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Home My WebLink About186-137 !"##$ % & '( )'*++,( )'( ) -( . /",0"*+1-2%34*5) ) ! ' ! ( )+( 16 '!+$7 )8 ! ) ( ' !5/ - 4$#*4) 9 / (- .! ( ( -( . / Digitally signed by Stephanie Pilch DN: C=US, O=CPAI, CN=Stephanie Pilch, E=stephanie.r.pilch@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-07-27 09:23:16 Foxit PhantomPDF Version: 9.7.0 Stephanie Pilch 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured feet feet true vertical feet feet Effective Depth measured feet feet true vertical feet feet Perforation depth Measured depth feet True Vertical depth feet Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 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 Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: 2. Operator Name: Senior Pet. Engineer: Senior Res. Engineer: CollapseBurstTVDLengthCasing Authorized Signature with date: Authorized Name: 5. Permit to Drill Number: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf measuredPlugs Junk measured STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl measured true vertical Packer WINJ WAG Water-Bbl MD 15. Well Class after work: Exploratory Development Service Stratigraphic 16. Well Status after work: Oil Gas W DSPL a GSTOR GINJ SUSP SPLUG 5.070, 25.071, & 25.283) J G Plug Perforations Fracture Stimulate Pull TubingOperations shutdown Perforate Other Stimulate Alter Casing Change Approved Program Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory StratigraphicService 6. API Number: mber): 8. Well Name and Number: onic data per 20AAC25.071): 10. Field/Pool(s): ry: ured feet feet ticalfeet feet ured feet feet ticalfeet feet epth feet epth feet true vertical depth) d and true vertical depth) summary: lumes used and final pressure: tion: ion: CollapseBurstTVD 5. Permit to Drill Number: Size Gas-Mcf g Ju easu ed 4. W ell Class Before W ork: Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl ue e ca W ater-Bbl MD Form 10-404 Revised 3/2020 Submit Within 30 days of Operations ConocoPhillips Alaska, Inc PO Box 100360 Anchorage, AK 99510 186-137 50-029-21631-00-00 ADL0025519, ADL0025629 KRU 3K-14 n/a Kuparuk River Field/Kuparuk River Oil Pool 8960 6943 8559 n/a 8775 6794 8548 6616 Conductor 77 16" 115 115 Surface 4713 9-5/8" 4750 3299 Production 8905 7" 8940 6928 8648-8750 6694-6774 2-7/8" J-55 8574' MD 6636' TVD Camco HRP-1-SP Packer 8548' MD 6616' TVD n/a n/a n/a n/a 320-211Stephanie Pilch Well Integrity & Compliance Specialist Stephanie Pilch/Sara Carlisle n2549@conocophillips.com (907) 659-7126 IA SCP - Secure ✔ ✔ ✔✔ ✔ Digitally signed by Stephanie Pilch DN: C=US, O=CPAI, CN=Stephanie Pilch, E=stephanie.r.pilch@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-07-27 09:23:56 Foxit PhantomPDF Version: 9.7.0 Stephanie Pilch By Jody Colombie at 10:25 am, Jul 27, 2020 DSR-7/27/2020 SFD 7/28/2020 RBDMS HEW 7/27/2020 VTL 8/12/20 !"#$ %& ' % % %() (%'*%++&&,-* ' '%+ *' )%(% ' *)++$*)++)%' )*%+&*,&%+ !"$ ! 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G*""% "% %# G*$*+ &?16&? -" #? ,? # "? #G%? ? ,* -*%" #$% " &22 -" # *#+ *+ " *" , 12 #" " $ &C # + , #" * + " #6%, 0 &14 (? *" C ,*- -*%-* ,, , 0 & (? "% # "D ##" G - ,*"* ( , **# * " ! *% **#% #$% ! "? %" ,** K 1 -%" **#% #$% " ! #$% %"*? " % ! %" ,** %"K? %K? 4 %K # "*" Last Tag Annotation Depth (ftKB) End Date Last Mod By Wellbore Last Tag: RKB (Tag Scale in Tbg) 8,494.0 5/22/2020 zembaej 3K-14 Last Rev Reason Annotation End Date Last Mod By Wellbore Rev Reason: Set RBP 6/27/2020 famaj 3K-14 Notes: General & Safety End Date 1/9/2003 Annotation NOTE: WAIVERED WELL: IA x OA COMMUNICATION Wellbore 3K-14 End Date 11/2/2010 Annotation NOTE: Mandrel @ 8484 - Flow cut mandrel w/ extended packing, damaged by erosion, ext pkg dmy sealing Wellbore 3K-14 Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread Wellbore CONDUCTOR 16 15.06 38.0 115.0 115.0 H-40 WELDED 3K-14 SURFACE 9 5/8 8.92 37.0 4,749.9 3,931.0 36.00 J-55 BTC 3K-14 PRODUCTION 7 6.28 35.2 8,939.5 6,927.6 26.00 J-55 BTC 3K-14 Tubing Strings Des String Max Nominal OD (in)ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt (lb/ft) Grade Top Thread Wellbore TUBING 2 7/8 2.44 35.0 8,574.0 6,636.2 6.50 J-55 EUE8rdABMO D 3K-14 Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) Wellbore 35.0 35.0 0.20 HANGER CIW TUBING HANGER 2.875 3K-14 1,792.2 1,774.5 22.14 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.312 3K-14 8,530.0 6,602.4 40.30 SBR CAMCO OEJ SBR 2.312 3K-14 8,547.6 6,615.8 39.99 PACKER CAMCO HRP-1-SP PACKER 2.347 3K-14 8,563.4 6,628.0 39.72 NIPPLE CAMCO D NIPPLE NO GO 2.250 3K-14 8,573.3 6,635.7 39.54 SOS CAMCO SHEAR OUT SUB 2.441 3K-14 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) Wellbore 8,559.0 6,624.6 39.79 PLUG 2 7/8" P2P CPP287054SC w/ Equalizing Valve CPEQ287SC07 and 2' Debris Extension. OAL 7.4' Max OD 2.225" 6/27/2020 0.000 3K-14 8,742.0 6,768.0 37.01 FISH 40 FRAC BALL- 7/8" Diameter Balls used during HYD. FRAC 1988 7/3/1988 3K-14 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) Wellbore 37.0 37.0 0.21 HANGER 8.921 3K-14 38.0 38.0 0.22 CONDUCTOR 15.062 3K-14 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com Wellbore 8,648.0 8,672.0 6,693.7 6,712.5 A-3, 3K-14 6/11/1988 4.0 RPERF Tornado Link Jet; 90 deg 3K-14 8,650.0 8,670.0 6,695.3 6,711.0 A-3, 3K-14 6/13/1996 4.0 RPERF 2 1/8" EJ; 180 deg ph; Orient +/- 90 deg 3K-14 8,662.0 8,663.0 6,704.7 6,705.5 A-3, 3K-14 6/13/1996 1.0 IPERF 2 1/8" Strip; single shot 3K-14 8,666.0 8,671.0 6,707.8 6,711.7 A-3, 3K-14 1/15/1987 1.0 APERF 2 1/8" Strip; single shot 3K-14 8,690.0 8,710.0 6,726.7 6,742.5 A-2, 3K-14 6/11/1988 4.0 RPERF Tornado Link Jet; 90 deg 3K-14 8,696.0 8,697.0 6,731.4 6,732.2 A-2, 3K-14 1/15/1987 1.0 APERF 2 1/8" Strip; single shot 3K-14 8,704.0 8,705.0 6,737.8 6,738.5 A-2, 3K-14 1/15/1987 1.0 APERF 2 1/8" Strip; single shot 3K-14 8,714.0 8,715.0 6,745.7 6,746.5 A-2, 3K-14 1/15/1987 1.0 APERF 2 1/8" Strip; single shot 3K-14 8,719.0 8,720.0 6,749.6 6,750.4 A-2, 3K-14 1/15/1987 1.0 APERF 2 1/8" Strip; single shot 3K-14 8,725.0 8,726.0 6,754.4 6,755.2 A-2, 3K-14 12/26/1986 1.0 IPERF 2 1/8" EJ; single shot 3K-14 8,731.0 8,732.0 6,759.2 6,760.0 A-2, 3K-14 12/26/1986 1.0 IPERF 2 1/8" EJ; single shot 3K-14 8,740.0 8,750.0 6,766.4 6,774.3 A-2, 3K-14 12/26/1986 1.0 IPERF 2 1/8" EJ; single shot 3K-14 Mandrel Inserts St ati on No /S Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com Wellbore 1 2,802.6 2,563.0 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,283.0 12/19/2008 3K-14 2 4,978.5 4,091.9 MERLA TMPD 1 GAS LIFT GLV BK 0.188 1,326.0 12/19/2008 3K-14 3 6,150.2 4,906.1 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 6/12/2020 3K-14 4 6,673.5 5,268.8 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 12/19/2008 3K-14 5 7,135.0 5,593.6 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 7/16/1996 3K-14 6 7,595.7 5,921.8 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 8/12/1998 3K-14 7 8,057.4 6,253.8 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 6/28/1988 3K-14 8 8,483.8 6,567.4 MERLA TGPD 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/5/2002 3K-14 Stimulation Intervals Start Date Proppant Designed (lb) Proppant In Formation (lb) 1/7/1988 00:00 7/18/1996 00:00 Frac Summary Stg # Start Date Top (ftKB) Btm (ftKB) Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) 1 1/7/1988 8,648.0 8,750.0 1 7/18/1996 8,648.0 8,750.0 Comment SSSV: TRDP 3K-14, 6/28/2020 7:36:51 AM Vertical schematic (actual) PRODUCTION; 35.1- 8,939.5 IPERF; 8,740.0-8,750.0 FISH; 8,742.0 IPERF; 8,731.0-8,732.0 IPERF; 8,725.0-8,726.0 APERF; 8,719.0-8,720.0 APERF; 8,714.0-8,715.0 APERF; 8,704.0-8,705.0 RPERF; 8,690.0-8,710.0 FRAC; 8,648.0 RE-FRAC; 8,648.0 APERF; 8,696.0-8,697.0 APERF; 8,666.0-8,671.0 IPERF; 8,662.0-8,663.0 RPERF; 8,650.0-8,670.0 RPERF; 8,648.0-8,672.0 SOS; 8,573.3 NIPPLE; 8,563.4 PLUG; 8,559.0 PACKER; 8,547.6 SBR; 8,530.0 GAS LIFT; 8,483.8 GAS LIFT; 8,057.4 GAS LIFT; 7,595.7 GAS LIFT; 7,135.0 GAS LIFT; 6,673.5 GAS LIFT; 6,150.2 GAS LIFT; 4,978.4 SURFACE; 37.0-4,749.9 GAS LIFT; 2,802.6 SAFETY VLV; 1,792.2 CONDUCTOR; 38.0- 115.0 HANGER; 35.0 KUP PROD KB-Grd (ft) 39.01 Rig Release Date 8/5/1986 Annotation Last WO: End DateH2S (ppm) Date... TD Act Btm (ftKB) 8,960.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292163100 Wellbore Status PROD Max Angle & MD Incl (°) 48.30 MD (ftKB) 4,200.00 Legal Wellname 3K-14 Common Wellname3K-14 AK All Wellbores Schem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y Samantha Carlisle at 8:31 am, May 26, 2020 320-211 Digitally signed by Sara Carlisle DN: OU=Drilling & Wells, O=ConocoPhillips Alaska, CN=Sara Carlisle, E=sara.e.carlisle@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-05-22 21:19:35 Foxit PhantomPDF Version: 9.7.0 Sara Carlisle VTL 6/05/20 10-404 OA SCP DSR-5/26/2020 ADL0025519 DLB NA X DLB 05/26/2020 X X dts 6/5/2020 6/5/2020 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2020.06.05 12:30:59 -08'00' RBDMS HEW 6/9/2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 22 May 2020 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 3K-14 (PTD 186-137) to diagnose and remediate sustained casing pressure of 2400 psi on the inner annulus (exceeding 45% of the burst rating of the production casing) through either repair or secure. Please contact Stephanie Pilch or myself at 659-7126 if you have any questions. Sincerely, Sara Carlisle Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 CPAI Well Integrity & Compliance Specialist Proposal Summary for Troubleshooting High Inner Annulus Pressure 3K-14 (PTD 186-137) Kuparuk River Unit gas-lifted producer 3K-14 was reported for sustained inner annulus (IA) pressure while the well was shut in. The well has live gas-lift valves in the tubing string, so CPAI believes the most likely source of communication to the IA is a malfunctioning or damaged gas- lift valve. The scope of the troubleshoot procedure will be to identify the source of the IA pressurization. This well is historically noted for scale buildup, which may impair initial diagnostics. If scale restricts drift access, the well will be loaded with heavy fluid to reduce the pressure below 2000 psi, a scale clean-up will be progressed, and then diagnostics for continued troubleshooting will re-start. Proposed Overview of Work: 1. Mobilize Slickline to 3K-14. 2. Utilize a holefinder or similar through-tubing equipment to isolate the source of the sustained casing pressure. 3. Replace gas lift valves as necessary to restore integrity to the well. a. If drift access is limited based on scale, attempt to pull a gas-lift valve for a circulation point. b. Circulate heavy fluid to reduce inner annulus pressure below 2000 psi. c. Mobilize coiled tubing as needed to perform scale-removal intervention to re- gain drift access needed. 4. If it is determined that the sustained casing pressure has a cause other than a gas lift valve, continue diagnostics based on these findings or progress interventions to secure the well. 5. When annulus pressure indicates that integrity has been restored or the well has been mechanically secured, continue normal daily surveillance of the annular pressure. 6. Submit 10-404 to AOGCCC. Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 8,724.0 6/1/2013 3K-14 osborl Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Replaced OV 4/28/2019 3K-14 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 38.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l…Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 37.0 Set Depth (ftKB) 4,749.9 Set Depth (TVD) … 3,931.0 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.2 Set Depth (ftKB) 8,939.5 Set Depth (TVD) … 6,927.6 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 2 7/8 ID (in) 2.44 Top (ftKB) 35.0 Set Depth (ft… 8,574.0 Set Depth (TVD) (… 6,636.2 Wt (lb/ft) 6.50 Grade J-55 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 35.0 35.0 0.20 HANGER CIW TUBING HANGER 2.875 1,792.2 1,774.5 22.14 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.312 8,530.0 6,602.4 40.30 SBR CAMCO OEJ SBR 2.312 8,547.6 6,615.8 39.99 PACKER CAMCO HRP-1-SP PACKER 2.347 8,563.4 6,628.0 39.72 NIPPLE CAMCO D NIPPLE NO GO 2.250 8,573.3 6,635.7 39.54 SOS CAMCO SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 8,742.0 6,768.0 37.01 FISH 40 FRAC BALL- 7/8" Diameter Balls used during HYD. FRAC 1988 7/3/1988 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,648.0 8,672.0 6,693.7 6,712.5 A-3, 3K-14 6/11/1988 4.0 RPERF Tornado Link Jet; 90 deg 8,650.0 8,670.0 6,695.3 6,711.0 A-3, 3K-14 6/13/1996 4.0 RPERF 2 1/8" EJ; 180 deg ph; Orient +/- 90 deg 8,662.0 8,663.0 6,704.7 6,705.5 A-3, 3K-14 6/13/1996 1.0 IPERF 2 1/8" Strip; single shot 8,666.0 8,671.0 6,707.8 6,711.7 A-3, 3K-14 1/15/1987 1.0 APERF 2 1/8" Strip; single shot 8,690.0 8,710.0 6,726.7 6,742.5 A-2, 3K-14 6/11/1988 4.0 RPERF Tornado Link Jet; 90 deg 8,696.0 8,697.0 6,731.4 6,732.2 A-2, 3K-14 1/15/1987 1.0 APERF 2 1/8" Strip; single shot 8,704.0 8,705.0 6,737.8 6,738.5 A-2, 3K-14 1/15/1987 1.0 APERF 2 1/8" Strip; single shot 8,714.0 8,715.0 6,745.7 6,746.5 A-2, 3K-14 1/15/1987 1.0 APERF 2 1/8" Strip; single shot 8,719.0 8,720.0 6,749.6 6,750.4 A-2, 3K-14 1/15/1987 1.0 APERF 2 1/8" Strip; single shot 8,725.0 8,726.0 6,754.4 6,755.2 A-2, 3K-14 12/26/1986 1.0 IPERF 2 1/8" EJ; single shot 8,731.0 8,732.0 6,759.2 6,760.0 A-2, 3K-14 12/26/1986 1.0 IPERF 2 1/8" EJ; single shot 8,740.0 8,750.0 6,766.4 6,774.3 A-2, 3K-14 12/26/1986 1.0 IPERF 2 1/8" EJ; single shot Frac Summary Start Date 1/7/1988 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 1/7/1988 Top Depth (ftKB) 8,648.0 Btm (ftKB) 8,750.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Start Date 7/18/1996 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 7/18/1996 Top Depth (ftKB) 8,648.0 Btm (ftKB) 8,750.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,802.6 2,563.0 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,283.0 12/19/2008 2 4,978.5 4,091.9 MERLA TMPD 1 GAS LIFT GLV BK 0.188 1,326.0 12/19/2008 3 6,150.2 4,906.1 MERLA TMPD 1 GAS LIFT OV BTM 0.250 0.0 4/28/2019 4 6,673.5 5,268.8 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 12/19/2008 5 7,135.0 5,593.6 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 7/16/1996 6 7,595.7 5,921.8 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 8/12/1998 7 8,057.4 6,253.8 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 6/28/1988 8 8,483.8 6,567.4 MERLA TGPD 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/5/2002 Notes: General & Safety End Date Annotation 1/9/2003 NOTE: WAIVERED WELL: IA x OA COMMUNICATION 11/2/2010 NOTE: View Schematic w/ Alaska Schematic9.0 11/2/2010 NOTE: Mandrel @ 8484 - Flow cut mandrel w/ extended packing, damaged by erosion, ext pkg dmy sealing Comment SSSV: TRDP 3K-14, 4/30/2019 7:50:03 AM Vertical schematic (actual) PRODUCTION; 35.1-8,939.5 IPERF; 8,740.0-8,750.0 FISH; 8,742.0 IPERF; 8,731.0-8,732.0 IPERF; 8,725.0-8,726.0 APERF; 8,719.0-8,720.0 APERF; 8,714.0-8,715.0 APERF; 8,704.0-8,705.0 RPERF; 8,690.0-8,710.0 RE-FRAC; 8,648.0 FRAC; 8,648.0 APERF; 8,696.0-8,697.0 APERF; 8,666.0-8,671.0 IPERF; 8,662.0-8,663.0 RPERF; 8,648.0-8,672.0 RPERF; 8,650.0-8,670.0 SOS; 8,573.3 NIPPLE; 8,563.4 PACKER; 8,547.6 SBR; 8,530.0 GAS LIFT; 8,483.8 GAS LIFT; 8,057.4 GAS LIFT; 7,595.7 GAS LIFT; 7,135.0 GAS LIFT; 6,673.5 GAS LIFT; 6,150.2 GAS LIFT; 4,978.4 SURFACE; 37.0-4,749.9 GAS LIFT; 2,802.6 SAFETY VLV; 1,792.2 CONDUCTOR; 38.0-115.0 HANGER; 35.0 KUP PROD KB-Grd (ft) 39.01 Rig Release Date 8/5/1986 Annotation Last WO: End Date 3K-14 H2S (ppm) Date... TD Act Btm (ftKB) 8,960.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292163100 Wellbore Status PROD Max Angle & MD Incl (°) 48.30 MD (ftKB) 4,200.00 WELLNAME WELLBORE3K-14 From:Loepp, Victoria T (CED) To:Well Integrity Compliance Specialist WNS & CPF3 Subject:Re: KRU 3K-14 (PTD 186-137) Report of Sustained Casing Pressure Date:Thursday, May 21, 2020 6:26:46 PM Sara, Verbal approval is granted to proceed with diagnostic work as outlined below. Please submit a 10-403 as soon as possible. Thanx, Victoria Sent from my iPhone On May 21, 2020, at 6:17 PM, Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> wrote: Good Evening Victoria, KRU producer 3K-14 (PTD 186-137) was reported to have exceed the IA DNE to a maximum pressure of 2400 psi today. The well pressure was unable to be bled down and remains at 2400 psi. This well has 7”, 26 lb./ft., J-55 production casing that has an internal yield rating of 4,980 psi (45% here is 2,241 psi). Because the pressure exceeded 45% of the burst pressure of the casing, a 10-403 form will be submitted with a proposal for corrective action. In the interim, we intend to begin troubleshooting the source of the high IA pressure as soon as possible. Slickline has the opportunity to be on the well as early as tomorrow morning and intends diagnose and if possible, repair the source of communication. If slickline is unable to repair the source of communication the well will be secured or fluids will be loaded into the well to manage the IA pressure. Could you please respond with verbal approval to progress wireline diagnostics/repair? A 90-day TIO plot and wellbore schematic are attached. Sincerely, Sara Carlisle (Heskin) / Stephanie Pilch Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 | n2549@cop.com Cell: 907-331-7514 | sara.e.carlisle@cop.com Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ~ ~"~- L/ ~.,~ Well History File Identifier RESCAN DIGITAL DATA [] Color items: [] Diskettes, No. D Grayscale items: D Other, No/Type [] Poor Quality Originals: Other:~~-~' ¢ ~ TOTALPAGES: ?~ ORGANIZED BY: NOTES: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE; OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other IS~ Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ PAGES: ?/'--j~' (at the time of scanning) SCANNED BY:--/BEVERLY BREN VINCE~ARIA LOWELL RESCANNEDBY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /SI General Notes or Comments about this file: PAGES: Quality Checked (done) Rev1 NOTScanned,wpd � 3}C-l4(] report Page l of ` -- -- '_-- ^ --=- \k- 137 Regg,Ja00es B (DOA) From: N8K Problem We Gupv[n1817@oononophiUipn.com] Sent: Tuesday August O5.2OD85:24PyN To: Reog. James B(OOA); Maunder, Thomas E(DOA) Cc: NGK Problem Well Supv; NSKVVeU Integrity Proj Subject: 3K-14(t&3 Attachments: 3K-14T|Ojpg;3K-14.pdf Tom/Jim Kuparuk gas lifted producer 3K-14 S1 and showing signs of TALAsDn2munication. The IA is pressu e above lift qas pressure. Since most CPF3 wells are Sl a TIFIL was not completed. However, we are assuming it would follow up with slickline to troubleshoot tha-QLVs and repair the leak if possible. The current TWO pressure are 3/1760/1570. The well was added to the weekly SCIP report and is already on the master SCIP report for IAxOA communication. Attached is 80 day T|O plot and schematic. «<3K-14T|O. pgp» ««3K-14.pdt^> Please contact meot your convenience if you have questions orcomments. K8JLove|ond Well Integrity Project Supervisor ConouoPhiUipo Alaska, Inc. Office (QO7)85S-7O43 2 b 00c Cell (SO7)043-1O87 -- � � � ]2/l0/2A09 KRU 3K-14 PTD 186-137 8-5-08 TIO Pressures CHOKE FTP FTT IAP OAP T1110 Plot - 3K -14 200 1500 ..... .... ... .. ..... ......................................................................................... ? 7% 150 1000 .............................................................. � ........ ....... ....................... E F- cn 100 s d CL 0 500 ........... .. . . .................................. ........... ............................... 50 0 0 01-Mar-06 0 1 -Apr-08 01-May-08 01-Jun-08 01-JUI-08 01-Aug-08 Date • ;Y ConocoPhillips Alaska, Inc. KRU 3K -14 3K -14 API: 500292163100 Well Type: PROD Angle 0 TS: 42 deg 0 8439 SSSV Type: TRDP Orig Completion: 8/5/1986 Angle Q TD: 36 deg 0 8960 SSSV Annular Fluid: Last W /O: Rev Reason: CONDUCTOR (1792 -1793, UPDATE OD 2.875) Reference Log. __ ReLLoq Date: Last Update: 11/9/2006 Last Tag: 8638 TD: 8960 ftK6 Last Tag Date: 5/15/2006 Max Hole Angle: 48 de 4200 Gas Lift MandrelNalve Casing String - ALL STRINGS 1 Description Size Top Bottom TVD Wt Grade Thread (2803 -2604, CONDUCTOR 13.375 0 115 115 68.00 H-40 SURFACE 9.625 0 4750 3931 36.00 J -55 Gas Lift PRODUCTION 7.000 0 8932 6922 26.00 J -55 MandrelNalve Tubing String - TUBING 2 Size To Bottom TVD Wt Grade I Thread (4976 -4979' 2.875 0 8574 6636 6.50 J -55 1 . EUE 8rd MOD Perforations mma Interval TVD Zone Status Ft SPF Date Type Comment 8648-8650 6694-6695 A -3 2 4 6/11/1988 RPERF Tornado Link Jet; 90 de 8650-8662 6695-6705 A -3 12 8 6/13/1996 RPERF 2 1/8" EJ; 180 deg ph; Orient +/- 90 de 8662-8663 6705-6706 A -3 1 9 6/13/1996 RPERF 2 1/8" EJ; 180 deg ph; Gas Lift MandrelNalve Orient +/- 90 de 4 8663-8666 6706-6708 A -3 3 8 6113/1996 RPERF 2 1/8" EJ; 180 deg ph; (6673 -6674, Orient +/- 90 de 8666-8670 6708-6711 A -3 4 9 6/13/1996 RPERF 2 1/8" EJ; 180 deg ph; Orient +/- 90 de 8670-8671 6711-6712 A -3 1 5 6/11/1988 RPERF Tornado Link Jet; 90 de 8671 -8672 6712-6713 A -3 1 4 6/11/1988 RPERF Tornado Link Jet; 90 de 8690-8696 6727-6731 A -2 6 4 6/11/1988 RPERF Tornado Link Jet; 90 de 8696-8697 6731 -6732 A -2 1 5 6/11/1988 RPERF Tornado Link Jet 90 de 8697-8704 6732-6738 A -2 7 4 6/11/1988 RPERF Tornado Link Jet 90 de 8704-8705 6738-6739 A -2 1 5 6/11/1988 RPERF Tornado Link Jet; 90 de 8705-8710 6739-6743 A -2 5 4 6/11/1988 RPERF Tornado Link Jet 90 de 8714-8715 6746-6747 A -2 1 1 1/15/1987 IPERF 2 1/8" Strip; single shot 8719-8720 6750-6751 A -2 1 1 1/15/1987 IPERF 2 1/8" Strip; single shot 8725-8726 6755-6755 A -2 1 1 12126/1986 IPERF 2 1/8" EJ; single shot 8731 -8732 6759-6760 A -2 1 1 12/26/1986 IPERF 2 1/8" EJ; single shot 8740-8750 6767-6775 A -2 10 1 12/2611986 IPERF 2 1/8" EJ; single shot + Gas Lift Mandrels/Yalves I St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Viv Mfr Run Cmnt 1 2803 2563 Mersa TMPD GLV 1.0 BK 0.156 1352 11/191200 2 4978 4092 Mersa TMPD GLV 1.0 BK 0.156 1343 9/20/1996 3 6150 4906 Meda TMPD DMY 1.0 BK 0.000 0 12/6/1986 SBR 4 6673 5269 Meda TMPD OV 1.0 BK 0.188 0 12/26/200 (8530 -8531, 5 7135 5594 Mersa TMPD DMY 1.0 BK 0.000 0 7/16/1996 OD:2.875) 6 7596 5922 Mersa TMPD DMY 1.0 BK 0.000 0 8/1211998 7 8057 6254 Meda TMPD DMY 1.0 BK 0.000 0 6/28/1988 8 8484 6568 Mersa TGPD DMY 1.5 RK 0.000 0 12/25/200 1 PKR (8548 -8549, 1. FLOW CUT MANDREL w /E)(TENDED PACKING OD:6.156) Other (plugs, equip., etc. - JEWELRY Depth I TVD I Type Description ID 1792 1774 1 SSSV Camco'TRDP -1A -SSA' 2.312 NIP 8530 6603 SBR Camco'OEJ' 2.312 (8563 -8564, 8548 6616 PKR Camco'HRP -I -SP' 2.347 OD:2.875) 8563 6628 NIP Camco'D'Nipple NO GO 2.250 8573 6636 SOS Camco 2.441 To TUBING 6636 TTL 2.441 01D:2875, Fish - WARNING!! ID2441) Depth I Description Comment 8742 140 - FRAC BALLS 140 - 7/8" Diameter Balls used during HYD. FRAC on 713/88 Perf - -- - == General Notes (8648 -8672) -_ = Date I Note -_ -- 1/812003 GLV #8 8484' DAMAGED BY EROSION, EXTENDED PACKAGE DMY PRESENTLY SEALING. Pert — = 1/9/2003 WAIVEREDWELL: ]A x OA COMMUNICATION (8714 -8715) — — I 40 -FRAC BALLS (8742 -8744, OD 0.875) I Pert (8740 -8750) -- - -- . . ~ ConocoPhillips Alaska jjJL {) P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 & ;-,ITHT1¡ July 28, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 o 1 7{)G7 SCANNED f:\ U G ~-,\?11 \~ Dear Mr. Maunder: EnclDsed please find a spreadsheet with a list of wells from the Kuparuk field (KRD). Some of these wells were found to have a void in the conductor by surface casing annulus. The volume of annular void subsequently was filled with a corrosion inhibiter 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. Please call Perry Klein or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ') ! -~_. 7/'L'illo7 Perry KI . ConocoPhillips Well Integrity Supervisor . . jUL 3 .1 2007 o C:t ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/28/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft na çal 3K-1 186-101 19' 2.6 19" 7/7/2007 7 7/27/2007 3K-2 186-102 53' 7.2 9" 7/7/2007 3.7 7/22/2007 3K-3 186-103 43' 5.8 11" 7/7/2007 4.2 7/27/2007 3K-5 186-123 66' 9.0 26" 7/7/2007 9.6 7/22/2007 3K-6 186-124 58' 7.9 13" 7/10/2007 4.8 7/22/2007 3K-7 186-125 70' 10.5 35" 7/7/2007 13.2 7/22/2007 3K-8 186-126 54' 4.0 9" 7/10/2007 3.6 7/22/2007 3K-9 186-174 26' 9.0 16" 7/10/2007 6 7/22/2007 3K~ 11 186-164 43' 6.5 21" . 7/10/2007··· 7.8 . .. . 7/16/2007·· 3K-13 186-136 8" none 8" 7/10/2007 3.1 7/16/2007 3K-14 186-137 8" none 8" 7/10/2007 3.1 7/16/2007 3K-15 186-138 50' 6.0 22" 7/10/2007 8.4 7/22/2007 3K-16 186-139 46' 7.0 27" 7/10/2007 9.6 7/22/2007 3K-17 186-152 56' 8.0 30" 7/10/2007 10.7 7/22/2007 3K-18 186-151 38' 5.5 23" 7/10/2007 8.4 7/22/2007 MEMORANDUM- State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, Commissioner Tom Maunder, P. i. Supervisor DATE' May 18, 2001 FROM: John Crisp, SUBJECT' Petroleum Inspector Safety Valve Tests Kuparuk River Unit 3K -Pad May 1,8,2001- I traveled to Phillips Alaska's Kuparuk River Field to witness Safety Valve System tests. Ernie Barndt was Phillips Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner. I witnessed one failure, SSV on 3K-27 would not pass the DP test. The valve was serviced & passed the re-test The AOGCC test report is attached for reference. I inspected 14 well houses on lQ Pad w/no problems witnessed. SUMMARy; I witnessed SVS testing in Kuparuk River Field. 14 wells, 28 components tested. 1 failure witnessed. 3.57% failure rate. 14 well houses inspected. Attachments: SVS KRU 3K 5-18-01jc NON-CONFIDENTIAL SVS KRU 3K 5-18-01jc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Operator Rep: Emie Bamdt AOGCC Rep: John Crisp Submitted By: Date: Field/Unk/Pad: Kuparuk River Unit 3K Pad Separator psi: LPS 65 HPS 5/18/01 Well Permit Separ Set L/P Test Test Test Date oa, WAG, ~I~J, Number Number PSI PSI Tdp Code Code Code Passed GAS or CYCLE 3K-01 1861010 65 70! 50 P P OIL 3K-03 1861030 65 70 55 P P OIL 3K-06' 1861240 65 70 50 P P OIL .. 3K-09A 1861740 65 60 54 P P OIL . . 3K-10 1861630 63 70 52 P P OIL 3K-11 1861640 65 70 50 P P OIL ,3K-14 1861370 65 60 58 P P OIL 3K-16 1861390! 65 70 70 P e OIL 3K~i7 1861520 65 60 35 e e " OI~' 3K-23 1970970 65 70 58 P "'P " OiL 3K-24 1982490 651 70 50 P P OIL 3K-27 1970460 65 70 52 P 4 OIL 3K-32 1970760 65 70' 55! P P .... OIL 3K-35 1971090 65 70 50! P P OIL Wells: 14 Components: 28 Failures: 1 Failure Rate: 3.57% [2]90 Day Remarks: RJF 1/16/01 Page 1 of 1 SVS KRU 3K 5-18-01jc MICROFILMED 9/11/O0 DO NOT PLACE ANY' NEW MATERIAL UN ER THIS PAGE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1060' FSL, 316' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1221' FNL, 1409' FEL, Sec. 1, T12N, R9E, UM At effective depth 1311' FNL, 1144' FEL, Sec. 1, T12N, R9E, UM At total depth 1333' FNL, 1082' FEL, Sec. 1, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 69 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3K-14 9. Permit number/approval number 86-137 10. APl number 50-029-21631-00 11. Field/Pool Kuparuk River Field/Oil Pool 8960 feet 6943 feet Plugs (measured) None Effective depth: measured 884 7 true vertical 6851 feet Junk (measured) None feet Casing Length Size Structural Conductor 8 0' 1 6" Surface 471 3' 9 - 5 / 8" Intermediate Production 8904' 7" Liner Perforation depth: measured 8648'- 8672', true vertical 6693' - 671 2', Cemented Measured depth True vertical depth 1540 # Poleset 1 15' 1 15' 1340 Sx AS III & 4750' 3299' 330 Sx Class G 350 Sx Class G 8 9 3 2' 6 9 2 3' 175 Sx AS I 8690'-8710', 8714', 8719', 8725', 8731', 8740'-8750' 6726'-6741', 8714', 6749', 6753', 6758', 6765'-6773' Tubing (size, grade, and measured depth) 2.875", 6.5#/ft., J-55 @ 8574' Packers and SSSV (type and measured depth) PKR: Camco HRP-I-SP @ 8548'; SSSV: Camco TRDP-1A-SSA @ 1792' RECEIVED 13. Stimulation or cement squeeze summary Re-perforate 'A' Sands on 6/13/96 MA~ 2 0 17°)! Intervals treated (measured) ORIGINAL 8 6 5 0'- 8 6 7 0' NItlIJJa 011 & I~J Cons, ~ommil~ion Treatment description including volumes used and final pressure Perforate using 2-1/8" EJ w/ BH Charges, 4 spf, 180° PH, oriented +/- 90`0 f/ IowsideAnl~h0rltoe 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 5 9 5 513 48 1240 163 5 9 5 513 48 1246 163 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ' ' '.,4~ Title Wells Superintendent Form 404 R~v/ 06/~-5'~ Date ..~'~'/~"'~7 SUBMIT IN DUPLICATE Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT '~' K1 (3K-14(W4-6)) WELL JOB SCOPE JOB NUMBER 3K-14 FRAC, FRAC SUPPORT 0603960256.1 DATE DAILY WORK UNIT NUMBER 06/13/96 RE-PERF 'A' SAND DAY OPERATION COMPLETE ] SUCCESSFUL KEY PERSON SUPERVISOR 1 (~ Yes O NoI (~ Yes (~ No SWS-BAILEY PAISE ESTIMATE 230DS36KL $6,016. $23,661L~-~ ~--~. Initial Tb.q Press Final Tb.cl Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 200 PSI: 200 PSI 1200 PSI 1200 PSII 1000 PSII 1000 PSI DALLY SUMMARY IRE-PERF 'A' SAND INTERVAL 8650'-8670' (REF DIL DATED 8/4/86) USING 2-1/8" EJ W/BH CHARGES, 4 SPF, 180 DES PH, ORIENTED +/- 90 DES F/LOWSIDE TIME LOG ENTRY 17:15 MIRU SWS. HELD SAFETY MTG. 17:45 18:30 19:00 AT SURF W/GUN#1; ALL SHOTS FIRED. 19:30 20:15 20:45 21:30 PT LUB TO.2500#; TEST OK. RIH W/GUN#1 - WGT BAR, MPD, OCL, 2-1/8" EJ W/BH CHARGES, 2 SPF, 0 DES PH, ORIENTED -90 DES F/LOWSIDE TO SHOOT 8650'-8670' (REF DIL DATED 8/4/86) -BLEED WHP; SHOOT WELL 300#. GUN FIRED; POH. PT LUB TO 2500#; TEST OK. RIH W/GUNCY2 - WGT BAR, MPD, CCL, 2-1/8" EJ W/BH CHARGES, 2 SPF, 0 DES PH, ORIENTED +90 DES F/LOWSIDE TO SHOOT 8650'-8670' (REF DIL DATED 8/4/86i BLEED WHP; SHOOT WELL 300#. GUN FIRED; POH. AT SURF W/GUNfY2; ALL SHOTS FIRED. RDFN. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $0.00 $2,000.00 ARCO $0.00 $1,800.00 DOWELL $0.00 $13,845.00 SCHLUMBERGER $6,016.00 $6,016.00 TOTAL FIELD ESTIMATE $6,016.00 $23,661.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1060' FSL, 316' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1221' FNL, 1409' FEL, Sec. 1, T12N, R9E, UM At effective depth 1311-' FNL, 1144' FEL, Sec. 1, T12N, R9E, UM At total depth 1333' FNL, 1082' FEL, Sec. 1, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 69 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3K-14 9. Permit number/approval number 86-137 10. APl number 50-029-21631-00 11. Field/Pool Kuparuk River Field/Oil Pool 8960 feet Plugs (measured) None 6943 feet Effective depth: measured 8847 feet Junk (measured) None true vertical 6851 feet Casing Length Size Cemented Structural Conductor 8 0' 1 6" 1540 # Poleset Surface 471 3' 9-5/8" 1340 Sx AS III & Intermediate 330 Sx Class G Production 8904' 7" 350 Sx Class G Liner 175 Sx AS I Perforation depth: measured 8648' - 8672', true vertical 6693' - 6712', Measured depth True vertical depth 115' 115' 4750' 3299' 8932' 6923' 8690'-8710', 8714', 8719', 8725', 8731', 8740'-8750' 6726'-6741', 8714', 6749', 6753', 6758', 6765'-6773' Tubing (size, grade, and measured depth) 2.875", 6.5#/ft., J-55 @ 8574' Packers and SSSV (type and measured depth) PKR: Camco HRP-I-SP @ 8548'; SSSV: Camco TRDP-1A-SSA @ 1792' 13. Stimulation or cement squeeze summary RECEIVED MAR 2 0 14. Fracture Stimulate 'A' Sands on 7,18,96 I GINA Intervals treated (measured) ~ i~'\ Oil & GaS Cons. Cl~lll~MSiOll 8 6 4 8 '- 8 6 7 0' Anchorage Treatment description including volumes used and final pressure Pumped 157.7 Mlbs of 20/40,12/18, & 10/14 ceramic proppant into formation, fp was 5959 psi Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 5 9 5 5 1 3 48 1241 163 8 2 4 4 0 4 226 1255 189 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,~,i,,~/'~~/~~/~ Title Wells Superirltendent Form /1.0'- ~'0 4(' ~e,¢'0~15-"~ Date SUBMIT IN DUPLICATE .,O Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT '~ K1 (3K,14(W4-6)) WELL JOB SCOPE JOB NUMBER 3K-14 FRAC, FRAC SUPPORT 0603960256.1 DATE DAILY WORK UNIT NUMBER 07/18/96 'A' SAND REFRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 6 (~) Yes O NoI (~ Yes ~ No DS-GALLEGOS PENR~(~E~/~ ESTIMATE KM1219 230DS36KL $60,625 $104,295 Initial Tb.cl Press Final Tb.cl Press Initial Inner Ann Final Inner Ann I Initial Outer An~ I ,Fil~l Outer Ann DALLY SUMMARY FRAC'D 'A' SAND AS DESIGNED. PLACED 157,736 LBS SAND BEHIND PIPE, LEFT 817 LBS IN WELLBORE. TOP 4,500' OFTBG IS DIESEL-FILLED. USED 13,752 LBS 20/40, 139,513 LBS 12/18 AND 5,288 LBS 10/14 PROPPANT. TIME LOG ENTRY 07:00 MIRU DOWELL PUMPING EQUIP AND APC SUPPORT EQUIP. 08:45 WORK UP AND QC FLUIDS. 09:30 HOLD PRE-JOB SAFETY MEETING, PRIME PUMPING EQUIP, SET TREE SAVER, PRESSURE TEST TO 8,950 PSI. 10:00 'START PUMPING BREAKDOWN/CONDITIONING STAGE. 10:20 FINISH PUMPING BREAKDOWN/CONDITIONING STAGE, S/D. FFP = 4,948 PSI, ISIP = 1,785 PSI. CONDUCT PULSE TESTING AND MONITOR WHP. 11:20 FINISH MONITORING WHP, START PUMPING DATAFRAC. 11:35 FINISH PUMPING DATAFRAC, S/D. FFP = 6,037 PSI, ISIP = 1,899 PSI. MONITOR WHP AND CALCULATE PAD. 12:55 START PUMPING PAD: 52 BBLS XL GEL H20 @ 5 BPM. 13:05 INCREASE RATE TO 20 BPM, PUMP 88 ADD'L BBLS OF PAD. 13:10 START ADDING 2 PPA 20/40 PROPPANT, PUMP :100 BBLS @ 20 BPM. 13:15 SWITCH TO 12/18 PROPPANT, PUMP 500 BBLS @ 20 BPM WHILE RAMPING PROP CONC FROM 2 PPA TO 8 PPA. 13:40 PUMP ADD'L 225 BBLS @ 20 BPM W/FLAT PROP CONC OF 8 PPA. 13:53 PUMP ADD'L 22 BBLS @ 17 BPM WHILE RAMPING PROP CONC FROM 8 PPA TO 10 PPA. 13:55 PUMP ADD'L 22 BBLS @ 16 BPM W/FLAT PROP CONC OF 10 PPA. 13:57 CUT PROPPANT, PUMP 17 BBLS XL GEL H20 FLUSH @ 15 BPM. 13:58 SWITCH TO DIESEL, PUMP 33 BBLS @ 13 BPM. 14:00 S/D. FFP = 5,959 PSI, ISIP = 2,906 PSI. MONITOR WHP. 14:15 FINISH MONITORING WHP. FSIP = 2,650 PSi. RDMO DOWELL AND APC. 16:15 WELL SECURE AND EVERYBODY OFF LOCATION. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $663.00 APC $4,120.00 $9,745.00 APC-PUMPING $0.00 $300.0,0 ARCO $270.00 $2,070.00 DOWELL $56,235.00 $78,638.00 HALLIBURTON $0.00 $6,099.00 LI'I-I'LE RED $0.00 $765.00 SCHLUMBERGER $0.00 $6,016.00 TOTAL FIELD ESTIMATE $60,625.00 $104,296.00 ARCO Alaska, Inc. Post Office Bo. J0360 Anchorage. Alaska 99510-0360 Teiephone 907 276 12!5 November 9, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in duplicate are multiple Reports of Sundry Well Operations on the following Kuparuk wells. Conversions 3N-11, 3N-10, 3N-05, 3N-04, 3F-12, 3F-03, 3F-08, 3N-03, 13, 1E-21, 1E-19, 1E-23, 1E-lA, 1E-04, 1E-16 andlE-27 Fractures and Stimulations · 3K-14, 3C-16, 3K-17, 1E-14, 3N-17, 3F~16 and 2V-12 Perforatign8 3N-11, 3F-11 and 3N-SA 1E-30 Failed MIT 3N-1 2, 3N- If you have any questions, please call me at 265-6840. Sincerely, G. B. Srr~llwood Senior Operations Engineer Attachments cc: J. Gruber M. L. Hagood S. P. Twiggs KOE1.4-9 ATO 1478 ATO 1120 ATO 1130 RECEi.VED NOV 1 5 ]988 Ala~ t}il & Gas Cons. Co.lmf~[.Orx ...... '~,~; An~orag, :;~ .... ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCornpany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown__ Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1060' FSL, 316' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1221' FNL, 1409' FEL, Sec. 1, T12N, R9E, UM At effective depth 1311' FNL, 1145' FEL, Sec. 1, T12N, R9E, UM At total depth 1333' FNL, 1082' FEL, Sec. 1, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 6. Datum elevation (DF or KB) RKB 6~) 7. Unit or Property name Kuparuk River Unit 8. Well number 9. Permit number/approval number 8-472 10. APl number 50-029-21631 11. Field/Pool Kuparuk River Oil Pool feet 8960' MD feet Plugs (measured) 6943' TVD feet None ~: ~' L ~ j i~,-~ D 8847' MD feet Junk (measured) 6851' TVD feet None Casing Length Size Structural Conductor 80' 1 6" Surface 4 71 3' 9 - 5 / 8" Intermediate Production 8 9 3 2' 7" Liner Perforation depth: measure Cemented Measured depth 1540# Poleset 115' MD 1340 Sx AS III & 4750' MD 330 Sx Class G 350 Sx Class G & 8932' MD 6920' TVD 175 Sx ASI 8622', 8666', 8668', 8670', 8696', 8704', 8714', 8719' MD 8725', 8731', 8740'-8750', 8648'-8672', 8690'-8710', MD r'.Anch0rag0 115' TVD 393O' TVD true vertical 6704', 6707', 6709', 6710', 6730', 6736', 6744', 6748' TVD 6753', 6758', 6765'-6773', 6693'-6710', 6725'-6741' TVD Tubing (size, grade, and measured depth) 2-7/8", J-55, tbg w/tail @ 8574' Additional Perfs: MD: 8648-8672 Packers and SSSV (type and measured depth) TVD: 6692-6711 HRP-1-SP pkr @ 8548' & TRDP-1A-SSA SSSV @ 1792' 13. Stimulation or cement squeeze summary See Well Service Report Intervals treated (measured) See Well Service Report Treatment description including volumes used and final pressure See Well Service Report 14. Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 510 191 0 106O Tubing Pressure 100 Subsequent to operation 7 0 0 350 0 11 O0 140 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form ~- ~¢./t ~ / ¢/~%t,/t-'¢'''¢~ /¢4.~¢~' Title 0-404 Rev,,/06/15/88 Sr. Operations Engineer Date ,,//./¢/"D .~ SUBMIT IN DUPLICATE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM,,SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate f~ Plugging [] Perforate ~ Pull tubing Alter Casing [] Other [] 2. Name of Operator ARCO Alaska= Tnt 3. Address P.0. Box 100360, Anchoraqe, Alaska 99510-0360 4. Location of well at surface 1060' FSL, 316' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1221' FNL, 1409' FEL, Sec. At effective depth 1311' FNL, 1145' FEL, Sec. At total depth 1333' FNL, 1082' FEL, Sec. 11. Present well condition summary Total depth: measured true vertical 1, T12N, R9E, UM 1, T12N, R9E, UM 1, T12N, R9E, UM 8960' MD feet 6943' TVD feet Plugs (measured) 5. Datum elevation (DF or KB) RKR 69 6. Unit or Property name Kuparuk River Unit . Feet 7. Well number ".)V I /1 Dv,,.-,,-I 8, Approval number 8-472 9. APl number 50-- fl?q-?l 621 10. Pool Kuparuk River 0il Pool Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 8847' MD feet 6851' TVD feet Length Size Junk (measured) None Cemented Measured depth True Vertical depth 80' 16" 4713' 9-5/8" 8932' 7" measured true vertical None 1540# Poleset 115' MD 115' TVD 3930' TVD 6920' TVD 12. 1340 SX ASIII & 4750' MD 330 SX Class G 350 SX Class G & 8932' MD & 175 SX ASI 8662' 8666' 8668' 8670' 8696' 8704' 8714' 8719' MD 8725' 8731' 8740'-8750' 8648'-8672' 8690'-8710' MD 6704' 6707' 6709' 6710' 6730' 6736' 6744' 6748' TVD ~h~53' 6758' 6765'-6773' 6693'-6710' 6725'-67411 TVD ~bing (size, grade and measured dep__ ~ ' ' ' 2-7/8" J-55 tbg w/tail @ 8574'MD Packers and SSSV (type and measured depth) HRP-1 pkr @ 8548' & TRDP-1A-SSA SSSV ¢ 1792' stimulation or cement squeeze summary Attached Intervals treated (measured) 13. Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl 526 185 0 Casing Pressure ~bing Pressure 1850 110 1800 120 789 396 0 Prior to well operation Subsequent to operation 14. Attachments Daily Report of Well OperationsX[] Copies of Logs and Surveys Run 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Date .S." '~ Submit in Duplicate Form 10-404 Rev. 12-1-T86 WELL: Ti.JO · PERFS: MD · PERFS: HOLE flN6LE ~,-PERFS: DRTE: CONTRACTOR: ARCO REP: AFE #: SAND PERF INTERURL CDMPRNV ACTUAL UOLUME RATE PRESSURE STG/£UM MID EFF. PRO: ~) \ ~'o\¢ EFF. SLURRV: 2~c:x~ ~ WHTPA: ,/~,2,"/o / L/I FRAC SOliD: .~,,5 / ISIP: Z.~7..~ / ! TIS.FRIC: ~]~$ PERF FRIC: .~,(~ / DESIGN PROP. PROP. ANN. VOLUME MESH CONe. WT. PRESS. STG/CUM EFF. PROP: ...f0:, _ _ . LOS ,NTERUflL: FLUID ~MP: FLUID UISC:~ LEAK OFF: 5 MIN. ~" I0 MIN. IS MIN. '"-------' NOTES: ARCO Alaska, Inc. Date: September 7, 1988 RETURN TO: Transmittal #: 7285 ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records 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 F- 1 3 Kuparuk Fluid Level Report 8 - 2 7 - 8 8 Casing 3 K - 1 8 Kuparuk Fluid Level Report 8 - 2 7 - 8 8 Tubing 3 B - 1 3 Kuparuk Fluid Level Report 8 - 2 6 - 8 8 Casing ' 3 Q- 15 Kuparuk Fluid Level Report 8 - 2 7 - 8 8 Casing ' 3 N-0SA Kuparuk Fluid Level Report 8 - 2 6 - 8 8 Casing ,~ 3 H - 1 4 Kuparuk Fluid Level Report 8 - 2 6 - 8 8 Casing 1 E - 1 2 Kuparuk Fluid Level Report 8 - 2 6 - 8 8 Casing ", 3 K- 1 4 Kuparuk Fluid Level Report 8 - 2 6 - 8 8 Casing ' 3 ! - 0 3 Kuparuk Fluid Level Report 8 - 2 6 - 8 8 Casing 1 Y- 0 6 Kuparuk Well Pressure Report 8 - 2 6 - 8 8 Both Sands ,.1 Y-0 7 Kuparuk Well Pressure Report 8 - 2 6 - 8 8 Sand 'A' Receipt Acknowledged: D&M State of Alaska ... Chevron Unocal Mobil SAPC STATE OF ALASKA ALASh,~ OIL AND GAS CONSERVATION COMM,.~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend '; Operation Shutdown '} Re-enter suspended well iT] Alter casing E1 Time extension' Change approved program :2 Plugging _r--j Stimulate ,~ Pull tubing'' Amend order F! Perforate E' Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, ]]nc RKB 69 feet 3. Address 6. Unit or Property name PO Box 100360~ /l_n_chor'ag~ Al< c)qE1F)-F)RRF) Kuparuk River Unit 4. Location of well at surface 7. Well number 3K-14 ]~(~§~'ol~lro, d,,3~.]n6~_i~Ft~.~,Sec 35 T13N R9E UM ' ' ' ' 8. Permit number Permit #86-137 k21 ' FNL, 1409' FEL, Sec. 1, T12N, R9E, UM eTfeclive ~lepth 9. APl number !311' FNL, 1145' FEL, Sec. 1, T12N, R9E, UM 5o-- 029-21631 At total depth 10. Pool !333' FNL, !082' FEL, Sec. !, T!2N, RgE, UM ~Jpar~Jk RivPr Oil Pnol 11. Present well condition summary Total depth' measured 8960' ND feet Plugs (measured) None true vertical6943, TVD feet Effective depth: measured feet Junk (measured) None true vertical8847'HD feet 6851' TVD Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 80' 16" 1540# Poleset 115' MD 115' TVD Surface 4713' 9-5/8" 1340 SX ASIII & 4750' MD 3930' TVD xxx;~~te 330 SX Class G Production 8932' 7" 350 SX Class G & 8932' MD 6920' TVD Liner xxxxxxxxxxx & 175 SX ASI Perforation depth: measured 8622' 8666' 8668' 8670' 8696' 8704' 8714' 8719' MD 8725' 8731' 8740'-8750' 8648'-8672' 8690'-8710' MD true vertical 6704' 6707' 6709' 6710' 6730' 6736' 6744' 6748' TVD 6753' 6758' 6765'-6773' 6693'-6710' 6725'-6741' TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail @ 8574' Packers and SSSV (type and measured depth) 12.Attach~n~e~ntsy"'' Description summary of proposal ~'[~etailed operations \B~'~ketch ~ ~:.~.. ...... ~,, :7~'L7 See attached 13. Estimated date for commencing operation ,1.~n~ 23: lqRR 14. If proposal was verbally approved Name of approver -- ~- '_ ~iaska 0ii & Gas [;0ns. £;0mi-~.4ssi0R 15. I hereby certify that the foregoing is true and correct to the best of my knowledge !, Signed //~,>t ~ ,/~/ 2,.~,~ .¢,~ ¢'~~ Ti t le Sr. Operations Engineer - ~ Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test E] Location clearanceI Approved Cqpy Returned ;. _. Approved by Date 6/15/88 LONNIE C. SMITH Commissioner by order of the commission Date'_cc' Form 10-403 Rev 12-1-85 Submit in triplicate Attachment 1 Kuparuk Well 3K-14 Fracturing Procedure June 7, 1988 Summary: Well 3K-14 will be refractured in the A Sand with gelled diesel and propped with 16- 20 mesh Carbo-Lite proppant. A diesel/10% Musol soak is recommended prior to the treatment for asphaltene control. The treatment consists of a pre-pad for ISIP calculations, pad, and 16-20 mesh Carbo-Lite slurry stages pumped "on-the-fly" at 20 BPM. Proppant concentrations are ramped up from 2 to 10 PPG. Silica Flour is added only to the pre-pad and pad stages, for leak-off control. Pre Job Slickline: 1. Perform pre frac A Sand well test. 2. Pull GLVs at 2803', 4978', 6673', 8057', and 8484'. 3. Pressure test the tubing. Run DVs. Pre Job Checklist: 1. Inspect all tanks for cleanliness. 2. Check diesel for contamination prior to gelling, i.e. "black diesel", water, etc. 3. Check proppant for fines due to excessive handling. Request sieve analysis of proppant and obtain proppant sample. 4. Record proppant weight before and after the fracture treatment. 5. Obtain a sample of the gelled diesel with breaker. Treatment Procedure: 1. RU fracturing equipment. Install "Tree Saver". Pressure test all lines. ,J~-!~'-"! ''?' i'":'"' 2 Pressure up annulus to prevent buckling the tubing. Set pressure to acO'88¢f¢ Oil & Gas "'"' ' for thermal effects, achieving a maximum of 3500 psi during the treatment. 3. Pump 100 bbl Pre-pad stage. Shut down for ISIP calculations. * Check tank straps against metered volume. Correct flush volume accordingly. ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company AR3B-6001-A . Set pumps to trip off at 7250 psi wellhead pressure. pressure exceeds 7000 psi. 5. Pump fracture treatment per attached schedule: Rate should be reduced if * All slurry stages should be mixed "on-the-fly". * Use silica flour in the PRE-PAD and PAD ONLY at 40 Ibs/Mgal. Slurry stages should contain NO silica flour. * Strap tanks "on-the-fly" during the pad stage to insure meter accuracy. * Ramp up slowly between slurry stages to avoid high density spikes. * Call flush as the densimeter drops from 10 PPG. * Expected Wellhead Treating Pressure: WHTP 494O psig Fracture Gradient 0.75 psi/ft TVD (6703' TVD) Tubing Friction 270 psi/1000 ft (8539' MD) 6. Bleed down annulus pressure after the treatment. 7. RD fracturing equipment. Flowback Procedure: , Operations Engineering will notify Production to begin the flowback after verifing the gel break time from fluid samples taken during the job. DO NOT BEGIN THE FLOWBACK IF THE GEL HAS NOT BROKEN. If the gel remains unbroken, contact Anchorage Engineering to discuss options. , To start flowback, crack open choke to establish a 5 to 10 bbl per hour flow rate. If excessive proppant is produced or unbroken gel is apparent, SI well and contact Operations Engineering for directions. Do no exceed 10 bbl per hour for the first day of flowback. Record tank straps, choke settings, and WHPs. * The flowback is intended to remove gel residue without disturbing the proppant. , On the second day, decrease wellhead pressure by 50 psi every two hours. Take shakeouts during flowback to check for gel or proppant. , When the shakeout shows no gel or proppant, and the BS&W is less than 2%, the well can be turned to the DS-3K production facilities. 5. Send strap sheets to J. Currier/B. O'Dell for transmittal to Anchorage Engineering. 6. Perform 12 hour A Sand well test following flowback. ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company AR3B-6001-A KUPARUK WELL 3K-14 'A' SAND REFRACTURE PUMPING SCHEDULE *June 7, 1988' STAGE FLUID DESCRIPTION CLEAN VOLUME PUMP RATE PROP. CONC. PROPPANT PROPPANT WT DIRTY VOLUME HIT PERFS BBLS BP M PPG DESCRIPTION LBS STG/CUM BBLS 1 DIESEL/10% MUSOL 40.0 I 0 2 DIESEL FLUSH 40.0 1 .............................................. SHUT DOWN 3 GD PRE-PAD 100.0 2 0 ................................................... SHUT 4 GD PAD 600.0 2 0 5 GD w/2 PPG 18.4 2 0 6 GD w/4 PPG 85.0 2 0 7 GD w/6 PPG 94.9 2 0 8 GD w/8 PPG 59.1 20 9 GD w/9 PPG 43.0 2 0 1 0 GD w/10 PPG 27.8 20 1 1 GD FLUSH 51.0 +SV 20 0 40/ 40 52 0 - - 0 40/ 80 92 OVERNIGHT TO SOAK ................................................... 0 40 Ibs/Mgal SILICA FLOUR 0 100/ 1 O0 52 DOWN FOR ISIP ...................................................... 0 40 Ibs/Mgal SILICA FLOUR 0 600/ 700 1 52 2 16/20 M CARBO-LITE 1544 20/ 720 752 4 16/20 M CARBO-LITE 14282 100/ 820 772 6 16/20 M CARBO-LITE 23916 120/ 940 872 8 16/20 M CARBO-LITE 19873 80/ 1020 992 9 16/20 M CARBO-LITE 16239 60/ 1080 1072 1 0 16/20 M CARBO-LITE 11661 40/ 11 20 1132 0 - - 0 51/ 1171 1172 TOTAL GELLED DIESEL= 1079.2 BBLS + SV TOTAL DIESEL = 76.0 BBLS SILICA FLOUR = TOTAL MUSOL = 4.0 BBLS 1. All fluids should be maintained at 70 to 90 F on the surface. 2. Stages 3 and 4 are Gelled Diesel with 40 lbs/1000 gal silica flour and enough breaker for an 8 hour break. 3. Stages 5 through 10 are Gelled Diesel (8 hour break), WITHOUT SILICA FLOUR, 4. Stage 11 is Gelled Diesel with Iow temperature breaker ( 8 hour break). 5. Stage 11 should include a volume adjustment for surface equipment between the wellhead and densimeter. 6. This job is intentionally underflushed by 1.0 bbl. The blender tub should be bypassed at flush. 16/20 M CARBO-LITE = 8751 5 LBS 11 76 LBS Sundry Notice- Well 3K-14 A Sand Fracture Treatment No BOP's will be used during the treatment. The treatment will be pumped through a manifold on the surface, with a tree saver on the wellhead. No workover fluids will be used during the treatment. A Sand pressure (6200'SS)= 2334 psi, 05/10/88 PBU Anchor~,9~: ADDENDUM WELL: 1/27/87 3K-14 Frac Kuparuk "A" sand perfs 8662', 8666', 8668', 8670', 869~, 870~', 8714', 8719', 8725', 8731' & 8740'-8750' per procedure dated 1/19/87. Stage 1: 50 bbls gelled diesel @ 20 BPM, 6627-6200 psi Stage 2: 47 bbls gelled diesel 1 ppg 100 mesh @ 20 BPM, 6200-5800 psi Stage 3: 360 bbl$ gelled diesel @ 20 BPM, 5800-6035 psi Stage 4: 33 bbls gelled diesel 2 ppg 20/40 mesh @ 20 BPM, 6035-6145 psi Stage 5: 34 bbls gelled diesel 3 ppg 20/40 mesh @ 20 BPM, 6145-6300 psi Stage 6: 35 bbl$ gelled diesel 4 ppg 20/40 mesh @ 20 BPM, 6300-6195 psi Stage 7: 37 bbls gelled diesel 5 ppg 20/40 mesh @ 20 BPM, 6195-6150 psi Stage 8: 38 bbls gelled diesel 6 ppg 20/40 mesh @ 20 BPM, 6150-6072 psi Stage 9: 20 bbls gelled diesel 7 ppg 20/40 mesh @ 20 BPM, 6072-6108 psi Stage 10:17 bbls gelled diesel 8 ppg 20/40 mesh @ 20 BPM, 6108-5944 psi (cut stage 3 bbls short) Stage 11:51 bbls gelled diesel @ 20 BPM, 5944-5950 psi Fluid to Recover: 684# Sand in Zone 1900# 100 mesh & 38,800# 20/40 Mesh Sand in Csg: 1299# 20/40 mesh Avg Pressure: 6100 psi Drill~__~p~is°r ~ / Date / ARCO Alaska, In( Posl Office uox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: March 11, 1987 Transmittal # 5933 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records 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. 2T-16 2T-12A 2A-11 3A-9 lA-1 3A-9 1H-3 3K-i3 3K-14 3I-1 3F-15 CET/CEL 9-15-86 8181-8720 CET/CEL 9-27-86 4595-6644 CET/CEL 3-14-86 5800-6564 CET 7-26-86 2000-6299 CEL/CET 8-29-86 2708-7255 CET/CEL (After Squeeze) 7-31-86 2128-6039 CET 7-16-86 6891-7617 CET/CEL 8-17-86 6849-8455 CET/CEL 8-18-86 7215-8844~ CET/CEL 1-24-86 7588-8887 CET/CEL 1-13-86 6600-7384 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Mobil .SAPC Unocal Vault (film) . Chevron ARCO Alaska, Inc. is a Subsidiary of AllantlcRichfleldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO,v~MlSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number . ARCO Alaska, Inc. 86-137 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21631 4. Location of well at surface 9. Unit or Lease Name 1060' FSL, 316' FWL, 5ec.35, T13N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1221' FNL, 1409' FEL, Sec. 1, T12N, R9E, UM 3K-14 At Total Depth 11. Field and Pool 1333' FNL, 1082' FEL, Sec. 1, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk Ri vet 0i 1 Pool RKB 69' ADL 25629, ALK 2562 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 07/29/86 08/04/86 01/27/87* N/A feet MSL 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8960'MD 6943'TVD 8847'MD 6851 'TVD YES~[]~ NO [] 1792' feet MDI 1700' (Approx) 22. Type Electric or Other Logs Run DIL/SP/SFL, GR, FDC/CNL, Cal, CET, Gyro, GR/CCL/Temperature log 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" 1540 # Poleset 9-5/8" 36.0# J-55 Surf 4750' 12-1/4" 1340 sx AS Ill & 330 sx Class G 7" 26.0# J-55 Surf 8932' 8-1/2" 350 sx Class G & 175 sx AS I 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) 2- 7/8" 8574 ' 8548 ' 8662'MD 6703'TVD 8719'MD 6748'TVD 8666'MD 6706'TVD 8725'MD 6753'TVD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 8668'MD 6708'TVD 8731 'MD 6758'TVD 8670'MD 6710'TVD 8740'-8750'MD 6765'-677~TVD DEPTH INTERVAL (MD} AMOUNT & KIND OF MATERIAL USED 8696'MD 6730'TVD See attached Adderdum, dated 01/29/87~ for Fracture dar 2. 8704'MD 6736'TVD Perforated w/1 spf, 8714'MD 6744'TVD 0° phasing 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR oIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief ~lCscriPtion of lithology, porosity, fractures, aPparent dips and presence of oil, gas or water. Submit core chips. ~one *Note: Drilled RR 08/05/86. Tubing run 12/07/86. Perforated well 12/06/86 & 01/15/87. WC2: 035: DAN I Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~ 29. - 30. ' ; · . . . . . GEOLOGIC MARKERS FORMATION TESTS . ; . . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 8403' 6506' N/A Base Kuparuk C 8504' 6582' Top Kuparuk A 8626' 6675' Base Kuparuk A 8789' 6804' 31. LIST OF ATTACHMENTS Addendum, (dated 01/29/87). 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~.,~"~,J'~/~/ --' Title Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 1/27/87 3K-14 Frac Kuparuk "A" sand perfs 8662', 8666', 8668', 8670', 869~i~, 870,~', 8714', 8719', 8725', 8731' & 8740'-8750' per procedure dated 1/19/87. Stage 1: 50 bbls gelled diesel @ 20 BPM, 6627-6200 psi Stage 2: 47 bbls gelled diesel 1 ppg 100 mesh @ 20 BPM, 6200-5800 psi Stage 3: 360 bbls gelled diesel @ 20 BPM, 5800-6035 psi Stage 4: 33 bbls gelled diesel 2 ppg 20/40 mesh @ 20 BPM, 6035-6145 psi Stage 5: 34 bbls gelled diesel 3 ppg 20/40 mesh @ 20 BPM, 6145-6300 psi Stage 6: 35 bbls gelled diesel 4 ppg 20/40 mesh @ 20 BPM, 6300-6195 psi Stage 7: 37 bbls gelled diesel 5 ppg 20/40 mesh @ 20 BPM, 6195-6150 psi Stage 8: 38 bbls gelled diesel 6 ppg 20/40 mesh @ 20 BPM, 6150-6072 psi Stage 9: 20 bbls gelled diesel 7 ppg 20/40 mesh @ 20 BPM, 6072-6108 psi Stage 10:17 bbls gelled diesel 8 ppg 20/40 mesh @ 20 BPM, 6108-5944 psi (cut stage 3 bbls short) Stage 11:51 bbls gelled diesel @ 20 BPM, 5944-5950 psi Fluid to Recover: 684# Sand in Zone 1900# 100 mesh & 38,800# 20/40 Mesh Sand in Csg: 1299# 20/40 mesh Avg Pressure: 6100 psi Drill~pervisor ~ / Date / $ UB.$ URFA CE DIRECTIONAL SURVEY [~ UIDANCE ~'~ONTINUOUS r~OOL Company Well Name ARCO ALASKA~ INC. 3K-14 (1060' FSL~ 316' FWL~ SEC 35~T13N,R9E,UM) Field/Location KUPAURK~ NORTH SLOPE1 ALASKA Job Reference No. 71691 WEST Date 18-AUG-86 Computed By:.' HALSTEAD GCT DIRECTI3NAL SURVEY CUSTOMER LISTING FOR ARCO ALASKAt INC. 3K-14 KUPARUK NORTH SLOPE,ALASKA SURVEY DATE: 18-AUG-86 ENGINEER: WEST METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 60 DEG 18 MIN EAST ARCO ALASKA, INC. 3K-14 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 6-SEP-86 PAGE DATE OF SURVEY: 18-~UG-86 KELLY BUSHING ELEVATION: 69.00 FT ENGINEER: WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET . DEG MIN 0.00 0.00 -69.00 0 0 N 0 0 E 100.00 100.00 31.0'0 0 34 S 76 4 W 200.00 199.99 130.99 0 35 N 88 46 W 300.00 299.99 230.99 ~0 35 N 87 45 W 400.00 399.98 330.98 0 41 S 88 20 W 50'0.00 499.97 430.97 0 37 S 85 43 W 600.00 599.97 530.97 0 35 S 88 20 W 700.00 699.96 630.96 0 33 N 87 37 W 800.00 799.96 730.96 0 33 N 82 54 W 900.00 899.95 830.95 0 37 S 80 49 W N 65 36 W N 56 36 E N 51 38 E N 68 20 E S 88 12 E S 70 ~,8 E S 61 36 E S 57 31E S 56 19 E S 55 25 E 1000.00 999.95 930.95 0 15 1100.00 1099.90 1030.90 3 20 1200.00 1199.53 1130.53 6 18 1300.00 1298.74 1229.74 7 48 1400.00 1397.55 1328.55 9 43 1500.00 1495.62 1426.62 12 58 1600.00 1592.42 1523.42 15 37 1700.00 1688.06 1519.06 18 41 1800.00 1781.65 1712.65 22 26 1900.00 1872.91 1803.91 25 40 0.00 0.00 0.00 N 0.00 E -0.24 0.61 0.16 S 0.36 W -1.12. 0.08 0.29 S 1.45 W -2.01 0.16 0.24 S 2.45 W -3.02 0.08 0.23 S 3.61 W -3.97 0.01 0.30 S 4.75 W -4.86 0.06 0.36 S 5.81 W -5.73 0.04 0.35 S 6.80 W -6,63 0.05 0.28 S 7.79 W -7.52 0.05 0.28 S 8.82 W -8.26 1.42 0.41 S 9.75 W -7.52 4.00 1.17 N 7.98 W -3.76 2.36 5.99 N 0.91 W 1.96 5.65 12.74 N 9.52 E 14.07 3.43 14.77 N 24.63 E 32.56 4.18 10.66 N 43.57 E 57.44 2.88 0.45 N 66.39 E 86.59 4.01 14.63 S 91.34 E 121.70 3.19 162.39 3.23 2000.00 1961.74 1892.74 29 0 2100.00 2047.67 1978.67 32 27 2200.00 2130.49 2061.49 35 47 2300.00 2209.51 2140.51 39 41 2400.00 2284.28 2215.28 43 43 2500.00 2354.10 2285.10 46 53 2600.00 2422.23 2353.23 46 49 2700.00 2490.97 2421.97 46 17 2800.00 2560.35 2491.35 45 55 2900.00 2630.15 2561.15 45 32 S 54 47 E 208.10 S 54 14 E 258.95 S 53 24 E 314.60 S 52 55 E 375.35 S 52 45 E 441.16 S 52 50 E 512.11 S 52 46 E 584.68 S 52 34 E 556.68 S 52 15 E 728.01 S 51 56 f 798.88 3000.00 2700.35 2631.35 45 42 3100.00 2769.70 2700.70 46 6 3200.00 2839.37 2770.37 45 31 3300.00 2909.72 2840.72 45 4 3400.00 2980.59 2911.59 44 37 3500.00 3052.30 2983.30 43 50 3600.00 3124.77 3055.77 43 15 3700.00 3197.93 3128.93 42 43 3800.00 3271.32 3202.32 43 13 3900.00 3343.75 3274.75 43 30 S 52 3 E 869.34 S 53 14 E 940.76 S 52 51 E 1011.94 S 52 24 E 1082.36 S 52 4 f 1152.22 S 51 59 E 1221,17 S 51 44 E 1289.36 S 51 21 E 1356.72 S 52 53 E 1423.91 S 53 52 E 1492.41 0.00 N 0 0 E 0.39 S 66 40 ~ 1.48 S 78 40 W 2.47 S 84 30 W 3.61 S 86 22 4.75 S 86 25 5.82 S 86 25 W 6.81 S 87 4 W 7.79 S 87 58 W 8.82 S 88 I1 W 9.76 S 87 34 W 8.07 N 81 38 W 6.06 N 8 38 W 15.90 N 36 45 E 28.72 .N 59 2 E 44.86 N 76 14 E 66.39 N 89 36 E 92.51 S 80 54 E 33.85 S 120.79 E 125.45 S 74 20 E 56.79 S 154.56 E 164.66 S 69 49 E 3.36 2.97 4.00 3.72 4.56 1.20 0.59 0.84 0.60 0.57 83.05 S 192.20 E 209.37 S 66 37 E 112.71 S 233.82 E 259.57 S 64 15 E 145.78 S 279.03 E 314.82 S 62 24 E 182.55 S 328.00 E 375.37 S 60 54 E 222.67 S 380.86 E 441.18 S 59 41 ~ 265.95 S 437.87 E 512.31 S 58 43 310.15 S 496.20 E 585.16 S 57 59 = 354.18 S 553.97 E 657.52 S 57 24 E 398.10 S 611.04 E 729.28 S 56 54 E 442.10 S 667.53 E 800.66 S 56 29 E 1.52 0.59 0.67 0.36 0.68 0.48 0.73 0.48 2.16 0.96 486.08 S 723.56 E 871.67 S 56 6 E 529.64 S 780.94 E 943.60 S 55 51 E 572.69 S 838.32 E 1015.26 S 55 39 E 615.83 S 894.79 E 1086.23 S 55 27 E 659.04 S 950.57 E 1156.68 S 55 15 E 701.97 S 1005.47 E 1226.26 S 55 4 E 744.44 S 1059.73 E 1295.08 S 54 54 E 786.86 S 1113.09 E 1363.13 S 54 44 E 828.84 S 1166.49 E 1430.97 S 54 36 E 869.59 S 1222.11 E 1499.91 S 54 33 E COMPUTATION DATE: 6-SEP-86 PAGE ARCO ALASKA~ INC. 3K-14 KUPARUK NORTH SLOPE~ALASKA DATE OF SURVEY: 18-AUG-86 KELLY BDSHING E'LEVATION: ENGINEER: WEST INTERPOLATED VALUES FOR EVEN IO0 FEET OF MEASURED DEPTH 69. Ob FT TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 4000.00 3416.27 3347.27 44 9 S 53 6 E 1560.77 4100.00 3486.73 3417.73 46 17 'S 53 6 E 1631.14 S 54 52 E 1704.30 S 56 51 E 1778.84 S 56 25 E 1852.72 S 56 5 E 1925.69 S 55 55 E 1997.87 S 55 45 E 2069.18 S 55 59 E 2140.03 S 56 14 E 2210.81 4200.00 3554.35 3485.35 48 18 4300.00 3620.80 3551.80 48 8 4400.00 3688.03 3619.03 47 22 4500.00 3756.20 3687.20 46 39 '4600.00 3825.21 3756.21 46 2 4700.00 ,3895.09 3826.09 45 28 4800.00 '3965.44 3896.44 45 10 4900.00 4035.90 3966.90 45 17 S 56 33 E 2281.74 S 56 54 E 2352.40 S 57 43 E 2422.58 S 59 38 E 2494.15 S 61 3 E 2566.31 S 62 8 E 2638.70 S 62 31 E 2711.18 S 62 58 E 2783.63 S 63 16 E 2856.07 S 63 39 E 2928.33 5000.00 4106.22 4037.22 45 14 5100.00 4176.84 4107.84 44 48 5200.00 4247.97 4178.97 45 6 5300.00 4317.77 4248.77 46 2 5400.00 4387.01 4318.01 46 19 5500.00 4455.97 4386.97 46 27 5600.00 4524.82 4455.82 46 29 5700.00 4593.68 4524.68 46 29 5800.00 4662.53 4593.53 46 26 5900°00 4731.54 4662.54 46 18 S 64 2 E 3000.39 S 64 26 E 3072.04 S 64 56 E 3143.59 S 65 20 E 3215.35 S 65 46 E 3287.17 S 66 0 E 3359.04 S 66 18 E 3430.82 S 66 49 E 3502.51 S 67 21 E 3574.06 S 67 48 E 3644.64 6000.00 4800.72 4731.72 46 4 6100.00 4870.31 4801.31 45 51 6200.00 4939.95 4870.95 45 58 6300.00 5009.34 4940.34 46 7 6400.00 5078.60 5009.60 46 11 6500.00 5147.77 5078.77 46 13 6600.00 5217.01 5148.01 46 9 6700.00 5286.28 5217.28 46 6 6800.00 5355.62 5286.62 45 55 6900.00 5425.87 5356.87 44 51 S 68 7 E 3714.36 S 68 23 E 3784.22 S 68 34 E 3853.90 S 69 0 E 3923.58 S 69 38 E 3992.98 S 70 6 f 4061.97 S 70 36 E 4130.76 S 70 58 E 4199.65 S 71 23 E 4268.15 S 71 30 E 4336.29 7000.00 5496.95 5427.95 44 48 7100.00 5567.83 5498.83 44 50 7200.00 5638.85 5569.85 44 44 7300.00 5709.82 5640.82 44 49 7400.00 5780.98 5711.98 44 27 7500.00 5852.42 5783.42 44 19 7600.00 5923.97 5854.97 44 22 7700.00 5995.33 5926.33 44' 23 7800.00 6066.98 5997.98 44 12 7900.00 6138.93 6069.93 43 48 2.11 2.21 2.96 0.75 0.73 0.63 0.98 0.24 0.29 0.40 0.34 0.88 2.12 0.78 1.47 0.33 O. 35 0.32 0.45 0.33 0.47 0.42 0.62 0.32 0.36 0.23 0.36 0.46 1.05 1.13 0.43 0.43 0.25 0.62 0.39 0.43 0.48 0.89 0.20 0.46 FEET FEET FEET DEG MIN 910.61 S 1277.41 E 1568.75 S 54 30 E 953.28 S 1334.09 E 1639.67 S 54 27 E 996.98 S 1393.39 E 1713.33 S 54 24 E 1038.41 S 1455.57 E 1788.01 S 54 29 E 1079.08 S 1517.42 E 1861.98 S 54 34 1119.72 S 1578,25 E 1935.11 S 54 38 1160.21 S 1638.24 E 2007.47 S 54 41 1200.34 S 1697.45 E 2078.98 S 54 44 E 1240.27 S 1756.24 E 2150.04 S 54 46 E 1279.84 S 1815.15 E 2220.98 S 54 48 E 1319.18 S 1874.37 E 2292.06 S 54 51 E 1358.04 S 1933.56 E 2362.82 S 54 55 E 1396.14 S 1992.62 E 2433.05 S 54 58 E 1433.24 S 2053.85 E 2504.49 S 55 5 E 1469.05 S 2116.50 E 2576.37 S 55 14 E 1503.30 S 2180.30 E 2648.32 S 55 24 E 1536.98 S 2244.53 E 2720.33 S 55 35 E 1570.18 S 2309.00 E 2792.30 S 55 47 E 1602.94 S 2373.71 E 2864.25 S 55 58 E 1635.27 S 2438.45 E 2936.01 S 56 9 E 1667.09 S 2503.27 E 3007.58 S 56 20 E 1698.34 S 2567.93 E 3078.74 S 56 31 E 1728.98 S 2632.83 E 3149.79 S 56 42 E 1759.26 S 2698.16 E 3221.03 S 56 53 E 1789.09 S 2763.83 E 3292.36 S 57 5 1618.57 S 2829.75 E 3363.74 S 57 16 1847.77 S 2895.74 E 3435.04 S 57 27 1876.47 S 2961.90 E 3506.28 S 57 38 1904.53 S 3028.26 E 3577.37 S 57 50 E 1931.59 S 3094.08 E 3647.52 S 58 1 E 1958.00 S 3159.28 E 3716.83 S 58 12 E 1984.13 S 3224.81 E 3786,31 S 58 23 E 2009.94 S 3290.30 E 3855.63 S 58 34 E 2035.46 S 3355.97 E 3925.00 S 58 45 E 2060.29 S 3421.70 E 3994.10 S 58 56 E 2084.35 S 3487.39 E 4062.81 S 59 8 E 2107.85 $ 3553.18 E 4131.36 S 59 19 E 2130.92 S 3519.34 E 4200.05 S 59 30 E 2153.40 S 3685.38 E 4268.39 S 59 42 E 2175.50 S 3751.21 E 4336.40 S 59 53 E COMPUTATION DATE: 6-SEP-86 PAGE ARCO ALASKA~ INC. 3K-14 KUPARUK NORTH SLOPE~ALASKA DATE OF SURVEY: lB-AUG-B6 KELLY BUSHING ELEVATZON: ENGINEER: WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 8000.00 6211.26 6142.26 43 34 8100.00 6283.69 6214.69 43 31 8200,00 6356,40 6287,40 43 10 8300.00 6429.76 6360.76 42 32 8400.00 6503.69 6434.69 42 5 8500.00 6578.48 6509.48 40 49 8600.00 6655.05 6586.05 39 5 8700.00 6733.49 6664.49 37 50 8800.00 6813.28 6744.28 35 53 8900.00 .6894,29 6825.29 35 53 8960.00 6942.89 6873.89 35 53 69.O0'FT FEET DEG/IO0 S 71 55 E 4403,97 S 72 8 E 4471,48 S 72 10 E 4538.65 S 72 8 E 4605.16 S 72 7 E 4671.05 S 70 44 E 4736.[8 S 71 36 E 4799.36 S 71 46 E 4860,15 S 70 32 E 4919.26 S 70 25 E 4976.97 S 70 25 E 5011.60 0.41 0.36 0.36 0.53 0.55 1.68 2.28 1.07 3.33 0.00 0.00 FEET FEET FEET DEG MIN 2197.15 S 3816.77 E 4404.00 S 60 4 E 2218.40 S 3882.38 E 4471.48 S 60 15 E 2239.38 S 3947.74 E 4538.66 S 60 26 E 2260,18 S 4012.44 E 4605.23 S 60 36 E 2280.82 S 4076,53 E 4671,21 S 60 46 ~ 2301,96 S 4139,45 E 4736.46 S 60 55 2322,81 S 4200.29 E 4799,78 S 61 3 E 2342,24 S 4259,19 E 4860,74 S 61 11 E 2361,34 S 4316,35 E 4920,04 S 61 19 E 2380.96 S 4371.59 E 4977.93 S 61 25 E 2392,75 S 4404,73 E 5012,68 S 61 29 E VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH COMPUTATION DATE: 6-SEP-86 PAGE ARCO ALASKA, INC. 3K-14 KUPARUK NORTH SLOPE,ALASKA DATE OF SURVEY: 18-AUG-86 KELLY BUSHING ELEVATION: 69.00 FT ENGINEER: NEST INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPT TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -69.00 0 0 1000.00 999.95 930.95 0 15 2000.00 1961.74 1892.74 29 0 3000.00 2700.35 2631.35 45 42 4000.00 3416.27 3347.27 44 9 5000..00 4106.22 4037.22 45 14 6000.00 4800.72 4731.72 46 4 7000.00 5496.95 5427.95 44 48 8000.00 6211.26 6142.26 43 34 8960.00 6942.89 6873.89 35 53 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOOTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN N 0 0 E 0.00 N 65 36 N -8.26 S 54 47 E 208.10 S 52 3 E 869.34 · S53 6 E 1560.77 S 56 33 E 2281.74 S 64 2 E 3000.39 S 68 7 E 3714.36 S 71 55 E 4403.97 S 70 25 E 5011.60 0.00 1,42 3.36 1.52 2.11 0.34 0.47 0.43 0.41 0.00 0.00 N 0.00 E 0.00 N 0 0 E 0.41 S 9.75 W 9.76 S 87 34 W 83.05 .S 192.20 E 209.37 S 66 37 E 486.08 S 723.56 E 871.67S 56 6 E 910.61 S 1277.41 E 1568.75 S 54 30 1319.18 S 1874.37 E 2292.06 S 54 51 1567.09 S 2503.27 E 3007.58 S 56 20 E 1958.00 S 3159.28 E 3716.83 S 58 12 E 2197.15 S 3816.77 E 4404.00 S 60 4 E 2392.75 S 4404.73 E 5012.68 S 61 29 E COMPUTATION DATE: 6-SEP-86 PAGE ARCO ALASKA, INC. DATE DF SURVEY: 18-AUG-86 3K-14 KUPARUK NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: WEST 69.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET DF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -69.00 0 0 N 0 0 E 69°00 69.00 0.00 0 21 S 71 25 W 169.01 169.00 lO0.O0 0 36 S 87 9 W 269.01 269.00 200.00 0 33 N 86 5 W 369.02 369.00 300.00 0 40 S 89 50 W 469.02 469.00 400.00 0 37 S 85 35 W 569.03 569.00 500.00 0 36 S 86 47 W 669.04 669.00 600.00 0 33 N 88 36 W 769.04 769.00 700.00 0 34 N 84 53 W 869.05 869.00 800.00 0 37 S 82 54 W 0.00 0.00 0.00 N 0.00 E -0.06 0.73 0.08 S 0.12 W -0.84 0.29 0.29 S 1.13 W -1.74 0.02 0.25 S 2,14 W -2.70 0.14 0.22 S 3.23 W -3.70 0.10 0.27 S 4.41 W -4.59 0.12 0.35 $ 5.49 W -5.46 0.06 0.36 S 6.49 W -6°35 0.11 0.31 S 7.48 W -7.26 0.22 0.22 S 8°48 W 0.00 N 0 0 E 0.14 S 55 1 W 1.17 S 75 38 W 2.16 S 83 15 W 3.24 S 86 6 4.42 S 86 27 5.50 S 86 21 6.50 S 86 51 W 7.49 S 87 37 W 8.48 S 88 29 W 969.05 969.00 900.00 0 30 1069.07 1069.00 1000.00 2 3 1169.31 1169.00 1100.00 5 30 1270.00 1269.00 1200.00 7 27 1371.05 1369.00 1300.00 9 14 1472.73 1469.00 1400.00 11 58 1575.71 1569.00 1500.00 15 '8 16?9.91 1669.00 1600.00 17 54 1786.37 1769.00 1700.00 21 58 1895.66 1869.00 1800.00 25 31 S 81 16 W N 50 46 E N 54 39 E N 59 45 E N 86 28 E S 74 2 E S 63 42 E S 57 53 E S 56 28 E S 55 26 E -8.09 0.56 0.40 S 9.54 W -8.11 4.28 0.32 N 9.16 W -5,00 2.91 4.07 N 3.44 W -0.24 3.36 10.97 N 5.98 E 9.97 3.24 14.71 N 19.86 E 26.78 4.74 12.50 N 37.96 E 51.00 3.26 3.47 N 60.69 E 80.24 3.81 11.22 S 85.98 E 116.63 3.38 160.53 3.26 9.55 S 87 36 W 9.16 N 88 0 W 5.33 N 40 10 W 12.50 N 28 35 E 24.71 N 53 29 E 39.96 N 71 46 E 60.79 N 86 43 E 86.71 S 82 33 E 31.05 S 116.56 E 120.63 S 75 5 E 55.73 S 153.02 E 162.85 S 69 59 E 2008.32 1969.00 1900.00 29 18 2125.43 2069.00 2000.00 33 14 22~8.03 2169.00 2100.00 37 43 2379.11 2269.00 2200.00 42 49 2521.88 2369.00 2300.00 47 5 2668.12 2469.00 2400.00 46 29 2812.45 2569.00 2500.00 45 52 2955.32 2669.00 2600.00 45 23 3098.98 2769.00 2700.00 46 7 3242.22 2869.00 2800.00 45 19 S 54 44 E S 54 2 E S 53 5 E S 52 46 E S 52 51 E S 52 39 E S 52 12 E S 51 51 E S 53 14 E 212.14 3.50 272.71 3.16 343.08 3.90 427.04 4.18 527.99 0.43 633.79 0.45 736.88 0.77 837.85 0.42 940.03 0.59 0.59 S 52 38 E 1041.74 85.40 S 195.51 E 213.35 S 66 24 E 120.83 S 245.03 E 273.21 S 63 45 E 162.96 S 302.01 E 343.17 S 61 38 E 214.05 S 369.53 E 427.05 S 59 55 E 275.61 S 450.64 E 528.24 S 58 32 F 340.16 S 535.62 E 634.51 S 57 34 403.58 S 618.12 E 738.21 S 56 51 466.42 S 698.52 E 839.93 S 56 16 ~ 529.20 S 780.35 E 942.87 S 55 51 E 590.90 S 862.25 E 1045.29 S 55 34 E 3383.69 2969.00 2900.00 44 42 3523.13 3069.00 3000.00 43 43 3660.57 3169.00 3100.00 42 54 3796.83 3269.00 3200.00 43 11 3934.?5 3369.00 3300.00 43 23 4074.51 3469.00 3400.00 45 44 4222.08 3569.00 3500.00 48 23 4371.86 3669.00 3600.00 47 34 4518.64 3769.00 3700.00 46 32 4662.78 3869.00 3800.00 45 35 S 52 7 E 1140.86 S 52 0 E 1237.02 S 51 28 E 1330.26 S 52 ~9 E 1421.76 S 53 33 E 1516.12 S 53 2 E 1612.97 S 55 36 E 1720.75 S 56 33 E 1832.03 S 56 2 E 1939.21 S 55 50 E 2042.72 0.54 0.53 0.62 2.15 1.09 2.14 2.60 0.92 0.85 0.60 651.99 S 941.51 E 1145.22 S 55 17 E 711.82 S 1018.08 E 1242.25 S 55 2 E 770.14 S 1092.16 i 1336.39 S 54 48 E 827.52 S 1164.77 E 1428.81 S 54 36 E 883.71 S 1241.35 E 1523.77 S 54 33 E 942.27 S 1319.45 E 1621.37 S 54 28 E 1006.35 S 1406.99 E 1729.84 S 54 25 E 1067.63 S 1500.13 E 1841.26 S 54 33 E 1127.29 S 1589.50 E 1948.66 S 54 39 E 1185.42 S 1675.50 E 205'2.44 S 54 43 E ARCO ALASKA~ INC. 3K-14 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 6-SEP-86 PAGE 6 DATE OF SURVEY: 18-AUG-86 KELLY BUSHING ELEVATION: ENGINEER: WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 4805.05 3969.00 3900.00. 45 10 4947,11 4069,00 4000,00 45 19 5088,95 4169,00 4100,00 44 52 5229,95 4269,00 4200,00 45 32 5373,90 4369.00 4300,00 46 16 5518,90 4469,00 4400,00 46 28 5664.17 4569,00 4500.00 46 29 5809.39 4669,00 4600.00 46 25 5954,20 4769,00 4700,00 46 12 6098,12 4869,00 4800,00 45 51 6241.88 4969,00 4900,00 46 2 6386,15 5069,00 5000.00 46 10 6530,68 5169,00 5100.00 46 11 6675,06 5269,00 5200,00 46 8 6819,18 5369,00 5300,00 45 42 6960,63 5469,00 5400,00 44 41 7101,65 5569,00 5500,00 44 50 7242,46 5669,00 5600.00 44 46 7383.22 5769,00 5700.00 44 29 7523,17 5869.00 5800.00 44 18 7663.07 5969.00 5900.00 44 29 7802,83 6069,00 6000.00 44 12 7941,61 6169.00 6100.00 43 42 8079,73 6269.00 6200,00 43 35 8217,27 6369,00 6300.00 43 5 8353.22 6469,00 6400.00 42 17 8487.46 6569,00 6500.00 41 1 8617.95 6669°00 6600,00 38 44 8744.83 6769.00 6700.00 37 13 8868.79 6869.00 6800,00 35 53 69,0 mo FT FEET DEG/IO0 S 56 1 E 2143.60 S 56 23 E 2244.25 S 56 52 E 2344.63 S 58 21 E 2443.88 S 60 33 E 2547.42 S 62 12 E 2652,39 S 62 49 E 2757,68 S 63 18 E 2862,86 S 63 52 E 2967,42 $ 64 25 E 3070.70 S 65 6 E 3173.65 S 65 43 E 3277.23 S 66 5 E 3381.07 S 66 40 E 3484.64 S 67 29 E 3587.70 S 67 58 E 3686.88 S 68 24 E 3785.38 S 68 43 E 3883.48 S 69 31 E 3981.38 S 70 13 E 4077.92 S 70 48 E 4174.20 S 71 23 E 4270.09 S 71 41 E 4364.50 S 72 6 E 4457.81 S 72 9 E 4550,21 S 72 8 E 4640.34 S 70 49 E 4728.11 S 71 42 E 4810.43 S 71 38 E 4886.97 S 70 25 E 4958.96 S 70 25 E 5011,60 0.24 0.43 0.88 2.20 1.44 0.36 0.37 0.48 0.39 0.41 0,43 0.37 0,28 0,42 1,31 0,46 0,44 0,31 0,54 0,21 0.21 0,19 0.40 0,20 0,55 1,13 1,97 2.14 1,75 0.00 0,00 FEET FEET FEET DEG MIN 1242,27 S 1759,21 E 2153.61 S 54 46 E 1298,44 S 1843.04 E 2254.50 S 54 50 E 1353,79 S 1927,04 E 2355.04 S 54 54 E 1407.45 S 2010.69 E 2454.34 S 55 0 E 1459.85 $ 2099.99 E 2557.57 S 55 11 1509.70 S 2192.41 E 2661,92 S 55 26 1558,35 S 2285.88 E 2766.53 S 55 42 E 1606.00 S 2379,79 E 2871.00 S 55 59 E 1652,59 S 2473,58 E 2974,83 S 56 15 E 1697,76 S 2566,71 E 3077,41 S 56 31 E 1741,72 S 2660.16 E 3179.63 S 56 47 E 1784,99 S 2754,72 E 3282,48 S 57. 3 E 1827.57 S 2849,99 E 3385,62 S 57 19 E 1869.36 S 2945,38 E 3488,52 S 57 35 E 1909,80 S 3040,95 E 3590,93 S 57 52 E 1947,63 S 3133.56 E 3689,51 S 58 8 E 1984,56 S 3225,89 E 3787',46 S 58 24 E 2020,83 S 3318.15 E 3885.08 S 58 39 E 2056,19 S 3410,68 E 3982,55 S 58 54 E 2089.83 S 3502.63 E 4078.70 S 59 10 E 2122,43 S 3594.88 E 4174.67 S 59 26 E 2154.03 S 3687.24 E 4270.32 S 59 42 E 2184.59 S 3778.50 E 4364.57 S 59 57 E 2214.11 S 3869.08 E 4457.81 S 60 13 E 2243,00 S 3958,98 E 4550,23 S 60 27 : 2271,Z3 S 4046,64 E 4640,45 S 60 41 2299,23 S 4131.71 E 4728,37 S 60 54 2326.36 S 4211.01 E 4810.88 S 61 4 ~ 2350,80 S 4285,18 E 4887,64 S 61 15 E 2374.83 S 4354.35 E 4959.86 S 61 23 E 2392.75 S 4404.73 E 5012.68 S 61 29 E 8960.00 6942.89 6873.89 35 53 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH ARCO ALASKA, INC. 3K-14 KUPARUK NORTH SLOPE,ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD COMPUTATION' DATE: 6-SEP-86 PAGE DATE OF SURVEY: 18-AUG-86 KELLY BUSHING ELEVATION: 69.00 FT ENGINEER: WEST INTERPOLATED VALUES FOR CHOSEN HORIZONS MEASURED DEPTH BELOW KB FROM KB SURFACE LOCATION AT ORIGIN: 1060' FSL, 316' FWL, SEC 35, T13N, R§E,' U TVD RECTANGULAR COORDINATES SUB-SEA NORTH/SOUTH EAST/WEST 8403.00 8504.00 8626.00 8789.00 8847.00 8960.00 6505.91 6581.51 6675.31 6804.39 6851.35 6942.89 6436.91 2281.43 S 4078.45 E 6512.51 2302.83 S 4141.92 E 6606.31 2327.92 S 4215.76 E 6735.39 2359.23 S 4310.22 E ";' 6782.35 2370.55 S 4342.32 E 6873.89 2392,75 S 4404.73 E ARCO ALASKA, INC. 3K-14 KUPARUK NORTH SLOPE,ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARU'K A PBTD TD COMPUTATION DATE: 6-SEP-86 PAGE DATE OF SURVEY: 18-AUG-86 KELLY BUSHING ELEVATION: ENGINEER: WEST 69.06' FT ~~¢~~ STRATIGRAPHIC MEASURED DEPTH BELOW KB 8403.00 8504.00 8626.00 8789.00 8847.00 8960.00 SUMMARY SURFACE LOCATION AT. ORIGIN= 1060' F.SL, 316' FWL, SEC 35, T13N, RgE,' U TVD RECTANGULAR COORDINATES FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 6505.91 6436.91 2281.43 S 4078.45 E 6581.51 6512.51 2302.83 S 4141.92 E 6675.31 6606.31 2327.92 S 4215.76 E 6804.39 6735.39 2359.23 S 4310.22 E 6851,35 6782.35 2370.55 S 4342°32 E 6942.89 6873.89 2392.75 S 4404.73 E FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 8960.00 6942.89 6873.89 5012.68 S 61 29 E SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 3K-14 F ! 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N--N-t.N-~...~- .4...~...;...N.--N--.N ....... ;-..;.--;-.-;--~-;...~...~-..~ ...... +.?.~..;. ;..:..;4.-.71...;.~ +. ;4 ...... ~...;..; .~ .4.-~...~-~..-[.~-L4-~ ...~.-.~-.-~-..~.-.~---~.. ~-.~.-L..-~-L.L-~...Li-L.~...; ..... ~...i..-~-.-~--.;--.~-.~--~.-.~ ..... L.~,.4...~...~-.L-;,..~..~ ...... L.~_L.Lj. ;..L ~. L L ~. ~. L. X. L ............ ~ i.. i.~ i..i 7000 ]19. PROJECTION ON VERTICAL PLANE 119. - 299. SCALED IN VERTICAL DEPTHS HORIZ SCALE = ]/ ]000 IN/FT ARCO Alaska, Inc. Pos! Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #5854 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH Finals (blueline unless specified otherwise)' 3K-1~ 5" DIL 8-27-86 4761-9572 5" FDC Porosity 8-27-86 4761-9548 '~2" FDC Raw 8-27-86 4761-9548 ~ ~ ~"2" FDC Porosity 8-27-86 4761-9548 ~"-~,~ ~,~5" FDC Raw 8-27-86 4761-9548 · '~ ~,~2" DIL 8-27-86 4761-9548 Cyberlook 8-27-86 4761-9548 3K-14~Cyberlook 8-4-86 8300-8900 '"'2" DIL 8-4-86 4752-8948 ~2" FDC Porosity' 8-4-86 8000-8922 ~" FDC Raw 8-4-86 8000-8922 ~"~ ~" FDC Raw 8-4-86 4752-8922 ~5" FDC Porosity 8-4-86 8000-8922 -~5" DIL 8-4-86 4752-8948 3K-16-~' 5" DIL "'J2" DIL '~ 5" FDC '""5" FDC ~ 2" FDC "'J2" FDC Raw ~ Cyberlook 8-19-86 4893-9046 8-19-86 4893-9046 Porosity 8-19-86 8275-9021 Raw 8-19-86 8120-9021 Porosity 8-19-86 8275-9021 8-19-86 8120-9021 8-19-86 4893-9006 Receipt Acknowledged- Date' Distribution' NSK Drilling State :.of.~.A1 aska; Ra thme 11 Vault (film) D&M Johnston (ven. pkg) ........ '-- '-~ ~ ~ ~,,h,~i~imrv ef AtlanticRichlieldCompany ALASKA STATE OF ALASKA AND GAS CONSERVATION COMMIS .~N REPORT OF SUNDRY WELL OPERATIONS Operation shutdown ~ Alter Casing ~ Other Stimulate .~, Plugging '-- Perforate - Pull tubing COvlPLE~ 1. Operations performed: 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1060' FSL, 316' FWL, Sec.35, T13N, RgE, At top of productive interval 1221' FNL, 1409' FEL, Sec. 1, T12N, R9E, LH At effective depth 1311' FNL, 1145' FEL, Sec. 1, T12N, R9E, At total depth 1333' FNL, 1082' FEL, Sec. 1, T12N, R9E, UM 5. Datum elevation (DF or KB) RKB 69' 6. Unit or Property name Kuparuk River Unit 7. Well number 3K-14 8. Approval number 372 9. APl number 50-- 029-21631 10, Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured 8960'1VD feet Plugs (measured) true vertical 6943 "['VD feet Effective depth: measured 8847'rVD feet Junk (measured) true vertical 6851 "]'VD feet Feet None Cas~]no~lductor Lengt~o, Size6,, Cemented1540~ Pol eset Measured 115depth'rvD True115Vertical, TvD depth Surface 4713' 9-5/8" 1340 sx AS III & 4750'iVD 3930'7VD 330 sx Class G Production 8932' 7" 350 sx Class G & 8932'MD 6920'TVD 175 sx AS I Perforation depth: measured None None true vertical Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail @ 8574' Packers and SSSV (type and measured depth) HRP-I-SP pkr @ 8548' & TRDP-1A-SSA SSSV @ 1792' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressbre 13. Representative Daily Average Production or Injection Data N/A OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments (Corpletion Well History w/Addendun, dated 9/02/86) Daily Report of Well OIDe~r-a.t. ions~(_~ ..... ; Copies of Logs and Surveys RunXZ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge .... Form 10-404 Rev. 12-1-85 Title Associate En.~ineer Date IZ-17-,gL~ Submit in Duplicate (Dm) SW0/Z43 ADDENDUM WELL: 8/19/86 8/14/86 3K-14 RU Schl, rn GR/JB f/8850' WLM - surf. Rn CET f/8844'-7215'. Rn gyro f/8802'-surf. RD Schl. Arctic Pak w/175 sx AS I & 60 bbls Arctic Pak. Drilling Supervisor Date ARCO O~, and Gas Company Daily Well History-Final Report Instructions: ~recare and Suum~ :he "Final Report" CF, :he f~rst Wed,'-esday aqer a'~o..'.,ab~e has ~ee~ ass~oe~ 3r ,'.e;' 'S =~uc~e; 43an:!:.red ~r S3[d. "Final Report" shou~C be suSm~t:eC aisc ,',Fen ooeratJons are sus~e~ed Accounting District ICounW cr Parish Alaska Fieid Lease or Ur'i! Kuparuk River Auth. or W.O. no. Yit~e AFE AK1461 North Slope Borough ADL 25629 Completion Nordic 1 API 50-029-21631 Alaska 3K-14 Operator IA.R.Co. W.I. ARCO Alaska, Inc. ' 56.24% Spudded or W.O. begun Date Complete 12/6/86 Date and depth Complete record for each day reported as of 8:00 a.m. 12/07/86 Iotal number of wells (ac.ye or inactive) on this cst center prior to plugging and bandonment of this well our I Prior status if a W.O. 1500 hrs. 7" @ 8932' 8847' PBTD, RR 6.8 ppg diesel ~Ccept rig @ 1500 hrs, 12/6/86. NU & tst DOPE. RU & rn 260 jts, 2-7/8", 6.5#, J-55 EUE 8RD AB-Mod tbg w/SSSV @ 1792', HRP-1-SP pkr @ 8548', TT @ 8574'. Tst tbg & ann to 2500 psi. Tst SSSV; OK. ND BOPE, NU & tst tree; OK. Displ well w/diesel. RR @ 0800 hrs, 12/7/86. Old TO I New TD PB Depth 8847 ' PB'i'D Released rig I Date [Kind of r g 0800 hrs. 12/7/86 I Rotary Classifications {oil. gas. etc.) J Type completion (single, dual, etc.) Oil I Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Inte~,sl Oil or gasTest time Production .. Oil on test Gas per day Pump size, SPM X length Choke size T.P. C,P. Water % GOR Gravity Allowable Effective date corrected , . The above is correct For ,o r~ [~e~ar~is~ribu~'~ O]~il'illg see Procedures Manual. Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C "Numher all daily well history forms consecutively las Ihey are prepared for each we I. iPage no. 1 DIvI~o~ of AtlantlcRIchfleldCompe~y STATE Of ALASKA - ALA~,..~ OIL AND GAS CONSERVATION CON, .... $SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon - Suspend Z Operation Shutdown}CC: Re-enter suspended well -- Alter casing ;-; Time extension ~ Change approved program ~ Plugging ~ Stimulate ~ Pull tubing ~ Amend order- Perforate '- Other - 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchoraqe~ AK 99510 4. Location of well at surface 1060' FSL, 316' FWL, Sec 35, T13N, R9E, UN At top of productive interval 1186' FNL, 1554' FEL, Sec. 1, T12N, R9E, UM (Approx) At effective depth 1297' FNL, 1141' FEL, Sec. 1, T12N, R9E, UM (Approx) At total depth 1319' FNL, 1074' FEL, Sec. 1, T12N, R9E, UM (Approx) 5. Datum elevation (DF or KB) 69 ' RKB 6. Unit or Property name Kuo~ruk River Unil; 7, Well number 3K-14 8. Permit number 86-137 9. APl number 50-- 029-21631 10. Pool kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface 8960 'MD feet 6945 ' TVD feet 8847 'MD feet 6857 ' TVD feet Production Length Size 80' 16" 4713' 9-5/8" 8932 ' 7" Plugs (measured) None Junk(measured) None Cemented Measured depth 1540# Pol eset 115'MD 1340 sx AS III & 330 sx Class G 4750 'MD 350 sx Class G 8932 'MD True Vertical depth llS'TVD 3299 ' TVD 6923 ' TVD Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None 12.Attachments Description summary of proposal Well Hi story 13. Estimated date for commencing operation December, 1986 Detailed operations program BOP sketch 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~~ ~[~L~ Title Associate Engineer Date 3-~0 ~/~ Commission Use Only (DAM) SA/101 Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity I Approval No. ? [] T.t by order of Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate . RCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL IPBDT .~ /<-/q r'r~NTRACTOR t~,~MARKS IFIELD- DISTRICT- STATE OPERATION AT REPORT TIME /'4 Y~ WELL SERVICE REPORT ~lIDO /~?..-- /2__q?~ -- ,~4zo ~''- O i' L · ~. $ . / f 71 .~z54._ / ,v'rv /2,si 12S5~ I~/CHECK THIS BLOCK IF SUMMARY CON'BNUED ON BACK / REMARKS CONTINUED: /.200 ~/~?o~ L~ DESCRIPTION DAILY ACCUM. TOTAL ~SAMCO OTIS ~., 2.. o r~ SCHLUMBERGER / /_5~0 oo /Y_.s-. DRESSER.ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER , B. J. HUGHES Roustabouts Diesel /2~O0 X ¢¢Z.. 7'. /2_. ~5".~"2_ Methanol Supervision Pre-Job Safety Meeting ~000 ~0 O0 " AFE · _ TOTAL FIELD ESTIMATE /2. (,,.~' _5- Z_. 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 Alaska Field Kuparuk River Auth. or W.O. no. AFE AK1461 County. parish or borough North Slope Borough IL ....or Unit ADL 25629 ITitle Drill JState Alaska IWell no, 3K-14 Doyon 9 API 50-029-21631 Operator IARCO W.I- ARCO Alaska, Inc. 56.24% SpuddedorW.O. begUnspudded Date 7/29/86 IH°ur 2100 hrs. IPri°rstatusifaW'O' Date and depth es of 8:00 a.m. 7/30/86 7/31/86 8/01/86 8/02/86 thru 8/04/86 Complete record for each day reported 16" @ 115' 1257', (1142'), Drlg Wt. 9.1+, PV 14, YP 26, PH 8.5, WL 14.0, Sol 6 Accept rig @ 1900 hfs, 7/29/86. NU diverter sys. Spud well @ 2100 hrs, 7/29/86. Drl 12¼" hole to 1257'. 457', 0.8°, N76.2E, 456.99 TVD, +2.31VS, 0.76N, 3.10E 953', 0.9°, N85.7W, 952.93 TVD, -0.60 VS, 5.89N, 2.67E 1139', 4.5°, N59.9E, 1138.69 TVD, -5.05 VS, 12.31N, 1.20E 16" @ 115' 3591', (2334'), Drlg Wt. 9.3, PV 12, YP 10, PH 8.5, WL 13.2, Sol 7 DD & surv 12¼" hole to 3591'. 1328', 8.2°, N72.6E, 1326.50 TVD, 7.37 VS, 20.71N, 20.29E 1705', 18.5°, S56.7E, 1692.85 TVD, 89.44 VS, 4.23S, 100.55E 2249', 37.2°, S51.9E, 2171.14 TVD, 341.68 VS, 155.38S, 304.72E 3152', 45.7°, S53.2E, 2817.60 TVD, 965.28 VS, 535.43S, 805.86E 9-5/8" @ 4750' 4770', (1179'), Rn'g 9-5/8" Wt. 9.4, PV 11, YP 10, PH 9.0, WL 11.2, Sol 8 Drl & surv 12¼" hole to 4770', short trip, C&C, POH. RU & rn 119 its, 9-5/8", 36#, J-55 BTC csg w/FC @ 4667', FS @ 4750' 3658', 42.9°, S52.2E, 3179.90 TVD, 1315.53 VS, 749.56S, 10~6.90E 4255', 48.3°, S56.7E, 3597.44 TVD, 1739.54 VS, 997.40S, 1433.72E 4710', 45.3°, S56.5E, 3908.87 TVD, 2070.50 VS, 1179.96S, 1710.59E 9-5/8" @ 4750' 8960', (4210'), C&C hole Wt. 9.9+, PV 17, YP 7, PH 9.0, WL 4.0, Sol 10 Rn 119 jts, 9-5/8", 36#, J-55, BTC csg w/FC @ 4667', FS @ 4750'. Cmt w/1340 sx AS III w/10#/sx Gilsonite, followed by 330 sx C1 "G" w/2% S-1 & .2% D-46. Displ using rig pmps, bump plug. CI? @ 1030 hrs, 8/1/86. RIH, DO cmt & flt equip + 10' new hole. Conduct formation tst to 12.5 ppg EMW. Drl & surv 8½" hole to 8960'. 5032', 45.2°, S55.2E, 4135.56 TVD, 2298.48 VS, 1308.33S, 1899.83E 5472', 46.5°, S61.7E, 4442.03 TVD, 2613.75 VS, 1473.43S, 2168.73E 5973', 46.4°, S63.7E, 4787.22 TVD, 2976.62 VS, 1639.96S, 2491.38E 6987', 44.9°, S68.4E, 5490.66 TVD, 3703.23 VS, 1938.34S, 3157.96E 7991', 43.8°, S70.7E, 6207.65 TVD, 4396.49 vS, 2181.93S, 3816.85E 8355', 42.6°, S73.2E, 6472.99 TVD, 4640.51VS, 2259.12S, 4053.74E The.~ is correct IDate'~/7 ~ I Title Drilling Supervisor For i~orrn prepar.a'~or) and distribu~on~ see ProceduresqM. edual, Section Drilling, Pages 86 and 87, ARCO Oil and Gas Company Daily We,, 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 of time. On workovers when an official test is not required upon completion, report comptetion and representative test data in blocks provided. The "Final Reporl" form may be used for reporting the entire operation if space is available. District IC°unty or Parish I Alaska Field ~Lease or Unit I Kuparuk River Auth. or W.O. no. ~Title I AFE AK1461 Doyon 9 North Slope Borough ADL 25629 Drill Accounting State cost center code Alaska IWen~_14 API 50-029-21631 I otal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well our I Prior status if a W.O. I 2100 hrs. Operator A.R.Co. W.l. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Spudded 7 / 29/86 Date and depth Complete record for each day reported as of 8:00 a.m. 8/o5/86 8/06/86 9-5/8" @ 4750' 8960', (0'), LD DP Wt. 9.9+, PV 16, YP 8, PH 9.0, WL 3.8, Sol 10 Circ & pmp pill, short trip, C&C, spot 50 bbl w/10% diesel pill, POOH. RU Schl, rn DIL/SP/SFL f/8960'-4750', GR f/8960'-1000', FDL/CNL f/8960'-8050', CAL f/8960'-7250', RD Schl. Make cond'g run, POOH, LD DP. 8905', 34.4°, S70.0E, 6902.04, 4977.23 VS, 2367.51S, 4379.57E 7" @ 8932' 8960' TD, 8847' PBTD, RR 9.9 ppg Brine Chg rams to 7" & tst. RU & rn 217 its + 1 mkr jt, 7", 26#, J-55 BTC csg w/FS @ 8932', FC @ 8849', Mkr Jt @ 8932'. Cmt w/100 sx 50/50 Pozz w/4.0% D-20, .5% D-65 & .2% D-46, followed by 250 sx C1 "G" w/3% KC1, .9% D-127, .3% D-13 & .2% D-46. Displ using rig pmps, bump plug. ND BOPE, instl pack-off & tbg head, tst to 3000 psi. RR @ 2400 hfs, 8/5/86. Old TD New TD PB Depth 8960' TD 8847' PBTD Released rig Date Kind of rig 2400 hrs. 8/5/86 Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The.~? is correct ~; f?;o~?u~, ~'~Y2~U~'o°, '-~- Drilling, Pages 86 and 87. Drilling Supervisor ARCO Alaska, In Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 08-21-.86 TRANSMITTAL # 5747 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole LIS Tape Plus Listing' Schl' One copy of each ~3K-14 08-04-86 Run #1 0996.0-8983.0 2 2 198~ ~ .Alaska Oil &A6na~oOr:~:. Commission Receipt Acknowledged: State of Ak Date: ARCO Alaska. Inc. is a Subsidiary ol AtlanlicRichfieldCompany MEM-ORAr-'-OUM Staf of Alaska TO' A~_LASKA OIL X~D GAS CONSERVATION COM2.~I~zON C. V. C 1-~ DATE' August 11, 1986 Chairma~Z- FI LE NO.: D. JFB. 8 THRU: Lonnie C Sml't:~i TELEPHONE NO.: C ommis s ioner John F Boyle_- / ~' ~--- Petroleum Engzneer Assr FROM: SUBJECT: BOP Test ARCO KRU 3K-14 Permit No. 86-137 Kuparuk River Field Frzday, Augus~ i, 198o: After observing the BOP test at ARCO PBU ~I ~2 ~el~' %--~raveled to AP, CO KRU 3K-14 to witness a BOP test on Doyon Rig #9. The test began at 4:15 p.m. and concluded at 5:45 p.m. There were no failures, and I filled out an AOGCC BOP report which is attached. In surm~ary, I witnessed the successful BOP test at ARCO KRU 3K-14 well. Attachment ~':' -'-:'%::..--::::-z./:': ! i . · ..... ' '.' .. B.O.P.E. Inspection Report :~:~_ Operator- ARCO -: :T '~ .... '. .... I' -:'~~ :~- -.--. : - :4 '5? :' ': .-5:5_::~'~5~- General HouSekeepingel~,~ Rtg-~ I~t~ -- ~ese~e sit O~ . · Mud Systems Visual Audio .: Trip Tank Pit Gauge ' Flow Monitor · --- Gas Detectors BOPE Staek ./i.' :.- :' ': Choke Line Valves Check Valve Representative Representative ~Oy ' ACC~ATOR SYST~ FuZZ Charge Pressure ~q~O pressure After Closure'/~-O 0 _ Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: Controls: Master psig psig rain ~ sec. ~ min~ sec. ~ ~ ~.f~ /g./f~ psig ' ' ............ ' Kelly and Floor Safety Valves Test Pressure-::::< Lower Kelly 0 k Test Pressure B2ll Type . Inside BOP Choke Manifold No. Valves No. flanges ,? oo ~ 3oD-~ Adjustable Chokes Hvdrauicall¥ operated choke 300o Results Test : Failures ~ Test Time l · Repair or Replacement of failed equmpment to be made within ______ 'C°mmiSsi°n °ffice n°tified' ~)~XRemarks: ~7 ~ ~ / days and Inspector/ ..... .,',, f-'i ~. .__C '1, .,' Distribution orig. - AO&GCC cc - Operator cc - Supe~isor Inspector ~ July 15, 1986 Mr. J. B. Kewin Regional Drilling Engineer A~CO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: KuParuk River Unit 3K-14 ARCO Alaska, Inc. Permit No. 86-137 SUr. Loc. 1060'FSL, 316''~L, Sec. 35, T13N, R9E, UM. Btmhote Loc. 1419'F!'~, I147'FEL, Sec. 1, T12N, R9E, Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indenmify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~here a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. .~y t~u .~'~yours ,M l/ : ~/ f /.J .~~- . ..... ~-- C. V. Chatterton~ Chairman o f Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE CO~flSSION d!f Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery STATE OF ALASKA ALASKA ,_ ,L AND GAS CONSERVATION Ct_ ,~MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill .~ Redrill []1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil ~ Re-Entry [] Deepen ~1 Service [] Developement Gas ~ Single Zone'~ Multiple Zone ~ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 69', PAD 35' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P.O. Box 100360 Anchorage, AK 99510 ADL 25~29 ALK 2562 4. Location of well,at ~rface ~ ¢,,,r,~b,~/¢¢'~-~ 7. Unit o~property Name 11. Type Bond (see 20 AAC 25.025) 1060'FSL, 316'F~L, Sec.35, T13N, R~E, UM Kuparuk River Unit Statewide At top of produbtive interval 8. Well nu .tuber Number 1186'FNL, 1554'FEL, Sec.1, T12N, R~E, UM 3K-14 #8088-26-27 At total depth 9. Approximate spud date Amount 1419'FNL, 1147'FEL, Sec.1, T12N, R~E, UM 07/25/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 8868 ' ND 1060' ¢ surface feet 3K-13 25'(~ surface feet 2560 f6912'TVP) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth1000 feet Maximum hole angle 44 0 Maximurnsurface 2355 psig At total depth (TVD) ~4br9 psig 18. Casing program Settinco Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) ................ C, · C, ~ '..,'.,,,...'..., ..,..,, , i ..-' , , ..,*' ,L. ,,,.., v I '~_1 /~_l,O_~ /~ll "~ {'11~ I_~ ~2~T('~ I1 ~ C~l ' "~ , '~C I I,-/"21,1 '~Ol, l,! 1 '~ I, ~ ¢~ A~ I I I £. HF-FRW 330 sx C!_~ss C b!e~d 8-1/2" 7" 26.0# J-SS BTC 88~' IR4' 34' 8RCR' 6912' 200 sx Class Cfminim,~m HF-ERW TOC 5(~0' abov top of 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 depth Structural Conductor R[CEIVED Surface Intermediate J U L ! 1 1986 Production Liner Alaska Oil & Gas Cons. Commission Perforation depth' measured Anchorage true vertical 20. Attachments Filin~ fee~ Property plat [] BOP Sketch~.~ DiverterSketch X Drilling program/~ Drilling fluid program ~Timevs depth plot [] Refraction analysis ~ Seabed report [] 20AAC 25.050 requirements 21. I hereby certify tJ:;¢~ t~e foregoing is tr~.~pe~ correct to the best of my knowledge · / .~ ./¢ ~'~- . Regional Drilling Engineer Date Signed / /'/~',~,f;-~/Q~....~" ~Z/;%4/(/T,tle Permit Number App See cover letter J .%? 'Z-r /., _*~ / 86 for other requirements Conditions of approval Samples required [] Yes [7~.-No Mud Icg required ~ Yes ~',..No Hydrogen sulfide measures ~ Yes ?, No DirectiOnal survey required ~--Yes ~ No R equiredworki 'n~~~~~o~~,~~/SM; [] 5M; [] 10M; ~ 15M ~'--/~ Other: .-- by order of Approved by Commissioner the commission Date I=nrm 113_/Ir'11 R~v 19-1-g.6 ~ / Subr~i [riplicate ARCO ALASKA-, [NC_ PAD 3K. WELL NO, 14 PROPOSED ..... KUP.ARUK FIELD.~ NORTH_~OPE? :ALASiKA___ EASTHAN WH[PSTOCK~ INC.. 39 EOC TVD=2)33 T~D'2475 DEP'542i TOP UONU SNDS- IVD~2704 1~D=~99~ DEP-90~ TOp W SAK SNDS TYD=3444-TffD-4026 DEP-1624 i ~12 TvD'3744 T.D-4445 0EP-1915 9 5/8' CsO PT TVD~4'-' TI~T, ~72~-DEF~ 2~ T: .................................. AVERAGE ANGLE ,.. RECEIVED .. K-5 TVD=S?S4 TI"ID-r265 OEP=3884 JUL 1 j 1986 Alas~ Oil & Gas Cons T['-Z-OHE-D ..... TVDA6324 THD=804? D'EP~442g ..... % - ,~ .Commission T/ ZONE C TVD=6431T~D=8196 DEP=4533 T/ ZONE A TYD=6647 T~D=8497 DEP~4744 TARGET-CNTR'TVD-6?O8-Tt'ID~8583:'~DEP=4803~ B/ KUP SNDS TVD~6769 T~D-8668iDEP=486~ TD (LOG PT) TVD-6912 T~D-8868:DEP-5002 ............................ 6000_ 70.00 0 1000 2000 3000 4000 5000 - - -VERTICAL SECT[ON- -'~'~-~-~.~. ...._.,~ ~ ~_:~"~~~ .... ~- ~ .............. r ~ , ~ · .~ '. .... ~-~ ~ ~ _ . . ~ . ; :~ .~ ' =-~ .... ~--~ ............ . ~ ~, -- : ..... ~ ....... . ~ .............. v----'.--'m ....... ~ .... -~~ ..... ~-'-~ · =~- --~ ....................... ' .... ._ ~_' '.~'- /.q _' L~.Z .__-"_L'Z.L."~Z~" .~q} -' 7L_LZ_-Q'¥2LL_-.'.~-~; ..... ~-. ~- .-~-~- :. ~;J/LL--_--:xC .... ~L'._-__~L'- ..... ~ '- ] '- ....;"-' ........... . -~--~-- - ~ ......... - + ......... ~ ............. j .......: ...... . .... ~ ..... ~;B~-~}-~'~- ~' - :--x~-u--~u-~ ~:~ ~_ {.:: ..:." ~. _: ..; ' ' '. ~' ' , . .... ~ .... . I~~ ~ ,- ,..--- ..... --- --- ........................... : ........................................ ~--~- .- ' -; - · t - , ' . . -~ .... _ ........... ~ ...... ~ ...... ~ - ~ ..... : ~ ........ ~ / ..... . .... ~~ , := _ :. _.~ ......~~~_- ..... _ ........ ~____~..~~ ;~--~- -!'' I - ' I ' '' ' ~~~. ~ /'~ !' /- t ...... ...... ~._ . ...... .~ ........... ~ ......... ,_ .. ~p. - ..~ .... --i ' I .... ~ ' ~ -- ~' ~ ~-~~ .... ~~F;'. ...... ~ -~;~ ~ ~ .... I-~ - . . .... --_._ - ......... ~ .... ~ ~ , t- ' '~80~'~--' ............ l--' : -' i'-: ....... t ' · -'j .__~: _i __: .... r~_.~ ..... ~ .... ~ ..... ~-! ~o9~---~~--- '-- :-- :--- ' ~" · -- -:I= ~ .....h .....~- f ..... 1:~5~ .... ~ ~' ~';- - '~"~; ~ .... I ' ..... ~ .----~- ~ ....... t- - : ...... 99~ - : ............ , ....... I --~~ ~: ;-~ ~: .... :--:'-r:_/~ -" !z___~:-_ _~---~ '~u ..... . ' : ~, : ~ ; ~ ~ . _ L._L~~-_. - . ~-~-_~- ~__ -:rx-i_~-~-~_~;~ ..... --_.~---: -- -.~_ ~___- ~: - .. ~'-~ ': __ ~-~;_.~':-u .... ..~.. ~'. _.-..~ -':_; .... ~~ L--~ ..... ~ .....~ .... ~- / .......... I-~ ..... ~- -- '~--~-- h .... i .....~-~- ~--t ...... i .... ~~ -->-~ .... i ........ ~- z ' : / _m: '-'- :~~~--' _~_~': ~ -"; ..... .-.r .... ~-~ ~. ~ ....... u ........ -._ ~ ...... : ........... ~ .... : ............. ~-. ~---~ ....... i ...... ._. ~ .... ,..._ / ~ ..... ~_~e~__. ~s~_ ~.- ~1:: ..... ~ __. --~~:~-~-_ -_--.--. _~: .... -':~::': _ -- ' - - i.- ~-: :--'- --~------~ - X -'~:-' ..... 7 .... ............ ~_ ~~-_ . ~ll J / : ' ' ' ....... ~ .......... j~ ...... /~ - -/ : ........... ,.--' ~ .... ---~ .......... ' - RECEIVED 5~.- ._ _ ' .... / J U L 1 1 1986 ~ 5o o_._ ~. - {._ // ...... /.; ......... ~ - .... ] Alaska Oil & 6as Cons. 6om~ission ~1 951 _ ~_/- - ' ' L~ ~ Anchorage ~ 20?3 I 400 ..... / ~ J 400.. __. ~-'::-~."~ ~- 100 200 300 400 soo soo [ 2000 - 3000 _ KUPARUK R I VER UN I T 20" D I VERTER $CHEMAT I C DESCRIPTION 1. 16" CONDUCTOR. 2. TANKO STARTER HEAD. 3. TANKO SAVER SUB. 4. TANKO LONER QUICK-CONNECT ASSY. S. TANKO UPPER QUICK-CONNECT ASSY. 6. 20" 2000 PSI ORILLINQ SPOOL N/lO" OUTLETS. 7. 10" HCR BALL VALVES N/lO" DIVERTER LINES, A SINQLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 8. 20" 2000 PSI ANNULAR PREVENTER. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20 AAC2S. 03S (b) MA I NTENANCE & OPERAT I ON . 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLON AIR THROUGH DI VERTER L I NES EVERY !2 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF NELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOMINO DIVERSION. JUL1 !)-9i)6 ~ NOT SHUT IN NELL G~ cons. commis¢~NOER ANY C I RCUMSTANCES. Anchorage SI 0~002 RI m 7 6 ACC~TOR C.~A¢ITY TEST I. (I-ECl( ~ FILL A~TDR RESERVOIR TO ~ LEVEL WITH HYORAL[.IC FLUID. Z. ASSLRE THaT ACO, MJ_ATCR PR[~ IS ~ PSI WITH 1__5C~_ PSI ~~ ~ ~ ~T~. ~. ~ TI~, ~ ~ ~ ~T~ SIXThlY 4. ~ ~ ~ ~, ~ A~~ L~ LIMIT IS 45 ~~ ~I~ TI~ ~ I~ ~I ~INI~ 4 2 I,:}-5,/~" SOP STACK TEST I. FILL B(~ STACX A~ C~ MANIFOLD WITH ARCTIC DIESEL. 2. C~CX THAT ALL LCXCX CX~ ,~ IN ~I~_U-EAD ARE FLLLY F~'TRACTI~. SEAT TEST PLUG IN WITH RL~INO JT A~ RUN IN LCX~ SC~. LII~ VALVES ADdACENT TO B4~ STACK. AIL 4. ~ UP TO 7.50~SI-A~ HOLD FOR IO MIN. IN- C~ PRES~ TO~~ HOD FCR I0 MIN. BLEED P;~~ TO O' PSI. 5. ~ AhN,LAR ~ AN:) MNIJAL KILL AN~ LI~E VALVES. CL__PISE_ TOP PIPE ~ ~ H(~ VALVES C~ ~ILL AN~ O-K](E LIr~,~.---~ 6. TEST TO 250 PSI AJ~>~ AS IN STEP 4. 7. CCNTINUE TESTING ALL VALVES, LI~.S, ~ DO<ES WITH A 2.50 PSI LON AJ~) 5000 PSI HIOH. TEST AS iN STEP 4. DO NOT ~ TF_~T ANY ~ .~AT NOT A FLI_L CLC~ING PC~ITIYE SEN_ (~-K~KE, ~IE~l TEST CHCKE5 THAT EX] ~[Tr FULLY CLCGE. 8. ~ TCP PIPE RAV~ AN~ CLOSE ~OTT(]~ PIPE TEST BOTTGM PIPE RNV~ TO ~50 PSI ~ ~ PSI. 9. CPEN 80TTC~I PIPE RAMS, BAO< ~LrT RLt~ING JT I0. CLOSE ~LI~) RA~S AN~ TEST TO 250 PSI AN~ 5000 PSI. II. ~ ~[.I~[~ RAMS AJ~ RETRIEVE-TEST PLUG. MAKE MANIFOLD AN~ LINES AR[ FULL ~F NCN-Fli~.-ZING FLUID. SET AU_ VALVES IN DRILLING POSITIC~. I~.' TEST STAh[~PIPE VALVES, KELLY, KELLY COO(S, CRILL PIPE SAFETY VALVE, ~ Ih~IDE ~ TO 250 PSI 3000 PSI. i5. RECCR~ TEST IN=CRMATIC~J CN BLCIt~IJT Pf~-VENTER TEST FG~I, SIG~, AND SEN~ TO DRILLING ~ISCR. 14. PF_RF(];~ ~ETE BC~E TEST AF'rE~ NIPPI. ING L~ '~EEKLY THEREAFTER F1JNCTI~LLY CPERATE BCPE .DAILY 510084001' REV. ~4AY ~ 5, 19~: GENERAL DRILLING PROCEDUR~ KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. Pressure test to 3500 psig. 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary X,~_s tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture sCimulate. [~ DEe~SERI MUD ~ CLEANER II STI STIR STIR LWK4/ih TYPICAL MUD SYSTEM SCHEMATIC DRILLING FLUID PROGRAM Spud to 9-5/8" Surface Casing Drill out to Weight Up Density 9.6-9.8 8.7-9.2 PV 15-30 5-15 YP 20-40 8-12 Viscosity 50-100 35-40 Initial Gel 5-15 2-4 10 Minute Gel 15-30 4-8 Filtrate AP1 20 10-20 pH 9-10 9.5-10.5 % Solids 10-+ 4-7 Weight Up to TD 10.3 9-13 8-12 35-45 3-5 5-12 6 9.5-10.5 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & 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 (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. LWK5 / ih ARCO Alaska, inc. ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 7, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built L~ation Plat - 3K Pad (Wells I - 18) Dear 14r. Chatterton-' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU1/12 Enclosure If ARCO Aiaska. Inc. is a Subsidiary of AtlanticRichfieldCompany i ii i i , I_~_ i : 6 . . LOCATED IN PROTRACTED LOCATED IN PROTRACTED SECTION 35~ T. 13N.~ R. 9E.~U.M. SECTION 35~ T. 13N.~ R. 9E.~U,M. I - Y - 6,~,~.74 ~T. 70'~'0Z.7~" 10 - Y · 6,~,153.79 ~T. 70'~'~.076~ Z - Y - 6,~,~3.~ ~T.. 70'~'02.53~' 11 - ~" 6,~,1~.7~ ~T. .. X - 5~,~.1~ L~G. 149'45'~.9~~ X · 5~,~5.7Z L~G. 1~' ~, 318' ~ ~" ~.5 P~" ~.5 11~' ~, 316' ~ 4 - Y - 6,~,353.~ ~T. 7~'02.~14" 13 - Y" 6,~,078.~ ~T. 70'25'59.3~3" 1359' F~, 318" ~ ~ ' ~.7 P~" ~.5 1~' ~, 316' ~ 13~' ~, 317' ~ ~ ' ~.8 P~ ~.5 1~' ~, 311' ~ ~ - Y" 6,~,~3.M ~T. 70'~'01.5~1" 15 - ~ - 6,~,0~.63 ~T. 70'25'~.8451" 1~' ~, 317' ~ ~" ~.9 P~' ~.5 10~' ~, 316' ~ 7 - Y - 6,~,~8.~ ~T. 70*~'01.~" 16 - V" 6,~,~3.~ ~T. 7~'~.59~' 1~' ~, 317' ~ ~' ~.0 P~" ~.5 1~' FSL, 315' ~ ~" ~.0 P~- 34.5 8 - Y - 6,~,253.70 ~T. 70'26'01.0~ 17 - y - 6,~7,g78.81 ~T. 7~25'~.3551" 125g' ~L, 317' ~ ~" ~.O P~ ' ~.5 ~5' FSL, 31~' ~ ~ · ~.0 P~" ~.5 9 - Y - 6,~,2~.65 ~T. 70"26'~.8124" 18 - Y - 6,~7,9~3.69 ~T. 7~25'~.1~ ] ' 5~,~5.9Z L~G. 149'~5'~.~" X - 529,~5.73 L~G. lg9',5'~.9977" 12~' FSL, 317' ~ ~' ~.1 P~- ~.5 959' ~L, 31~' ~ NOTES . -, " I. ALL COORDINATES ARE A.S.R, ZONE4. ~ALL DISTANCES SHOWN ARE TRUE. 3. HORIZONTAL POSITIONS BASED ON 3K CONTROL MONUMENTS PER LHD 4. VERTICAL POSITIONS BASED ON 3K TBM No. 4 ~ TBM No. 5 PER LHD ~ ASSr. FROM S/C DRAWING CED-RIXX-3070 rev.~ 5.0. G. ELEVATIONS INTERPOLATED i CER~FICA~ OF SURVEYOR: i HEREBY C~l~ THAT I AM PROPERLY _ REGISTERED AND LICENSED TO PRACTICE LAND ~RVEYINO IN ~E STATE OF ALASKA ~O THAT ~_~.. -- , ..... . TNI~ PLAT REPRESENTS A LOCATION SURVEY -' -.~ MADE BY ME OR UN~R MY SUPERVISION, AND ~ ' THAT ALL DIMENSIONS AND OTHER DETAILS ~ SURVEYED FOR: ~ ARCO Alaska, nc. ~ ~~' DAT~ ~ .~V ~SS ~ KUPARUK PROdECT -, ., -.. ~w.~ DRILL SITE 3K CONDUCTOR ~.~- ',~, ~ECK~O ~T. ' ' 8SSO& AS-BUILT LOCATIONS ~r~ ~u~va~, Sure 201, A~ho~e, A/aska 9950~ llS~ NOT TO SCALE I III I I (2) Loc (3) Adm±n LISTi:FOR 8) (~. thru (10 and 1~3) ,' '. ..'. 'YES NO the permit fee attached ~ - 2. Is well to be located in a defined p°ol ..................... 3. Is well located proper distance from proper~y line .......... .. ~ 5. Is sufficient undedicaced acreage available in this pool .. 6. Is well to be deviated and is wellbo~e plat included ...... 7. Is opera~or the only affected par~y .... , .................... 8. Can pe~it be approved before ten-day wai~ ................ ' (1.4 thru 22) (23 thru 28) 11. 12. 13. REMARKS 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. Is conductor string provided ........................................ 15. Will surface casing protect fresh water zones ....................... 16. Is enough cement used to circulate on conductor and surface ......... 17. 18.' 19. 20. 21. 22. 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 ............................ ~f 23. 24. 25. 26 27. 28. 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 ~C)O psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (6) OTHER ./~/, A. (29 thru 31) (6) Add: 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 ............................................. HO Geology: Enginq~ring: WM LCS WVA MTM~-- HJH" -- va //5/ rev: 04/03/86 6.011 POOL INITIAL CLASS STATUS GEO. AREA UNIT NO. ON/OFF SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. · -':-' .....5 C H L U Pi B S R S E R .... ~:= LIS TAPE VERiFmCATrGN. . . LISTTNG P 010.H0£ 'v'E~iFIC~Ti?'N LISTING ,RV!C5 NaM£ :EDIT TE :86/08/1,5 IGIN : ~Et NAME :149320 INTiNU,~TiJN ~ :O1 :EVlOUS REEL : iMMfNTS :LIBRARY TaP TAPE HE~DER :i:$ !RV!CE NAME :EDIT ,TE :85/08/16 ~IGIN :FS1A ~P~ NAr4E : INTINUATION ~ :01 :EVIGU$ TAP= : tMMENTS :Li3R~RY TAPE : ~-It: HEADER ...... , ,-- -~- 'LE NAME :EDIT . :RViCE NAME : !R.S ION ~ : ~TE : ~XIMUM L~NGTH : 1024 'LE TYPE ~EVIOUS FILE : : INFORMATION RECORDS :::-':: ~:E.M CONT'ENTS UNiT TYPE C,6TE SIZE CODE ~ :: ARCO ALASKA, INC. 000 000 0~8 0,55 ~ : 3K-14 000 000 '006 065 ~ : KUPARUK 000 000 008 085 kNG: gE 000 DO0 002 065 ]WN: 13N 000 goo 004 065 :CT: 33 000 000 002 065 }UN: NORTH SLOPE 000 000 012 065 FAT: ,ALA:SKA 000 000 008 065 ~EM CONTENTS UNIT TYPE CATE SIZE CODE P O!O,H02 VERiFiCATION LISTING mAGE 2 SCHLUMSERGER ALASKA Ca _ ~.,MPUTiNG CENTER MPANY = ARCO ALASK~ ZNC LL = 3K-14 ELJ = KUPARUK UNTY = NORT~ S,LfOPE 3, CROUGH ATE = ALASKA NUMBER A'T .,ACC: 7155Z ~NE, DATE LOGGED: 4 AUG 86 T HALSTEAD SING PE FLUID NSZTY SCOSZTY LOSS : '9.625" ,~ 4752' - 6iT SIZE : B.5" TO 8960' : LSNO POLYMER = 9.90 LB/G NM = 4.850 ~ 68 DF ~ .:0 ~ 68 DF : 4~.0 S RMF = 4.~¢, = 9.0 RMC = 2.920 ~ 68 DF = 3°8 C3 RM AT 5H'T = 2.317 $ 150 DF TRIX SANDSTONE ..... -'-,- THIS DAT~ H~S NOT BE=N~. DEPTH SHIFTED, - GVCRLAYS~ FIELD, PRINTS -,.-,.-,--,..,- ~:,: ;',: ::.: 4: ................................ ' ..... P OIO.H02 VERiFiCATICN LISTING PAGE 3 SCHLUMB ;RGER LCGS iNCLUDED WITH ThIS ~GN DUAL INDUCTION SPHERICALLY ~OCUS=D LOG (DZL) 3ATA AVAILABLE: 8943' TO ~7~2' FDRMATI3N DENSITY COMPENS,ATED LOG (FDN) COMPENSATED N=UTRON LOG (FE, N) DATA AVAILASLE: 8922' TD 8000' GAMMA RAY ZN CASING CGR.CNL) D~T~ AVAILABLE: ~$25' TD 1000' DATA FORMAT RECORD 4TRY BLOCKS 'TYPE SIZE REPR CODE ENTRY 2 1 66 0 ~ I 66 i 8 ~ 73 50 9 4 65 .lIN !6 0 I 65 0 NTUM SPECIFICATION BLOCKS 4EM SERVICE SERVIC~ UNIT API API API API FILE SIZE SPL REPR PROCESS I~ ORDER # LOG TYPE CLASS MOD NO.. CC3E (OCTAL) ~PT 'F'T O0 000 O0 0 0 4 1 68 go000000000000 :LU DIL JHMM O0 220 OI 0 0 4 i 68 CO000000000000 .D OIL OHMM O0 120 46 0 O 4 1 68 00000000000000 .M OIL OHMM O0 120 4~ 0 0 4 1 68 OOO00000000000 'P OlO.H02 VERIFICATION LISTING oAGE 4 L! ,'35 HO ,~.T IRA ;NL ;NL ,, OIL DiL FDN ~9N FDN F 3N FDN FDN =DN FDN F 3N CNL MV O0 010 Ol 0 GAP~-, O0 310 Oi GAFi 00 310 O1 O IN O0 280 O1 G/C3 O0 350 02 0 G/C3 O0 356 Ct 0 ,30 42O O1 0 O0 000 O0 0 PO OC, 890 O0 0 CPS 00 330 31 0 CPS O0 330 30 0 G~PI 00 310 gl 0 : DATA ~PT !PT ~PT ) t03 )HI ~PT ~PT ~PT ~PT ~PT 8983.0000 SFLU -18.5000 GR 2.0273 DRHO 38.2324 NCNL 8900.0000 SFLU -25.0000 GR 2.4531 DRH3 37.5485 NCNL 8800.0000 SFLU -31.0000 GR 2.4102 DRHO 44.5313 NCNL 8700.0000 SFLU -43.0000 GR 2.3496 DRHO 29.5410 NCNL 8600.0000 SFLU -32.0000 GR 2.4043 DRHO 30.1758 NCNL 8500.0000 SFLU -37.0000 GR 2.8223 DRHO 24.4141 NCNL 8400.0000 SFLU -35.0000 GR 2.5'781 DRHO 30.9570 NCNL 8300.0000 SFLU -4.6.0000 GR 2.5'117 DRHO 169. O. 2206. . 142. O. 2130. . 101. --0. 1808. 59. O. 2394. . 78. O. 2578. . 2960. . 103. O. 2038. 2. 119. O. 0586 2500 0985 OOO0 9!97 1250 0088 0000 1309 0625 0010 0000 9375 1250 0073 0000 9277 0625 0000 0000 3398 1875 0176 0000 4043 5625 0488 0000 8789 0525 0376 ltd GR NRAT FCNL iLO NRAT FCNL ltd GR NRAT FCNL ILD GR NRAT FCNL ILD GR NRAT FCNL ltd GR NRAT FCNL iLD GR NR AT FCNL ILD GR NRAT 4 1 6° ,j z~ 1 68 4 1 68 4 1 58 4 1 68 4 i 4 1 4 1 58 4 1 68 4 1 68 4 1 68 4 ! 68 2.9707 i L M 169.2300 CALZ 3.1133 RNR~ 654.0000 G2 2.6230 iLM 142.1250 C~Li 3.2'012 RNRa 619.0000 GR 2.0801 !LM 101.0625 CALi 3.5957 RNRA 462.0000 GR 11.9297 ILM 69.1250 CALl 2.6973 RNRA 840.0000 GR 4.0625 iLM '78.0625 CALl 2.8008 RNRA 828.0000 GR 4.5820 ILM 38.1875 CALI 2.4082 RNRA i179.0000 GR 2.5977 ILM 103.5625 CALl 2.9980 RNRa 633.0000 GR 2.4,529 iLM 119.0525 CALl 3.1309 RNRA O00OO00 0000000 0000000 0000000 0000000 0000000 0000000 0000000 0000000 0000000 0000000 0000030 OOO0000 0000000 0000000 0000000 0000000 OOOO000 O00000O 0000000 0000000 0000000 0000000 0000000 2.7285 5.8359 3.3730 -999.2500 2.6934 8.6094 3.4395 -999.2500 2.1211 8.7891 3.9121 -999.2500 12.1641 8.3516 2.84'96 .-,999.2500 4.28.!3 9.0859 3.1133 -999.2500 4.9297 9.0078 2.5098 -999.2500 2.6035 11.2109 3.2969 -999.2500 2.5527 .10.3203 3.1035 ~P 010,~02 VERIFICATICN LiSTiNG °AG: 5 ~Hi 33.7402 NCNL !PT 8200.3000 S~LU ~ -43.5000 GR ~0~ 2.3008 O~dC ~Hi 47.9004 NCNL ~PT 8100,0000 SFLU ~ -55.0000 GR 105 2.3984 CRWO ~Hi 50.2~41 NCNL ~PT 8000.0000 SFLU ~ -60.0000 GR t05 2.5234 DRHO ~HI 46.2~91 NCNL ~PT 7900.0000 SFLU ~ -62.5000 GR igB -'999,2500 DRHO ~HI -999.2500 NCNL EPT 7800.0000 SFLU P -56.5000 GR 1OB -999.2500 DRHO PHI -999.2500 NCNL EPT 7700.0000 SFLU P -52.5000 GR HOB -99~.2500 DRHO PHi -999,2500 NCNL EPT 7600,0000 SFLU P -78.2500 GR HOB -999.2500 DRM~ PHI -999.2!500 NCNL EPT 7500.0000 SFLU P -82.7500 GR HOB -999,2500 DRHO PHI -999.2505 NCNL EPT 7400.0000 SFLU P -74.0000 GR HO~ -999.2500 DRH3 PHI -999.2500 NCNL EPT 7300.0000 SFLU P -64.5000 GR HOB -999.2500 CRHO PHI -999.2500 NCNL EPT '7200.0000 SFLU P -72.0000 GR 1883.0000 1.5557 iLD 117.2500 GR -0.0039 1395.0000 FCNL 2.6465 ~ ~LD 166.B750 0.0132 NRAT 1664.0000 PCNL 119. 812:~, Gl 0.0425 NRAT 1725.0000 FCNL ~.7305 ILO 202.2500 -999,2500 NRAT -9'99.2500 ¢CNL 3.6348 ILO 202,5000 GR -999.2500 NRAT -999,2500 FCNL 3.0605 !LD 134,5000 GR -999.2500 NR,AT -999.2500 FCNL 3.6270 ILD 114.0625 GR -999.2500 NRAT -999,2~00 FCNL 3,3086 ILD 129,5000 GR .-999,2500 NRAT -999.2500 FCNL 2.9756 ILO 164.1250 GR -999.2500 NRAT -999.2500 FCNL 1.6191 !LD 75.5250 GR -999.2500 NRAT -999.2500 FCNL 1.6172 ILD 104,562~ GR 606.5300 1.5S57 iLM 117.2500 CALl 3.8223 RNRA 414.7300 Gq 2,6875 ILM 16.6,3750 CALl 3,9668 RNRA 391,50n0~ =~R 1,5889 iLM 119.8125 CALl 3,7344 PNRA 406,7500 GR 3.3730 ILM -999.2500 CALl -999.2500 RNR& -99'9,2500 GR 2.7500 iLM -999.2500 CaLl -999,2500 RNRA -9'99,2300 GR 3,2480 ILM -999,2500 CALl -999.2500 RNRA -999.2500 GR 3,3867 i'LM -999.2500 CALl -9'99,2500 RNRA -999,2500 GR 3,3633 !LM -999,2500 CALl -999,2500 RNR~ -999,2500 GR 2.9062 iLM -999.2500 CALI -999.2500 RNR~ -9'99.2500 GR 1.7539 ILM -999.2500 C~LI -999.2500 RNRA -999.2500 GR 1.7549 'iLM -999.2500 CALl -99 -99 -99 -99 -99 -99 -99 -99 -99 -99 - 99 -99 -99 - 9 '9 -99 -99 -99 -99 -99 -99 '-99 -99 -99 -99 -99 -99 9.2500 1.5986 9.3203 3.8437 9.2500 2.5973 9.5078 4.2500 9.2500 !.6270 9.2991 4.2393 9.2500 3.64 26 9.2500 9.2500 9.2500 2,7227 9.2500 9.2500 9.2500 3.3867 9.2500 9.2500 9.2500 3.4121 9.2500 9.2500 9.2500 3.3535 9,2500 9,2500 9,2500 2,9980 9,2500 9.2500 9.2500 1,7803 9.2500 9.2500 9,2500 1.7852 9.2500 Ip OlO.H02 VERiFICATIEN LISTING PAGE 6 ~3B -999.2300 DRM2 'Hi -999.2500 NCNL 'PT 7100.0000 SFLU ~ -67.0000 GR t05 -999. 2500 DRHO ~Hi -999. 2500 NCNL tOB -~9~.2300 DRH3 ~flI -999.2~00 NCNL ~PT 6900.0000 SFLU ~05 - 999.2500 DR~'~ ~HI -999.2~00 NCNL ~PT 6~00.0000 SFLU : -80.5000 G~ i~B -999.2500 DRH~ ~HI -9R9. 2500 NCNL ~PT 6700.0000 SFLU ~ -~9.8125 GR ~OB -999.2500 DRHO ~Hl -999.2500 NCNL ~PT 6600. 0000 SFLU ~ -76.8750 GR ~GB -999.2500 DRHO ~Hi -99~. 2500 NCNL ~PT 6500.0000 SFLU ~ -74.0625 GR tOB -999.2500 DRHO PM! -999.2500 NONL ~PT 6400.0000 $FLU : -79.5000 g~ oHi -999.2500 NCNL ~PT 6300.0000 SPLU ~ -77.312~ GR ~OB -999. Z 500 DRHO ~HI -999.2~00 NCNL ~PT 6200.0000 SFLU ~ -74.7500 GR ~OB -999.2500 DRH~ ;Hi -999. 2500 NCNL EPT gtO0.OO00 S~LU -9'99.2500 NRAT -999.2500 FCNL 1.9951 !LD 111.4375 GR -9~9.2500 NRAT -999.2500 FCNL 1.7520 ILD 112.0625 GR -999.2500 NRAT -999.2500 :CNL 2.9570 1LD ~7.5875 GR -999.2500 NRAT -9~9.2500 FCNL 2.2461 ILD 100.1250 GP -999.2500 NR~T -999.2500 FCNL 2.3457 ILD 114.2500 GR -999.2500 NR~T -999.2500 FCNL 2.7773 ILD 99.7500 GR -999,2500 NRAT -999.2500 FCNL 2.6777 !LD 95.7500 GR -999.2500 NRAT -999.2500 FCNL 2.6758 tLD 101.2500 GR -999.2500 NRAT -999.2500 RCNL 2.9727 ILO 90.7500 GR -999.2500 NRAT -999.2500 FCNL 2.8301 iLD 86.1250 GR -999.2500 NR~T -999,2500 ~CNL 3.2852 iLC -999.2500 RN~ -999.2500 GR 1.9678 !LM -999.2500 CALl -999.2500 RNR~ -999.2500 GR 1.9541 iLM -999.2500 C~Li -999.2500 RNR,6 -9'99.2500 GR 3.1992 !LM -999.2500 CALl -999.2500 RN~A -999.2500 GR 2,7422 iLM -999,2~00 CALl -999.2500 RNRA -999.2500 GR 2.5~79 iLM -999.2500 CALl -999.2500 RNRA -999,2500 GR 3.0117 ILM -999'.2300 CALl -999.2500 RNR~ -999.2500 GR 2.9121 ILM -999.2500 CALl -999.2500 RNRA -999.2.500 GR 3.0762 ZLM -999.2500 CALl -999.2500 RNR~ .-999.2500 GR 3,1406 ILM -999,2500 CALl -999.2500 RNRA -99'9,2500 GR 3,0293 ILM -999.2500 CALl -999.2500 RNRA -999.2500 GR 3.37'70 ILM -999.2500 ~99.2:0~ 2.0078 -999.250,3 -999.2500 -999.2500 1.9573 -999.2500 -999.2500 -999.2500 3.2227 -999.2500 -999.2500 -999.2500 2.6428 -999.2500 -999.2500 -999.2500 2.5586 -999.2500 -999.2500 -999.2500 3.0000 -999.2~00 -999.2500 -999.2500 2.9102 -999.2500 ,-999.2500 -999.2500 3.0156 -999.2300 -999.2500 -9'9~,. 2.500 3.1348 -999.2500 -999.250'0 -999,2500 3.0195 -999.2500 -999.2500 -99'9.2500 3.2246 CP OiO.H02 VER!=iCATI2N LiSTiNG PA'SE 7 ) -85.7503 GR ~di -999.2500 NCNL fPT 6300.0000 SFLU ~ -88.7300 GR t05 -'999.2500 D~d3 ) n I - 999.2500 NC NL fPT 3900.0000 SFLU ~ -33.5000 GP t~B -999.2500 3RH:3 ~MI -999.2~00 NCNL EPT ;800.0000 SFLU ~ -91.0000 G~ ~88 -999.2500 DRH3 ~HI -999.25'00 NONL EPT ~700.0000 SFLU ~ -95.0000 G{ ~08 -999.2500 ORh3 ~HI -'999.2500 NCNL EPT 5500.0000 5FLO P -44.0000 GR iDB -999.2500 DRHO ~HI -999.2:500 NCNL EPT 5500.0000 SFLU ~ -49.7500 GE ~OB -999.2500 SRHO PHI -999.,2500 NCNL EPT $400.0000 SFLU P -43.5000 G~ ~05 -999.2500 DRHO PHI -999.2500 NCN, L EPT 5300.0000 SFLU P -46.5313 GR HO8 -999.2.500 DRHO PHI -999.2500 NCNL EFT 5200.0000 SFLU P -49.0000 GR HOB -999.2500 DRHO PHI -999.2500 NCNL EPT 51'00.0000 S~LU P -~9,7500 GR HOB -999.2500 DRHS PHi -999.2500 NCNL 96.7500 GR -9~9.2500 NRAT -999.2500 FCNL 2.9558 IL2 98.9375 GR -999.2500 NRAT -999.2500 FCNL 2.4531 ILS 97.6250 OR -999.2500 NRAT -999.2500 FCNL 2.6523 ILD 106.6875 GR -999.2500 NRAT -999.2500 ~CNL 2.8320 ltd 95.8750 GR -999.2500 NRAT -999.2500 FCNL 2.8574 ltd 10B.0625 GR -999.2500 NRAT -999.2500 FCNL 2.0645 ltd 100.5000 GR -999.2500 NRAT -999.2500 FCNL 2,5352 ltd 100.3125 GR -999.2500 NRAT -999.2500 FCNL 2.2988 ltd 105.7500 GR -999.2500 NRAT -999.2500 FCNL 3.3262 ILD 83.,2500 GR -999,2500 NRAT -999.2500 FCNL 3.3535 iLD 98.6250 GR -999.2500 NRAT -999.2500 FCNL -999.2500 CALl -9~9.2503 RNRA -999.25,30 Gg 3.025~ iLM -999,2500 CALl -999.2500 RNR& -999.2500 GR 2.716.8 ILM -999.2500 CALl -999.2500 RN~A -999.2500 GR 2.9297 ZLM -999,2500 CALZ -999.2500 RNR& -999.2500 GR 3.13~7 iLM -999.2500 CALi -999.2500 RNRA -999.2500 GR 3,3848 ILM -999.2500 CALl -999.2500 RNRA -999.2500 GR 1.8281 !LM -999.2500 CALl -999.2500 RNRA -999.2500 GR 2.8770 ILM -999.2500 CALl -999,2500 RNRA -999,2500 GR 2.6406 ILM -999.2300 CALl -999.2500 RNRA -999.2500 GR 3.6895 !LM -999.2500 CALl -999.2500 RNRA -999.2500 GR 3,74~0 ILM -9'9'9,2500 CALi -99'9.2500 RNRA -999.2500 GR -999.2500 -'999.2500 -999.2500 3.0527 -999.2500 -999.2500 -999.2500 2,5719 -999.2500 -999.2500 -999.2500 2.8867 -999.2500 -999.2500 -999.2500 3.0684 -999.2500 -999.2500 -999.2500 3.2734 -999.2¢00 -999.2500 -9'99.2500 1.8848 -999.2500 -999.2500 -999.2500 2.7949 -999.2500 -999.2500 -999.2500 2.5527 -999.2500 -999.2500 -999.2500 3.5801 -999.2500 -999.2500 -999.2500 3.6973 -999.2500 -999.2500 -999.2500 P OlO.H02 VERIFIgA, TICiN LISTING PT HI PT HI PT HI PT Hi PT PT .,HI PT 0,3 Hl PT O3 HI PT ,mT PT 3000.0000 SFLU -56.5000 GR -999.2500 ORHO -999.2300 NCNL 4900.0000 SFLU -52.2500 GR -999.2500 DRHD -999.2500 NCNL 4800.0000 SFLU · -75.7500 GR -999.2500 DRH3 -'999.2500 NCNL 4700.0000 SFLU -999.2500 GR -999.2300 DRHO -999.2500 NCNL 4600.0000 SFLU -99'9.2500 GR -999..2500 DR~G -999.2500 NCNL 4300.0000 SFLU -999.2500 GR -999.2500 DRH~ -999.2500 NCNL 4400.0000 SFLU -999.2500 GR -999.2500 9RHC -999.2500 NCNL 4300,0000 SFLU -999,2500 GR -999,2500 DRHO -999.2500 NCNL 4200.0000 SFLU -999.2500 GR -999.2500 -999.2530 NCNL 4100.0000 SFLU -9'99.2330 SR -999.2500 DRHC -999.2500 NCNL 4000.0000 S=LU -999,2500 GR -999,2500 DRm3 -999' ~300 NCN; 3,6055 iLD 95.1875 GR -999,2~00 NRAT -999,2~00 FCNL 1.4951 ILD 91 9375 -999.2500 NRAT -999.2500 FCNL 4.742.2 ILD 92.9375 GR -999.2500 NRAT -999.2300 FCNL -999.2500 ILO -999,2500 GR -999,2500 NRAT -9'99,2500 FCNL -999.2500 ILD -999,2500 GR -999,2500 NRAT -999,2500 FCNL -999,2500 ILD -999.2500 GR -999.2500 NRAT -999,2500 FCNL -999.2500 ILO -999.2300 GR -999.2500 NRAT -999.2500 FCNL -99'9.2500 IL3 -999,.25C0 GR -999,2500 NRAT -999.2500 -999.2500 ILO -999.2500 Gq -999.2500 N'RAT -999.2500 =CNL -929.2500 -999.2500 Gq -999.2500 NRAT -~99. .~500 FCNL -999.2300 iL3 -999,2500 GR -999.2500 ~RAT 3,9518 iLM -999,2500 CALl -999,2500 RNRA -999,2500 GR 2,0859 ILM -999.2500 C~LI -999.2500 RNRA -9'99,2500 GR 4,3.~87 ILM -999,2300 CALi -999,2500 RNRA -999.2300 GR -999.2300 ILM -999.2500 CALI -999.2500 RNRA -999,2500 GR '-999.2500 -999.2500 CALI -999.2300 RNRA -999.2500 GR -999.2500 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR -999.2500 ILM -999.2500 CALl -999.2500 RNRA -999.2500 GR -9'99.2500 iLM -99'9.2500 CALl -999.25010 RNRA -999.2500 GR -999.25C0 iLM -9'99.2503 CALi -999.2500 ~NRA -999.2500 OR -999.2500 ILM -999.2500 CALl -999.2500 RNRA -999.25J0 GR -999,2500 ILM -999.2502 C~Li -999.2500 RNRA -'9:99.2500 GR 3,7754 -999.2500 -999.2500 -999.2500 1.4648 -999.2500 -999.2500 -999.2500 4.3867 -999.2500 -999.25,00 126.6875 -999.2500 -999.2500 -999.2500 66.4375 -999.2500 -999.2500 -999.2500 60.5625 -999.Z500 -999.2500 -999.2500 50.6,250 -999.2500 -999.2500 -999,2500 50.8125 -999.2500 -999.2500 -999.2500 48.3438 -999.2500 -999.2500 '-999.2500 51.2500 -999.2500 -999.2500 -999.2500 4~.3125 -999.2500 -999.2500 -999.2500 3'~.0625 IP OlO.H02 VERIFICATION LISTING ~GE 9 !PT ) ~PT ) ~PT :PT ~PT .=PT ~PT )HI .= PT .=PT )HI .=PT EPT 408 3900.0000 SFLU -999.2500 GR -999.2500 DRHC -999.2500 NCNL 3800.0000 SFLU -999.2500 GR -999.2500 -999.2300 NCNL 3700.0000 SFLU -999.2500 -9'99.2500 -999.2503 NCNL 3600.0000 SFLU -999.2500 -999.2500 -999.2500 NCNL 3500.0000 SFLU -999.2500 G~ -999.2500 DRdO -999.2500 NCNL 3400.0000 SFLU -999.2500 GR -999.2,500 DRHD -999. 2500 NCNL 3300.0000 SFLU -999.2500 GR -999.2500 -999.2500 NCNL 3200.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 NCNL 3100.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 NCNL 3000.0000 SFLU -999.2500 GR -999.2500 DRHj '-9'99.2500 NCNL 2900.0000 SFLU -999,2,500 GR -999.2500 D~HO -993.2500 iLO -'9'99.2500 GR -999.2500 NR~T -999 2500 FCNi -999.2500 ILC -9R9.2500 N~T -999.2500 FCNL -995.2500 iLD -999.2500 GR -999.2500 NRdT -999.2500 ~CNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 ~CNL -99'9,2,500 ILD -999.2:500 GR -999.2300 NRAT -99'9,2500 FCN'L -999.2500 iLO -999.2500 GR -999.2500 NRA'T -999.2500 FCNL -999.2500 ILD -999.2500 GR '-99'9.2500 NRAT -999.2500 FCNL -999.~500 IL -999.2500 GR -999.2500 N'RAT -999.2500 FCNL -999.2500 iLD -99'9.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILD -999.2500 GR -999.2500 NR~T -9~9.2500 iL~ -9~9 2500 C.&L~ -999.2500 RNRA -999.2500 GR -999.2550 ILM -999.2500 CALl -999.2500 RNR& -99~.2500 GR -999.2500 ILM . ..c500 CALI -999.2500 RNR4 -999.2500 GR -9'99.2500 ILM -999.2500 CALl '-999.2500 RNRA -999.2500 GR -999.2500 ILM -999.2500 C~LI -999.2500 RNRA -99'9.2500 G'R -999.2500 !LM -999,2500 CALI -999.2500 RNRA -999.2500 GR -999.2500 !LM -999.2500 CALI -9~9.2500 ~Nm~ -999.2500 GR -999.25'00 ILM -999.2300 CALl -999.2500 RNR4 -999.2500 GR -999.250.0 ILM -999.2500 CALl -999. 2500 RNRA -999.2500 GR -999.2300 !LM -9'99,2500 CALl -999.2500 RNRA -999.2500 GR -9'99.2500 ILM -999.2500 CALl -9'9'9.2500 RNRA -999.2500 -999.2500 -999.2500 52.5313 -999.2500 -999.2500 -999.2500 38.0625 -999.2500 -999._~ -999.2500 52.4375 -99~.2500 -999.2500 -999.2500 42.2187 -999.2500 -999.2500 -999.2500 18.5938 -999.2500 -999.2500 -999.2500 30.5719 -999.2500 -999.2500 -999.2500 43.06,25 -999.2500 -999.2500 31.5156 -999.2500 -999.21500 -999.2500 41.4063 -999.2500 -999.2500 -999.2500 30.640~ -999.2500 -99'9.2500 -999.2500 'P OlO,H02 VSRIFiC~TiON LISTING PIGE 10 'Hi 'Hi ) )Hi ~HI '.'PT :.PT :HI '.-PT )HI .:PT )HI -t03 ~H! 5PT PHI -9 2~ -9 -9 -9 27 -9 -9 -9 26 -9 -9 -9 25 -9 -9 -9 24 -9 --9 23 -9 -9 -9 22 -9 --9 -9 21 -9 --9 -9 2O --9 -9 -9 19 --'9 -9 --9 --9 99 O0 99 99 99 O0 99 99 99 O0 99 99 99 O0 99 99 99 O0 99 99 99 O0 99 99 99 O0 99 99 99 O0 99 99 99 O0 99 99 99 O0 99 99 99 O0 99 · 2500 NCNL ,0000 SFLU ,2500 GR ,2500 ,2500 NCNL ,OOO0 SFLU .2500 GR ,2500 ,2500 NCNL ,0000 SFLU ,2500 GR .2500 .2500 NCNL .$000 SFLU .2500 GR ,2500 ,2500 NCNL .0000 SFLU .~500 GR ,2500 DRH~ ,2500 NCNL · 0000 SFLU ,2500 GR · 2500 DRHJ ,2500 NCNL .0000 SFLU .2500 GR ,2500 DRHO ,2500 NCNL ,0000 SFLU ,2500 GR .2500 DRHO · 2500 NCNL · 0000 SFLU .2500 GR .2500 DRH~ ,2500 NCNL ,0000 SFLU ,2500 GR .2.500 ORHO .2500 NCNL .0000 SFLU ,2500 GR -999,2500 ~CNL -999.2500 ILD -999,25C0 GR -~S$,Z500 NRAT -9'99.2500 FCNL -999,2500 !LD -999,2500 GR -999.2500 NR~T -~99.2500 ~CNL -999.2500 iLD -999,2500 OR -999,2500 NRAT -999,2500 FCNL -99'9.2500 ILD -999.2500 GR -999,2500 NR~T -999.2500 FCNL -999.2500 ILD -999.2500 GR -999,2500 NRAT -999.2500 FCNL -999.2500 -999,2500 GR -999.2500 NR~T -999,2500 FCNL -999,2500 ILO -999,2500 GR -999,2500 NRAT -999,2500 FCNL -999,2500 ILD -999.2500 GR -999,2500 NRAT -959.2500 FCNL -999,2500 ILD -999.2500 GR -999,2500 NRAT -999.2500 FCNL -999.2500 1ILO -999.2500 GR -999.2500 NRAT -999,2500 FCNL -999.2500 ILO -999.2500 GR -9'99.2500 GR -999,2500 ILM -999,2500 C.&Li -999,2503 RNRA -9'99,2500 GR -999.2500 iLM -999.25~0 C~Li -999.2500 RN~A -999.2500 GR -999.2500 iLM -9'99,2500 CALl -999.2500 RNR~ -999.2500 GR -999,2500 ILM -999.2500 CALi -999.2500 RNRA -999,2500 ~R -999,2500 ILM -999.2500 CALl -999.2500 RNR~ -999,2500 GR -999,2500 ILM -999.2500 CALI -999.2500 RNRA -999,2500 GR -999,2500 ILM -999,2500 CAL,i -999.2500 RNRA -999.2500 GR -999.2500 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR -999,2500 ILM -999,2500 CALI -999.2500 RNRA -999.2500 GR -9991.2500 ILM -999.2500 CA/I -999.2500 RN~A -999.2500 GR -999.2500 ILM -999.2500 CALS 48.0313 -999.2500 -999,2500 -999.2500 39,2500 -999.2500 -999,2500 -999.2500 37.3125 -999.2500 -999,2500 -999.2500 39.8437 -999,2500 -999,2500 -999.,2500 35.7188 -999.2500 -999,.2500 -999.2500 33.0313 -999.2500 -999.2500 -999.2,500 28.8750 -9919.2500 -999.2500 -999.2500 48.7813 -999.2500 -999.2500 -999.2500 32,2813 -999,.2500 -999.2500 -999,2500 30.4844 -9'99.2500 -999,2500 -999,2500 47.5625 -999.2500 -999.2500 P OlO.H02 VERi=iCATiCN LISTING ?aGE 1! lOB -'999.2500 HI -993,2500 NCNL :PT 1700,0000 SFLU ' -99'9,2500 GR lOB -999.2500 'Hi -'999.2500 NCNL 'PT 1600.0000 SFLd ' -999.2503 GR IDB -999,2500 'HI -999,2500 NCNL :PT 1500,0000 SFLU ' -999,2500 GR IOB -9'99.2500 ORHD 'HI -999.2500 NCNL :PT 1~00.0000 SFLU ~ -999.2500 GR ~05 -999.2500 ,DRHO ~Hi -999.2500 NCNL :PT 1300,0000 SFLU ~ -999.2500 GR tGB -999,2500 DRHO ~HI -999.2500 NCNL :PT 1200,0000 SFLU ~ -999,2500 GR iDB -999.2500 DRHO ~Hi -999.2500 NCNL :PT 1100.0000 SFLU > -999,2500 GR iDB -999.2500 DRHO ~Hi -9'9'9 2500 NChJ~' ~PT 1000,0000 SF.LU ~ -999,2500 GR iDB -999.2500 DRHg ~Hi -999,2500 NCNL :PT 996.0000 SFLU ~ '-999.2300 GR iD8 -999.2500 DRHO ~Hi -999.2500 NCNL FILE TR&iLER IL,E NAME :EDI'T ERVICE NAM~ : ERSION # : ~TE : .001 -999.2500 NR&T -9'99.2533 FCNL -999.2500 ILS -999.2500 GR -9~9.25C0 NRAT -999.2500 FCNL -999.2500 ItC -999.2500 -999.2500 NRAT -999,250C FCNL -999.2500 -9'99,2500 GR -999,2500 NRAT -999.2500 FCNL -999.2500 iLO -999.2500 GR -999.2500 NR~T -999,2500 FCNL -999.2500 ILD -999.2500 GR -99'9,2500 NRAT -9'99.2500 FCNL -999.2500 ILD '-999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2,500 FCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 ~CNL -999.2500 iLD -999.2500 GR -999.2500 NRAT -999,2500 FCNL -999.2500 RNRA -999.2500 GR -999.2500 -999.2500 CALi -999,2500 RNRA -999.2500 GR -999.2500 ILM -999,2500 CALI -999.2500 RNR~ -999.2500 GR -999.2~00 -999.2500 C~LI -999.2500 RNRA -999,2500 GR -999,2500 ILM -999.2500 CALl -999.2500 RNRA -9'99,2500 GR -999,2500 ILM -9'99.2500 CALI -999.2500 RNR4 -999.2500 GR -999.2500 ILM -999.2500 CALi -999.2500 . :RNRA -999,2500 GR -999,2500 ILM -9'99.2300 CALl -999.2500 RNRA -999.2500 GR -9'99,2500 ILM -999.25'00 CALl -999.2500 RNRA · -999,2500 GR -999.2500 ILM -999.2500 CALl -999.2500 RNRA -999.2500 GR -999.2500 35.71~ -999.2500 -999.2500 -999.2500 ~5.8437 -999.2500 -999.2500 -999.2500 22.9052 -999.2500 -999.2500 -999.2500 40.!250 -999.2500 -999.2500 '-999.2500 28,8906 -9'9'9.2500 -999.2500 -999.2~00 47.8750 -999.2500 -999.2500 -999.2500 30,5938 -999,2500 -999.2500 -999.2500 33.3125 -999.2500 -99'9.2500 -999.2500 53.6875 -999.2500 -999.2500 -999.2500 63.5625 P OlO.H02 V=R~FiCATIgN,_ ~ ,. LISTING PAGE 12 XIMUM LENGTH : 1024 LE TYPE : XT FiLE NAME : TAPE TRAILER ~::~:~ RVICE NAME :EDIT TE :86/08/15 IGiN :FS1A PE NAME : NTINUATiON ~ :01 XT TAPE NAME : MMENTS :LiBRaRY TAPE REEL TRAILER. ~,--,- RVICE NAME :'EDIT TE :8,5/08/15 IGI~ : EL N~&M.:_ :149~20 NTINUATIDN # :01 XT REEL NAM5 : MMENTS :LIB:RZIRY TAPE