~5 ~5 ~5 &5 65 ~5 ~5 ~5 ERROR COMMENT RECORDS Pagm THIS IS THE REPEAT SECTION FOR FULL WAVE SONIC; LOG. 'i~ :~:~ ENTRY BLOCKS ENTRY DATA FORMAT SPECIFICATIONS TYPE SIZE CODE Pagm 10 1 1 gg ~ 1 gg ~ ~ 79 4 1 GG 8 4 73 ii 1 GG 1g 1 GG 0 0 GG ENTRY BLOCK LEGEND TYPE DESCRIPTION Data record type ( logical record type number ) Datum spmci~ication block t~pe Data f'ramm sizm ( b~tez ) Up / Down ~lag ( 1 = up., ~55 = down., 0 = nmithmr Optical log depth scale ( 1 = ¢¢¢t, 255 = m~t~rz, Frame spacing .( depth di??erence bmtwemn ~ramez ) Unit. z o~ ~rame spacing Maximum .~ram~z p~r record Datum specification block' sub-type Terminator ~ no more entries ) ) 0 = time DATA FORMAT DATUM SPECIFICATION BLOCKS SPEC I I CA T I O NS Pagm 11 MNEM SERVICE SERVICE AP1 AP1 AP1 AP1 FILE ID ORDER # UNIT LOG TYPE CLASS MOD # PRC # SIZE LVL SMPL RC PROCESS INDICATORS DEPT FWS 367697 CALl FWS 367697 GR FWS 367697 6461 FWS 367697 SCAE FWS 36?697 TDiC FWS 36769? .ALT FWS 36?697. SCFi FIdS 367697 SCF3 FWS 36?69? SDCS FWS 367697 Gi FWS 36?697 FT 6'2 0 0 2 2 IN 62 280 i 2 2 GAPI 62 3i0 I 2 2 DB 62 98O 21 2 2 US?F 62 970 78 2 2 US 62 52 4 2 2 62 980 i 2 2 US/F 62 50 3 2 2 US?F 62 50 3 2 2 62 50 ~ 2 2 DB 62 980 22 2 2 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 ! 68 4 0 i 68 4 0 1 68 4 0 1 68 4 0 1 68 4 O i 68 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O00000 000000 000000 000000 000000. 000000 000000 000000 000000 O00000 000000 000000 000000 000000 000000 00.0000 000000 000000 0000.00 000000 000000 000000 000000 DEPT SCF3 CALI DATA G4Ol RECORDS SC~£ TDIC RLT SCF1 Page 12 6,860,000 i00.277 6800. 000 89. 775 6700, 000 I01 .557 6600,000 89.21i 6500. 000 112.i13 6400. 000 i 12. 863 6300 ..000 i 09. 923 , 8. -999. 9. 1. 8. i 14, l, Il. i 9, . 846 083 982 250 1 02 226 982 499 717 623 570 203 474 939 1 04. 463 1 3,667 87.743 44,500 99. 464 45.667 65.525 48.500 99.671 51 . 500 107'.847 50. '167 238.912 4,9.833 3,833 2. 167 4.500 3.167 -2.5'00 -5. O00 -5,500 1 O0. 203 90. 095 i 04. 378 90.244 114. 090 114,123 111,435 0. 000 O.OOO O..000 0.000 O. 000 O. 00.0 :0.0 0 O -. 0:02 -.002 .027 .017 .027 ,010 O.OOO 100 89 105 9O 116 11.3 112 045 763 025 625 703 429 576 FILE TRAILER File name: HLS.O02 · Haximum length: 974. TRA I L£R RECORDS Service name: Version #:SFMG Date: File tppe: LO Next ¢ile: 89/01 / 04 Page 13 ~:** TAPE TRAILER **** Service name: HLS Next tape REEL TRAILER Smrvice name: HLS Next. reel: Date: 90/07/28 Origin: PLS Tape name: H9:04154 Comments: Continuation #: Date: 90/'08/:08 Origin:.PLS Reel name: H904164 Continuation Comments: HLS FORMATION EVALUATION SYSTEMS -- HEADQUARTERS LIS VERIFICATION LISTING FOR: ARCO ALASKA 3G-11 KUPARUK RIVER UNIT Below are the mnemonics used on the ARCO ALASKA INC. 3G-11 Well LIS tape. 1 1 1 31 41 41 41 42 42 42 93 93 1 1 1 31 41 41 41 42 42 42 93 93 0 ROPS 1 WBCS 2 RPMS 0 TCDX 0 GRBX 1GRAX 2 GRCX 0 SNBX 1 RSAX 2 RSCX 1 CSAX 2 CSCX Rate Of Penetrationlft/hr Surface WOBIklbs Surface RPMIrpm CDS Temperature [MWD]ldeg F Gamma Ray Base [MWD]lcput Gamma Ray App [MWD]}MWD-API Gamma Ray Cor (MWD) I MWD-API Resistance (SN) Base [MWD]lohms Resistivity (SN) App [MWD]lohm-m Resistivity (SN) Cor [MWD] I ohm-m Conductivity (SN) App [MWD] I mmhos/m Conductivity (SN) Cor [MWD] I mmhos/m ** reel header ** service name :RGD date :90/08/02 origin :2300 reel name :770TAK continuation# :01 previous reel : comment :TELECO OILFIELD SERVICES PROPRIETARY FIELD TAPE ** tape header ** service name :RGD date :90/08/02 origin :2300 tape name :770TAK continuation # :01 previous tape : comments :RIG DOYON 14 ** file header ** file name :770TAK. 001 service name :RGD version # : 1.31 date :90/08/02 maximum length :1024 file type :LO previous file : ** information records ** table type :TOOL MNEM STAT LENG WEIG HEIG GR ALLO 0.000 0.000 0.000 RSN ALLO 72.000 0.000 0.000 DCDS ALLO 360.000 0.000 0.000 ** information records ** STAT PUNI TUNI table type :CONS MNEM VALU BS UNAL CS I Z UNAL SD UNAL WMUD UNAL SHT UNAL BHT UNAL TD UNAL YEAR UNAL MONT UNAL DAY UNAL ** information records ** IN IN F LB/G DEGF DEGF F IN IN F LB/G DEGF DEGF F 8.500 9.875 3400.000 10.700 0.000 0.000 6550.000 90.000 8.000 2.000 table type :CONS MNEM STAT PUNI TUNI VALU SON UNAL Ri UNAL R2 UNAL R3 UNAL R4 UNAL R5 UNAL R6 UNAL R7 UNAL R8 UNAL HIDE UNAL WN UNAL CN UNAL FN UNAL FL UNAL FL1 UNAL LUL UNAL ENGI UNAL WITN UNAL DFT UNAL LONG UNAL LATI UNAL STAT UNAL COUN UNAL DMF UNAL LMF UNAL PDAT UNAL APIN UNAL RESISTIVITY/GAMMA/DIRECTIONAL 3G-11 ARCO ALASKA KUPARUK RIVER UNIT ANCHORAGE GEHRES/ST.PIERRE PRICE ALASKA NORTH SLOPE RKB RKB OS1 OS2 OS3 0S4 OS5 0S6 TLAB TCS TN1 TN2 TN3 TN4 TN5 TN6 TN7 TN8 TN9 TN10 TNll TN12 SECT TOWN RANG NATI CONT MSS MFSS MCSS SLAB CLAB CS1 CS2 CS3 BS1 BS2 BS3 HLD RUN LUN OPER LLUN LCC BLI TLI EPD UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL USA NAM STATE COUNTY 9.875 12.25 8.50 INCL 0.000 2300.000 0.000 0.000 0.000 0.000 0.000 0.000 APD UNAL EKB UNAL EDF UNAL EGL UNAL TDD UNAL TDL UNAL CW1 UNAL BSD1 UNAL CBD1 UNAL CBL1 UNAL CW2 UNAL BS D 2 UNAL CBD2 UNAL CBL2 UNAL CW3 UNAL BSD3 UNAL CBD3 UNAL CBL3 UNAL STEM UNAL MRT UNAL DFD UNAL DFV UNAL DFPH UNAL DFL UNAL RMFS UNAL RMS UNAL RMCS UNAL MST UNAL MFST UNAL MCST UNAL ** information records ** table type MNEM :PRES OUTP F F F F F F LB/F F F F LB/F F F F LB/F F F F DEGF DEGF LB/G S C3 OHMM OHMM OHMM DEGF DEGF DEGF STAT GRCX GRCX ALLO GRCX GRCX ALLO RSAX RSAX ALLO ROPS ROPS ALLO WBCS WBCS ALLO ILD0 ILD DISA ILD1 ILD DISA F F F F F F LB/F F F F LB/F F F F LB/F F F F DEGF DEGF LB/G S C3 OHMM OHMM OHMM DEGF DEGF DEGF TRAC Ti Ti T2 T3 T3 T2 T2 655 655 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 CODI LLIN LGAP MLIN LGAP LLIN LDAS MDAS DEST MODE NB NB GRAD NB NB GRAD GRAD TT1 TT1 DISA TT2 TT2 DISA TT3 TT3 DISA TT4 TT4 DISA TENS TENS DISA 12 DUMM DISA 13 DUMM DISA 14 DUMM DISA 15 DUMM DISA 16 DUMM DISA 17 DUM~ DISA 18 DUMM DISA 19 DUMM DISA ** information records ** T3 T3 T3 T3 T3 Ti Ti Ti Ti Ti Ti Ti Ti LLIN LSPO LDAS LGAP LSPO LLIN LLIN LLIN LLIN LLIN LLIN LLIN LLIN 1 1 1 1 1 NEIT NEIT NEIT NEIT NEIT NEIT NEIT NEIT SHIF SHIF SHIF SHiF NB. NB NB NB NB NB NB NB NB table type :FILM MNEM GCOD GDEC DEST DSCA 1 E2E -2- PF1 S2 2 EEE -2- PF2 D500 ** information records ** table type :AREA MNEM STAT BEGI END PATT DEST 1 DISA 2 DISA 3 DISA 4 DISA 5 DISA 6 DISA 7 DISA 8 DISA ** data-format record ** entry blocks type 4 8 size 1 4 Zl Zl Z1 Zl Zl Zl Z1 Zl repr code 66 68 Z1 Z1 Z1 Z1 Zl Z1 Zl Zl entry 255 60.000 BLAN BLAN BLAN BLAN BLAN BLAN BLAN BLAN NEIT NEIT NEIT NEIT NEIT NEIT NEIT NEIT 9 4 65 .liN 12 4 68 -9999.000 0 2 79 0 datum specification blocks WARNING the following table is in LIS Datum Specification Block Sub-Type 0 and the API Type Codes may be Unreliable!!! mnem service service id order # DEPT ROPS WBCS RPMS TCDX GRAX GRCX SNBX RSAX RSCX CSAX CSCX INC AZM TVD unit api api api api file size spl repr log type class mod no. code FT 00 000 00 00 0 4 1 68 00 000 00 00 0 4 1 68 00 000 00 00 0 4 1 68 00 000 00 00 0 4 1 68 00 000 00 00 0 4 1 68 00 000 00 00 0 4 1 68 00 000 00 00 0 4 1 68 00 000 00 00 0 4 1 68 00 000 00 00 0 4 1 68 00 000 00 00 0 4 1 68 00 000 00 00 0 4 1 68 00 000 00 00 0 4 1 68 00 000 00 00 0 4 1 68 00 000 00 00 0 4 1 68 00 000 00 00 0 4 1 68 process level depth = 3400.0000 feet ROPS 1.0000 WBCS GRAX 105.2700 GRCX RSCX 4.3700 CSAX AZM 1.0000 TVD depth = 3500.0000 feet ROPS 82.3900 WBCS GRAX 127.6400 GRCX RSCX 6.4200 CSAX AZM -9999.0000 TVD depth = 3600.0000 feet ROPS 30.7600 WBCS GRAX 31.2300 GRCX RSCX 56.6900 CSAX 1036.3200 meters 1.0000 RPMS 1.0000 112.4600 SNBX 0.6500 220.6200 CSCX 228.7000 1.0000 1066.8000 meters 29.4700 RPMS 0.0000 136.3600 SNBX 0.9800 147.8600 CSCX 155.9300 -9999.0000 1097.2800 meters 7.7500 RPMS 0.0000 33.3600 SNBX 6.8100 21.2400 CSCX 17.7000 TCDX RSAX INC TCDX RSAX INC TCDX RSAX INC 1.0000 4.5300 1.0000 86.0000 6.7700 -9999.0000 93.2000 47.1500 -9999.0000 AZM depth = ROPS GRAX RSCX AZM depth = ROPS GRAX RSCX AZM depth = ROPS GRAX RSCX AZM depth = ROPS GRAX RSCX AZM depth = ROPS GRAX RSCX AZM depth = ROPS GRAX RSCX AZM depth = ROPS GRAX RSCX AZM -9999.0000 TVD -9999.0000 3700.0000 feet .... 1127.7600 meters 93.9500 WBCS 24.8800 RPMS 0.0000 108.8200 GRCX 116.2600 SNBX 0.6500 4.3600 CSAX 221.1400 CSCX 229.2100 -9999.0000 TVD -9999.0000 3800.0000 feet 1158.2400 meters 139.8900 WBCS 27.5500 RPMS 0.0000 122.0100 GRCX 130.3500 SNBX 0.6400 4.2900 CSAX 225.0900 CSCX 233.1200 -9999.0000 TVD -9999.0000 3900.0000 feet 1188.7200 meters 96.8600 WBCS 30.5700 RPMS 0.0000 136.3900 GRCX 145.7100 SNBX 0.6500 4.3700 CSAX 220.6200 CSCX 228.7000 -9999.0000 TVD -9999.0000 4000.0000 feet 1219.2000 meters 220.2500 WBCS 9.8600 RPMS 0.0000 107.7700 GRCX 115.1400 SNBX 0.6100 4.0900 CSAX 236.6900 CSCX 244.5800 -9999.0000 TVD -9999.0000 4100.0000 feet 1249.6800 meters 405.9600 WBCS 10.4300 RPMS 0.0000 104.4100 GRCX 111.5400 SNBX 0.6200 4.1600 CSAX 233.4600 CSCX 241.3900 -9999.0000 TVD -9999.0000 4200.0000 feet 1280.1600 meters 295.7400 WBCS 12.6900 RPMS 0.0000 112.8400 GRCX 120.5500 SNBX 0.5100 3.4200 CSAX 285.0300 CSCX 292.3600 -9999.0000 TVD -9999.0000 4300.0000 feet 1310.6400 meters 38.9000 WBCS 20.9400 RPMS 0.0000 -9999.0000 GRCX -9999.0000 SNBX -9999.0000 -9999.0000 CSAX -9999.0000 CSCX -9999.0000 -9999.0000 TVD -9999.0000 TCDX RSAX INC TCDX RSAX INC TCDX RSAX INC TCDX RSAX INC TCDX RSAX INC TCDX RSAX INC TCDX RSAX INC 98.6000 4.5200 -9999.0000 102.2000 4.4400 -9999.0000 105.8000 4.5300 -9999.0000 -9999.0000 4.2300 -9999.0000 -9999.0000 4.3100 -9999.0000 -9999.0000 3.5100 -9999.0000 -9999.0000 -9999.0000 -9999.0000 depth = 4400.0000 feet 1341.1200 meters ROPS GRAX RSCX AZM depth = ROPS GRAX RSCX AZM depth = ROPS GRAX RSCX AZM depth = ROPS GRAX RSCX AZM depth = ROPS GRAX RSCX AZM depth = ROPS GRAX RSCX AZM depth = ROPS GRAX RSCX AZM depth = ROPS GRAX RSCX 248.4900 WBCS 20.4600 RPMS 0.0000 96.4500 GRCX 103.0400 SNBX -9999.0000 -9999.0000 CSAX -9999.0000 CSCX -9999.0000 -9999.0000 TVD -9999.0000 4500.0000 feet .... 1371.6000 meters 352.5700 WBCS 6.0100 RPMS 0.0000 121.0200 GRCX 129.2900 SNBX 0.3600 2.4700 CSAX 399.2000 CSCX 405.3000 -9999.0000 TVD -9999.0000 4600.0000 feet .... 1402.0800 meters 229.6400 WBCS 6.4300 RPMS 0.0000 -9999.0000 GRCX -9999.0000 SNBX 0.4800 21.3100 CSAX 45.1900 CSCX 46.9300 -9999.0000 TVD -9999.0000 4700.0000 feet .... 1432.5600 meters 204.0100 WBCS 16.9500 RPMS 0.0000 127.3200 GRCX 136.0200 SNBX 0.4100 2.7600 CSAX 355.9300 CSCX 362.4900 -9999.0000 TVD -9999.0000 4800.0000 feet .... 1463.0400 meters 201.2000 WBCS 7.2300 RPMS 0.0000 100.7900 GRCX 107.6700 SNBX 0.4900 3.3100 CSAX 294.7600 CSCX 301.9800 -9999.0000 TVD -9999.0000 4900.0000 feet 1493.5200 meters 158.5300 WBCS 5.1600 RPMS 0.0000 191.7300 GRCX 204.8300 SNBX 0.7900 5.2100 CSAX 183.8500 CSCX 192.1000 -9999.0000 TVD -9999.0000 5000.0000 feet .... 1524.0000 meters 109.9200 WBCS 2.6600 RPMS 0.0000 150.6300 GRCX 160.9200 SNBX 0.3500 2.4200 CSAX 407.0700 CSCX 413.0800 -9999.0000 TVD -9999.0000 5100.0000 feet 1554.4800 meters 112.9400 WBCS 6.7500 RPMS 0.0000 176.3200 GRCX 188.3700 SNBX 0.3500 2.4200 CSAX 407.0700 CSCX 413.0800 TCDX RSAX INC TCDX RSAX INC TCDX RSAX INC TCDX RSAX INC TCDX RSAX INC TCDX RSAX INC TCDX RSAX INC TCDX RSAX INC 105.8000 -9999.0000 -9999.0000 -9999.0000 2.5100 -9999.0000 -9999.0000 3.3200 -9999.0000 -9999.0000 2.8100 -9999.0000 114.8000 3.4000 -9999.0000 116.6000 5.4400 -9999.0000 118.4000 2.4600 -9999.0000 118.4000 2.4600 -9999.0000 AZM -9999.0000 TVD -9999.0000 depth = ROPS GRAX RSCX AZM 5200.0000 feet 1584.9600 meters 178.0100 WBCS 6.5900 RPMS 0.0000 171.1800 GRCX 182.8800 SNBX 0.5700 3.8400 CSAX 252.5000 CSCX 260.2000 -9999.0000 TVD -9999.0000 depth = ROPS GRAX RSCX AZM 5300.0000 feet .... 1615.4400 meters 147.8600 WBCS 7.9300 RPMS 0.0000 148.6100 GRCX 158.7600 SNBX 0.7300 4.8200 CSAX 199.3300 CSCX 207.6000 -9999.0000 TVD -9999.0000 depth = ROPS GRAX RSCX AZM 5400.0000 feet 1645.9200 meters 167.1900 WBCS 8.2600 RPMS 0.0000 126.3600 GRCX 134.9900 SNBX 0.5500 3.6700 CSAX 264.6700 CSCX 272.2300 -9999.0000 TVD -9999.0000 depth = ROPS GRAX RSCX AZM 5500.0000 feet 1676.4000 meters 144.7600 WBCS 9.0700 RPMS 0.0000 117.5600 GRCX 125.6000 SNBX 0.5400 3.6400 CSAX 267.2500 CSCX 274.7900 -9999.0000 TVD -9999.0000 depth = ROPS GRAX RSCX AZM 5600.0000 feet 1706.8800 meters 162.1200 WBCS 5.7800 RPMS 0.0000 135.0700 GRCX 143.5300 SNBX 0.7000 4.6900 CSAX 207.7000 CSCX 213.1700 -9999.0000 TVD -9999.0000 depth = ROPS GRAX RSCX AZM 5700.0000 feet 1737.3600 meters 76.3000 WBCS 22.6200 RPMS 0.0000 140.4500 GRCX 149.2500 SNBX 0.6600 4.4600 CSAX 218.9500 CSCX 224.3000 -9999.0000 TVD -9999.0000 depth = ROPS GRAX RSCX AZM 5800.0000 feet .... 1767.8400 meters 47.8600 WBCS 25.5000 RPMS -9999.0000 95.6200 GRCX 101.6100 SNBX 0.8400 5.6100 CSAX 172.4500 CSCX 178.3200 -9999.0000 TVD -9999.0000 TCDX RSAX INC TCDX RSAX INC TCDX RSAX INC TCDX RSAX INC TCDX RSAX INC TCDX RSAX INC TCDX RSAX INC 118.4000 3.9600 -9999.0000 119.5000 5.0200 -9999.0000 120.2000 3.7800 -9999.0000 122.0000 3.7500 -9999.0000 123.2600 4.8100 -9999.0000 124.0200 4.5700 -9999.0000 128.4600 5.8000 -9999.0000 depth = 5900.0000 feet 1798.3200 meters ROPS 54.7600 WBCS GRAX 140.8200 GRCX RSCX 4.3100 CSAX AZM -9999.0000 TVD depth = 6000.0000 feet ROPS 60.0200 WBCS GRAX 139.8100 GRCX RSCX 4.4600 CSAX AZM -9999.0000 TVD depth = 6100.0000 feet ROPS 49.7400 WBCS GRAX 132.8300 GRCX RSCX 6.0800 CSAX AZM -9999.0000 TVD 11.0800 149.6400 226.5000 -9999.0000 7.1100 148.5700 218.9500 -9999.0000 8.2600 141.1600 158.4500 -9999.0000 depth = 6200.0000 feet .... ROPS 40.7800 WBCS 16.8600 GRAX 147.2700 GRCX 156.5000 RSCX 4.6200 CSAX 211.1200 AZM -9999.0000 TVD -9999.0000 depth = 6300.0000 feet .... ROPS 58.3100 WBCS 38.8700 GRAX 258.2400 GRCX 292.4900 RSCX 3.7100 CSAX 262.0500 AZM -9999.0000 TVD -9999.0000 depth = 6400.0000 feet ROPS 81.1400 WBCS 40.0600 GRAX 158.2600 GRCX 179.2500 RSCX 3.2900 CSAX 296.7300 AZM -9999.0000 TVD -9999.0000 depth = 6500.0000 feet ROPS 74.4700 WBCS 42.2800 GRAX 158.3200 GRCX 179.3200 RSCX 2.0900 CSAX 473.4500 AZM -9999.0000 TVD -9999.0000 RPMS 0.0000 SNBX 0.6400 CSCX 231.7600 1828.8000 meters RPMS 0.0000 SNBX 0.6600 CSCX 224.3000 1859.2800 meters RPMS 0.0000 SNBX 0.9100 CSCX 164.5000 1889.7600 meters RPMS 0.0000 SNBX 0.6800 CSCX 216.5500 1920.2400 meters RPMS 0.0000 SNBX 0.5500 CSCX 269.9000 1950.7200 meters RPMS 0.0000 SNBX 0.4900 CSCX 304.1800 1981.2000 meters RPMS 0.0000 SNBX 0.3100 CSCX 479.0200 TCDX RSAX INC TCDX RSAX INC TCDX RSAX INC TCDX RSAX INC TCDX RSAX INC TCDX RSAX INC TCDX RSAX INC 134.6000 4.4100 -9999.0000 136.4000 4.5700 -9999.0000 140.0000 6.3100 -9999.0000 123.8000 4.7400 -9999.0000 133.8900 3.8200 -9999.0000 136.4000 3.3700 -9999.0000 140.0000 2.1100 -9999.0000 ** file trailer ** file name :770TAK.001 service name :RGD version # : 1.31 date :90/08/02 maximum length :1024 file type :LO next file name : DIRECT DIGITAL LOGGING COMPUTER PROCESSED ANALYSI$ :_LLLLLLLLL L...LLLLLLLLL IIIIIIIII! iiiiilIilI II II ii Ii Ii II Ii Ii IiliIIIIiI IIiiIIiIII ~oo~ DDDDDDDDD UU UU SSSSS~SSSS DDDDDDDDDD UU LIU SS SS DD DD UU UU SS DD DD UU UU SS DD DD UU UU SSSSSSSSS DD DD UU UU SSSSSSSSS DD DD UU UU SS DD DD UU UU SS DD DD UU UU SS SS DD DD UU UU o~oo~o~o DDDDDDDDDD UUUUUUUUUUUU SOo ..... o~ DDDDDDDDD UUUUUUUiJLIU MM MM PPPPPPPPPPI MMM .MMM PPPPPPPPPPi MMMM MMMM PP i NM MM NM MM PP t MM MMMN HM PP i MM MM MM PPPPPPPPPPi MM MM PPPPPPPPPPi MM MM PP MM MM PP MM MM PP MM NM PP MM MM PP ii ill llil ii 1i II ii li I1 iliiiilii I1 I11 1111 11 ii 11 ii I1 ii I1 tlllililll 1111111111 3333333333 333333333333 33 33 33 333333333333 3333333333 AA AAAA AA AA AA RA AA AA AA AA AAAAAAAAAAAA AAAAAAAAAAAA AA AA AA AA AA AA AR AA 555555555555 777777777777 55555555555'5 77777777777 55 77 77 55 77 55 77 555555555 77 5555555555 77 55 77 55 77 55 77 555555555555 77 55555555555 77 UU UU GGGGGG~GG~ UU UU GGGGGGGGGGGG UU UU GG GG UU UiJ GG UU UU GQ UU UU GG UU UU GG UU UU GG GGGGG UU UU GG GGGGG UU UU GG GG UUUUUUUUUUUU GGGGGGGGGGGG UUUUUUUUUU GGGGGGGGGG AA MN AAAA MMM MI AA AA NMMM MHI AA AA MM MM AA AA MN MMMM I AA AA MM MM I AAAAAAAAAAAA MM AAAAAAAAAAAA M~ AA AA ~ AA AA MM AA AA M~ AA AA MM 9999999999 OOOOOOOO 999999999999 OOOOOOO00 99 99 99 99 O'O 99 99 O0 999999999999 O0 999999999999 O0 99 O0 99 O0 99 99 O0 999999999999 000000000 9999999999 00000000 ~,mrvice name: &G5FOl Pr~viou~ reel: HEADER Date: 90/08/03 Origin: Comments: RECORDS Reel name: Page Continuation #: O~ S~r. vice name: &GDF01 Prmvious tape: Date: 90/08/03 Origin: Comments: Tape name: 367697 Continuation #: Oi File name: .OOl Sepvice name: Version Date: Maximum length: 1024 File t~pe: LO Previous ?ile: 1`1 t,I E I'1 CN FH C 0 U N STAT CI'RY AP iN LAT i LONG SECT TOWN RANG EKB EDF EGL PD LMF · DHF RUN T I1`IE D A T E LCC SON LUN FL LUL EN6 ~ &l ~ T N DD CBDi CBLI TLi BLi TCS f'LA8 8HT HR T HT HSS DFD H '.,' I S D F P H DFL RH RHF HFST HFSS RHC INFORMATION RECORDS CONTENTS ARCO ALASKA ~G-11 KUPARUK RIVER NORTH SLOPE ....... ALASKA ....... USA ....... 20133,000 .................. 0 Drag. 0 Hin. O. 0 Smc 0 Oeg. 0 Min. 0. 0 Smc 12N .... I~E .... 89. 000 , oo 000 53. 000 . bis ....... i<8 ....... KB ....... 21.OO.OOO., 27,." 7,"90.. -'"0 ~ r ,w m r ,I · r r ~67697 51939 NORTH SLOPE NORTH SLOPE ADD l ~.uN LOWEN 6900, OOO 6.893.000 3354,000 3345,0 00 ~27.0 O 0 6884,0 O0 , 1600. 000 , 2100,000 , i17,000, . 117,000. . L,, ND CIRCULATED i0.800 48,000 8,000, 5.700, I ,730, 1 ,300, 77. 000 i'iE AS. 2.270 ....... i i · i i i NC. APi NUN: 50-i03-20133 07.-27-90 I I ' I I IlIIlIlIII I IIlIlI I IIIIII I II r II · ii 11 i r iliIii [)ATE LOGGED: ill, IIAI I1 ii ii i · i ~l iii i Iii i iii i , i · i · I , i, i · I i I r m , , · I r . I · i i , r , I · · · , i I i i , , · · ,, . r r . .i Ir i|1 il! e · i . · · ii ri · i , UN I T TYPE CATE; SIZE 0 0 40 0 0 40 0 0 40 0 0 20 0 0 20 0 0 20 0 0 4 0 0 ,34 0 0 :34 0 0 2 0 0 3 0 0 ~ FT 0 3 4 FT 0 3 4 FT 0 ,3 4 0 3 2 O 3 2 0 ,3 2 0 0 2 0 0 4 0 O 8 0 0 2 0 '0 1 O 0 '0 1 0 0 0 20 0 '0 2 0 0 :0 2 0 0 .O 2 0 FT O 3 4 FT 0 3 4 FT 0 3 4 FT O 3 4 FT 0 3 4 FT 0 3 4 HR 0 2 4 HR 0 4 4 DEGF 0 I 4 DEGF O I 4 0 2 20 0 2 20 LB/G 0 2 4 CP O 2 4 0 2 ,4 0 2 ,4 OHHM 0 2 4 OHHM 0 2 4 DEGF 0 2 4 O 2 12 0 H Fl M 0 2 4 CODE 65 65 65 6.,5 65 65 65 65 65 65 68 65 65 65 79 68 65 '79 65 65 65 65 65 6,5 68 68 68 68 6@ 68 65 68 68 68, 68 68 6,5 68 Page ERROR INFORMATION RECORDS Page H N E M MCST HCS~S CS BS CONTENTS ,.-'7. 000 .................................................. biEAS ............................................. 9.{325 ................................................... 8,500 ................................................... UNIT DEGF TYPE CATG SIZE 4 i2 4 4 CODE 65 68 68 ERROR COMMENT RECORDS h.~ll Location Comment Well Location Commmnt W,ill I._ocmtion Comment Well Location Comment i.,.;,=~ll File Comment 1: l.,.l~ll Film Comment 2: t.,iall File Comment 3: SURFACE: 2538' CHLORIDES = 2700 FNL & 120' FWL THIS L. I PPM. HRI,ML,SDL?DSN RUN IN COMBINATION. TRPE CONTAINS COLVILLE DISTRIBUTION DATA ONLY. Well File Comment 4: ;+:* LIS tape written by: ANCHORAGE COMPUTING CENTER ~:~ All curve and tool mnemonics used are those which most closely match :+:~ Halliburton curve and tool mnemonics, HALLIBURTON TO SCHLUMBERGER TOP BOTTOM MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT 3325.00 6910,00 GR SDL GAPI GR SDL GAPI 3327.00 6905,00 FDSN DSN2 CPS FDSN DSN2 CPS 3327.00 6905.00 HDSN DSN2 CPS NDSN DSN2 CPS 3327,00 6905.00 HPHI DSN2 DECP HPHI DSN2 DECP 3327,00 6905.00 NEAT DSN2 C/C NEAT DSN2 C/C 3327.00 6905,00 OPE SDL DPE SDL 3327.00 6905,00 DPHI SDL DECP DPHI SDL DECP 3327..00 6905.00 DRHO SDL G?C3 DRHO SDL G/C3 3327.00 6905.00 FSDL SDL CPS FSDL SDL CPS 3327,00 6905,00 Page NSDL PE PELC QL QS QPE RHO8 M I N V MHOR CALl HDR HDX HMR Ht',IX HDRS HMRS HDCH HMCN DFL SP TENS SDL ~DL SDL SDL SDL SDL SDL ML HL SDL. HRI HRI HRI HRI HRI HRI HRI HRI HRI HRI SDL CPS G/C3 OHMM OHMM IH OHMM OHNM MMHO MMHO OHMM MV NSDL PE PELC QL QS QPE RHOB MINV HNOR CALl HDR HDX HHR HMX HDRS HMRS HDCN HMCN DFL SP TENS SDL SDL SDL SDL SDL SDL SDL ML ML SDL HRI HRI HRI HRI HRI HRI HRI HRI HRI HRI SDL CPS G/C3 OHMM OHMM IH OHMM OHMM MMHO HMHO OHMM M9 LBS 3327,00 3327. O0 3327. O0 3327,0'0 3327,00 3327.00 3327,00 3327.00 3327.00 3327..00 3327,00 3327,00 3327,00 3327,:00 3327,00 3327,00 3327,80 3327,00 3327.0'0 3327,00 3327,00 6905 O0 6905 O0 6905 O0 6905 O0 6905 O0 6905 O0 6905.0]3 6905,80 6905.0 0 6905. O0 6905. O0 6905. O0 69 O5. O 0 6.'905. O0 6905,00 6905. O0 6905. O0 6905.00 6905. O0 6905 , O0 6905 · O O DLOD GR1 ILMi ILD1 ClL. Di SGRDi TENSl SDL DILT DILT DILT DILT DILT DILT LBS GAPI OHMM OHHH MHHO OHMM LBS COM'MEN DLOD SDL GR DILT ILH DILT ILD DILT CILD DILT SGRD DILT TENS DILT T RECORDS LBS 3327, O0 6905, O0 ISRPI 3327,.0'0 6905. O0 OHHH 3327. O0 6905. O0 OHMH 3327, O0 6905. O0 I'IHHO 3327,00 6905,013 OHMH 3327. O0 G905, O0 LBS 3327. O0 69'05. O0 Page DATA ~-~: · ~ ENTRY BLOCKS EHTRY FORMA T SPEC I F I CA TYPE SIZE CODE 1~ 1 66 0 1 ~ T IONS TYPE DESCRIPTION I6 Datum zpec'i¢ication block sub-t~pe O Terminator ( no more entrie~ ) DATA F'ORMAT SPEC I F I CAT I'ONS DATUM SPECIFICATION BLOCKS **** Page ri N E H SERVICE SERVICE AP1 AP1 AP1 APl FILE iD ORDER # UNIT LOG TYPE CLASS MOD # PRC SIZE LVL SMPL RC PROCESS INDICATORS DEPT ~67697 FT 0 0 0 0 GR SDL 367697 GAPI 94 O 0 i FDSN DSH2 ~67697 CPS 94 0 0 NDSN DSN2 367697 CPS 94 .0 0 NPHi DSN2 3&7697 DECP 94 NRAT DSH2 367697 C?C 94 .0 O i DPE SDL 367697 94 0 0 i DPHI SDL 367697 DECP 94 0 0 DRHO SDL 367697 G/C3 94 '0 0 i FSDL SDL 367697 CPS 94 0 0 1 HSDL SDL 367697 CPS 94 0 0 PE SDL 367697 94 O 0 1 PELC SDL 367697 94 0 0 i QS SDL J67~97 94 .0 0 QPE SDL 367697 94 0 0 i RHOB SDL 36?697 Q?C3 94 .0 O i HiNV HL 367697 OHMH 94' .'0 0 1 HNOR MI. 367697 OHHM 94 .0 0 'i CALl SDL 36?697 IN 94 0 O '1 HDR HRi 367697 94 0 0 i HD× HRI 36?69? 94 .0 0 1 HHR HRI 367697 94 0 0 '1 HHX ttRI 367697 94 0 0 '1 HDRS HRi 367697 OHHH 94 0 0 1 HHRS HRI 367697 OHHH 94 ;0 0 1 HDCN HRi 367697 HHHO 94 0 0 HMC:N HRI 367697 MMHO 94 0 0 DFL HRi 367697 OHHH 94 0 0 1 SP HRI 367697 HV 94 0 0 TENS 3DL 36?69? LBS 94 0 0 i DLOD 9DL 367697 LBS 94 0 0 GR D[LT 36?697 GRPI 94 0 [L.H DILT 36769? ONHH 94 0 0 [LD DILT 367697 OHHH 94 .0 0 1 C[LD DILT 36?69? MHHO 94 0 SGRD DILT 367697 OHHH 94 0 0 TENS DiLT 36?69? LBS 94 0 0 1 1 4 0 1 68 0 4 0 1 68 0 4 0 i 68 0 4 0 I 68 0 4 0 i 68 0 4 0 i 68 0 4 0 i 68 0 4 0 1 68 0 4 0 1 68 0 4 0 i 68 0 4 0 I 68 0 4 0 1 68 0 4 0 1 68 0 4 0 I 68 0 4 0 1 68 0 4 0 1 68 0 4 0 1 68 0 4 0 1 68 0 4 0 1 68 0 4 0 1 68 0 4 0 i 68 0 4 0 i 68 0 4 0 i 68 0 4 0 1 68 0 4 0 1 68 0 4 0 1 68 0 4 0 i 68 0 4 0 1 68 0 4 0 1 68 0 4 0 t 68 0 4 0 1 68 0 4 0 t 68 0 4 0 1 68 0 4 0 1 68 0 4 0 1 68 0 4 0 1 68 0 4 0 i 68 0 4 0 1 68 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 00.0000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000.00.0 000000 000000 000000 000000 000000 0,0000'0 000000 000000 000'000 0000.00 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 .000000 000000 000000 000000 000000 000000 0.00000 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 000000 000000 000000 000000 000000 DA TA RECORDS 6905. 000 ,034 2,440 -i 2345. 000 94.96? 6900. 000 ,034 2.440 94.96? 8800, '000 .04~ 2.4:~6 5,263 81 ,594 104 6427 i -12345 2 104 6427 i 2 2 9-0 6755 4 5 4 6938 2 2 68 0274 14 8886 i l 'i 6700, 000 , 2,403 99,750 .463 ,2i7 ,390 .000 .120 .463 ,217 ,390 ,075 ,120 ,676 ,550 .935 ,i78 ,570 .316 ,438 ,li2 ,594 ,535 .130 · I 05 ,378 ,639 ,010 ,87i .771 ,550 ,449 ,447 2079.432 15933.883 2,063 -12345,000 2.222 2079,432 2,063 478.i66 2,222 2667,922 16178,520 3,94:9 189,99i 4,299 :1680. O11 16197,064 2,10.7 379,658 2,436 2554,974 16583.883 9.580 ~3,646 17,784 1214,743 17951,062 1 ,43i 692.491 i ,450 15511.764 ,357 7,935 0,000 .124 4.7.07 4,386 -,00:9 ,049 -i,O00 8,849 0.000 0.000 0,000 0,000 -12345,000 4,i92 123450000, 4890,829 26.748 450.02i 2.689 125i,820 15511 4 8 48i 450 16795 3 8 i93 232 14374 3 385 4i0 17i69 2 8 56 12899 4 14 690 689 6600, 000 ,023 2,285 15,712 69,130 6500,000 .061 2,161 i . 444 1 00,099 764 .707 ,849 ,827 02i .363 .i40 ,117 ,607 .740 ,874 . '102 .442 ,560 .180 ,505 ,984 ,3'13 ,232 · 357 7,935 O. 000 ,124 4,3:96. -. 008 , 049 -1 , 000 345 . 3[95 85. O12 400,205 35,972 4. 192 i 23450000. 4949,054 26 , 748 2.69i 2780,203 ,292 6,696 O,'O00 .133 3.247 ,060 -..003 -1.000 200,697 43.'038 214,364 17,435 5.838 346,448 4876,273 1471.154 5.405 4759,825 ,414 9.101 0,000 ,147 4,447 .-,023 -,032 -1,000 293.39i 73.579 346.922 36.958 3.i22 350,954 4774,381 1466,696 3.558 4628.820 ,315 7,148 0,000 ,219 3. 022 -, 025. -, 004 -1 , 000 77,717 10, 466 69,284 5,056 16,633 371 ,771 4788,938 1390.909 25. 328 4687,045 .395 . 488 11 , 295 O. 000 ,294 . 676 4 , 787 -, 028 -, 0i7 -1 , OOO .893 455,020 147,729 573. 626 73,304 , 1 04 i ,698 362,573 4745,269 1390,909 .804 2,200 4439.592 Page bEPT DRHO RHOB HDRS GR FSDL HMRS iLM FDSN NSDL MNOR HDCN ILD DA NDSN PE C~LI HNCN C]LD ¸T A RECORDS NPH I PELC HDR DFL SGRD NRAT QL HDX SP TENS DPE HMR TENS DPH! QPE DLOD Pag~ 6400.000 .060 2,30i 2,376 108,5i3 6300,000 -999,250 --999,250 1 .900 242,828 6200,000 -999,250 -999,250 3,329 .--999,250 6100,000 -.'999,250 -999,250 3.625 -999,250 6000, 000 -99'3.. 25 0 --999,25 0 3, 097' · -99'3., 25 0 5900,000 -999,250 -999.250 3,611 -999.250 108,4.33 8586,55 i i , 787 2.4i8 2,225 232. i 41 -999,2_.50 -999,250 i ,9t3 i .956 146,981 -999,250 -999,250 -999,250 1 04, 186 -999,25'0 -999,250 3.543 -999,250 110,136 -999,250 -999,250 3,020 -999,25O 113.170 -999,250 -999,250 3.462 -999,25O 1270,503 17175. i, 974 420,864 2,084 -999,250 -999,250 -999,250 52.6.290 i. 91'1 -999,250 -999,250 -999,250 300,387 -999,250 -999,250 -999,250 -999,250 275,853 -999,250 -999,250 -999,250 -999,250 322.859 -999,250 -999,250 -999,250 -999,250 276.917 -999,250 13009. 043 4.004 11 ,495 413.517 479 ,B92 -999.250 -999.250 9.476 522.740 523,206 -999,250 -999,250 ii0.368 297.758 -999,250 -999,250 -999,250 1 O, 6.02 282.226 -999,250 -999.250 -999.250 11 , 296 331,092 -999,250 -999.250 -999,250 10.663 288.824 -999,250 ,495 4.4i8 332,346 2,859 3. 060 -999,250 -999,250 366,860 2.5i2 3.140 -999,250 -999.250 239,099 3,676 -999,250 -999,250 -999,250 198.147 3,557 -99'9,250 -999,250 -999.250 242,359 3. 157 -999,250 -999,250 -999,250 225.240 3.801 -999,250 10.891 ,037 83,042 344.417 4425,036 -999,250 -999,250 96,197 348,501 4301,368 -999,250 -999,250 44.534 361,984 -999,250 -999,250 -999,250 39,246 341,689 -999,250 -999,250 -999,250 47,44i 334,200 -999,250 -999.250 -999.250 40.990 3i7.851 -999.250 0,000 -.024 390.83i 4657.933 -999.250 -999,250 441 ,284 4556.040 -999.250 .-999,250 280.282 4439,592 -999.250 -999,25-0 243,107 4337,700 -999,250 -999.250 290,087 4337,700 -999.250 -999,250 265.792 4206.695 ,209 -i,O00 30.975 i44~.863 -999,250 -999,250 44,252 1377,535 -999,250 -999,250 14.824 i453,322 -999.25'0 -999.250 18,967 1332. 955 -999.250 -999.250 19,876 1270.542 -999,250 -999,250 i6.149 1310.664 DEPT DRHO RHO8 HDRS GR FSDL MIN¥ HMRS ILH FDSN NSDL MNOR HDCN ILD DATA NDSN PE CALl HHCN CiLD RECORDS NPHI PELC NDR DFL SGRD NRAT QL HDX TENS DPE QS HMR TENS DPHI QPE DLOD Page 10 5800. 000 -999.250 -999.25 0 4.670 -999.25 0 5700, .000 -999.25 0 -999,250 3.7:32 -999.250 5600.000 -999.250 -999.250 3,603 -999.250 5500, 000 -- :¢ ~,. 250 -999.25 0 ~. 346 -999,25 0 5400.000 -999.250 -999.250 3.289 -999.250 5300. 000 -999,250 -999.250 3.201 -999.25 0 91.677 -999.250 -999.250 4.650 -999,250 1'09,741 -999,25.0 -999.250 3,561 -999,250 1'04,863 -999,250 .-999,250 3,456 -999.250 103,391 -999,250 -999,250 3,2;39 -999.25-0 124,702 -999.250 -999,250 3,15.0 -999,250 132,805 -999,250 -999,250 3, 1 '09 -999,250 -999,250 -999,250 -999,250 214,154 -999,250 -999,250 -999,250 -999,250 267.975 -999,250 -999,250 -999.250 -999.250 277,550 -999,250 -999,250 -999,250 -999,250 298.849 -999,250 -999,250 -999,250 -999,250 304,011 -999,250 -999,250 -999,250 -999,250 312.450 -999,250 -999 9 215 -999 -999 -999 12 280 -999 -999 -999 289 -999 -999 -999 11 308 -999 -999 -999 t2 317 -999 -999 -999 10 32i -999 ,250 .250 .91I .059 .250 ,250 .250 ,318 .803 .250 ,250 ,250 ,038 ,337 ,250 ,250 ,250 ,912 ,721 ,250 .250 .250 ,028 .468 ,250 250 ,250 ,491 .635 ,250 -999,250 -999.250 177.546 4.888 -999,250 -999,250 -999.250 219.333 3.74i -999,250 -999.250 -999.250 225.450 3,745 -999,250 -999,250 -999,250 239,863 3,384 -999.250 -999,250 -99'9,250 246. 720 3,135 -999,250 -999,250 -999,250 244,098 3. 332 -999,250 -999,250 -999.250 29,308 333,058 -999,250 -999.,250 -999.250 42.291 326.120 -999.250 -999,250 -999,250 45. 066 324,466 -999,250 -999,250 -999,250 50,366 34.1,216 -999,250 -999,250 -999,250 50,908 ,350.745 -999,250 -999.250 -999,250 49.718 360.686, -999.250 -999,250 -999.250 204.677 4133.915 -999,25:0 -999.250 259.849 4104.803 -999,250 -999.250 266,323 4090,247 -999.250 -999.250 285.345 4002.911 -999. 250 -999,250 294,251. 4046,579 -999.25'0 -999,250 291. 936 3828.238 -999,250 -999,250 I i, 977 1306,206 -999,250 -999.250 18,103 1288,374 -999,250 -999.250 20,382 1266,084 -999,25'0 -999.250 22,581 1520.192 -999.250 -999.250 21. 138 1368,619 -999,250 -999,250 19,847 1234.878 DEPT DRHO RHOD HDRS ~R FSDL MINV HNRS iLM FDSN NSDL MNOR HDCN ILD DATA NDSN PE CALl HHCN CiLD ~,z00,000 t57.822 -999.250 -999 -999. 250 -999. 250 -999. 250 -999 .... .~99,250 -999. 250 -999. 250 1 0 3, i24 3, Oig 320. 080 33i -999,250 -999,250 -999,250 -999 5100,000 t82,482 -999,250 -99'9 -999.250 -999,250 -999.250 -999 -.999.250 -999.25.0 -999.250 8 2,430 2.336 4il,442 428 .-999.250 -999,250 -999,250 -999 5000.000 J35.855 -999,250 -999 -999.250 -999.250 -999.250 -999 -999.250 -999,250 -999.250 10 1.580 1,489 632,972 671 -999,250 -999,250 -999,250 -999 4900,000 J76,365 -999,250 -999 -999.250 -999,250 -999,250 .-999 -.~.. 250 -999,250 -999,250 i0 3.769 3,665 265,348 272 --999.250 -999,250 -999,250 -999 RECORDS NPHI PELC HDR DFL S~RD .250 -999.250 .250 ,800 257.i01 .227 3,192 ,250 -999,250 ,250 -999,250 ,250 -999,250 .898 346,459 .124 2,572 ,250 -999.250 .250 -99'9,250 .250 -999.250 ,399 425.081 ,485 i,445 ,250 -99'9.250 ,250 -999,258 ,250 -99'9,250 .928 233.490 .846 4.018 ,250 -999,250 4800..000 90,742 -999,250 -999,250 -999.250 --999.250 -999.25.0 -999.250 -999.250 -999.250 .-999,250 -999,250 -999,250 9,908 263,~95 3.162 2,978 316,236 335.848 2.476 -999.250 -999.25.0 -999.250 -999,250 -999.250 4700 -999 -999 2 -999 101 .416 -999.250 -999,250 2.100 -999,250 -999,250 -999,250 -999,250 444.444 -999,250 -999.250 -999,250 1 0.206 476.2'00 -999.250 -999,250 -999.250 333.888 2.077 -999.250 ,000 .250 .250 .250 ,250 NRAT QL HDX SP TENS -999,250 -999.250 49.602 328,560 -999,250 -999,250 -999,250 96,141 340.047 -999.250 -999,2S0 -999.250 126,651 321,779 -999.250 -999,250 -999,250 50.995 338.385 -999,25'0 -999,250 -999.250 61,t39 335,858 -999.250 -999,250 -999,250 88,093 341 ,395 -999,250 DPE QS HMR TENS : -999,250 -~.~50 309,i50 3930.i30 -999,250 -999,25.0 4i8,036 3755,458 -999.25:0 -999,25O 557.555 3726,346 -999,250 -999.250 266,460 3740.902 -999.250 -999,25.0 325,312 3653,566 -999,250 -999,250 428,187 3624.454 DPHI QPE HHX DLOD -':.399,250 -999.250 i8.786 1288.374 Page -999.250 -999.250 40,722 i404.283 -999.250 -999.250 63.i74 1524.650 -999,250 -999,250 19,940 1457,780 -999.250 -999.250 29,832 1431,031 -999,250 -999,250 44,421 1350.787 DATA RECORDS DEPT GR FDSN NDSN NPHI NRAT DPE DPHI DRHO FSDL NSDL PE PELC QL QS QPE RHO8 MINV MNOR CALl HDR HDX HMR HMX HDRS HMRS HDCN HMCN DF.L SP TENS DLOD ~R ILH iI_D ClLD S~RD TENS ~600,000 84,41 0 -999,250 -999. 250 -999°250 -999.250 .3. 302 3. 063 -999,250 -999,250 4500, 000 131 ,27! ~ 250 -999 250 -99'~. 250 -999,250 2.77 0 2, -999,250 -999,250 4400.000 93,9'09 -999.250 -999,250 -999,250 -999,250 2,675 2.43! -999,250 -999,250 4300,:000 t01,4'26 -999,250 -999,250 -999.250 -999,25.0 3.'017 2,663 -999,250 -999,25.0 4200.:000 91,897 -999,250 -999.250 -999,250 -999,250 3,461 3,077 -999,250 -999,250 -999,250 -999.250 -999.250 302,844, -999,250 -999.2.50 -999.250 9.660 326.509 -999,250 -99'9,250 -999.250 -999,250 36i,0i6 -999,250 -999.250 -999.250 9,394 385,590 -999.250 -99'9,250 -999,250 -999,250 373.S52 -999,250 -99'9, :250 -999,250 I O. 522 41 I, 364 -999,250 -999,250 -999,250 -999.250 33i,439 -999,250 -999,250 -999.250 12.0'11 375.529 -999,250 -999,250 -99'9,250 -999,250 288,944 -999,250 -999.25.0 -999.250 10.7.01 324,9e4 -999,250 -999,250 -999,250 -999,250 280.087 -999,250 -999,250 -999,250 10,09.0 316.125 -999.250 4100.000 1-01,565 -999.250 -999.250 -999,250 -999,250 3.570 3,163 -999.250 -999.250 -999.250 -999.250 241 ,7i 1 2,907 -999,250 -999,250 -999.250 279,056 2.604 -999,250 -999,250 -999.250 293,470 2,647 -999,250 -999,250 -999,250 243,649 3,142 -999,250 -999,250 -999,250 240,333 2,629 -999,250 -999,250 -999,250 2i8,850 2.899 -999,250 -999.250 -999,250 52.299 345,59@ -999,250 -999,250 -999,250 63,879 347.433 -999,250 -999,250 -999.250 73,451 331.207 -999,250 -999,250 -999,250 56.294 341,744 -999,250 -999,250 -999.250 53,943 333,092 -999,250 -999,256 -999.25.0 41,414 337,592 -999,250 -999.250 -999.256 298.070 3522,562 -999,250 -999,250 347,503 -999,25'0 -999,250 374,359 3.085.880 -999.258 -999,250 329.579 3042,212 -999,250 -999.250 3.03,519 3173,2'16 -999,250 -999,250 279,276 2925.764 Page 12 -999,250 -999,250 24,994 1422.i15 -999,250 -999.250 30.792 1337.4i3 -999,250 -999,250 36,427 1377.535 -999,250 -999,250 2:9,9S6 '127 0. 542 -999,250 -999.250 25.895 1279,458 -999,250 -999,250 20,613 1292.832 DEPT DRHO RHOB HDRS ~R GR FSDL HIHV HMRS FDSN NSDL MNOR HDCH ILD DA NDgN PE CALI HHCN CiLD 'T A RECORDS NPNI PELC HDR DFL NRAT QL HDX TENS DPE QS HHR TENS DPHI QPE DLOD Pagm 13 4000,000 -999,250 -999,250 4,087 -999,250 3900.000 -999,250 -999,250 3,907 -999.250 S800,000 --999.250 -999,250 4,409 -999,250 JTO0,O00 -999,250 -999,250 5.208 -999,250 ,3600,000 -999,250 -999.250 8,243 -999.250 JSO0.O00 -999,250 --999,250 5.746 -999,250 t 05.123 -999.250 -999.250 3.681 -999.250 102.295 -999,250 -999.250 3.444 -999.25.0 104.429 -999.250 -999,250 3,972 -999,250 102,069 -999,25.0 -999.250 4.464 -999,256 74,145 -999,25 0 -999,25.0 6.,366 -999.250 107.378 -999,250 -999,250 4,830 -999,25!3 -999.250 -999.250 -999.250 244.702 -999,250 -999.250 -999,250 -999,250 255.95i -999.250 -999,250 -999,250 -999,250 226,790 -999,250 -999,250 -999.250 -999,250 192.029 -999.250 -999,250 -999.258 -999.250 121.310 -999.250 -999.250 -999.250 -999.250 174.031 -999.250 -999,250 -999.250 10.858 271.677 -999.250 -999.250 -999.250 290.389 -999,250 -999.250 -999.250 tt.025 251.777 -999,250 -999,250 -999.250 11.013 224.032 -999.250 -999,250 -999.250 10.288 157.084 -999.250 -999.250 -999.250 1 I , 992 207.048 -999.250 -999,250 -999.250 205.462 3.332 -999.250 -999.250 -999.250 205.~-~ 3.089 -999,250 -999,250 -999.250 i90.677 3.607 -999.250 -999.250 -999.250 165.226 3.655 -999.250 -999,250 -999,250 92,216 5.i21 -999,250 -999,250 -999 2= 147,542 4,260 -999,250 -999 -999 40 334 -999 -999 -999 39 333 -999 -999 -999 35 327 -999 -999 -999 320 -999 -999 -999 12 313 -999 -999 -999 21 299 -999 .250 .250 .973 .1 79 .250 .250 ,250 .I 90 .911 .250 .250 .250 ,138 ,i72 .250 .250 ,250 .084 ,585 ,250 .250 .250 .529 . '184 .250 .250 ,250 .418 .883 .250 -999,250 -999.250 260,297 2896.652 -99'9.25'0 -999.250 262,099 2852.983 -999.25.0 -999. 250 244.558 2969.432 -999.250 -99'9.258 215.347 2663.755 -999.250 -999.250 125.278 2547.307 -999.250 -999,258 191 .757 2547.307 -999.250 -999,250 i8,722 1234.878 -999.250 -999.250 19.689 i185.839 -999.250 -999.250 i5.383 1306,206 -999.250 -999,250 10.240 1168,007 -999,250 -999,250 4.421 t154.633 -999,250 -999.250 13,882 1087.763 DEPT DRHO RFIOB HDRS 3400. 000 -999,250 -999.250 3,48? -'999.250 ~R FSDL MINV HMRS ILM 71 ,919 -999. 250 -999.250 3. 047 -999,250 DATA RECORDS FDSN NSDL MNOR HDCN ILD NDSN PE CALI HHCN CILD NPHI PELC HDR DFL S~RD NRAT QL HDX SP TENS DPE .QS HMR TENS -999.250 -999,250 -999,250 286.745 -999.250 -999,250 -999.250 i I . 088 528. i 92 -999.25,0 -999,250 -999,250 207,855 2,i58 -999.250 -999.250 -999.250 32.0~31 308.366 -999,250 -999,25.0 -999,250 266. i 77 2576.419 DPHI QPE HNX DLOD Page 14 -999,250 -999,250 13,183 1217. 046 FiLE TRAILER Film name: &G5FO~ . Haximum length: ~024 TRAILER RECORDS Service name: File type: LO Version #: Next ¢ile: Date: Page 45 · ~.:** FiLE HEADER Fi le name: ,0'02 Service name~ Version Date: Haximum length: 1024 File type: LO Previous ?lie: H N E I'1 CN FN COUN STAT CTRY AP Iii LATI LOHG SECT TOtJN RANG EKB EOF EGL. PD LbiF DMF RUH T It,lE DATE LOC SOH L U H FL LUL ENGI W DD DL CBDi. CSL1 TLi 8Li TCS TLA8 8HT MAT MT HSS DFD MV]S DFPH bFL RN RbiF MFST HFSS RHC I NFOR'MAT I ON RECORDS COHTENTS ARCO ALASKA INC. 3G-Ii API KUPARUK RIVER DATE LOGGED: NORTH SLOPE ................. ALASKA ................. USA 20133.000 ............................ 0 Deg, 0 ~in, O. O S~c. N ..... 0 Deg. 0 Min. O, 0 Smc. W ..... I2N ........ ; ..................... 0SE .............................. 89.000 ........................... 88,000 ............................ 53.000 ........................... ~S , , . .., . , . , ~ , . , ~ . , , ' . ' ' iiIIlilllIIlll$l*lllII I .II ilIlIIilI 2100.000 ........................... 27/ 7790 ........................... 30,.~....,...,,.'.'''' 367697 ............................ 51939 ........................ ',' NORTH SLOP~ .................. NORTH ~LOPE ............. . ..... ADDISON .................. LOWEN .................. 6900,00'0 .............................. 6893.000 .............................. 3354.000 ............................... 3345,000 ............................... 3327,000 ............................... 6884,000 ............................... i600, OOO ............................... 21 00. 000 ............................... li7.000 ................................ I 17.000 ................................ LSND ................... CIRCULATED 10.800 ....... 48,000 ....... 8,000 ........ 5,700 ........ 1 .730 ........ 1 ,300 ........ 77,000 ....... HEAS, . 2,270 ........ mmm mlwmwmmmImmmmm'm lit iIllII$.IImllIll IliillllIIlIlIIlIIIl iliIilIlIIIlIIIlIlII IIilliiIIIIIIIlIIIlllIII m 50-103-20133, u,,-zr-,~ u. mmmlmmlmmlmllmlfmlm immm m . . · mi smm ammm~, imimii . I m · Imm,Il m m ~ ~ m m I I I I I · I i I · i m m . m m · i I m , . m imlmmIlIII .illmWllilmmlmlII UNIT TYPE CATG SIZE 40 40 40 20 20 20 4 34 34 2 3 3 4 4 4 2 2 2 2 4 8 2 10 10 20 20 20 2O 4 4 4 4 4 4 4 4 4 4 20 20 4 4 4 4 4 4 4 12 4 CODE 65 65 65 65 6,5 65 Ge 65 6,5 65 65 68 68 68 65 65 65 79 68 65 79 65 65 65 65 65 6,8 68 68 6,8 68 68 68 G5 65 6,8 6,8 68 68 6,8 68 65 68 Page ERRO'R 1¸6 L: 5 BS I NFORMAT I ON RECORDS CONTENTS UNIT ??. 00'0 .................................................. I'IE~S ............................................. 9,625 ................................................... 8,500 ................................................... DEGF TYPE CATG SIZE 4 4 4 CODE Page ERROR 17 'COMMENT RECORDS Well L Wall L Well L Well L !del 1 Fi ;.del I Fi tdell Fi Wel I Fi · r. ;~ :~ :~ ~: *:~ ocation Comment 4: SURFACE: 2538' FNL & 120' FWL ocation Comment 2: ocation Comment 3: ocation Comment 4: la Comment ~: CHLORIDES = 2700 PPM. HRI,ML,SDL?DSN RUN IN COMBINATION. le Comment 2: THIS L.I.S. TAPE CONTAINS COLVILLE DISTRIBUTION DATA ONLY. le Comment 3: le Commant 4: LIS tape written by: ANCHORAGE COMPUTING CENTER All curve and tool mnemonics used are tho~e which Halliburton curve and tool mnemonics. most clo~el.~ match HALLIBURTON TO SCHLUMBERGER TOP BOTTOM MNEM SERVICE .UNIT MNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT 3325.00 6910,00 GR2 SOL GAPI GR SDL GAPI 6295.00 6905,00 FDSN2 OSN CPS FDSN DSN CPS 6295.00 6905.00 NDSN2 DSN2 CPS NDSN DSN2 CPS 6295.00 6905,00 NPHI2 DSN2 DECP NPHI DSN2 DECP 6295.00 6905.00 HRAT2 DSN2 C?C NRAT DSN2 C?C 6295,00 6905,00 DPE2 SDL DPE SDL 6295,00 6905.00 DPHI2 SDL DECP DPHI SDL DECP 6295,'00 6905.00 DRH02 SDL G?C3 DRHO SDL G?C3 6295,00 6905.00 FSDL2 SDL CPS FSDL SDL CPS 6295,00 6905,00 Page 18 NSDL2 PE2 PELC2 QL2 QPE2 RHOB2 M I NV2 HHOR2 CALI2 HDR2 HDX2 HMR2 HHX2 HDRS2 HHP..$2 HDCN2 HHCN2 DFL2 SP2 TENS2 SDL SDL SDL SDL SDL SDL SDL HL HL SDL HRI HRI HRI HRI HRI HRI HRI HRI HRI NRI SDL CPS G/C3 OHMM OHMM IN OHMM OHMH MMHO MHHO OHMM MV LBS NSDL PE PELC QL QS QPE RHOB H I NV MNOR CALI HDR HDX HMR HMX HDRS HHRS HDCN HMCN DFL SP TENS SDL SDL SDL SDL SDL SDL SDL HL ML SDL HRI HRI HRI HR I HRI HRI HRI HRI HRI HRI SDL CPS G,..'C3 OHHH OHMM IN ONMM OHHM MMHO MMHO ORMM MV 6295, O0 6295, O0 6295, O0 6295. :00 6295. O0 6295. '00 6295, 6295,80 62'95, O0 6295, 6295. 6295, O0 6295,00 6295.80 6295,0'0 6295. O0 6295, O0 6295,0 6295. 'OO 6295, O0 6295. O0 6905, O0 6905 O0 6905 O0 6905 O0 6905 O0 6905 O0 6905 O0 6905. O0 6905, O0 6905. O0 69 05, O O 6905.00 6905..00 69'05.0'0 69'05, O0 69 05.00 6905. O0 6905. '00 6905, OO 6905.00 6905, O0 DLOD2 ILD~ CILD~ SGRD] TENS] SDL DILT DILT DILT DILT DILT DILT LBS GAPI OHMM OHMM MMHO OHMM LBS C O M M E N T DLOD SDL GR DILT ILM DILT ILD DILT CILD DILT SGRD DILT TENS DILT RECORDS LBS 6~95,.00 69.05 , O0 GAPI 6~95. O0 69'05, O0 OHMM 6295. O0 6905. O0 OHMM 6295. O0 6905, O0 MMHO 6~95, O0 6905. O0 OHMM 6295. O0 ~905 . O0 LBS 6~95. O0 6905. O0 Pag~ 19 DA~TA FORMAT ~: *.'~' ENTRY BLOCKS ***~ E i'.-I T R Y TYPE 16 0 SIZE :-~':** ENTRY BLOCK LEGEND **** TYPE DESCRIPTION 16 Datum zpeci¢ica.tion 0 Terminator ( no mor~ block sub-type mntriez ) SPECIFICA CODE 66 T I ONe~, Page 2O D A T A 0 R M.A DATUM SPECIFICATION BLOCKS ~ :+:. :+: :{< :+: :{z :+: :{.: * :.1-: :~: ~ :{~ :{< :~: ~ :~ ~ ~ :+: :~ :~, ~ ~ ~ ~ :~ :+:, ~ ~ :+: ~, :~ :~ T SPEC I F I CA T I O'N S Page 21 MNEM SERVICE SERVICE APl API APl API FILE ID ORDER # UNIT LOG TYPE CLASS MOD # PRO # SIZE LVL SMPL RC PROCESS INDICATORS DEPT 367697 FT .0 0 0 0 2 dR SDL 367697 GflPI 94 0 0 3 FDSN DSN 367697 £PS 94' O 0 3 NDSN DSH2 367697 ~PS 94 0 0 NPHi DSN2 367697 DECP 94 0 0 3 i NRRT DSN2 367697 C/C 94 0 0 3 i DPE SDL 367697 94 'O 0 3 DPHI SDL 367697 DECP 94 0 0 3 1 DRHO SDL 367~97 G?C3 94 0 0 FSDL SDL 367.697 CPS 94 :0 0 NSDL SDL 367697 CPS 94 0 0 3 1 RE SDL 367697 94 0 0 3 1 PELC SDL 367697 94 0 0 3 1 ~L SDL 367697 94' O 0 3 1 QS SDL 367697 94 0 0 3 1 ~PE SDL 367697 94 O 0 3 1 RHOB SDL 367697 G/C3 94 0 0 J 1 MINV ML 367697 OHMM 94' O 0 3 I HNOR ML 367697 OHMM 94 0 .0 3 1 CALi SDL 367697 IN 94 0 0 3 1 HDR HRi 367697 94 ~0 0 3 i HDX HRI 367697 94 0 0 3 1 HMR HRI 367697 94 0 0 3 1 HHX HRI 367697 94 0 0 3 1 HDRS HRI 367697 OHMM 94 0 0 3 1 HMRS HRI 367697 OHMM 94 0 0 3 1 HDCN HRi 367697 MMHO 94 0 0 3 1 HMCN HRI 367697 MMHO 94 0 0 3 I DFL HRI 367697 OHMM 94 '0 0 3 1 SP HRI 367G97 MV 94 :O 0 3 1 TENS SDL 367697 LBS 94 0 0 3 1 DLOD SDL 367697 LBS 94 0 0 GR DILT 367697 GAPI 94 0 0 3 1 ILH DILT 367697 OHMM 94 0 0 3 1 ILD DILT 367697 OHMM 94 0 0 3 1 CiLD DIL'F 367697 MMHO 94 0 0 3 1 SGRD DILT 367697 OHMM 94 O 0 3 I TENS DILT 367697 LBS 94 0 0 3 1 4 0 1 68 4 0 1 68 4 0 1 68 4 0 I 68 4 0 i 6'8 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 .:l- 68 4 0 1 68 4 0 t 68 4 0 I 68 4 0 1 68 4 0 1 68 4 0 I 68 4 0 I 68 4 0 '1 68 4 0 I 68 4 0 1 68 4 0 i 68 4 0 ~ 68 4 0 1 68 4 0 I {38 4 0 I 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 I 68 ,4 0 I 68 4 0 I 68 4 0 1 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 000000 0000'00 000000 000000 000000 000000 O00OO0 O0000O 000000 000000 0000'00 000000 OOOO00 O00000 000000 000000 O00OO0 000000 000000 000000 000000 000000 0'00000 000000 000000 OOO000 000000 00000,0 0000.00 000000 OOOO00 OOO000 000000 000000 0.00000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 00'0000 000000 000000 000000 000000 0000.00 000000 000000 000000 000000 OOOO00 000000 000000 000000 000000 000000 000000 '000000 O0000O 000000 000000 .000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O0.O000 000000 00000.0 00'0000 000000 00000'0 'O0000O 000000 000000 O0000O 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O00OO.O 000000' 000000 000000 000000 000000 000000 000000 DATA RECORDS DEPT GR FDSN NDSN NPHI NRAT DPE DPHI DRHO F~DL NSDL PE PELC QL Q~ QPE RHOB HINV MNOR CALI HDR HD~ HMR HDR~ HMR~ HDCN HNCN DFL ~P TEN~ DLOD ~R iLM iLD CiLD 8~RD TEN9 000 044 455 .000 250 .00 0 044 455 000 '225 000 028 415 32.3 000 037 4'00 000 027 293 297 5O4 000 O42 1319 436 36,5 1 08.618 6367.217 3. 795 -12345. OOO -999.250 I08.618 6367.217 3. 795 2 0 0 00. 0 0 O :2. 142 91. 291 6712.43~3 4.673 5,285 4.6'03 98,991 6961 ,661 ;3.010 2. 608 2. 559 71. 674 8203.66 0 7.678 14.453 18. 021 90.909 I 1 O27. 994 1 , 567 1 .442 1 .443 6905. . 2, -12345. 6900, , 2, 20000. 71, 6800, , 2, 5, 80, 6700. ! 2, 2, i00, 6600, . 2, 15, 69, 6500, . 2. 1. 99. 2039.771 15275.102 .357 7. 965 0.000 16008. 883 4 . 941 5. 295 - . 048 0 . 000 i , 996 8. 933 O. 000 O, 000 O, 000 -12345. 000 -12345. 000 . 014 123450000. 4861 .7i7 -999. 250 -999.250 -99'9. 250 -999. 250 2039.771 15275.1:02 .357 7.965 O, 000 16:008. 883 4.941 5. 295 -.048 O. 000 1 .996 8.933 O. 000 0,000 0.000 .050 .050 .014 123450000. 4876.273 2. 234 447.61 0 2.677 2547. 307 2519. 021 16651 .586 .308 7.031 0.000 15982.246 3.13i 3.8i 1 ..003 .004 4. 059 :3.979 2.00. 767 42.384 214. 005 187.868 189,202 5. 857 354. 575 4876. 273 4. 359 229. 400 5. 394 4716. 157 1656.773 14452.922 .425 9.279 O,O00 16219. 791 4. 104 4. 886 -. 0i2 -. 0'0") 2. 185 9. 098 293. 826 72..712 346.953 377. 942 383. 421 3. i38 359. 928 4672.488 2. 453 407. 662 3. 552 4628.820 2543.37;' 17147.~91 ..316 7.171 O, OO'O 16594. 609 2.890 3.5'03 .005 -. 018 9. 092 8. 984 79. 216 1 O. 224 69. 893 65. 372 69. 188 16. 390 .363.948 4934. 498 17. 152 58.301 21 . 760 4614.265 1207. 792 12967. 236 .499 11 . 420 O, O00 17734,156 4,467 4,836 ,014 ,023 1 . 442 14. 729 456. 789 147. 444 574. 520 696.286 693. 654 1.703 365.295 4701.601 1 . 443 693.204 2. t82 4425. 036 Page 22 .116 -i.O00 0..000 31.206 .116 -1,000 0,000 35.664 .140 -1.000 17.255 2215.647 .149 -1.000 36.413 1716.347 .214 -1.000 4.987 1801,049 ,3'09 -1,000 72.884 1488,986 DATA RECORDS · DEPT GR FDSN NDSN NPH I NRAT DPE DPH I DRHO FSDL NSDL PE PELC QL QS QPE RHOB M'I NV MNOR CALI HDR HDX HHR HMX HDP, S HMRS HDCN HHCN DFL SP TENS DLOD GR ILM ILD CILD SGRD TENS ,000 .068 ,299 ,357 .628 ,000 ,250 .250 ,250 ,OiO 6400 I 03. 682 8765,660 1 ,618 2.386 2,254 -999,2.50 -999,25 O -999,250 -999,258 .I , 949 1263,430 17315,973 1,952 424,266 2,122 -999,250 -999,250 -999,250 -999,250 i .896 13034,363 4,065 11,394 419,046 47t .286 -999,250 -999,250 -999.250 -999,250 527,584 6300 -999 -999 -999 238 · 501 1 O, 974 O, OOO , 21 0 4. 490 -, 001 , 0'05 -1 , 000 333,311 82,714 39i ,993 31 , 055 2,859 344,945 4687,045 1502,360 3. 067 4439. 592 Page 23 -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 3,105 4352,256 File name: &GSF'01.002 Haximum length: 1024 TRAILER RECORDS Service name: File type: LO Version Nmxt ~ilm: Bate: Page 24 REEL TRAILER Service name: &GSFOi Next rem 1: Date: gO?,OS?OJ Origin: Comments: Reel name: 36,769 ? Continuation TAPE ~ TRA.-ILER omrvicm name: &GSF01 Next tape: Date: 90/08/03 Origin Commcntz: Tape name: ~67697 Continuation if: 01
