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Home My WebLink About187-054WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďǇĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϭϴϳϬϱϰϬͲ^Ğƚ͗ϯϲϭϴϳJRBy Abby Bell at 1:43 pm, Dec 21, 2021 3M-1750029217290000 KRU WLWFLFINAL FIELD24-Apr-213M-1950029217370000 KRU WLLDLFINAL FIELD25-Apr-213H-0150103200840000 KRU WLCHCFINAL FIELD26-Aug-213H-1250103200880000 KRU WLCCLFINAL FIELD23-Sep-213H-1250103200880000 KRU WLCHCFINAL FIELD29-Aug-213H-1250103200880000 KRU WLCUTTERFINAL FIELD23-Sep-213H-1250103200880000 KRU WLCUTTERFINAL FIELD24-Sep-211L-1250029220330000 KRU WLSBHPSFINAL FIELD6-Nov-213G-2450103201450000 KRU WLTBG CORRFINAL FIELD29-Oct-211A-2550029221160000 KRU WL WHIPSTOCKFINAL FIELD12-Oct-211A-2350029221310000 KRU WLRBPFINAL FIELD12-Jun-211R-2050029222070000 KRU WLPPROFFINAL FIELD2-Jun-212M-1150103201590000 KRU WLPPROFFINAL FIELD27-Aug-212M-0750103201780000 KRU WLBACKOFFFINAL FIELD5-Aug-211Y-1950029223910000 KRU WLPPROFFINAL FIELD31-May-212T-3050103202190000 KRU WLLDLFINAL FIELD2-May-211Q-20A50029225890100 KRU WLSET RECFINAL FIELD2-Aug-212M-3350103202400000 KRU WLLDLFINAL FIELD18-Oct-211F-03A50029208530100 KRU WLPERFFINAL FIELD19-Oct-211Q-08A50029212250100 KRU WLIPROFFINAL FIELD30-Apr-211E-3350029227970000 KRU WLPPROFFINAL FIELD26-Mar-211D-13550029228160000 KRU WLLDLFINAL FIELD16-Jul-213F-13A50029214990100 KRU WLGLSFINAL FIELD17-Jul-212N-318 50103203430000 KRU WLSCMTFINAL FIELD12-Nov-211C-12750029230240000 KRU WLIPROFFINAL FIELD17-Nov-213S-24A50103204560100 KRU WLCUTTERFINAL FIELD25-Oct-213S-0350103204580000 KRU WLIBPFINAL FIELD26-Oct-211B-2050029231640000 KRU WLPPROFFINAL FIELD22-Apr-211E-11950029231980000 KRU WLLDLFINAL FIELD26-Jun-212W-1750029233700000 KRU WLPPROFFINAL FIELD28-Aug-211H-11850029235780000 KRU WLIPROFFINAL FIELD4-Nov-211H-11450029235840000 KRU WLIPROFFINAL FIELD23-Jun-211H-11350029235880000 KRU WLWFLFINAL FIELD22-May-21 Originated:Delivered to:3-Mar-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 3B-06 50-029-21336-00 906905927 Kuparuk River Multi Finger Caliper Field & Processed 6-Jan-21 0 1 2 3B-06 50-029-21336-00 906953734 Kuparuk River Packer Setting Record Field- Final 1-Feb-21 0 1 3 3K-03 50-029-21602-00 906961911 Kuparuk River Multi Finger Caliper Field & Processed 9-Feb-21 0 1 4 3K-27 50-029-22751-00 906880550 Kuparuk River Packer Setting Record Field- Final 22-Dec-20 0 1 5 3M-17 50-029-21729-00 906892184 Kuparuk River Packer Setting Record Field- Final 29-Dec-20 0 1 6 3M-17 50-029-21729-00 906892184 Kuparuk River Temperature Record Field- Final 30-Dec-20 0 1 7 3N-02A 50-029-21527-01 906798653 Kuparuk River Packer Setting Record Field- Final 31-Dec-20 0 1 8 3O-20 50-029-22750-00 906941859 Kuparuk River Multi Finger Caliper Field & Processed 24-Jan-21 0 1 9 3N-07A 50-029-21539-01 906604302 Kuparuk River String Shot Record Revised 16-Jul-20 0 1 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 03/08/2021 03/08/2021 PTD: 1870540 E-Set: 34741 Originated:Delivered to:3-Mar-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 3B-06 50-029-21336-00 906905927 Kuparuk River Multi Finger Caliper Field & Processed 6-Jan-21 0 1 2 3B-06 50-029-21336-00 906953734 Kuparuk River Packer Setting Record Field- Final 1-Feb-21 0 1 3 3K-03 50-029-21602-00 906961911 Kuparuk River Multi Finger Caliper Field & Processed 9-Feb-21 0 1 4 3K-27 50-029-22751-00 906880550 Kuparuk River Packer Setting Record Field- Final 22-Dec-20 0 1 5 3M-17 50-029-21729-00 906892184 Kuparuk River Packer Setting Record Field- Final 29-Dec-20 0 1 6 3M-17 50-029-21729-00 906892184 Kuparuk River Temperature Record Field- Final 30-Dec-20 0 1 7 3N-02A 50-029-21527-01 906798653 Kuparuk River Packer Setting Record Field- Final 31-Dec-20 0 1 8 3O-20 50-029-22750-00 906941859 Kuparuk River Multi Finger Caliper Field & Processed 24-Jan-21 0 1 9 3N-07A 50-029-21539-01 906604302 Kuparuk River String Shot Record Revised 16-Jul-20 0 1 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 03/08/2021 03/08/2021 PTD: 1870540 E-Set: 34740 Originated:Delivered to:8-Jan-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 3H-26 50-103-20208-00 906832308 Kuparuk River Patch Setting Record Field- Final 23-Nov-20 0 1 2 3K-27 50-029-22751-00 906831229 Kuparuk River Multi Finger Caliper Field & Processed 20-Nov-20 0 1 3 3K-27 50-029-22751-00 906831376 Kuparuk River Leak Detect Log Field- Final 21-Nov-20 0 1 4 3M-17 50-029-21729-00 906811709 Kuparuk River Leak Detect Log Field- Final 28-Nov-20 0 1 5 3N-02A 50-029-21527-01 906813982 Kuparuk River Leak Detect Log Field- Final 30-Nov-20 0 1 6 3N-02A 50-029-21527-01 906804224 Kuparuk River Packer Setting Record Field- Final 5-Nov-20 0 1 7 3S-07 50-103-20430-00 906801235 Kuparuk River Leak Detect Log Field- Final 4-Nov-20 0 1 8 3S-07 50-103-20430-00 906806709 Kuparuk River Packer Setting Record Field- Final 7-Nov-20 0 1 9 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 01/08/2021 01/11/2021 Abby Bell PTD: 1870540 E-Set: 34560 Originated: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd, Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Delivered to: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above Transmittal Date: RECEIVED APR /�2-++32w020 AOGC WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE 1 1E-20 50-029-20895-00 906260886 Kuparuk Multi Finger Caliper Field&Proc 23 -Jan -20 2 1E-12 50-029-20736-00 906207895 Kuparuk Leak Detect with ACX Processed 30 -Dec -19 3 1E-12 50-029-20736-00 906190298 Kuparuk Plug Setting Record Final -Field 19 -Dec -19 4 1F-05 50-029-20807-00 906223186 Kuparuk Injection Profile Log Field&Proc 8 -Jan -20 5 1R -23A 50-029-22200-01 906228630 Kuparuk Multi Finger Caliper Field&Proc 7 -Jan -20 6 WSW -11 50-029-20882-00 906310488 Shallow Sand Plug Setting Record Final -Field 12 -Feb -20 7 3G-05 50-029-20132-00 906174377 Kuparuk Packer Setting Record Final -Field 26 -Dec -19 8 3M-17 50-029-21729-00 906210841 Kuparuk Leak Detect Log Final -Field 29 -Dec -19 9 3N -02A 50-029-21527-01 906192001 Kuparuk Leak Detect Log Final -Field 23 -Dec -19 10 30-01 50-029-21836-00 906193765 Kuparuk Plug Setting Record Final -Field 20 -Dec -19 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com r Date: L/ lax Signed: 187054 32815 13 -Mar -20 PRINTS # CD # 0 1 0 1 Originated: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Delivered to: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above Transmittal Date: RECEIVED /VV APR �2'``�3 20�20 d'1Cv 187054 32808 23 -Apr -20 DATA TYPE # SERVICE ORDER # FIELD NAME JOB TYPE 15 -Feb -20 50-029-21445-00 1 Kuparuk Multi Finger Caliper 0 1 906323212 2 -Feb -20 Radial Cement Bond Log Final -Field 30 -Dec -19 0 1 Final -Field Final -Field 4 -Feb -20 50-029-22771-00 1 Kuparuk SBHP and Plug Setting Record 906290370 String Shot Record906290370 Final -Field 19 -Feb -20 0 agRAPI Tubing Punch Record 50-029-22751-00 Kuparuk Packer Set Record 50-029-21541-00 905268412 Kuparuk Packer Set Record 50-029-21592-00 906251137 Kuparuk Packer Set Record 50-029-21729-00 906236139 Kuparuk Packer Set Record Transmittal Date: RECEIVED /VV APR �2'``�3 20�20 d'1Cv 187054 32808 23 -Apr -20 DATA TYPE LOGGING DATE PRINTS # CD # Final -Field 15 -Feb -20 0 1 Final -Field 18 -Feb -20 0 1 21 -Jan -20 2 -Feb -20 3 -Feb -20 Final -Field 30 -Dec -19 0 1 Final -Field Final -Field 4 -Feb -20 0 1 10 -Feb -20 18 -Jan -20 0 1 Final -Field 19 -Feb -20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS _ANC@ halliburton.com 7l`' Date: Signed: L THE STATE ALASKA GOVERNOR MIKE DUNLEAVY Sara Carlisle Well Integrity and Compliance Specialist ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3M-17 Permit to Drill Number: 187-054 Sundry Number: 320-001 Dear Ms. Carlisle: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a ogc c. olaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Price DATED this T day of January, 2020. -3BDMS(-*� AN 13 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 21 Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Patch TbgO 2. Operator Name: 4. Current Well Class: Permit to Drill Number: ConocoPhillips Alaska, Inc. %5. Exploratory ❑ Development Stratigraphic ❑ Service 187-054 3. Address: 6. API Number: P.O. Box 100360, Anchcorage, Alaska 99510 50-029-21729-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 3M-17 Will planned perforations require a spacing exception? Yes ❑ No - 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25522, ADL 25523 Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8713 6548 8713 6548 3000 None 8400,8402 Casing Length Size MD TVD Burst Collapse Conductor 78' 16" 115' 115' Surface 4291' 9-5/8" 4328' 3363' Production 8649' 7" 8683' 6524' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8414-8444 6307-6331 2.875" J-55 8340 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - CAMCO HRP -1 -SP RETRIEVABLE MD=8309 TVD=6332 12. Attachments: Proposal Summary Q Wellbore schematic 13. Well Class after proposed work: y10 J Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strati ra hic g p ❑ Development Service [R/ 14. Estimated Date for 1/6/2020 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ Q WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: YES Date: 12/29/2019 Commission Representative: Victoria Loepp GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Sara Carlisle Contact Name: Sara Carlisle / Stephanie Pilch Authorized Title: Well Integrity and Compliance Specialist Contact Email: 11549 conOCO hllll S.COfil r� Contact Phone: 659-7126 6 tom/ Authorized Signature: �4ti Date: 12/31/2019 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: — O Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test (�/ Location Clearance ❑ Other: IBDMS � JAN 1 3 2020 ,,.,// Post Initial Injection MIT Req'd? Yes V No ❑ Spacing Exception Required? Yes No Subsequent Form Required:�- D- APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 1 VTGORIGINAL= I '�1, I N Form50-403 Revise/412Q'I7� Approved appY�Jtipri►isw�ly ipr11 �7rrom the date of approval. Submit Form and Attachmentsin Duplicate M8 C oz" ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 31, 2019 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 3M-17 (PTD 187-054) to pull and replace a retrievable tubing patch with a new retrievable tubing patch. The intent of this sundry is to replace approved sundry 319-507 which did not include details of the patch installation. Please contact Stephanie Pilch or myself at 659-7126 if you have any questions. Sincerely, SCVUQ1-G"1L4-'/ Sara Carlisle Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. *sem ,� KUP INJ WELLNAME 3M-17 WELLBORE 3M-17 ConoeoNhillips well Attributes Maz Angie&MD TD FIeItl NeTe Wellbore APINWI Wellbore Status cl r) MD IXKB) -1 Due XIKB) Alaska, Inc, K PAR KRN R 5 710292 71290 0 IN 0.45 2,0710071 9,]13.0 MVTRDP 120 (PPmI 11/12/2013 LanwOn F Dale 43.106 RX ]IZ1967se Dale 3RTLIOVBS.V.Rooed 1 Last Tag Verlieal vhemallc (a[Mb Annotation Depth MKS) End Data Welllnre LaiLMotl By ....... .__ ................. PwNDEa; 34,0 CONOUCTO R; aZB11s.D EtW. 1.83D.9 GAB UFT: 2,ma SURFACE; Si 327.B- CAS LIFT, 4.8671.1 Tec LEAK; 4,94[.71 GAS LIFT; 6.911.8 GAS UFT 6,0.31,7 chs uFT: s,paB.a GAS LIFT, 7.]W.6 OASUFT.1AIR< GAS LIFT: 8.2,14.4 sea', e.2sts PACKER;83001 NIPPLE; Bann SOS', .,.,a- FIB.; 0.R HSR:e4Ddlo IPERF;8,414.D8,44,i.D PRODUCTION; a 4.719, 6aca Last Tagr RKB 6,43).0I 10/2912019 I Jel umbaej ................. Last Rev Reason Annette End Data welllweLast MM By Rev Reason: Pulled Patch &ADDED TBG LEAK 11/3&2019 pell jus)'Ap Casing Strings casing Descrlpnon oD in) IDpn) rop nl<B) selDeptn (nHe) ser Depth lrvD)... wvLen l... Gmae Top Thread CONDUCTOR 16 15.06 37.0 115.0 115.71 62.E H-40 WELDED Cazi ng Descnption DD lin! Inlln) Top IRKS) Bet Deep, IHKB) Set Dep[M1(ND)... WMen (I... GYade Top iM1rexl SURFACE 95/8 8.]6 3].0 :,32].8 33633 36.00 J-55 BTC casing Desnlption GD e, ID(in) Top (flKB Bel Dep[h IRKS) ae[Gep(n lNo)... WIILen (I.. Gretle iapTM1reetl PRODUCTION ] 6?8 34.0 8,fi82.8 6523.9 26.00 J-55 BTC Tubing Strings Tunmq Dezoripeon sbma Ma... m(in1 Top I set Depth pc. set I ITVD) L.. 1'/t DWH) Graae Top C -11 -hon TUBING 27/6 2.44 34.0 8,339.5 6.24].0 6.50 J-55 EUEBrdABN1OD Completlan Details TopNo) Top)Nominal iop lRKB) IHKB) (°) Item Des cam ID Be 34.0 34.71 0714 HANGER FMC 2]8'x]"TBG Hanger&Pup 2.441 1,820.9 1,684.6 4529 SSBV CAMCO27/8"TRDP-IA-SSA SSSV&Pup joinl 2.312 8,291.5 6,208.1 3].1056R 27/8° CAMCO'OEJ' Seal Asey lD=2.313' 2,313 8,309.1 fg=7 37.00 PACKER 2716"xT'CAMCO HRP -I -SP RETRIEVABLE PACKER 2.34] 8,327.0 6,237.0 36.88 NIPPLE 2]/8" CAMCO'D'-Nipple ID=2.25" 2.250 8,338.8 6246.5 3fi]9 505 27/8"CAMCD Shear Sub (SOS)-Pinned@3500 psi. TTL ELMD 2.441 @ 8326 SANS 6/30/198] Other In Have (Wiregna retrievable plugs, valves, pumps, fish, etc.) TOP (ND) Tap and Top (HKB) me.) I °) I Dez Com Bun Dale ID Fir) 4,9440 3,788.8 46.02 TBG LEAKTBGLEAK FOUND 5'1512015 2.992 8,400.0 6,295.6 36.36 FISH 6'PORTION OF VIDED TOOL 9'E2010 0.000 8,402.0 629)3 36.34 FISH 1" GLV DROPPED IN RATHO LE 2/13/1998 D.DDO Perforations & Slots Top IXKB) Btm MKS)IXKB) -DTVetm IND) (HKB) Unketl2one Data Shot heOo1sIH ) Type Com 8A1AD 8,444.0 6306.9 6,331.1 A -1,3M-17 WM1 ad I 12.0 /PERF 5" HSC, 120 dog. phasing Mantlrel Inserts BI on Top1ND) -- ps- port Slxe TRO Pun Tpp IXKB) IHKB) Make Model ODed Sery TYPS Type (in) (psi) Run Date Com 2°777.6 2,313.5 MCMlurry FMHO 1 GAS LIFT DMY B11-2 0.000 TO 1 7152019 2 4.860.3 3°73D7 McMurry FMH 1 GASLIFT DMY BK -2 0.000 0.0 ]/5!2019 3 5,937.8 4,469.2 McMurry FMHO 1 GAS LIFT DMY SK -2 0000 0.0 914!1961 4 64317 4,810.0 McMurry FMHO 1 GAS LIFT DMY 6K-2 0.000 0.0 1 1&1920D8 5 6,893.3 5,136.4 McMurry FMHO 1 GASLIFT DMY BK -2 D.000 0,01914/1987 6 7,387.6 5,502.6 MDMUrty &MHO 1 GASLIFT DMY BK -2 0.000 0.0 101192008 J 7,816.4 5,834.2 MCMur, &MHO 1 GAS LIFT DMV BK -2 0.000 D.0 716,2019 B 8.2444 6,111.2 Mdlurry FMHO 11/2 GASLIFT OMY RK 0.000 00 11115/1997 Notes: General & Safety Ene Dace Annopenin j 1012MODS NOTE: UNABLE TO LATCH GLM X3 DUE TO TRASH ON LATCH 11/6/20719 NOTE'. VIEW SCHEMATIC /Alaska Scbemetic9.I) 9/&2010 N0TE6" PORTION OF VIDEO TOOL @6400' &1572019 NOTE: PREVIOUSLY WAIVERED FOR IMDA DURING GAS LIFT; REMOVED AFTER CONVERTED TO WATER INJECTOR 2019 ConocoPhillips Alaska 3M-17 Permit to Drill#: 187-054 3M-17 was patched in July to repair a known TAA leak. Following the patch set, the well was converted from production to injection. The well developed a leak during water injection on 10/18/19. The original patch was pulled, and diagnostics indicated that the lower patch packer was leaking. A leak detect log identified no new leaks. The intent of this procedure is to re -install a new patch across the known leak at 4944' MD. Slickline/RELAY 1. RIH and set catcher. Pull DMY from GLM#3. 2. Circulate well with 141 bbls seawater and 71 bbls diesel. Allow to u -tube. 3. Reset DMY in GLM#3. Pull Catcher. 4. Brush and flush patch area. 5. Install a —28 ft. 2-7/8" tubing patch across leak at 4944' MD. 6. Confirm patch integrity with MIT -IA. Troubleshoot as needed. 7. Perform AOGCC witnessed MIT -IA after BOL and stabilization. 8. Submit 10-404. Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Sunday, December 29, 2019 6:50 PM To: Well Integrity Compliance Specialist WNS & CPF3 Subject: Re: 3M-17 PTD#187-054 Sundry Clarification Follow Up Flag: Follow up Flag Status: Flagged Sara, Verbal approval is granted to proceed with the installation of the patch and patch extension on this water injector. However, please submit a 10-403 outlining this additional work as soon as possible for approval. Please note the required State Witnessed MIT -IA after stabilized injection. Thanx, Victoria Sent from my iPhone On Dec 29, 2019, at 12:32 PM, Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> wrote: Hi Victoria, 10-403 sundry #319-607 approval was granted for KRU injector 3M-17 (PTD #187-054). The outlined steps in the procedure detail pulling an existing patch and completing leak detect diagnostics but did not include steps for re -setting the patch. A 10-403 is required to re -set a patch in an injector (not pull it), so the content of sundry #319-607 is misleading. We intend to pull the existing patch, replace it in-kind and add an additional patch or patch extension as necessary to repair the TxIA. The details of the repair work would be included in the 10-404. Please let me know if it's okay to proceed installing a new patch(s) to repair 3M-17 under the existing approved sundry or if I should submit a new one. RELAY is planning to start diagnostics soon, and we may have the opportunity to repair the well when the unit is on-site for diagnostics. Clarification will help us know if we can proceed to repair or need to wait on a new sundry submission/approval for patch work to proceed. I have attached the approved sundry #319-607 for reference. Thank you! ScwwCcwU&1& (Hes4yv) / Rachel/ Katttk Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549@cop.com Cell: 907-331-7514 1 sara.e.carlisle@cop.com <3M-17 APPROVED 10-403 Pull Tubing Patch.pdf> THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Jill Simek Staff Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3M-17 Permit to Drill Number: 187-054 Sundry Number: 319-507 Dear Ms. Simek: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Je . Price Chair L� DATED this V day of November, 2019, RBDMSN�'NOV 132019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 DECEIVED 140V 0 ] 2019 AOGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program[] Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Pull Tubing Patch 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: COnocoPhllll s Alaska Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service p - 187-054 ' 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21729-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 3M-17 Will planned perforations require a spacing exception? Yes ❑ No 21 9. Property Designation (Lease Number): 10. Fieltl/Pool(s): ADL 25522, ADL 25523 Kuparuk River Field / Kuparuk River Oil Pool 11, PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8,713' 6,548' 8713 6548 3000psi NONE 8400, 8402 Casing Length Size MD TVD Burst Collapse Conductor 78' 16" 115' 115' Surface 4,291' 95/8 4,328' 3,363' Production 8,649' 7" 8,683' 6,524' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8414-8444 6307.6331 2.875" J-55 8,339' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - CAMCO HRP -1 -SP RETRIEVABLE PACKER MD= 8309 TVD= 6223 PACKER - UPPER WIDEPAK PKR MD=4931 TVD= 3780 PACKER- LOWER WIDEPAK PKR MD=4956 TVD- 3797 12, Attachments: Proposal Summary 0 Wellbore schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑ Service I] 14. Estimated Date for 11/13/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ El WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jill Simek Contact Name: Jill Simek Authorized Title: Staff Wells Engineer Contact Email: Jill.Simek@cop.com Contact Phone: (907) 2634131 Authorized Signature: Date: 11 COMMIS ION USE ONLY Conditions of approval: No W Commission so that a representative may witness Sundry Number: 31 q- 507 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test PrI, Location Clearance ❑ Other: RBDMS� NOV 1 3 2019 f Post Initial Injection MIT Req'd? Yes LTJ No ❑/ Spacing Ezc ion Required? Yes ❑ No Id Subsequent Form Required:/, - q -n4 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: b li V v B l L !/ � ORIGINAL �x'17 �m�andT,� Form IP903 R vvised 4IG/2017 Approved application is valid for 12 months from the date of approval. Attachments in ovplicate ConocoPhillips 3M-17 Permit to Drill #: 187-054 3M-17 is an injector with suspect TAA communication, which has been shut in for diagnosis and repair. This procedure outlines steps to pull existing patch and troubleshoot the new leak. Procedure: Slickline 1. MIRU. 2. RIH pull upper patch packer, spacer pipe, and anchor latch at 4,931' KB. 3. RIH and set test tool in lower packer. Perform CMIT to 1500psi. i. If CMIT passes, rerun upper patch assembly. MIT -T to 1500psi to confirm no other leaks. RDMO. Else, continue to Step#4. 4. RIH pull lower patch packer at 4,956' KB. 5. RIH with D&D holefinder to locate source of lower leak. 6. Replace defective gas lift valves in-kind. 7. Pressure test tubing and bleed off IA to confirm repair. 8. if additional leaks remain, secure well with plug in D Nipple @ 8,327' KB. 9. RDMO. i. If repair is successful, turn well over to DSO. ii. If repair fails, notify CPF3 PE (x7871) and Well Integrity Engineer (x7126). LDL steps to follow (see below). E -line - LDL Spinner/Temp 1. MIRU. 2. RIH with spinner/temp logging tool. Make baseline pass to CA -2 plug at 8,327' KB. 3. Begin pumping diesel down tubing, taking returns from the IA to activate the leak. 4. POOH to surface for a dynamic up -pass. 5. RIH to perform station stops at observed anomolies. 6. Ensure good data, then RDMO. Well to remain SI pending patch repair. JS KUP INJ WELLNAME 3M-17 WELLBORE 3M-17 *� Well Attributes Max Angle & MD TD Conoco tlName Willie eAPWW Wellbo,estalua Ic^I5) MDnnKBf pct San ral A:a3lte. 1110. IKIIPARIIH RIVFR UNIT 190099.71]991111 1, n on nn Oran 3M 1], It/]2119fl59:10 PM Last Tag Var4vg xlemaEc lacOmp Arb-tation Depth gal 1 End Date WeIIWre tzst Men By ""'"'---------- XPNGER; 31.c� COXOVCTOR: 3/.61150 .a.,.tpal.9 GAG UFT:2ma suamCE;a]w,azr.e_ GASUFT;4,aW,a uFR pgcNER (ME)1 aa31p SPACED PIPE`, as3s.D MR PACKER ME):4,ae.p Gas LIFT; 5,9378 GAS LIFF, 9a317 ras LIFT: e.w3s GaSUPT:7DE76 GAS LIFT. 7,she4 GASLIPT', Dg444 59R: a.3e>s PACKER: 6,3Ce.1 NIPPLE: III sos: esae.e FIEX A.0 FISH, 8.4030 IPERF; 9.414.Da.444.p� PRODDCTIGN;31.69,8a3,8 Last Tag; FIRS8,43)0 1012912019 3M-9 zembaej Last Rev Reason pnnatafian End Date WellEore Last Med By Rev Reason. Updated Tag DepN 10292019 3M -1J zembaej Casing Strings Lasing Desnipllan OD (in) ID (in) Topft I Set Depth MKB) set DMPb ITVD)... WDL¢n n... G2ae Top Tlrreatl CONDUCTOR 16 1606 37.0 115.0 1150 6250 IGH WELOEO Caslnp Description pO lin) ID (In) Tap Me) Sel Cepiry elKB) Ba[DepN (ND)... W1ILen lI... Graae iap Tll,eetl SURFACE 9518 8,76 37.0 4,327.8 3,363.3 36.00 J-55 BTC Cuing Descriptbn OD Hart ID 'In, Top 1HKa) set Depin Met SN DeathrVID... WDLan IL..Grade TOPTrywtl PRODUCTION 7 628 34.0 8,682.8 6.523.9 2600 J-55 BTC Tubing Strings Tubing Description SII Me... IDI,) Top (nKa) see Depm (n.. s¢t 0¢pm 1ND)L.. WIpWfn Gretle Top Lnnn¢=con TUBING 244 340 8,3395 6247.0 6M J-55 EU,FHABM0D Completion Details is Top 11V0) Top m=I Nammm Ter KIND) RIKB) 1•) X¢m SeaCom ID (in) MD 340 004 HANGER FMC 27/8" x T' TBG Hanger B Pup 2.441 1,820.9 1,684.6 4529 SSSV CAMCO2718-TRDP-IA-SEA SSSV B Pup joint 2312 8,291.5 0208.7 37.10 SBR 2718" CAMCO'OEJ' Seal Asay 10=2.313- 2.313 8,309.1 6,222.7 37.00 PACKER 27/1'CAMCO HRP -I -SP RETRIEVABLE PACKER 2.347 03270 02370 36.88 NIPPLE 2718" CAMCO'D' Nipple ID=225' 2250 8,338.8 6,246.5 3679 SOS 27/8"CAMCO hear Sit SOS) - Pinned 500 psi. L LM 2441 @ 8326' BWE 613011987 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top ITVD) Top,al Trip(nKS) (nice) (°) Dea Com Run Dors ID (in) 4,9310 3,]]9.8 46.02 UPR PACKER 2-703 UPPER WIDEPAK PACKER Ivy I FD)(SN: CP 7112/2019 1460 (ME) 287019) 79330 3,781.2 46.02 6PACERPIPE SPACER PIPE wI ANCHOR LATCH (SN: CPS 7/12/2019 1.310 PATCH DAL 28.79' 4,956.0 3,797 46 .2 02 PACKER 2- "L WER WIDEPAK PACKER(WTFD...: 71122019 1460 (ME) 28]020) 3,4000 0295.6 3635 FISH 6" PORTION OF VIDEO TOOL 9/62010 0.000 8,402.0 0.29].3 36.34 FISH 1" GLV EMPTY POCKET IN RATHOLE 2/1311998 0.000 Perforations IL Slots Top 1flK0) BM (XNB) Top(rvD) (ttKB) Dtm 1rvD) (Me) LInkM Zone Dah able pnotsm ) Type Com 8,414.0 BA44.0 6,306.9 6,331.1 A -1,3M-17 9141198] 1101PERF 5" HSC, 120 deg, phasing Mandrel Inserts sl ati Top TV I VMvs Latch P.R.S. TRD Run N Top dal iMB) Mase Dery T Type Ips) Run Dale Lom 2,777.6 2,313.5 McMurry GAS LIFT OMY BN -2 0.060 0.0 7152019 -2 D 2 4,860.3 3,730.7 MCMurry GAS LIFT DMV BK -2 0.000 0.0 7/52019 3 5,937.8 4,469.2 MCMurry GASLIFT DMV BK -2 0.000 0.0 9/411987 t 4 6,431.7 4,8100 McMurry GAS LIFT DMY BK -2 0.000 0.0 1011912008 5 6,893.3 5,1364 McMurry GASLIFT DMV BK2 0000 0.0 9141198] 6 7,3876 55026 MCMurry GASLIFT OMY BK2 0000 00 1W192008 ] 7,8164 5834.2 MCMurry GASLIFT DMV BK -2 0.000 00 71W2019 8 62444 61712 MCMuny FMHO 112 CTAS LIFT DMV RK 0000 0.0 1111511997 Notes: General & Safely End Date AnnobHon 1RJ12003 NOTE: WAIVERED WELL. IA x OA COMMUNICATION 1012212008 NOTE: UNABLE TO IATCH GLM#3 DUE TO TRASH ON LATCH 11162009 NOTE: VIEW SCHEMATIC whide aSchemaGC9.0 9162010 NOTE: 6• PORTION OF VIDEO TOOL @ 8400' Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Friday, October 18, 2019 9:14 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 3M-17 (PTD 187-054) IA pressurization report Chris, Kuparuk injector 3M-17 (PTD 187-054) was reported this morning by Operations to have been found with high IA pressure while injecting water. The well has been shut-in and freeze protected by Operations and DHD is currently performing initial diagnostics to review the well's condition. CPAI plans to leave the well shut-in while the diagnostic work is performed and evaluated. The appropriate paperwork and/or notifications will be submitted as necessary. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 187054 3 120 2 WELL LOG TRANSMITTAL # To: Alaska Oil and Gas Conservation Comm. September 9, 2019 Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Records: 3M-17 Run Date: 7/10/2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com 3M-17 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21729-00 RECE1VED SEP 12 2019 aoGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: C /[�(/I Signed: Operations Performed: Depth Depth Structural Conductor Surface Intermediate Production Liner STATE OF ALASKA OIL AND GAS CONSERVATION None COMMISSION REPORT OF SUNDRY WELL measuredNone OPERATIONS Abandon ❑ Plug Perforations❑ Suspend ❑ Fracture Stimulate ❑ measured Perforate ❑ Plug for Redrill LJerforate New Pool ❑ Other Stimulate ❑ Pull Tubing ❑ Alter Casing ❑ Repair Well ❑ Re-enter Susp Well ❑ ConocoPhillips Alaska, Inc. 4. Well Class Before Work: Deve1Opmentp P. O. Box 100360, Anchorage, Alaska sraphi� Strati 5. Per, Explo story❑ 99510 Service❑ 6. API n Per measured 8,713 feet true verticalPlugs i,bgt3 feet Junk measured 0 feet true vertical Packer � 0 feet Length Size MD 78 16 4,291 115 12 4,328 8,649 7 8,683 .•..0 vepm Measured depth -feet True Vertical depth -------------- Q feet I (size, grade, measured and true vertical depth) Name and Number: .11A 2 9 Operations shutdown L]Change ApPMved Program O r Prod to WINJ 17 187-054 tuber 50-029-21729-00 KRU 3M-17 measured None feet measuredNone feet measured 8309 feet true vertical 6623 feet TVD Burst 2875 J-55 l 8339 and SSSV (type, measured and true vertical depth) � P ) 2 7/8" x 7" - --� -' ---FL squeeze summary: treated (measured): It descriptions including volumes used and final pressure: Prior to well operation: 28 Subsequent to operation dachments( gmred per 20 AqC 25.0]0, 25.W1,g25.28: Report of well Operations r-1 s of Logs and Surveys Run ❑ d and Electronic Fracture Stimulation Data ❑ lereby certify that the foregoing is true and c 4uthorized Name: Devin Kozak Form 10-404 Revised 4/2017 CAMCO HRP- - CAMCO 2 7/8" PKR MD: 8309 1 TRDP-IA-SSA SP SSSV SSSV MD: 1821 RFTRIF rARI F Exploratory? 1 StatusStatus a ❑ WINJ O Of my my kn�— or Developmen❑ �il _WAG ❑ GINJ❑ WE Collapse 6247 PKR ND: 6223 SSSV ND: 1685 Servicep Stratigraphic ❑ Gas ❑ WDSPL SUSP❑ SPLUGO or N/A if Contact Name: Devin Kozak Contact Email: Dewn.Kozakoconocophillips.com } Contact QPhone: 907-263-4121 �J f Oc j �B�M Submit Original Only ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 July 22nd, 2019 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. reports the conversion of Kuparuk River Unit Well 3M-17 from Oil Production to Water Injection service. 3M-17 was operating as an producer and had been producing until 4/10/2019 when it was shut-in and converted to water injection on 7/15/2019. Enclosed you will find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. regarding 3M-17 (PTD# 187-054). If you have any questions regarding this matter, please contact me at 907-263-4121. Sincerely, I Devin R. Kozak Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry application Well Schematic A&I@NiN KUP PROD WELLNAME 3M-17 WELLBORE 3M-17 ��-_=ay.il't� CKVf1, AIaSYe.ln(:. Well Attributes Max Angle 8 MD TD WellGore APIIUWI Wellbo,e slalus NUPARUK RIVER UNIT500292P2900 PROD ncl ('I MD (NKp) Act .. IXXBI SO E5 200000 9,)13.0 Comment 1Q9 Epm) Dale MnW-i. End Dale KBG,tl lel Rig Release Dab S55V:TRDP 120 11/12/2013 LRA WO: 4310 7ID1987 RM-n.m2rm19s...wua Last Tag verti®I Wemal2lacuA Annotation 1 Depth InKBI End Dale wellbore last MM By - - -- - - 1VWGER; 3f.0- caNDULTDR. 31onsD .SSV, 1,209 GUUFTi z1d suaEACB;.zw.n.e- GA.OEr;.,. UPR PACKER (ME) d.W10 svACER PIPe, d.9n.D LWAPACKER(ME).4e ti GISUF[SeTe ws DET; d..1 T GAS UFp6 W33 WS UFT, 0187 GPS un. Tined GP. DFL; &Nd.. S.R;BE 5 PM.NER, 4.]19.1 MIELEI D.I .OS 319. let' ... RSH;8. 0 IPEPF a.tane,eJC.O- PROOIKTKKI; 30.Oe,YQ.B Last Tag: IEs121Of011, Leafing Tof Open Peds) Bd2300282019 3M-1) -1-dl Last Rev Reason Ann..V.n End Dab Wellbore Iusl Motl By Rev Reason: 3¢1 Patch ]/12/2019 3M -P bwotlnl Casing Strings ...in. De.floWn OD (in) mOn) rap InKBI sen cepk lnKal sn NPIK IND) wd.. a.. Gnae Top rnrm CANDUCTOR 18 15.06 37.0 115.0 1150 62.50 HdO WELDED Lasln9 Deacnptlon OD 6n1 IOIInI Tap (XN81 SN DePIn IXKBI Bal DePlN lN01... WVLan 11... Gentle ToiThmd SURFACE 95/0 B.]6 3]0 4.32).8 33fi3.3 3500 J-55 BTC Casing Deaaiplion Op(el ID lin) Top IXKBI $et Cep4l lkKe) Sar Daprn lNp � WVLan 11..Grade iNP TNreed PRODUCTION ] 628 340 JSSS2.6 16,5239 2600 j 5 BTC Tubing Strings cubing Desmiplion SoinB Ma... ID(In Top InKBI SN Depm(N..Sel pepinlND I... Wt IEXp Geade Top LpnnMion TUBING 27/8 2Ad 34.0 8,3395 6,247 6.511 J-55 EUEBNABMOO Completion Details TOP IND, TDp Incl xominal TDp InKB) (4.) M Ittm IN, cam ID(d) 340 34.0 0 04 I HANGER FMC 2718' x 7 TBG Hanger a Pup 2.441 10209 1504.6 4529 1 SSSV CAMCO2718"DROP A -SSA SSSV B PUP IdnI 2.312 8,291.5 6.208.7 3].10 SBR T71WCAMCOOEJ'Seal Assy ID=2.313' 2,313 8309.1 6.2n 71 3]00 PACKER 2718"x7'CAMCO HRP -1 -SP RETRIEVABLE PACKER 2347 8,327.0 6.237.0 36.88 1 NIPPLE 27W CAMCO'9'Nippe ID=2.25' 2.250 8330.6 6,2465 35.79 1 505 2710"CAMCO Shear Sub(505)-Pinned@3500, TTLELMD 2A41 ® 6326' SM BOOM 967 Other In Hole (Wireline retrievable plugs, valves, PUMPS, fish, etc.) IF INDI TOP Incl Top InKBI (XKB) VI Des Gam .) 49310 3,779.8 4602 UPR PACKER 29/6' UPPER WIDEPAK PACKER (MFD)(SN : CP .060 (ME) 207019) 4,933.0 3]612 46.02 SPACER PIPE SPACER PIPE w/ANCHOR IATCH(SN. GPS 28708) 310 PATCH DAL 28]9' 1711=0191A60 6.958.0 3,]9]2 46.02 LWR PACKER 2-718" LOWER WIDEPAK PACKER (WTFDI(SN: CP A60(ME) 287020) 8.400062956 36.35 FISH 6" PORTION OF VIDEO TOOL .0006.29]3 3636 FISH 1" GLV EMPTY POCKET IN RATHOLE 000 Perforations B Slots cop lkK81 Bsm IXKBI Top(WIN IXKBI erm mr, (RKB) LinW lYn¢ snot pens (¢notal DYe 1 TYX Com 8,414.0 0,444.0 83..9 6.331,1 A-1, 3M1Y17 9W198) 12.0 (PERF 5" H50, 120 deg. Phasing Mandrel Inserts St TDPIND) Valvv lake PD(i(in) TR(.0 N Top,777 12.31 Make MHO Wgnl Sery ryce Ipso Ron Dale Can K-2Tind00 1 2,))76 2.3135 MCMurry FMHO 1 GAS LIFT DMV BK -2 0.000 0.0 ]/52019 2 4,8503 3,730.7 MCMurry FMHO 1 GASLIFT DMV BK -2 0.000 00 7/5/2019 3 5.9378 44692 MCMurry FMHD 1 GASLIFT DMY BK.2 0000 00 914/1987 d 6,431.) 4,8100 MCMurry FMHO 1 GASLIFT DMY BK -2 0000 0.0 10119/2000 5 6,893.3 5.1384 MCMuI FMHO 1 GASLIFT DMY 172 0000 0.0 9l4/1907 8 ]38)8 5,5MCMuIry TIM -HO 1 LIFT DMY eK-2 0000 0.0 10119/2008 02.8 7 7,8184 5.034.2 MCMurry FMHO 1 GAS LIFT DMY BK -2 0.000 0.0 )/82019 8 8,2440 1 6.171.2 McMurly FMHO 11/2 GASLIFT DMV RK 0000 00 11/1511997 Notes: . General 8. Safety Entl Dak I Annolabn En 1/92003 NOTE: WANEREO WELL Iqx OA COMMUNICATION 10222000 NOTE: UNABLE TO LATCH GLM #3 DUE TO TRASH ON IATCH 11/62009 NOTE: VIEW SCHEMATIC w/Alaska Schemalic9S SibQ010 NOTE: 6' PORTION OF VIDEO TOOL ®04.' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 2 y' DATE: Wednesday, July 24, 2019 P.I. Supervisor Gl� SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3M-17 FROM: Matt Herrera KUPARUK RIV UNIT 3M-17 Petroleum Inspector Sre: Inspector Reviewed By: P.I. Supry -J)92- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3M-17 Insp Num: mitMFH190723100141 Rel Insp Num: API Well Number 50-029-21729-00-00 Inspector Name: Matt Herrera Permit Number: 187-054-0 Inspection Date: 7/21/2019 ' Packer Depth Well 3M-17 " Type Inj w "TVD 6222 ' Tubing PTD 1870540 " Type Test SPT Test psi 1556 T IA BBL Pumped: 13 BBL Returned: 22 r OA F -- Interval INITAL IP/F P % Notes: MIT -IA Post Producer/Injector Conversion per Sundry 318425 Pretest Initial 15 Min 30 Min J5 Min 60 Min i720 - 1720 1720 nzo 4 '_190 2435 " 2430 " 353 - 362 364 365 Wednesday, July 24, 2019 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS JUL 17 20+19 A n t�- r" �"''_ ions Abandon Plug Perforations rr-%'k6j �-A d 0 , Fracture Stimulate Pull Tubing Operations shutdown med: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool E2e ❑ Repair Well Q Re-enter Susp Well ❑ Other: patch_ Q or ConocoPhillips Alaska, Inc. _Tubing 4.Well ClassBefore Work: 5. Permit to Drill Number !ive Depth Development Q Exploratory ❑ 187-054 3. Address: P.O.Box 100360, Anchorage, Alaska 99510 Stratigraphic ❑ Service [36. API Number: 7. Property Designation (Lease Number): 50-029-21729-00-00 6314 Name and Number: ADI -0025522, ADL0025523 =me KRU 3M-17 9. Logs (List logs and submit electronic and printed data per0AC25.071 2A): feet 10. Field/Pool(s): 11. Present Well Condition Summary: Ku aruk River Field/Ku aruk River Oil Pool Depth measured 8,713 feet feet true vertical 6,548 feet !ive Depth measured 8,423 feet Lower Patch Packer true vertical 6314 feet 9 Length Size feet Conductor 78' 16" Surface 4291' 9.625" 115' Production 8649' 7' abon depth Measured depth 8414-8444 feet True Vertical depth 6306-6331 feet I (size, grade, measured and true vertical depth) rs and SSSV (type, measured and true vertical depth cation or cement squeeze summary: treated (measured): it descriptions including volumes used and final pressure: Collapse 2.875 Plugs 8340' measured feet CAMCO TRDP-IA-SSA Junk 1685' measured feet 4931' Packer Lower Patch Packer measured feet 3797 Packer CAMCO -HRP-1-SP true vertical feet MD TVD Burst 115' 115' 4328' 3363' 8683' 6524' Collapse 2.875 J-55 8340' 6247' SSSV CAMCO TRDP-IA-SSA 1821' 1685' Upper Patch Packer Paragon II Packer 4931' 3780' Lower Patch Packer Paragon II Packer 4956' 3797 Packer CAMCO -HRP-1-SP 8309' 6223' or - - � vvacer-eoi Casing Pressure Tubing Pressure Prior to well operation: NA NA NA NA NA Subsequent to operation: NA NA NA NA NA 14. Attachments (r Wild p r20 a C 25.070, 25.071, s 252831 15. Well Class after work: Daily Report of Well Operations ❑� Exploratory ❑ DevelopmentEl Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the for is true and correct to the best of my knowledge. Sundry Number or N/A if C.o. Exemot: Authorized Name: Sara Carlisle Authorized Title: Well Integrity Supervisor Form 10-404 Revised 4/2017 VTL. 9/¢/i 9 * JOW/9 Date: 7-1 (- RBDMS g6"jUL 18 2019 Contact Name: Rachel Kautz/Sara Carlisle Contact Email: 22549gconowohillios cora Contact Phone: 659-7126 Submit Original Only ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 15, 2019 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7t^ Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing patch set across a known tubing leak in producer KRU 3M-17 (PTD 187-054). Please contact Rachel Kautz or me at 659-7126 if you have any questions. Sincerely, Sara Carlisle Well Integrity Supervisor ConocoPhillips Alaska, Inc. Date Event Summary Executive Summary 05/15/19 07/05/19 07/06/19 07/11/19 07/13/19 Kuparuk producer 3M-17 required a tubing patch to cover a tubing leak located at 4944' RKB. The tubing patch was set across the leak site and subsequent testing passed to confirm tubing integrity was restored. RIH W/ LEAK DETECTTOOLS. PERFORM BASELINE TEMPERATURE PASS, OPEN IA TO FLOWLINE AND LRS BEGIN PUMPING DOWN TUBING. LRS PUMPING 0.5 BBL/MIN @ 200 PSI. LEAK FOUND @ 4944'. PERFORMED STATION SURVEYS @ 4958', 4950', 4944'. SET 2.29" CATCHER W/ PULLING TOOL @ 8311' RKB; PULLED OV @ SET DV @ 4860' RKB; PULLED GLV & SET DV @ 2778' RKB; PULLED DV @ 7816' RKB; LRS ON LOCATION TO PERFORM CIRC OUT W/ CISW FOLLOWED BY DIESEL (U -TUBE FP) & PERFORM CMIT TBG x IA (PASS) SET DV @ 7816' RKB; PULLED CATCHER ASSEMBLY @ 8311' RKB; PULLED 2.25" CA -2 PLUG @ 8327' RKB. JOB COMPLETE & READY FOR RELAY. SET 2.25 LOWER ER PACKER @ 4956' RKB (ME / SN: CP 287020 / OAL 3.77'), SET 2 7/8 ER TEST TOO IN PACKER @ 4956' RKB CMIT TBG x IA 2500 PASS, PULLED ER TEST TOOL @ SAME, SET UPPER 2.25 ER PACKER SPACER ANCHOR ASSEMBLY @ 4931' RKB (ME / SN: CP 287019 / CAL 26.12'), SET 2 7/8 ER TEST TOOL IN UPPER ER PACKER @ 4931' RKB MIT TBG 2500 PASS, PULL 2 7/8 ER TEST TOOL @ 4931' RKB. COMPLETE. CM IT TxIA TO 2500 PSI (PASS) Pre -Test T/I/O = 1575/1350/56 Pumped 1.25 bbls to pressure up T&IA to 2500 psi Initial T/I/O = 2525/2300/560 15 min T/I/O = 2525/2300/580 30 min T/I/O = 2525/2300/580 MIT -T TO 2500 PSI (PASS) Pre -Test T/I/O = 1675/1350/560 Pumped 0.75 bbls to pressure up T to 2500 psi Initial T/I/O = 2550/1350/560 15 min T/I/O = 2475/1350/580 min A (PASS TO 2500 PSI) I T/I/O = SI 1550/1190/576. T FL @ Surface. IA FL @ Surface. up the IA to 2000 psi with 19 gal of diesel. Start T/I/O = SI 1550/2000/587. 15 min T/I/O = 51 1550/1990/589. ured up the IA to 2500 psi with 19 gal of diesel. T/I/O SI 1550/2500/597. min T/I/O = SI 1550/2480/599. min T/I/O = SI 1550/2480/599. d the IA to 700 psi in 7 min. Final T/I/O = SI 1500/700/568 1 4---\ KUP PROD WELLNAME 3M-17 WELLBORE 3M-17 ConOCoPhillips AlaSka.lOt Well Attributes Max Angie&MD TD FINE Name Wal s ma Ammeal Wallnore alncl (') MO (NKB) AS Blm (tIKB) KUPARUKRIVERUNR 50 02 92 1129 0 0 PROD 50.45 2,000.00 9.]13.0 Cammvn\ NE (Ppm) Oalo MnolNlon EnE Oele Ke G,E (1x) Rig RaIMN Oaly SSSV: TRDP 120 11/1212013 " WO: 43.10 ]!2/190] 1..U, ]I1 xIM195'. is AM Last Tag Vatimunerand"Ant el) Annotation Oeam OmB) End Data .,be. Laid Mod By -- tuxKER;xI o - COrvpupTOR: 3x11115.0 ssw', Lax4° GA6UFT12.717e SUPFACE: 31D,OdIA- GAB UPT', apdea DPN PACKER Pal 40]1.0 SPACER PIPE', 4.5x3.0 Dog pACNER IMP, 4.0 GAS UFT: Ipeo. GAS UFT; 4431,1 G.s t,FT; 455x] GVRU11.31xe NAS DEC; tel. W611FP.8241A 6BR: B,ID1S .Hp fi.xm.1 NIPPLEAp,UP Sm.. State PIN 4amo .. 44pps ,PERF:IA1408.W.0- PRODUCTION: %.Dd.WxB - -- Las[Tag(EM21' of0l,Le IVIU99 of Open Perk) 8A23O 4282019 3M-1] xemhael Last Rev Reason Annolafmn Ena wta wonfiare Laal MOE sy Rev Reason. Set PelaM1 ]/1212019 3M-9 bwonM1l Casing Strings e.eiae Boamplmo CONDUCTOR Do (in) 1 Io (in) Top (mre) I Sal cepin p0s) Set ocpm(rVUL.. WN.en g... Some Top Thread 16 1506 37.0 1150 1150 62.50 H-40 WELDED CNIn.oaunplian SURFACE OO lin) 1O pea) Top(MB) Set pep lh(It KB) Set -min 11 vol... W1ILen (I... OneUe Top Thread 9518 6]6 37.0 432]8 3,363.3 36,OD J-55 BTC Caainq Description PRODUCTION OO(11) ID(in) Top(flKB) SU page LOAD) Sel Oepm(IVOf.. Wm -Gone Tap Tnrtatl ] 628 340 8.6828 8,5239 2660 A55 BTC Tubing Strings memp Deeefipuoa I steel Me... ID pea) Top INKS) sM Cepm (n.. set Depth Irvo L.. wylnrct Gmae Tap Connection TUBING 2]/0 2.44 34.0 8,3395 6,24].0 6.50 J-55 EUEBNABM00 Completion Details Top Man Top ll Nom net Top NNIS Ppa) PI Nem Dez cam Ip lin) 340 340 0.04 HANGER FMC 2 TOP x]"TBG Hanger &Pup 2.441 1,820.9 1,6040 4529 SSSV CAMGO2 TIB'TROP-IA-SSA SSSV It Pup loin[ 2.312 62915 6,2081 37.10 SBR 27,8'CAMCO'O J'Beel Assy 10=2.313" 2313 8.309.1 6,247 37.00 PACKER 27/8'x T'CAMCO HRP -ISP RETRIEVABLE PACKER 2347 8,3270 62378 Was NIPPLE 27/8" CAMDO 0 Nipple 10=2.25" 2.250 8,338.13 6,246.5 36.79 SOS 2718"CAMCO Snear Sub (SOS)- Pinned § WOO psi. TTL ELM 2.441 iR 8326 S WS 6/30/1987 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) TOP DlI I Top LONG) (NN.) Top mel C) Des Com ampale 10 en1 4.9318 3.]]9.8 4662 UPR PACKER 2-]18" UPPER WIDEPAK PACKER (WTPO)(SN: CP 711212019 (ME) 287019) 16130 4,9336 3,7812 4602 SPACER PIPE SPACER PIPE wI ANCHOR PATCH (SN WS 20]08) 711WO19 PATCH OVAL 28.79' 1.310 4,9560 3,]9].2 46.02 LWRPACKER 2-718' LOWER WIDEPAK PACKER (WrFp)(SN : CP 7/122019 (ME) 28]020) 1.460 8.4000 6,295.6 36.35 FISH 6" PORTION OF VIDEO TOOL 9/612010 0000 8,4020 6297.3 3634 FISH 1" GLV EMPTY POCKET IN RATHOLE 2U311998 0000 Perforations B Slots Top IflKB) BM (NI(B) raG-) atM-) UnFe43n e. page snot was (snot Wt Typ. Cam 8014.0 8,444.0 d.S 8,3089 G'SS 6,331.1 A-1, 3M-1] 9!41198] 12.0 ,PERF d- Ed'. I'D WS. pM1asing Mandrel Inserts an as N Pop Brad) VaM Lost Poelle-TRORun Top Note (GAS) Malas Model CO en) Sery Type Time (In) (pet) sumDale Cam 1 ?7]76 2313.5 McMumy Hill 1 GAS LIFT DW BK -2 0.000 00 7/512019 2 4.860.3 3.7307 MCMurry FMHO 1 GAS LIFT DMY B142 0,000 On 71SIM19 3 5,93]8 4,469.2 MCMurry Bell 1 GAS LIFT DMV BK -2 0,000 0.0 9/411987 4 6631] 4,010.0 MpMUrry Fill 1 GAS LIFT OMP BK -2 0.000 0.0 10/192008 5 6.893.3 5.1364 Mal FMHO 1 GAS LIFT DMV BK -2 0.000 0.0 911 6 7,387.6 5.502.6 MCMurry FMHO 1 GAS LIFT OMY BK -2 0000 0.0 10/192000 7 7,816.4 5,034.2 MCMurry FMHO 1 GAS LIFT OMY SK -2 OOOO 0.0 7162019 8 li 4 6,ifl.2 MCMurry FMHO I V2 GAS LIFT DMY RK 0000 OO 1111511997 Notes: General & Safety Endog announan 1/92003 NOTE: WAIVEREDWELL: W%OACOMMUNICATION 1012 2/2 0 0 0 NOTE: UNABLE TOLA C GLMp3DUETOTRASHONI.ATCH 11/6,2009 INCITE: VIEWSCHEMATIGWAIaska Schematic9.0 91612010 NOTE:B'PORTIONOFVIDEOTOCLSr84IO' Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Monday, July 15, 2019 8:59 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 3M-17 (PTD#187-054) 30 -Day Monitor Post Conversion from Prod. to Inj. Good Morning Chris, Thank you for taking the time to talk through the path forward for the conversion of KRU 31M-17 (PTDg187-054) from production to injection. To summarize our conversation, 3M-17 is a gas -lifted producer that has been internally waivered for IA x OA communication and passes a MIT -IA and MIT -OA as previously communicated on the 10-403 application for conversion from production to injection. We suspect the source of the IA x OA is through the packoffs when on gas -lifted production, leading 3M-17 to be specifically submitted as a water -only injector on the sundry application. We intend to complete the routine process to close out the 10-404 for conversion with a witnessed MIT -IA upon stabilized injection and will ensure to mark the well as a water -only injector. Additionally, we will place the well on a 30 -day monitor period to understand if IA x OA communication persists while on water injection. We will report any bleeds after stabilization or suspect communication while monitoring the well. We will plan to progress diagnostics to justify application for administrative approval if the IA x OA communication persists on water -only injection. Please let us know if you have any questions or disagree with the plan forward. Sincerely, SarwCarU*I& 0iwdki:n.) /Ra4mV Ka.utk Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n25490cop.com Cell: 907-331-7514 1 sara.e.carlisle(o)coo com Originated: Schlumberger PTS - PRINTCENTER 6411A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: n x.14 AOGCC s ` ATTN. Natural Resources Technician II Alaska Oil & Gas Conservation Commision �y 333 W. 7th Ave, Suite 100 +-*Aj Anchorage, AK 99501 18 70 54 30850 r • 30 -May -19 30May19-JW 01 me Please return via courier or sign/scan and email a copy to Date and CPAI. Schlumberger -Private ATransmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the Package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. PTD 1B;z--05-4 Loepp, Victoria T (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Monday, April 29, 2019 7:32 PM To: Loepp, Victoria T (DOA) Cc: CPA Wells Supt Subject: CPA] KRU 3M-17 (PTD#187-054) OA DNE Follow Up Flag: Follow up Flag Status: Flagged Hello Victoria, KRU gas lifted producer 3M-17 (PTD#187-054) was shut in on 4/11/19 for gas handling purposes during scheduled CPF3 maintenance. 3M-17 is internally waivered for IA x OA communication and has an OA DNE of 1400 psi. While shut in, the OA pressure exceeded ONE this morning and rose 1410 psi as a result of suspected TxIA communication. The production casing is 7 26# J-55 with an internal yield rating of 4,980 psi (45% here is 2,241 psi). Slickline was able to get on the well today and verified that the tubing is leaking and requires repair. CPAI plans for the well to be secured and remain SI until the tubing can be repaired. Please let me know if you have any questions or disagree with this plan forward. Sincerely, SarwCarb, st& (}febkjvv) /RaJwbKaatk Well Integrity Supervisor, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549(@cop.com Cell: 907-331-7514 1 sara.e.carlisle@coi2.com MEMORANDUM • To: Jim Regg '~ P.I. Supervisor ~ )fJ~`~ ,'!v~ ~~-ia; FROM: Chuck Scheve Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, December 26, 2007 SUBJECT: Mechanical Integrity Tests COtiOCOPHILLIPS ALASKA INC 3M-17 KUPARUK RIV LNIT 3M-17 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~,,3r~^=- Comm Well Name: KUPARUK RN UNIT 3M-17 API Well Number: 5 0-02 9-2 1 7 2 9-00-00 Inspector Name: Chuck Scheve Insp Num• mitCS071219074042 Permit Number: 187-054-0 Inspection Date: 12.1812007 Rel Insp Nam: Packer Depth Pretest Initial ~ 151VIin. 30 Min. 45 iVlin. 60 Min. Well I sM-I~ ITYpe Inj. ~ I T~ 6?z3 IA Io7s ~- i goo - _ I loo I~ I too j ----~- - p T I ta7osao ~TypeTest ~ SPT Test psi i tsss.~s ~ pA ~ 660 660 660 ~~ 660 ~; Interval °T~R P/F P Tubing ~ 9zs -~- 3000 -, z97s I z97s ~~~ ~I Notes' ~Veli has a waiver for IA x OA comunication. Well failed a TIFL. Leaking gas Gff valve was replaced and a plug set in the tubing tail ,'~1ETT was performed to verify tubing integrity. ~- ~.~C, ~;;,~~ i~L.n `~- ~;~1:% JAN ~ ~ 20~ . _ _ ,... Wednesday, December 26, 2007 Page 1 of 1 3M-17 (PTD 187054) Failed TIF Page 1 of 1 Re , James B DOA • J9 ~ ) From: Regg, James B (DOA) Sent: Tuesday, December 04, 2007 1:53 PM !, ~z~~ld~ To: 'NSK Problem Well Supv'; Maunder, Thomas E (DOA) i~~~ Cc: NSK Well Integrity Proj Subject: RE: 3M-17 (PTD 187054) Failed TIFL Brent - Just to be clear, the well must remain shut in until repaired. Conservation Order 494 requires such when the annulus pressure exceeds 45°I° of the casing's burst rating. I show the 2250 psi as 45.2% (MIYP of casing - 7" J55, 26ppf - is 4980 psi). A sundry application for the repairs, as stated in CO 494, will not be required for replacing a GLV. Contact Tom Maunder regarding sundry requirements for any other repair work on KRU 3M-17. Regardless, we will be looking for mechanical integrity testing to verify the completion of repairs. The Commission Inspectors should be contacted to witness pressure tests. Jim Regg Aoocc 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Monday, December 03, 2007 1:22 PM To: Maunder, Thomas E (DOA); Regg, James 8 (DOA) Cc: NSK Welf Integrity Proj; NSK Problem Well Supv Subject: 3M-17 (PTD 187054) Failed TIFL Tom & Jim, Kuparuk gas lifted producer 3M-17 (PTD 187054) failed a TIFL on 12/02/07 and was added to the weekly SCP report. The TIO prior to the TIFL was 1950/2250/750. The well had already been shut in prior to the TIFL. A leaking GLV is suspected. Slickline will trouble shoot the tubing leak and repair if possible. Attached is a schematic and a 90 day TIO plot. Please let me know if you have any questions. «3M-17 schematic.pdf» «3M-17 90 day TIO plot.jpg» Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager (907) 659-7000 pgr. 909 ~. ~~~ ; ~} ~ !~~r ~ ~5 ~c 1~ fl, 12/4/2007 ,- ~ ` KRU 3M-17 Cora4cc~~hli~ps A~ask,a, inc. .,. 3M-17 __ - --_~ _ API: 500292172900 Well T e: PROD An le ~ TS: _ 31i de dt ts394 r SSSV Type: TRDP Orig 7/2/1987 Angle @ TD: 36 deg @ 8713 sssv , ; ~ Com etion: (1a21-1a22, ~ Annular Fluid: Last W/O: Rev Reason: TAG FILL oD:z.a75) I Reference L Ref Lo Date: Last U date: 4/2/2005 ~ `~ Last Ta :8423 ~ L t T D t 3/30/2005 TD: 8713 ftK6 7 2(100 M H I A t 50 l r r Gas Lift MandrelNalve 1 (2778-z77s, Gas Lift MandrelNalve 2 (asso~asl, Gas Lift 3ndrelroummy Valva 3 (5938-5939, OD:4.750) Gas Lift MandrelNalve 4 (6432F>433, Gas Lift andrelroummy Valve 5 (6893894, OD:4.750) Gas Lift MandrelNalve s (7388-7389, Gas Lift MandrelNalve 7 pa16-7a17, Gas Lift andrel/Dummy Valve 8 (8244-8245, OD:5.500) SBR (8292-8293, OD:2.875) PKR (8309-8310, OD:6.151) NIP (8327-8328, OD:2.875) TUBING (0-8339, OD:2.875, ID:2.441) ~.~ F>{[{[ F ` I ~~ - l I f f .E !,:~ ~', i i jj ~~. ~„,1 -'i as aq a e. _ _ ax o e ng e. eq n Casing Siring -ALL STRINGS Descri lion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 115 115 62.50 H-40 SUR. CASING 9.625 0 4327 3363 36.00 J-55 PROD. CASING - 7.000 0 8683 6524 - 26.00 .I-55 - Tubin Stnn TUBING ~ - -. - Size ~ Top ~ Bottom _ ~ TVD i _ _ _ Wt ~ Grade ~ , Thread _ 2 875 y 0 I - - ___ _ °,',`~ 6247 _ _ 6.50 ~ J 55 ~ E - UE ;P[ ~ '~B MOD I Perfarations_ Summar~+ - _ Interval T TVD - I Zone - Statu - s ~ Ft_~SP~ _ Date T Typed - Comment --- - 8414 8444 6:~i, 6331 A-1 - 0~ 12 1 9/4/1987 ~IPERF S'H~r - - ; 1;'0 1~~1.phasing IC;ac Lift Manrlrelc,'~.'alvPC -- - - - - St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2778 2314 cMurra FMHO GLV 1.0 BK-2 0.125 1331 8/23/2003 2 4860 3731 cMurra FMHO GLV 1.0 BK-2 0.156 1355 8/23/2003 3 5938 4469 cMurra FMHO DMY 1.0 BK-2 0.000 0 9/4/1987 4 6432 4810 cMurra FMHO GLV 1.0 BK-2 0.188 1377 8/23/2003 5 6893 5136 cMurra FMHO DMY 1.0 BK-2 0.000 0 9/4/1987 6 7388 5503 cMurra FMHO GLV 1.0 BK-2 0.188 1362 8/23/2003 7 7816 5834 cMurra FMHO OV 1.0 BK-2 0.188 0 8/22/2003 8 _ 8244 6171 cMurra Other~plu~s, equ~., et De th TVD T e FMHO c.} -JEWELRY bMY _ 1.5 RK _ Descri lion 0.000 _ _ 0 11115/199. ID 1821 1684 SSSV Camco'TRDP-IA-SSA' 2.312 8292 6209 SBR Camco'OEJ' 2.313 8309 6223 PKR Camco'HRP-I-SP' 2.347 8327 6237 NIP Camco'D' Ni le NO GO 2.250 8339 6247 SOS Camco 2.441 8339 6247 TTL 2.441 'Fish -FISH _ ~ Depth _ D_e_scription _ C_om_ment_ 8402 i 1" GLV i Empt~r PocketFell to R_athole .General Notes Perf (8414-8444) MICROFILMED 9/28/00 DO NOT PLACE ANy NEW MATE~AL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIb~51ON REPORT OF SUNDRY WELL OPERATIONS ORIGIhlAL 1. Operation Performed: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging 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 Exploratory Stratigraphic Service Location of well at surface 881' FNL, 1569' FEL, Sec. 25, T13N, R8E, UM At top of productive interval 1357' FSL, 1865' FWL, Sec. 24, T13N, R8E, UM At effective depth 1252' FSL, 1806' FWL, Sec. 24, T13N, R8E, UM At total depth 1191' FSL, 1769' FWL, Sec. 24, T13N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 8713' 6547' feet feet 6. Datum elevation (DF or KB) 64' RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3M-17 9. Permit number/approval number 87-54 10. APl number 50-029-2172~) 11. Field/Pool Kuparuk River Field/ Kuparuk River Oil Pool Plugs (measured) None Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length 80' 4291' 8649' 7" measured 8414'-8444' true vertical 6306'-6331' 8592' 6450' Size 16" 9 5/8" feet Junk (measured) None feet Cemented Measured depth 203 sx CS II 1 1 5' 1500 sx AS III & 4328' 400 sx Class G True vertical depth 115' 3379' 300 sx Class G & 8683' 6553' Tubing (size, grade, and measured depth) 2-7/8", J-55 tbg w tail @ 8339' Packers and SSSV (type and measured depth) HRP-I-SP pkr @ 8309' & TRDP-1A-SSA SSSV @ 1821' 13. Stimulation or cement squeeze summary See attached well report Alaska Oil & Gas Cons. Commission Anchorage Intervals treated (measured) See attached well report Treatment description including volumes used and final pressure See attached well report 14. Pressure Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure 378 130 -0- 1120 1 1 1 2 706 -0- 1200 Tubing 130 126 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector Oil X Gas Suspended Service 17. I her.~~certify that the foregoing is true and correct to the best of my knowledge. Si~ined 'i ~~ (~. ~ Title Seni0r Operations Engineer Form 10-404 Rev 09/12/90 Date SUBMIT IN DUPLICATE ARCO Alaska, I.r,~.. ~ · Subsidiary of Atlantic Ricr~field C, REMARKS WELL SERVICE REPOR' FIELD- DISTRICT- STATE II It I/ /I ~ 7 /£15 - - ' ~ ~ ~ -gv .) )~ ' Alaska OJ! & 6~s Cons. Comm!snion ~ Anchorage ~ C~THIS BLOCK I¢ suMMA&Y CONTINUED O~BACK Re~ °F =FI miles knots 3H-01 3B-13 I E-29 1C-05 3M-17 2Z-20 30-10 31-12 3H-10 Kupaurk Kupaurk Kupaurk Kupaurk Kupaurk Kupaurk Kupaurk Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Kupaurk Fluid Level Report BHP Report 2-15-89 Casing 2-17-89 Casing 2-15-89 Casing 2-1 8-89 Casing/Tubing 2-16-89 Casing 2-18-89 Tubing 2-16-89 Casing 2-20-89 Tubing 2-13-89 BHP Receipt Acknowledged: --- Date: ............ DISTRIBUTION: D&M State of Alaska · ._ .. . SAPC Unocal Mobil Chevron ARCO Alaska, inc. Date: February 23, 1989 Transmittal #: 7432 RETURN TO: Transmitted herewith are the following items. one signed copy of this transmittal. 3F-15 3N-18 3F-01 3F-02 3F-09 3F-06 3F-10 3F-11 3F-15 3F-14 3N-10 3N-06 3N-09 31-01 3N-11 3N-14 3F-08 3N-01 3N-14 3F-15 3F~15 3F-13 3F-15 1B-05 1E-25 3B-11 3A-03 3H-01 2Z-1 9 31-12 1E-08 3M-18 ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Please acknowledge receipt and return Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kuparuk Well Pressure Report Kuparuk Well Pressure Report Bottom-Hole Pressure Survey Kuapruk Well Pressure Report Kuparuk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report 12-03-87 12-18-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 5-18-87 5-22-87 5-21-87 4-24-87 4-15-87 4-13-87 4-14-87 4-20-87 12-04-87 2-O2-89 8-27-87 8-27-87 8-25-87 2-20-89 2-19-89 2-20-89 2-21-89 2-21-89 2-20-89 2-2O-89 2-19-89 2-15-89 Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing 'Casing Casing Casing Casing Casing Casing Casing Tubing Sand 'C' Sand 'C' ~7°ra9e rnr~issio~, BHP ~~ Amerada Casing Casing ~ Casing [ I Tubing ~~ Tubin~ Casin~~ ~ Casin~ STATE Of ALASKA ~ ALASKA OIL AND GAS CONSERVATIONCOMMISSION Q ~ WELL COMPLETION OR RECOMPLETION REPORT AND LO 1. Status of Well Classification of Service Well OIL ]~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number AEC0 A1 aska, Inc. 87-54 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21729 4. Location of well at surface 9. Unit or Lease Name 881' FNL, 1569' FEL, Sec.25, T13N, R8E, UN Kuparuk River Unit At Top Producing Interval 101 Well Number 1387' FNL, 1865' FWL, 5ec.24, T13N, R8E, UN 3N-17 At Total Depth 11. Field and Pool 1191' FNL, 1769' FWL, 5ec.24, T13N, R8E, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 64'I ADL 25522 ALK 2558 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 06/26/87 07/01/87 10/20/87'I N/A feet MS LI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set 121.Thickness of Permafr°st 8713'ND, 6547'TVD 8592'MD, 6450'TVD YES EX NO [] 1821 ' feet MD 1600' (approx) 22. Type Electric or Other Logs Run DIL/SP/GR/SFL, FDC/CNL, Ca1, CBL/CCL/GR, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSIZE!WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED lb" 62.5# H-40 Surf 115' 24" 203 sx CS Ii 9-5/8" 36.0// J-55 Surf 4328' 12-1/4" 1500 sx CS Ill & 400 s; Class G 7" 26.0# J-55 Surf 8683' 8-1/2" 300 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Perforated w/12 spf, 120° phasing 2-7/8" 8339' 8309' 8414 '-8444 'MD 6306 ' -6331 'TVD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached Adden,lum~ dated 10/21/87, for fracture · . 27. N/A PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) I ' Date of Test Hours TeSted PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-'OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None R'ECEI EI) NOV 16.~/ '- /:Jaska 011 & Gas Cons. C0mmissi0:~ *Note: Drilled RR 7/2/87. Perforated well & ran tubing 9/5/87. Fractured well 10/20/87,Anch°rage WC~/IO1 :DAN I Submit in duplicate Form 10-407 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 8395' 6291' N/A Base Kuparuk C 8412' 6304' Top Kuparuk A 8412' 6304, , Base Kuparuk A 8466' 6348' , , 31. LIST OF ATTACHMENTS Addendum (dated 10/21/87) , , 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~~~.~ _ TitleAsSOciate Engineel' 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 8/05/87 10/20/87 3M-17 Rn 3B/GR to 8500'. Rn CBL/CCL/GR f/8564'-6200'. Rn gyro to 8500'. Frac Kuparuk A-1 zone perfs 8414'-8444' in ten stages per revised procedure dated 10/19/87 as follows: Stage 1: 100 bbls gelled diesel @ 8-20 BPM, 3600-4082 psi Stage 2: 450 bbls gelled diesel @ 20.1-20.2 BPM, 4400-4150 psi Stage 3: 50 bbls gelled diesel 2 ppg 20/40 sand @ 20.1 BPM, 4150-4491 psi Stage 4: 50 bbls gelled diesel 4 ppg 20/40 sand @ 19.9 BPM, 4650-5083 psi Stage 5: 50 bbls gelled diesel 6 ppg 20/40 sand @ i9.7 BPM, 5120-5300 psi Stage 6: 50 bbls gelled diesel 7 ppg 20/40 sand @ 19.7 BPM, 5395-5600 psi Stage 7: 50 bbls gelled diesel 8 ppg 20/40 sand @ 19.7 B?M, 5500-5550 psi Stage 8: 40 bbls gelled diesel 9 ppg 20/40 sand @ 20 B?M, 5785-5900 psi stage 9: 40 bbls gelled diesel 10 ppg 20/40 sand @ 20 BPM, 6160-5700 psi Stage 10:48.6 bbls gelled diesel flush @ 15.3-20 BPM, 5700-6267 psi Fluid to Recover: Sand in Zone: Sand in Csg: Avg Pressure: 833 bbls 64,409# 144# 5300 psi Drilling Super~s~r RE£EIIED NOV ].6~f ,:,iaska 011 & Gas Corm. Commissi'-:~ Anchorage / Da~e ' ADDENDUM WELL: 1119188 3M-17 RU hot oil unit. RIH, start pmp'g @ 700' w/1.4 BPM, 1400 psi. Continue in hole to 8400'. RIH to 8592', circ @ 1.7 BPM, 3800 psi. Made 2 passes to 8592'; no indication of fill in perfs. Fill indication @ 8582'. Pmp 178 bbls gelled diesel & 57 bbls diesel. Secure well. ~r~ng Supervi~ ~RV :< E Y I DEPTH I iF F:' Ii f IF:'F:'TH DEE I*i £" I iE'GREE>Z': 1 ~1~00 1082, 32 1 ]29, zS. 23 1220,, 69 J. 517. Y/ J 45:3, '77 600 700 75() '-' :' '~ ' 36 zlu 7. 17 W 4i ) F:'] 20 ,, :i;() W 4400 AilC:it f-::T 7, I'oOU FIELD ALI G U '.~; T :Al. VERT{ .,A[ INCL INAT'];CIN : I FU:£CT I0 DEl}RE ES - z? I:::EE'1 AT' NORTH F I El_ D Al '}L(~T 7 i'NTERPO~T£D ~ALLES FC'd~ EVEN EEF] 0 1000 lB-SEA b~E'RT I IDA/. REC] ANGLll i'~l::~ I: I TH NORTH/' 2000 0 0 l :=',( ~3 I I. 72 ? 5S; ~ !:.Sq 2'.F:9'5.54 J ?::33~ ~ 60 B82. C 3827, 22 3763 4.5~ ~ 25 :i4.47.25 3398, :2.'.~ N i 52i0, 7e, 514&. 76 4.0zI, 2. l:N~: CALCLLAT"£ "!N F'i~UCFEDU-<E!.~ ¢=lhE Bm,:,EL ON THE :=;E OF MEASUREO VEI:t F I ( 0 64 4,4 ,, O0 164 364. 868 973 1414 1564 O0 VEiF;,'T' I C:AI_ RE]2TAN(]I II Pu~ i (IORO INATE~--- F Ii.:'F'T H t',lr iRq H z 7;I'll i i! -I "'r,T / cJE,-c'T -,c, 4,00 o ~ OD ,:~.x }0 n~ ::',>: c O. 22 W ':u"i L) ,. '._~ l 0.30 W :,t)L) ,, O0 1 ~ 8:3 (., ~(j P7, fl':) 4.26 E J OUO. OO ~ ].'P~ ;! 0 N :200~ O0 ;204.~ T 5 400 ....... 325.67 N J. 9¢. .00 1700 F I ELD : i;F:'E;Fd:;~ Y- SI .U'i WE:I! 1[ N Fd. IE I.J8 k} E] 7( '1' i f'i iTg g, EFx I I _>,~1 MEASURED 1964,00 234,4. { )o 2,1x xl . O0 ] {iT REIi ]'ANGI I1 ~ - RTH ,." '. 690.06 798.63 N ] O10,, :lc 230 ~ 18 S38 ,, 2'7 3:306 /::'/.Ad E~453 2900. O0 4183 :,.-:.,:. 4329 4474 5:4(5:,,:], i.~,~ 400 00 2056.82 * '::'2,'L,C). 1:: ;;::3(!:,0. :: 1 .zdeU. }C z-{-,;,,, I ":, N (OORD 11NA E{ A E; 'T' / I E, 47.5 681. 10 71 SPEF;.'R Y- S;UN WElt. H;'LPAR_K FIEt B SUB-SEA T'Q TAL _K T ] _.I,4L FiE]D]-#' ,iFil 1[ I"IFF'TH N()tRT H/'.E;F f'AS;T/MEST 54S9 · ] ,q 5784 436 5~3J 4464. 607;:: ,z.7¢ I 506.4 4200.00 ',3153.5~ /i 2~0() ~ O0 325:3. :1:2 ¢14t (). O0 '3352.20 a;::;QO. O0 3734 60 382:3 ~ 25 4 (x:',:::~. /l 1434.26 416(::,. 55>., [475~'~ :.:.'i;F'E RRY.-t~i;IIN (gEL [ FZELD i:~t. IC:iLI:E;T 7. MEA~.UF;ED VF: F:,: i- I ~-' VERT IC:AL REL:] AiWu ,~.~ : OORDINAT [. EF 1H B~.::P DF F'TH N -' RTH/:::; ] '~ 1- .~oT/WE~ 7726 5764. (: ( 5700.00 4~56.01 N I E[...D ALtOI. k~ T 7, MEASURED DEPT~.I 5 8550 TIE'LiE ./:, ?, O -q. 5:; JB-~BEA VERTICAL DE'PT'H Fi~ECTANr:ii. [ AF,~ I '~]KIRDINA' NOF~TH/?FiU]-F~ EAST/WEST /-, '::v. _~1.9 4(:',1 /. 7 628~,.04 ~0~5. lA N 1067. 6::::05.8~ 4909.08, N ~:,4 :~:.5', ~ 49 4970.4~5 TOP KLIPARL T 0 T -[000 30 .ObO. 06 4500. O0 7500. O0 YERT I CFtL PROJECTION ARCO Alaska, In(- Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: October 12, 1987 Transmittal #: 6082 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. 3M-17 Kuparuk Well Pressure Report (Otis) 9-23-87 3M-21- Kuparuk Well Pressure Report (Otis) 9-24-87 2C-3 Kuparuk Well Pressure Report (Otis) 9-28-87 lA-10 Kuparuk Well Pressure Report (Camco) 10-1-87 lA-2 Kuparuk Well Pressure Report (Otis) 10-1-87 Static Static PBU 'A' Sand Receipt Acknowledged: DISTRIBUTION: D&M State of Alaska BPAE Chevron Mobil SAPC Unocal ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Ir~ Post Office dox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: October 2, 1987 Transmittal #:6074 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. 3M-17 Kuparuk Well Pressure ~port (Otis) 9-13-87 ~-20 Kuparuk Well Pressure Report (Otis) 9-15-87 3M-21 Kuparuk Well Pressure Report (Otis) 9-17-87 3M-22 Kuparuk Well Pressure Report (Otis) 9-16-87 1R-1 Kuparuk Fluid Level Report 8-22-87 1R-2 Kuparuk Fluid Level Report' 8-22-87 1R-4 Kuparuk Well Pressure Report(Otis) 8-23-87 1R-6 Kuparuk Well Pressure Report (Camco) 8-23-87 1R-8 Kuparuk Fluid Level Report 8-22-87 1R-11 Kuparuk Well Pressure ~port(Otis) 8-23-87 1R-13 Kuparuk Well Pressure Report (Otis) 8-22-87 1R-14 Kuparuk Well Pressure Report ~tis) 8-21-87 1R-16 Kuparuk Fluid Level Report 8-22-87 Static Static Static 'A' Sand Static 'C' Sand 'C' Sand 'C' Sand Static Receipt Acknowledged: DISTRIBUTION: gJaska oil ~ :Cons, Commi~ion Anchorage D&M BPAE Chevron Mobil SAPC Unocal ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STAT E O F A'LAS KA ALASi",A OIL AND GAS CONSERVATION COIv,,v, iSSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] COHPLETE Alter Casing [] Other~ Perforate ,~ Pull tubing 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 881' FNL, 1569' FEL, Sec.25, T13N, R8E, UM At top of productive interval 1357' FNL, 1865' FWL, Sec.24, T13N, R8E, UH 5. Datum elevation (DF or KB) RKB 64 ' 6. Unit or Property name Kuparuk River Unit 7. Well number 3M-17 8. Approval number 7-480 9. APl number 50-- 029-21729 At effective depth 1252' FNL, 1806' FWL, Sec.24, T13N, At total depth 1191' FNL¢ 1769' FWL¢ Sec.2% T13N~ 11. Present well condition summary Total depth: measured 8713 true vertical 6547 R8E, UM R8E~ UM 10. Pool Kuparuk River Oil Pool 'MD ' TVD feet feet Plugs (measured) None Feet Effective depth: measured 8592 'MD true vertical 6450 ' TVD feet feet Junk (measured) None Casing Length Size Conductor 80 ' 16" Surface 4291 ' 9-5/8" Pr oducti on 8649 ' 7" Cemented Measured depth 203 sx CS II 115'MD 1500 sx CS III & 4328'MD 400 sx Class G 300 sx Class G 8683'MD Rue Vertical depth 115'TVD 3379'TVD 6553'TVD Perforation depth: measured true vertical 8414 ' -8444 ' MD 6306 ' -6331 'TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tubing w/tail ~ 8339' Packers and SSSV (type and measured depth) HRP-1-SP pkr @ 8309' & TRDP-1A-SSA SSSV ~ 1821' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Well Hist~C'y) Daily Report of Well Operations L~ Copies of Logs and Surveys Run ~ Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '~,~/~/~~~ Title Associate Engineer Form 10-404 Rev. 12.1-85 J" - (Dani) SW02/85 Date ~ Duplicate(~ Submit in ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data Jn blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ICounty or Parish Lease or Unit Title J Accounting cost center code State Alaska I'Wal, §~_ 17 Field Alaska Kuparuk River North Slope Borough ADL 25522 Auth. or W.O. no. AFE AK2173 Completion Nordic #1 API 50-029-21730 Operator ARCO Alaska, Inc. Spudded or W,O. begun Complete A.R.Co. w~.6.24% Date 9/4/87 TacOtal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well / 0730 hrs'lH°ur IPri°r status if a w'O' Date and depth as of 8:00 a.m. 9/o8/87 Complete record for each day reported Old TD J New TO Released rig I Date 0800 hrs. Classifications (oil, gas, etc.) O±1 Producing method 7" @ 8683' 8592' PBTD, RR 7.0 ppg diesel Accept rig @ 0730 hfs,'9/4/87. ND tree, NU & tst BOPE. RIH, Perf well f/8414'-8444' @ 12 SPF. Make GR/JB rn to 8500'. RU & rn 252 its, 2-7/8", 6.5#, J-55 8RD AB-Mod tbg w/SSSV @ 1821', HRP-1-SP Pkr @ 8309', TT @ 8339'. Tst compl string. ND BOPE, NU & tst tree. Displ well to diesel. RR @ 0800 hfs, 9/5/87. 9/5/87 ~o~a~y Type completion (single, dual, etc,) J Single ~ Official reservoir name(s} [ Kuparuk Sands Flowing Potential test data Well no, Date Reservoir Producing Interval Oil or gasTest time Production Oil on t~'~t ' Gas per day , , , Pump size, SPM X length . Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected Drilling, Pages 86 and 87. AR3B-459-3-C · INumber all daily well history forms consecutively as they are preparea for each well. iPage no. Dlvlllon of AtlantlcRichfieldCc, mpany ARCO Alaska, Ir~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: September 10, 1987 Transmittal #6051 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. 3M-15 Cement Bond Log 8-3-87 5381-7397 3M-17 Cement Bond Log' 8-5-87 6200-8564 3M-19 Cement Bond Log 8-10-87 6500-8794 3M-22 Cement Bond Log 8-12-87 7890-9598 3M-18 Cement Bond Log 8-21-87 7689-8410 3M-14 Cement Bond Log 8-2-87 4903-7108 3M-13 Cement Bond Log 8-3-87 7495-9559 3M-20 Cement Bond Log 9-1-87 8700-10687 3M-11 Cement Bond Log 8-1-87 5252-7802 3M-16 Cement Bond Log 8-4-87 -7834 3M-lO Cement Bond Log 8-9-87 4700-7039 3M-12 Cement Bond Log(Coiled Tubing Conveyed) 8-12, 13-87 7403-10380 Receipt Acknowledged: DISTRIBUTION: NSK Drt~~ State of Alaska(+sepia) Vault(film) ARCO Alaska, Inc. Is a Subsidiary of AllanticRichfleldCompany STATE OF ALASKA '~ ALA,_.,A OIL AND GAS CONSERVATION CON,.,,~SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown ~ Re-enter suspended well [] Alter casing .E: Time extension ~ Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order ~ Perforate C Other 2. Name of Operator ARCO Alaska, Inc 3. Address P. O. Box 100360 Anchorage, AK 9951 0-0360 4. Location of well at surface 881 ' FNL, 1569' FEL, Sec.25, At top of productive interval T13N, R8E, UM 5. Datum elevation (DF or KB) RKB 64 ' 6. Unit or Property name Kuparuk River Unit 7. Well number 3M-17 8. Permit number feet 1397' FNL, 1878' At effective depth 1278' FNL, 1817' At total depth 1216' FNL, 1780' 11. Present well condition summary Total depth: measured true vertical FWL, Sec.24, T13N, R8E, UM (approx) FWL, Sec.24, T13N, R8E, UM (approx) FWL, Sec.24, T13N, R8E~ UM (approx) 9. APl number 50-- 029-7177q 10. Pool Kuparuk River Oil Pool 871 3 ' MD feet Plugs (measured) 6578 ' TVD feet None Effective depth: measured true vertical 8592 ' MD feet Junk (measured) feet 6481 ' TVD Casing Length Size Conductor 80' 1'6" Surface 4291' 9-5/8" Production 8649' 7" None Cemented 203 sx CS II 1500 sx CS III 400 sx Class G 300 sx Class G Measured depth llS'MD 4328'MD 8683'MD ~ue Verticaldepth 115'TVD 3379'TVD 6553'TVD Perforation depth: measured No ne true vertical None ~bing(size, grade and measured depth) None Packers and SSSV(type and measured depth) None 12.Attachments WELL HISTORY Description summary of proposal [] Detailed operations program [] BOP sketch 13. Estimated date for commencing operation August, 1987 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 C/~ ~ J~J.L~ Title As soo ia te E ngin ~r Conditions of approval Date Commission Use Only ([~ani) SA2/7? commission witness No. Notify so representative may Approval [] Plug integrity [] BOP Test [] Location clearance ................ . by order of Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Oil and Gas Companyv"~ 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 su~hmarized on the form giving inclusive dates only, District Alaska Field Kuparuk River Auth. or W.O. no. AFE AK2181 Doyon 9 ICounty, parish or borough North Slope Borough JLease or Unit ADL 25522 ITitle Drill IState Alaska jWell no. 3M-17 APl 50-029-21730 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m. 6/26/87 6/27/87 thru 6/29/87 6/30/87 Date 6/26/87 Complete record for each day reported ARCO W.I. JHour 0130 hrs. Ipri°r statue 56.24% if a W.O. 16" @ 115' 807', (692'), Drlg Wt. 9.1, PV 13, YP 28, PH 9.0, WL 13.2, Sol 6 Accept rig @ 2400 hrs, 6/26/87. NU diverter sys. Spud well @ 0130 hfs, 6/26/87. Drl surf hole to 807'. 9-5/8" @ 432~ 7100', (6293')~ Drlg Wt. 9.3, PV 7, YP 3, PH 9.0, WL 6.4, Sol 7 Drl & surv to 4351', short trip, CPU, POOH, LD DP. Rn 103 its, 9-5/8", 36#, J-55 BTC csg w/FC @ 4237', FS @ 4328'. Cmt w/1500 sx CS III & 400 sx C1 "G" w/2% A-7, 2 GHS D-66. Displ using rig pmp, bump plug . ND diverter. NU POPE & tst POPE. DO cmt & float equip + 10' new hole. Conduct formation tst to 12.5 ppg EMW. Drl to 7100'. 641', 5.8°, N 9.2E, 640..77TVD, 7.95VS, 9.09N, 1.47E 1189', 22.9D, Nll.SW, l165.86TVD, 141.66VS, 157.03N, 13.58E 1755', 42.1°, N21.2W, 1640.18TVD, 444.14VS, 452.14N, 61.78W 2468', 48.3~, N18.1W, 2120.63TVD, 970.64VS, 945.90N, 244.68W 3602', 46.3~, N17.6W, 2882.29TVD, 1810.13VS, 1740.56N, 517.17W 4251', 46.8~, N18.7W, 3326.13TVD, 2282.64VS, 2192.56N, 658.27W 4834', 46.2°, N18.gw, 3727.44TVD, 2705.21VS, 2592.89N, 794.55W 6535', 44.6", N26.7W, 4896.05TVD, 3940.22VS, 3735.98N, 1262.84W 9-5/8" @ 432~' 8372', (1272'), Drl Wt. 10.0, PV 19, YP 12, PH 8.0, WL 3.8, Sol 12 Drl to 8372'. 7132', 40.4°, N26.9W, 5336.20 TVD, 4341.52 VS, 4095.98, 1444.69 8168', 37.3D, N31.5W, 6140.68 TVD, 4987.75 VS, 4666.76, 1760.71 The above is correct Signature see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting District ICounty or Parish lState Alaska I North Slope Borough Field Lease or Unit Kuparuk River ADL 25522 Auth. or W.O. no. JTitle AFE AK2181 I Drill Doyon 9 API 50-029-21729 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m. Old TD 7/01/87 7/02/87 Released rig 0530 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing A.R.Co. W.I. 56.24% Date 6/26/87 Complete record for each day reported cost center code Alaska IWell no, 3M-17 Iotal number of wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well I our ~Prior status if a W.O, I 0130 hrs. 9-5/8" @ 432~' 8705', (333'), Rm to btm Wt. 10.0, PV 20, YP 14, PH 9.0, WL 4.4, Sol 11 Drl to 8705', short trip to 6785', CBU, POH. RU Schl, rn DIL/GR/SP/SFL/CAL f/8698' - 4325' WLM, FDC/CNL f/8698'-8150' WLM & 6600'-6400' WLM. RD Schl. Rm 8468'-8705'. 8600', 36.1°, N31.SW, 6487.34 TVD, 5241.51VS, 4886.53, 1896.18 7" @ 8683' 8713' TD, 8592' PBTD, RR 10.1 ppg Brine Rm to 8705', drl to 8713', C&C, POOH, LD DP. RU & rn 202 jts, 7", 26#, J-55 BTC csg & mkr jt w/FC @ 8592', FS @ 8683', Mkr Jt @ 8298'. Cmt w/100 sx Cl "G" w/2% A-2, 1% R-7 & 2 GHS F?-6L & 200 sx C1 "G" w/l% FL-19, .5% CD-31, .3% A-2 & 1GHS FP-6L. Displ w/brine. ND BOPE. Instl upper packoff & tree. Tst tree; OK. RR @ 0530 hrs, 7/2/87. Move rig to 3M-20. New TD Date 8713' TD IiPB Depth IKind of rig 7/2/87 I IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands 8592' PBTD Rotary 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 above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ARCO Alaska, Inc. Post Office' 100360 Anchorage, ,-,~aska 99510-0360 Telephone 907 276 1215 Date:July 22, 1987 Transmittal #6005 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. V~3M-20 5" DIL 7-9-87 974-11068 '~3M-20 Cyberlook 7-9-87 10200-10670 '='3M-20 2" DIL 7-9-87 974-10776 --3M-20 2" Porosity FDC 7-9-87 10200-10750 '-3M-20, 2" Raw Data FDC 7-9-87 10200-10750 ~"3M-20 5" Raw (+1.2") FDC 7-9-87 10200-110420 ~20 5" Porosity FDC 7-9-87 10200-11042 ~]M-16 5" Porosity FDC 7-11-87 6000-7916 --3M-16 Cyberlook 7-11-87 7350-7870 --3M-16 2" Raw Data FDC 7-11-87 6000-7916 ---3M-16 5" Raw Data FDC 7-11-87 6000-7916 __C~-~--3M-16~'~ 5" Dual Dipmeter 7-11-87 7350-7936 --3M-16 High Resolution FDC 7-11-87 6000-7916 ---3M-16 5" DIL 7-11-87 1000-7942 --3M-16 2" Porosity FDC 7-11-87 6000-7916 -- 3M-16 2" DIL 7-11-87 1000-7942 ~ 2" DIL 6-24-87 1000-8510~ -~3M-18 5" Raw Data FDC 6-24-87 4800-8484 ~,--3M-18' 2" Porosity FDC 6-24-87 4800-8484 --3M-18 Cyberlook 6-24-87 8000-8440 --3M-18 5" DIL 6-24-87 1000-8510 ---3M-18 5" Porosity FDC 6-24-87 4800-8484 -- 3M-18 2" Raw Data FDC 6-24-87 4800-8484 ~-17 Cyberlook 6-30-87 ~i~--3M-17 2" Raw Data FDC 6-30-87 8150-8666 ~-3M-17 2" Porosity FDC 6-30-87 ~ ~/'O ~.~81~0-~66~ -~-3M-17 5" Raw Data FDC 6-30-87 /]RL~i~$~6~ Receipt Acknowledged: ' Date: DISTRIBUTION: (~~0]l&AnchoragoCasC°ns'O°mmissi°n' NSK Drilling Rathmell D & M State of Alaska (+sepia) Vault(film) ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfieldCompany ARCO Alaska, Inc..---~ Post Offic/ .; 100360 Anchorag~ ,laska 99510-0360 Telephone 907 276 1215 Date: July 22, 1987 Transmittal #6005 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. ~--'3M-17A, 5" Dual Induction 6-30-87 4325-8692 ~---~M-17 2" Dual Induction 6-30-87 4325-8692 4~-3M-15 2" Dual Induction 6-19-87 3488-7590 ---3M-15 2" Raw Data FDC 6-19-87 3488-7564 ~_~--3M-15 5" Raw Data FDC 6-19-87 3488-7564 '--3M-15 5" Porosity FDC 6-19-87 3488-7564 '~-~3M-15 2" Porosity FDC 6-19-87 3488-7564 ~-3M-15 5" Dual Induction 6-19-87 3488-7590 ---3M-15 Cyberlook 6-19-87 Receipt Acknowledged: DISTRIBUTION: NSK Drilling State of Alaska(+ sepia) Vault (.film) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Offic/''~ 100360 Anchorage..-~laska 99510-0360 Telephone 907 276 1215 Date: July 22, 1987 Transmittal # 6003 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 ~ransmitted herewith are the following items. Please acknowledge .receipt and retur~ one signed copy of this transmittal. 3M-15 OH Lis Tapes 6-19-87 #72365 3M-16 OH Lis Tapes 6'11-87 #72361 3M-13 OH Lis Tapes 5-28=87 #72348 3M-17 OH Lis Tapes 6-30-87 #72405 3M-18 OH Lis Tapes 6-24-87 #72375 3M-14 OH Lis Tapes 6-4-87 #72353 3M-12 OH Lis Tapes 5-21-87 #72329 Receipt Acknowledged: DISTRIBUTION: M. Stanford · :i~:"S t a t ~" '::Of" iAlaska'' :, ARCO Alaska, Inc. is a Subsidiary ol AllanlicRichfieldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 29, 1987 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 3M Pad (Wells 1-22) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/pk GRU1/31 Enclosure Anchoraga ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 2.ALL DISTANCES SHOWN ARE TRUE. ALL WELLS LOCATED IN SEC. 25, TI3N, R8E, UMIAT MERIDIAN. $.ELEVATION$ ARE B.P.M.$.L. 4.REF. FIELO BOOK LeT-3, Pgk 7-I~.; L97-1, R 7; L 87-3,P 51- 53; ASPs 'X' ,202.17 6,016,225.10 6,016,246 6,016,271 . 24 6,016,294. 6,016,317.42 6,016,340.48 6,016,563.49 6,016,386.92 6,016,456.13 6,016,479 6,016,502.26 6,016,525.51 6,016,548.62 6,016,571.43 6,016,59 4.75 6,016,61 ?~99 !6,016,641.02 306, 506,136.45 506,145.98 506,155.57 506,165.07 506,174.63 5.0.6. ELEVATIONS FROM F.R. BELL & diSSOCIATES. o. ,. i i) MONUMENTS PER LHD Bi ASSOCIATES. ~I~ r) '? 1~37 306,184.13 506,193.52 506,205.14 506,232.02 506,241.52 506,251.07 506,260.73 506,270.~,0 $06,2'79.77 30~,299.40 306,299.05 506,$08.76 LATITU'I~E LONGITUDE DistEN.L. 70~2 ?'l t.7-~0" 149051'00.000" 1296' 70e 27'20.005"J 149056, 39.72 O'"! 12 T 3' 7 0°27'20.232~ 149°36; 59.439_~ 1250: 70°27' 20.459]149°56 39.157] 1227' 70o27; 20.683~ 149°36*.59,077~ 1204'. 70o27 20.913 149°56 58~96'1 ll91 149*56'30.316'J ll3e~ 149°56' 58.040"[ I 149°56;37.756:l ,! 12' 149°56~36.906~ IC)42', 149°36 56.6~7] I0 19 149°56:36.34.5.'! 996: 149°56 56D6 1 973 I O * I 49 56 55.779' 950' I O ' 49 56 35.501 927' 149°56155.217" 904' 149°56 34.933" 8 81 ' 49°56'54.647' 858' 70°27'21.140" 70027'2 I. 366" 70°27:21 596"' 70°27 22.504 70 27,22.734), 70°27 22.959 ?0°27', 23,186 70°27 23.4 lO' 70°27'23.639 70°27'25.868 ?0027'24.094. 'Dis f. F.E.L. 1741' 1732' 17~2', 1713 1703', 2694 1684~ 16 75 1665', 1636, 16 26 16 I 7~ 1607 1598' 1586' 1578' 1569' 1559' 23.1' 23.2' 23.4 83.4', 83.3 25.2' 23.1' 1.7' 21.5' 81.1' 20.9' 20.9~ 20.9 20.8' ,~d~Eiev. 26.6' 26.6' 26.9; 26.8 86.8', 86.7 26.6' 26.6' 26.4** 26.3, 26.3 26.4: 26.$ 26.4' 26.4' 86.3** 26.5 26.6' ~ 0/~, 17A~ ~P~, 117. ~ 7~'Z7'/~. 65~" /df'57'oo.~6/'~ ! ' /7~/' Z~.O' Z~.Z ' ~o1~ , lY;.77 ~ok, 1~ 7.~3 ~61S~EE~ AND LICENSED TO ~AC- STATE OF ~KA AND T~T THIS PLAT REPRESENTS i ~ATION ~L O ~,s~[,v~s~.~.~ ~.l~cc ~ , ~ut-~ t .~ [ WELL CONDUCT R AS-BUILT DIM~SIONS AND O~ER ~TAILS ARE ~RRECT AS OF '/8/'7 ~ ~~~[ , June 3, 1987 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Te!ecopy: (907) 276-7542 Re: Kuparuk River Unit 3M- 17 ARCO Alaska, Inc. Permit No. 87-54 Sur. Loc. 881'FNL, 1569'FEL, Sec. 25, T13N, R8E, UM. Btmhole Loc. I164'F~, 1788'F~, Sec. 24, T13N, R8E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. =' 1 To aid us in scheduling ~ze d 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. Where 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. C:-V. ~chatfie~tofi Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COM~'fISSION dlf 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 OIL ,.,,ID GAS CONSERVATION CO~vlrv,._SION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~ Redrill I~Il lb. Type of well. Exploratory I~ Stratigraphic Test L3, ,,Development Oil~,~ Re-EntryE~ DeepenE]I Service [] Developement Gas E3 Single Zone/~ Multiple Zone~ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 64', PAD 27' feet Kuparuk River Field Kuparuk River Oil Pool 6~ ~rop~t~esigo~i~ ~ p~.~Jd~%%S 100360 Anchorage, AK 99510-0360 aUL z~zz ~L~ Z~8 4. Location of well at surface 7. Unit or property Name 11. Type Bond (s~ 20 AAC 25.025) 881 'FNL, 1569'FEL, Sec.25, T13N, R8E, UM Kuparuk River Unit Statewide 1 3 9 ¢~ ~ ~f ~u'c¢i~t interval 8~ Well7number Number ~ bec.2~ T13N~ R8E~ UN N-1 ' ¢8088-26-27 At total depth 9~ Approximate spud date Amount 1168~FNL~ 1788~FWL~ Sec.2~ T13N~ R8E~ UN 06/1~/87 $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 3~- 1 6 8727 ~ ND 881'~ Surface feet 25' ~ Surface feet 2560 (6568'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 500 feet Maximum hole angle ~6 o Maximum surface 2008 psig At total depth (TVD) ~ 21 ~ psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5~ H-40 Weld 80' 35' 35' 115' 115' ~200 cf 12-1/4" 9-5/8" 36.0~ J-55 BTC 4164' 35' 35' 4199' ~393' 1500 sx AS I I I & HF-EF',W 400 sx Class G blend 8-1/2" 7" 26.0~ J-55 BTC 8693' 34' 34' 8727' 6568' 200 sx Class G(minimum HF-EF',W TOC 5)0' above tpp 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 Intermediate Production ~.* ,'~',¢ , ]q~? Liner Perforation depth: measured .... ~,,~ ¢'.', ....... ~ .... ~ true vertical /~'~CJ'~::~'~;: ~:~ 20. Attachments Fil~n~ fee~ Property plat' BOPSketch~ DiverterSketch~' Drilling program~' Drilling fluid program~Timevs depth plot ~'Refraction anal~is ~ Seabed repoCt~ 20AAC25.050 r~¢uirements~' 21. I hereby~ that the f~oi~;~ true and correct to the best of my knowledge Signe~ ___~/~~~'~¢¢{,~¢~~__ Title edmonD1 Dr, 11~ng Engineer Date '/ ~ U/ ~ ?- Commission Use Only (HRE) PD2/28 Permit Njmber J J APl number , J Approval date J See cover letter ' ~¢ ~,?-~ J 50-o ~.~t~,L-t 7;~rt I 06/03/87J for other requirements Conditions of approval Samples required ~ Yes '~ No Mud Icg required g Yes ~ No Hydrogen sulfide measures ~ Yes ~ No Directicnal survey required ~ Yes ~ No Required work~?~~ ~M; ~ SM; ~ IOM; ~ 1SM Other: ~ / X ~'~~ by order of ¢~ Approved by ~ Commissioner the commission Date I=nrm ln_~nl Rnv 19-1-RR' i Sub ' icate KUPARUK RIVER UNIT 20' DIVERTER SCHEMATIC L DESCRIPTION 1. 16" CONDUCTOR 2. FMC SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1 / 16" 2000 PSI BALL VALVES 4. 20" 2000 PSi DRILLING SPOOL W/10" OUTLETS S. 1 O" HCR BALL VALVES W/10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 6. 20" 2000 PSI ANNULAR PREVENTER 4 ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25,035(b) MAINTENANCE & OPERATION 2 i . , UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY, CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED, OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES JG I1-3-86 6 DIAGRAM #1 13-5/8" 5000 PSI R,SRRA BOP STACK I. 16' - 2.000 PSI TAI~CO STARTING ~ 2. I1' - 3000 PSI CASZN~ ~ 3. Ii ' - 3000 PSI X 13-5/8' - 5000 PSI 8:~AC~R SPOOL 4. 13--5/8' - 50(X) PSI PIPE RA~B 5. 13-5/8' - 5000 PSI ORILLIN~ SP(X]. W/~ AI~ KILL LI~_S 6. 13-5/8" - 5000 PSI ~ RAM W/PIPE RAMB ON TOP, ACCI~TOR CAPACITY TEST I. Q-ECl( ,el:) Fill ~TC]R ~OIR TO PROPER LEVEl. WITH HY[::RNIIC FLUID. ~ THAT A(::ti. Mi. ATOR ~ IS 3000 PSI WITH 3. ~ TINE, ~ CLOSE AiL UNIT8 SIMLI. TAI~EOIJ~LY ALL UNITS ~ (:LO~I~ WITH ~II~ ~ (:FF. 4. RE~ ON NADC REPORT, TI-[ A~AI~LE LCIII~ LIMIT IS 45 SE~ Cl. ClIINO TINE ~ 12~0 PSI RS~ININO 5 4 3 13-5/8, BOP STACK T~S..T I. FILL B(~ STACX ~ Q-EI(E M~EF(1.D WITH DIESEL. 2. (I-ECl( THAT ALL LO(I( ~ ~ IN _~-!/i.r~ FULLY RETRACTED. :SEAT TEST PLUG IN ~'11 ~D WITH ~l,NqI~ JT ~ RUN IN L~ SOREW~. LI~E VALVES ADJACBVT TO ~ STAO(. ALL 01J-ER 4. PRESS,;~ UP TO 293 PSI AN3 HOLD FOR I0 MIN. IN- CREASE PRESSI.{~ TO 3000 PSI AN3 HOLD FOR I0 MIN. BLEED PRE~ TO 0 PSI. LI~E VALVE~. CLOSE TOP PIPE RAt~ ~ HOR VALVES ON KILL ~ ~ LIliES. 6.TEST TO 250 PSI MN) 3000 PSI AS IN STEP 4. ?. CCNTINLE TESTINO ALL VALVES° LI~.So ~ ~ WITH A 250 PSI LC~ AN3 3000 PSI HIOH. TEST AS IN STEP 4. eX3 NOT ~ TEST A~Y 040(E THAT IS N3T A FULL O-OSIN~ posITI,YE S~AL mO<E. ON.Y 8. C~ TOP PIPE P.A~S AN3 CLOS~ ~n-rc~ PiPE TEST BOTTCM PIPE P.~aS TO 293 PSI AN3 3O0O PSI. 10. CLOSE BLIhD RAMS A~D TEST TO 250 PSI ~ 3030 PSI. II. OPEN B_IN3 R~v~ A~D RETRIEVE TEST PLUO. MN<E SURE MANIFOLD ~ LI~ES ERE FULL CF hi3q-FREEZINO FLUID. SET ALL VALVES IN DRILLINO POSITION. 12. TEST STAN3PIPE VALVES° KELLY° KE]..LY COQ(S° DRILL PIPE SAFETY VALVE° AkD INSICE ~ TO 250 PSI AN) 3000 PSI. 13. RECORD TEST IhF~TION ON BL~ PREVENTER TEST FORM° SIONo AN) SE{~) TO DRILLINO SUPERVISOR. 14. PERFCI~M CCIVlUL~ BOPE TEST AFTER NIPPLINO UP WEEKLY TI~ FUNCTICNALLY (]aERATE BOPE DAILY. 5 i 0084001 REV, 2 MAY 15, 1985 Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 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. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. nw~5 / i~ GENERAL DRILLING PROCEDUP.~ KUPARUK RIVER FIELD DEVELOPMENT WELLS i. 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 Xmas 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 stimulate. SHALE _ SHAKERS MUD ~ CLEANER STIR 4--~, STIR _.~ STIR TYP I CAL MUD SYSTEM SCHEMAT.I C LWK4 / ih (1) Fee CHECK LIST FOR NEW W~.~, PERMITS Company Arco YES 1. Is the permit fee attached .......................................... ~ (2) Loc ! (2 thru 8) (9 r.b.ru 13) (10 and 13) . (4) ~_.~.~ - ~.,/: ~. ,~/,f~ (14 thru 22) (5) BOPE ,'/~.,~.~/. ~'.m~-$~ (Z3 thru 28) (29 thru 31) Lease & Well No. NO 2. Is well to be located in a defined pool ............................. 3.. Is well located proper distance from property I/ne .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage avai~le in this pool ............ 6. IS well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... . 10. 11. 12. 13. Does operator h~ve a bond in force .................................. ~ Is a conserTation order needed ...................................... '~ Is a6m~rd, strative approval-needed ................................... Is the lease m~er appropriate .................. ~ 14. 15. 16. 17. 18. 19. 20. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... IS enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will c~nt 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 ............ = 21. Is old wellbore abandonment procedure included on 10-403 ............ 22. Is adequate wellbore separation proposed ............................ 23. Is a diverter system re~red .......................... - ............. 24. Is the drilling fluid program schematic and list of equipment adequate 25. Are necessary diagr~ and descriptions of diverter and BOPE attached. 26. Does BOPE have sufficient pressure rating - Test to ~0oo psig .. 27. Does the choke manifold comply w/AP1 RP-53 ~ay 84) .................. 28. Is the presence of ~S gas probable ................................. (6) Add: For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones .... 31. If an offshore loc., are survey results of seabed conditions 32. Additional requirements ............................................. ,, J Geology: rev: 01/28/87 6.011 ,, INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. 3HORE o I qO II Go 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. ~mmmm~mmmmmmm~eeemmm~ ~VP 010,H02 VERIf':ICATiU;'~ LISTING PAGE REEL HEADER )ATE 187/07/1~ IEEL NA~E 172405 ~ONTINUATION ~ :01 ~REV!OUS REEL : ~OMM~NT$ :bis TAP~ A~CO AbASKA~ ~* TaPE HEADER ½BRVICE NAM~ :EDIT )ATE JRIGIN :FS1A " N .O TINUATION # :01 >REV~OU$ TAPE : 20~MEN?$ :LIS TAPE~ ARC~ AbASKA~ INC, 3M-17, APl FILE H£ADER ~g~StON # ~AXIMU~ ~ENGTH : !024 Fi~LE TYPE PRE¥~OUS FILE ** iNFORmATION RECORDS CN : ARCO ALASKA, FN : KUPARUK 0~ SECT~ 25 COUN{ NOHTH.SLOPE~ STAT: A~ASKA ~NE~ CO~TE~TS PRES: E UNiT ~'YPE CATE SliZE CODE 000 000 017 0~5 000 000 O06 065 000 000 008 065 000 000 002 065 000 000 004 065 000 000 002 065 000 000 012 0~5 000 000 006 065 UNIT tYPE CATE SIZE CODE 000 000 001 065 :VP OlO,H02 VERIf~ICATION [,ISTING PAGE 2 SCHLUMBE~RGER ALASKA COMPUTING CENTER IO~PANY = ARCO ALASKA, iNC. 'Ebb = 3M"17 'OUNTY = NORTH SLOPE BOROUGH ;TATE = ALASKA [OB NUEBER AT AKCC= 72405 IUN #lw DATE BOGGEDt 30 JUN 87 'DPt R, SINES = 9.625" ~ 4327' ' =~ bSNO POLYMER = 10.0 LB/G =450,5 ~AXIMU~ RECORDED T£MPMRATURM = 1~B OF ~ATRIX SANDSTONE ~I~ SIZ~ = 8,5" R~ R~C R~ AT BHT VP O1O,M02 V~RIFIC~TIO~ bI$~rI~G PAGE **** THIS DATA HAS NOT BE~N DEPTH SHIFTED - OVER[!AY$ FIEbD PRINTS $CHbUMBERGE~ LOGS I~CbUDED W~TH THIS <SEE; FIbE EDIT,002 FO~ DATA AVAIbAB~E~ 8700" TO FORMATION DENSITY COMPENSATED DOG [FDN~ DATA AVAIhAObE~ CO{4PENSATED NEUTRON LOG (FDN) [A~A AVAILABbE: 870 ' TO 6400' GAMMA RAY IN CASING DATA AVAILABbE: 4300' TO i000' DATA FORMAT RECORD ** ~NTRY BbOCKS TYPE SIZE REPR CODE EN~rRY 2 I 66 0 4 ~ 66 ! 8 4 7~ 60 9 4 65 ,lIN 16 I 66 0 1 6~ 0 )ATU~ SPKCIFICATIO~i BhOCK$ YP OIO,M02 VERIFICATION blSTING PAGE 4 NEM SERVICE SERVICE UNIT API API API API FIbE SIZE SPL REPR ID !EPT ~FLU OIL LD OIL bM OIL ~R ;R FDN :ALI FDN ~HOB FDN )RHO FDN ~RA? FDN ~NRA FDN IPH! FDN )PHI FDN iCNb FDN aCN[, FDN KENS FDN ;R CHD FT O0 000 O0 0 0 4 I 68 O000OO0000OOOO oM~ oo 220 Ol o o 4 ~ 6e oooooooooooooo OH~ oo 1~0 46 0 0 4 ~ 6~ 00000000000000 OH~ OO 12o 44 o o 4 ~ 6e oooooooooooooo ~v oo olo ol o o 4 ~ se oooooooooooooo GAPI O0 310 Ol 0 0 4 1 6800000000000000 calx oo ~o o1 o o 4 1 6e oooooooooooooo zN oo 2~o o~ o o ~ I 6~ oooooooooooooo G/C3 oo 3~o 02 o o ~ X ~e oooooooooooooo GXC~ oo 3~ ol o o 4 ~ 6~ oooooo0ooooo0o oo 420 o~ 0 0 4 ~ ~e oooooooooooooo oo ooo oo o o 4 ~ ~e oooooooooooooo Po oo ~9o oo o o 4 ~ 6~ oooooooooooooo PU oo ego oo o o ~ ~ ~ oooooooooooooo cps oo ~3o ~ o o 4 1 6~ o0oooooooooooo cps oo 3~o 30 o o ~ I 6e oooooooooooooo ~ oo ~35 ~ o o ~ ~ 6e oooooooooooooo ~B oo 63~ 21 o o ~ 1 se oooooooooooooo GAP1 O0 310 01 0 0 4 1 ~800000000000000 ~B oo ~ 2~ o o 4 ~ 6e oooooooooooooo DATA )EPT 8726,5000 SFbU ~e .74;5oRo GR ~HOB -999,2500 DRHO ~PHI -999~2500 DPHI ~ENS -999,2500 TENS P ~HOB ~PHI 8ZO0.O000 SFLU ,75.0000 2.4668 3e,7207 DPH! 7t32,0000 DEPT SP NPHI 86000000 SFbU -160000 GR 244J4 DRRO 39404] DPHI 8768 0000 TEN8 NPi~I TENS 8500 0000 SFLU -16 9844 GR 2 4160 DRHO 43 0664 DP~I 8680.0000 ~ENS DEPT Bp NPHI 29654 tho 853750 GR -999 2500 NRAT -999 2500 NCNb 31700000 GR 29609 85 .3750 OR 0 og NRAT 11 10~? 2 NCNb 7132 0000 GR 3 2246 IhO 93 6875 OR 0 0308 NRAT 12 5237 NCNb 8768 0000 OR I 101 0 14 868.0 9134 1875 01217 NRAt !809 NCNi~ 0000 OR 8400,0000 SFLU 12,2303 -27,0000 OR 61,1250 GR 2,8906 DRHt'3 -0,~3170 NRAT 25,5859 DPHI -14.:~ B~35 NCNb 2,5620 IbM '999'2500 CAbl '999.2500 RNRA '999:~.00 FCNb '999 O0 TENS 2, 7693 l[,M 85. 50 CAb! 3'28!3 RNR.A 1858.0000 FCNh -999.2500 '~ENS 3.2024 93.6875 CAb! 3.0~9~g RNRA 98, 0 FCNh 1,'!875 CAb! 3,4785 [~NRA 1970'.0000 FCNI~ "999.2500 TENS 174743 61:1250 24414 RNRA 3104 0000 FCNb 2 6186 ,,,,'999 ,2500 ,,,999 2900 ,,,999 25.00 ,,,999 2500 ~,3379 556,.5000 -999.2500 3:2185 8 4766 J :369t 622 5000 -999 2500 1483 ] 3281 .5996 54{ 0000 .,,999 2500 19.3992 127 0000 VP OlO.H02 VERIFICATIUN LISTING PAGE 5 8512,0000 TEi~S 'EPT 8~00,0000 SFL!J ,P 20,9531 GR :HOM 2,7305 DRHO iPHI 41.406t DPHI iEN$ 8240,0000 TENS }EPT 8200,0000 SFLU ;P -28,5000 GR IHOB 2.3711 ORHO IpHI 48,5352 DPHI ~ENS 8264.0000 TENS !EPT ,P IHOB ~PHI CENS )EPT 5P ~HOB 8100 0000 -30 9375 GR -999 2500 -999 2500 DPHI -999 2500 TENS 8000 0000 SFLU 3~ 9687 -;9 2500 DRHO -999 2500 "999 2500 TENS 8512.0000 GR 1,6280 ILO 7,3750 GR 0.0044 NRAT 4,8769 NCNL ~240.0000 GR 2 5458 ILO 109 8125 GR 0 0332 ~RAT 16 9034 NCNL 8264 0000 GR 4,b265 221,8750 GR i 999,2500 NRAT 999,2500 NCNb ,,384,0000 GR 4 6014 IbO 242 8750 GR -999 2500 NRAT -999 2500 NCNb 8168 0000 GR EPT 7900,0000 SFbU 4,.3182 lbo p ,,39,0000 OR 136.~ 50 GR RHOB -999,2500 DRHO -999,2500 NRAT ~PHI -999.2500 OPRI -999 2500 NCNb . o9,2soo 8ooo2.,oooo 7800,0000 SFLU -42~0000 GR -999,2500 DRHO -999.,~500 DPHI "999, 500 TENS 7700 0000 SFbO -4.4 9687 GR -999 2500 DRHO -999 2500 DPMI '999 2500 TENS 00,:0000 SFLU 148,9687 Ga 999;2500 DRHO 999,2500 DPHI -999,2500 TENS EPT P RflOB DEPT St=' RHOB DEPT SP RHOB :PHI TENS DEPT RHOB NPMI 7500,0000 SFLU -44,00()0 GR -999,2500 DRHD '999,2500 DPHI 4 4731 98 4375 GR -999 2500 NRAT -999 2500 7888 0000 GR 5. 4804 ILO "999,2500 NRA -999,2500 NCNb 7840,0000 GR 112 -999 '999 7680 2491 ILO 2500 GR 2500 NRAT 2500 NCNL 0000 GR -999,2500 TENS 7~ 6709 Ib~ 3750 CALI 3 4434 RNRA 2064 0000 FCNb -999 2500 TENS : 4258 IL~ 10 8125 CALX 3,9570 RNRA 1671,0000 FCNh -999,2500 TENS 3 -999 -999 -999 -999 3832 250O 2500 RNRI 2500 2500 TENS 3,3817 Ib~ -999,2500 CAb][ -999,2500 RNRA 799.1 5oo 999, 500 TENS 3,7921 -999.2500 -999,2500 RNRA -999.2500 FC~L -999,2500 TENS 4, 33 Ib~ 0 RNRA '999. L -999,2500 TENS 4,5785 Ibr~ -999'2500 CAlyX -999,,2500 RNRA -999,2500 FCNL -999,2500 ~NS 4, ! 68 5 I b~ -999,2500 ClbI ~999 ' 2500 .999'2500 FCNb 999;2500 TENS 3,9443 IhO 3 -999~2500 NCNb -999 6650 iL~ 250O CALX 2500 RNRA 2500 FC~b; -999,2500 I 6658 9 0234 3 3359 018 5000 -999 2500 ~ 7 . I:o'ooo 999,2500 -99] 5659 3500 -999 2500 -999 2500 -999 2500 3 4897 -999 1500 -999 500 -999 500 -999 2500 3,9349 -999 ' 2500 -999,2500 ",999,2500 '999,2500 4,3695 "999,2500 '999. 2500 -999,~500 -99~,2500 . 4,7745 999;25OO -999,2500 -999,2500 -999'2500 4 1507 -999 2500 ,,999 2500 · "999 2500 -999 2500 3,6591 ,999 ~ 2500 99V~,2500 -999,2500 VP 010,H02 VERIFICATION LISTING PAGE 6 -999,2500 TENS 'EPT 7~00,0000 SFbU ;P 52,0000 GR =HOB -999,2500 DRHO ;PHI '999,2500 DPHI '£N5 '999,2500 TENS ~EPT 7300 ip -48 [HOe -999 ~PHI -999 'ENS -999 ~EPT 7200 ~P -58 tHOB -999 0000 SFbO 5000 GR 2500 DRHO 2500 DPHI 2500 TENS 0000 SFbU 0000 GR 2500 DRHO 2500 DPH! 2500 TENS ;P 5 0000 GR tHOB 99 2500 DaHO ~PHI -999'2500 DPHI FENS -999,2500 TENS )EPT 7000 ;P .55 tHOB -999 0pH! -999 tENS -999 )EPT 6900 ~P. -52 ~HOB -999 ~PHI -999 ~EN~ -999 )EP~ 6800 ~P -55 ~HOB -999 ~PH! ,-999 [gN$ -999 ~EPT 6700 ~P RHOB -999 ~PHI -999 [~NS -Egg NpH! 0000 8FbU 4375 GR 2500 DRHO 2500 DPHi 2500 TENS 0000 SFbU 5OO0 Ga 2500 DRHO 2500 DPHI 25O0 TENS 0000 SFbU 0000 GR 2500 DRHO 2500 DPHI 2500 TENS 0000 SFGU 0000 GR 2500 DRHO 2500 DPHI 25OO TENS 6600,0000 -61.5000 2i:. 40 SFLU GR 7732,0000 GR 3 7288 101 1250 -999 2500 -999 2500 7512 0000 GR NRAT NCN[~ GR 4,1803 ILO ~093.5625 GR 9 ,2500 NRAT 999,2500 NCNb 432,0000 GR 3 8824 97 5000 -999 2500 -999 2500 7144 0000 4 0~54 89 0000 -999 2500 -999 2500 7052 0000 GR NRAT NCNb lbo GR NRAT NCNL G~ 3,~197 i08, 375 GR '999 500 NCNb 6924,0000 GR 12 '50 L; R .999;2500 NRAT 999,2500 NCNb 6932'0000 GR 3 2281 I O3 ·6250 -999 2500 -999 2500 6740 0000 NCNb 999,2500 NCNL 6680,0000 GR 3,6197 i07,9375 GR 0,0684 NRAT 15,3646 NCNb -999.2500 3,7856 -999 2500 -999i2500 -999 250O -999,2500 3 7042 -999 2500 -999 2500 -999 2500 -999 2500 IbM CA[,I RNRA FCNb TENS CAb! RNRA 4,0404 IbM -999'2500 CALl -999,2500 RNRA -999,2500 FCNL -999,2500 TENS 4,~811 IbM -999, 500 CA.bi -999.2500 RNRA -999'2500 FCNG -999,2500 TENS 3,7724 IbM -999,2500 CAb! 2500 RNRA -999,~:uu TENS 3,~785 -999, 500 -999,2500 RNRA -999 .~500 FCNL -999:500 TENS 3,2777 IbM -999'2500 CAbI -999':2500 RNRA -999,2500 FCNL -999,2500 T~NS ~,5445 IL2 -999,~500 CAbI -999,2500 RNRA -999,2500 FCN~ -999,2500. TENS · CAbI I09, 2,1187 RNRA 1987, 000 FCNh -999,2500 -99~ 7934 2500 -999 0 .,,, -999 2500 -99~ 7573 2500 =999 2500 -999 2500 -999 2500 4 0609 -999:2500 -999 2500 -999 2500 -999 2500 . 4,1458 999,2500 -999,2500 -999,~500 -999,2500 -999,2500 -999'2500 -999,2500 3 )960 =999 ~500 -999 ~500 -999 ~500 -999 2500 .99~' 500 '9~; 500 -~99,.2500 2500 -999,2500 -999;.2500 .'999,2500 3,72~4 2500 B8 ,0000 VP 010,H02 VERIFICATION LISTING PAGE 7 6340,0000 TENS 6504.0000 GR 'EPT ;P iPHl 6500,0000 SfbU -54,5000 GR 2'27~ DRHO 22:97,5 DPHI 657 0000 TENS 1 9870 1001]125 000B3 NRA~ 22 8220 ~;CNL 6760,0000 GR ~EPT ;P [HOB iPHI ;ENS 6400 0000 SFhU -63 0000 GR 2 38B7 DRHO 20 2637 DPHI 6204 0000 TENS 3 6735 119 3500 GR 0 0522 NRAT 15 8381 NCNb 6332 0000 GR !EPT ~P ~PHI FENS 6300,0000 SrbO -54,4375 GR -999,2500 DRHO -999,2500 DPH! -999,2500 TENS 2 5903 13 8125 GR - 99 2500 NRAT -999 2500 NCNb 6408 0000 GR )EPT 5P ~HOB ~P~I 6200 OOOO SFLU -56 0000 GR -999 2500 DRHO -999 2500 DP~I -999 2500 TENS 2,0174 IbD 122,2500 GR 999, 500 NCNb 6044,0000 GR )EPT ~ PHI 6~00,0000 SFbU .69,0000 GR ,999,2500 DRHO 999'2500 DPH! -999,2500 TENS 3 5590 135 0000 GR -999 2500 NRAT -999 2500 NCNL ~1.48 0000 GR D~PT RHOB 6000 0000 $FbU '78 5000 GR -999 2500 DRHO -999 3500 DP8I -999 2500 TEN8 4,2921 IbD 99,:2500 9 9 * ,250 0 N C N L 63~]4~0000 EPT P RHOB TENS 5900,0000 ;5FLU .6o;9_687 -999,2500 DRHO -999,2500 D~MI -999,2500 TENS 2 0445 ILD 92 4375 GR '999 2500 NRAT -999 2500 NCNL 5980 0000 GR DEPT 5P RHOB TENS 580U 0000 '6! 4375 G~ "999 2500 "999 ~500 "999 ~500 TENS , 9434 9 , 5000 GR '-999,2500 NRAT -999 '(~500 NCNB 6068: 000 DEPT NPHI 5700 0000 SFbO -63 0000 GR "999 2500 DRHO '999 3500 DPHI '999,2500 TENS 1 b243 iLH 103 8750 CAb! 1 0352 R~RA 2190 0000 FCNb -999 2500 TENS 3,~35a 115, 75O CAbI 881.02~68 , O0 FCNL, !999,2500 TENS 2 5b19 IbM -999 2500 CAbI -999 2500 RNRA -999 2500 FCNL -999 2500 TENS 2 4657 Ib~ -999 2500 ClbI -999 2500 RNRA -999 2500 FCNL -999 2500 TENS . 3,8249 Iht4 ,:.,999 ' 2500 CAb! .999,2500 RNRA 999,~500 FCNL ,,999,2500 TENS '999 '999 '999 '999 1157 2500 CAb! 2500 2500 2 1954 ,,999:.. 500 CAbi -999 ~500 R.NRA · ,999 ~500 FCN5 -999 2500 TENS :9929,i482 .IBM ,2500 CAbI 999'2500 RNRA -999 '2500 FCN5 -999,2500 TENS 2,4676 IbD 2'6254 93,4375 GR -999'~2500 CAbI .999,2500 NRAT -999,2500 RNRA 999 ~ 2500 NCNb -999; 3500 FCNb '999,2500 9436 7188 0000 25OO 3 6403 10 0625 2 3047 816 5000 -999 2500 "999,2500 ,,"999,2500 -.999",2500 999,2500 -999 ,,999 -999 25{}0 -999 2500 99'9, O0 ,,,999,2500 4 0255 ,,999 2500 -999 2500 ,,,999 2500 ,,999 2500 -9~~' '00! o0 .99i' O0 2,0974 .,999;:2500 -999'2500 '999':2500 '999; 2500 2 5901 ,,999 2500 -999 2500 ,-999 2500 VP 010,H02 VHRIFICATION LISTI,",G PAGE ~ENS =999.2500 TENS 5984.0000 GR 'EPT 5600,0000 SFLU ~P -65,5000 GR ,HOB -999,2500 DRHU iPHI -999,250() DPHI 'ENS -999,2500 TENS 2.0424 ILL 102,2500 GW -999,2500 NEAT -999.2500 NCNb 5644.0000 GR ;P 5500 0000 SFbU -6B 0000 GR -999 2500 DRHO -999 2500 DPHI -999 2500 TENS J 1679 ~102 2500 999 2500 NRAT -999 2500 NCNb 5680 0000 GR )EPT ;P ~HOB ~PHI 401,i0000 SFLU -6 0000 GR 99 2500 DEMO 99 2500 DPHI -99 2500 TENS 2 6900 89 5625 GE -999 2500 NEAT '999 2500 NCNL 5528 0000 GE )EPT ;P tHOB 5300 0000 -68 9375 -999 2500 -999 2500 -999 2500 DRHO DPHI TENS ~ 1544 ILL 61 6563 GR -999 2500 NEAT -999 2500 NCNL 5640 0000 GR !EPT ~P {HOB ~PHI 5200 0000 SFbU -73 5OOO GR -999 2500 DRHO -999 2500 DPHI -999 2500 TENS 3,9~17 IbD 92,.0 O0 GR -999,2500 NEAT -999~.2500 NCNL 540:~,:0000 GE EPT P ~ P H l ii 0 ,0000 SFbU . ooo ~99,2500 TgNS ..~500 OPHI 3 .I10 999 -999 5180 4920 IbD g 375 GR 2500 NEAT 250O NCN5 0000 GR ?EPT ~P ~PH I lENS 50O0 0000 SFbU -75 5000 GE ..999 2500 DRHO -999 2500 DPHI -999 2500 TENS 3 112 -999 -999 5084 15b 1 0000 GR 2500 NRAT 2500 NCNL 0000 ~EPT ~P ~PHI 4900 0000 -79 2500 '999 2500 -999 2500 -999 2500 DPHI ] 8647 i O0 5625 GR -999 2500 NRAT -999 2500 4964 0000 )EP T ~P ~HO~ 4800 0000 8FbO -76 7500 GE '999 2500 DRHO '999 2500 ~PHt 0,5494 IbP -999 500 i~R:AT -999.2500 NCNb -999.2500 TgNS 2 3212 ibm -999~2500 CALl -999,2500 RNRA '999,2500 FCNb '999,2500 T~NS 3,5793 IbM -999,2500 CAbI -999,2500 RNRA -999,2500 FCNb '999,2500 TENS 3 -999 -999 -999 -999 907 500 2500 RNRA 2500 FCN5 2500 TENS 2 -999 ,-999 -999 -999 ,9573 ILM ,2500 CALl ,2500 RNRA ,2500 FCNb ,2500 TENS 4 -999 -999 -999 -999 25 C A ~I ! oo O0 FCNI,, 500 TENS 3,9070 II~M '999'2500 CALl '999.:2~00 ~NRA "999'2 O0 CNI., '999,2500 ~ENS '999,2500 CAb! :999,2500 RNRA .999 *2500 999,2500 TENS -999 -999 -999 7 387 Ibt~ 500 CAbI 500 RNRA 500 FCNb 2500 TENS 0,4269 Ih~ '999.2500 CALI -999,2500 RNRA -999,2500 FCNb -999,2500 2 2536 -999 2500 -999 2500 -999 2500 -999 2500 999; 500 -999,2500 -999,2500 2 9457 -999 2500 -999 2500 -999 2500 -999 2500 2,8664 -999,2500 -999,2500 -999', 2500 -999,2500 4 0058 -999 2500 · ,999 2500 -999 2500 ,,999 2500 3,8~75 -999,2 O0 -999~500 - 500 -999'2'500 3,4057 -999,2500 :500 '999'!~,500 '.999, -999,2500 2 O083 -999 25 "999 2500 "999 2500 0,4041 -999,2500 '999,25,00 '99~;2500 tVP t)!,0,H02 VERIFICA:~ION LISTING PAGE 9 'ENS -999,2500 TENS 4892,0000 GR ~EP? 4!00 0000 SFLU ;P ' -79:7500 GR IHOB -999,2500 DRHO iPH! -999,2500 DPMI ,E S -999'2500 TENS 3 3634 IbD 97 9375 GR -999 2500 NRAT -999 2500 NCNb 4928 0000 GR )EPT 4600,0000 SFbU ''80,0000 GR '999 2500 DRHU '999 2500 DPH! '999 2500 TENS ,9601 10 ,8750 GR 999,2500 NRAT :999.2500 NCNb 4704,0000 ~P ~HOB ~PHI. FENS 2 3128 90 1250 -999 2500 NRAT -999 2500 NCNb 4524 0000 EPT RHOB ~PHI tENS 4400 0000 SFLU -90 2500 GR ''999 2500 DRHO -999 2500 DPHI ''999 2500 TENS -999,2500 lENS RHOB ~PHI 4300,0000 SFLU 38,5000 GR -;99,2500 DRHO --~99,2500 DPHI - 99'2500 TENS 3 7989 Ih~ -999 2500 CALl -999 2500 RNRA -999 2500 FCNb -999 2500 TENS 2,3176 IbM "999,2500 CAb! '999,2500 RNRA '999,2500 FCN5 '999,2500 TENS RHOB 4200 '999 -999 ,,999 -999 0000 SFLU 2500 GR 2500 DRHO 2500 DPHI 2500 TENS 2 9978 IbM -999 2500 CAhI -999 2500 RNRA -999 2500 FCNL -999 2500 TENS DEPT RHOB NPH! TENS 4100 O000 -999 2500 -999 2500 -999 2500 DP~I -999 2500 TENS '999.2500 DEPT RHOB 4000,0000 SF:LU "999,2500 G R -999,~500 DRHO -999,2500 OPHI -999,2500 ~rENS 3 6193 -999 2500 -999 2500 -99~ 2500 -999 2500 DEPT s~ R H 0 ~ NPHI 3900 0000 SFLU ,,999 2500 GR -999 2500 DRHO "999 2500 DPHI 2 2143 -999 2500 -999 2500 -999 2500 -999 2500 2,7495 -999,2500 25OO -999,2500 4,183~ ILO 4.46~9 IL~ 4,2889 98.3125 GR '999;2500 CALl -999'2500 :999.2500 NRAT -999,2500 RNRA -999,2500 999,2500 NCNb -999;2500 FCNL -999,2500 4348'0000 GR -999,2500 T~NS --999,2500 20 O0 67 ''999 -999 4432 0000 9375 250O 2500 0000 ''999 2500 i5~ -999 2500 CA~I '999 2500 RNRA "999 2500 FCN'~ 52 3125 ~ENS -999 2500 Ih~ '99911500 CALl '99~ 500 RNRA "99 ~500 FCNL 62 062 TENS '"999,2500 '999'2500 CALl -999,2500 RNRA -999'2500 FC · 58'1975 TENS -999,2500 ~I~ -,999.2500 Chbi -999 ~ R!~IRA · ,999 FCNL -999 ~00 !bD '999:' O0 GR ''999,~500 NRAT -999,~ 500 NCNb ''999,2500 GR '999,2500 "'999 ' 2500 GR ''999,2500 NRAT -999'2500 NCNb -999,2500 GE ''999 2,500 lb[) -999 2500 GR -999 2500 NRAT -999 ~500 NCN[~ -999 500 GR '999,2500 IbP '999 ~5'00 GR -999~ 500 NRAT -999,2500 NCN[~ 2000.0000 '999,2500 "999,2500 -999,2500 4~88,0000 -999 2500 ..999 2500 -999 2500 ,,,999 2500 4420 0000 "999,2500 "999 '"999.2500 "999'2500 4348,0000 -999,2500 ''999,2500 "999,2500 "999,2500 4 2 0 0 ' 0 0 0 0 "999, :2500 "999,2500 '''999,2500 m999,2500 ,VP OlO.H02 VERIFICATION LISTING PAGE 10 ' N '999,2500 TENS -999.2500 GR ;P ',HOB 3800 0000 SFbU -999 2500 GR -999 2500 DRHO -999 2500 OPHI -999 25U0 TENS -999 2500 IbD -999 2500 GR -999 2500 NRAT -999 2500 NCNL -999 2500 GR )EPT ~700,0000 SFbU -999.2500 :ENS -999' 2500 TENS -999 500 GR )E:PT ;P 3600 0000 8FGU -999 2500 GR -999 2500 DRHO -999 2500 DPHI '999 2500 TENS '999.2500 -999.2500 -999'2500 NRAT -999,2500 NCN[, -999.2500 GR ~HOB 3500,0000 SFbU .999,2500 GR ~999,2500 DRHI3 .999'2500 DPHI 999,2500 TENS -999 2500 IbD -999 2500 GR -999 2500 NRAT -999 2500 NCNL -999 2500 GR ~P ~HOB ~ PHi 3400 0000 SFbU -999 2500 GR -999 2500 DRHO -999 2500 DPHI -999 2500 "'"i -999,2500 -999 ]500 999: - 500 NRAT -999,~500 -999, 500 GR P ~pH:! tENS 3300 0000 SFLU -999 2500 GR -999 2500 DRHO -999 2500 DPHI -999 2500 T~NS -999,2500 Ib~ -999,2500 GR -999,2500 NRAT -999;2500 NCNL "999,2500 OR EPT P ~.HO~ ~PHI 200,0000 SFLU 999'2500 (iR 9'99,2500 DRHO 999,2500 DPHI 999,2500 TENS -999 -999 -g99 -999 -99g 2500 2500 NRAT 2500 NCNL 2500 GR D~PT SP RHOP TENS 3100 0000 SFLU '999 2500 GR '999 2500 DRHO -999 2500 DPHI '999 2500 TENS ! oo -999, 500 R '999, 500 NRA~ .9~9. 500 Ga DEPT 3000,0000 SFLU SP ,,,999'~500 GR RHOB -999,2500 DRHO NPHI '999~2500 DPHI -999 2500 · ,999 2500 OR -999 2500 NRAT -999 2500 NCNb 63,0938 TENS =999.2500 Ih~ -999.2500 UA~I -999.2500 RNRA -999.2500 FCNL, 44.2187 TENS -999,2500 IbM -999,2500 CAhI -999,2500 RNRA -999,2900 FCNb ~2.4688 TENS 999,2500 IbM :999.2500 CAb! -999.2500 RNRA -999.2500 FCNI~ 48.2~87 T~NS -999,2500 ISM -999,2500 CA~I -999,2500 RNRA -999,2500 ~CNb ~0,5156 T-~N$ '999,2500 IbM -999,2500 CabI -999,2500 -999,2500 FCNb 48,0938 TENS -999,:!500 Ib~ -999, 500 C~bI -999. 500 RNRA -999, 500 FCNh 47, 625 TENS -999 '999 -999 -999 3O 500 CAbI 500 RNRA 500 FCNb 6250 ~r B N S -999 ,,999 -999 -999 54 2500 IbM 3500 C Ab I 2500 FC N b 0313 T E N S -999 ,~500 lDO -999 ~ 00 -999: 500 IbM CA~I NNRA FCN5 3954,0000 99 500 99!!2500 8 000 -999 2500 -999 2500 -999 2500 -999 2500 3904 0o00 -999,1500 '999,2500 '999,2500 3870,0000 -999 2500 -999 2500 -999 25O0 "999 2500 3840 0000 -9.99 2500 - 999 2500 -999 2500 -999 2500 3644 0000 ,,,99~. 2500 -999 2500 -999 2500 ,,,999 2500 3614 0000 ,,,999,2500 -999,2500 -999; 2500 -999,2500 3500,0000 -999 2500 ,,,999 2500 -999 2500 -999 2500 3510 0000 "999,2500 "999'2500 -999,2500 -999,2500 VP OlO,a02 VERIFICATION blSf!NG PAGE I1 ENS -999.2500 TENS -999.2500 ~EPT ~900 0000 SFLU :P -999:2500 GR HOB 999,2500 DRHO PHI ~999.2500 DPHI 'ENS -999,2500 TENS -999 2500 ILO -999 2500 GR '999 2500 NRAT '999 2500 NCNL -999 2500 GR 'EPT 2800,0000 SFLU ip -999;~500 GR 'HOB -999,2500 DRHO tPHI -999.2500 DPHI ~EN$ -999.2500 TENS -999 2500 -999 250O -999 2500 NRAT -999 2500 NCNb -999 2500 ;p ~HOB 2700 OOOO SFLU -999 2500 GR -999 ~500 DRHO -999 2500 DPHI -999 ~500 TENS -999.2500 -999 '2500 -999,2500 NRAT -999.2500 NCNb -999,2500 GR )EPT }p 2600 0000 SFLU -999 2500 GR ',.999 2500 ORHO -999 2500 DPH1 -999 2500 TENS -999 2500 -999 2500 GR -999 2500 NRAT -999 2500 NCNb -999 2500 GR 500, 999 -999 -999 -999 0000 SFbU ~500 GR 2500 DRHO 2500 DPHI 2500 TENS ',.,.999 2500 -999 .2500 GR -999 .2500 NRAT -999 2500 ~CNL~ -999 2500 ?EPT ~P {MOB CENS 2400 0000 SFLU -999 2500 GR -999 2500 ORHO -999 2500 DPMI -999 2500 T~N$ 5P {PHI 2~,0000 SFb,U " , ~500 GR -999~2500 DRHO ,.999.2500 DPHI -999,2500 TENS -999 2500 -999 250O -999 2500 -999 2500 39 .3125 2) EPT 2200 0000 SFLU -999 2500 GR -999 2500 DRHO ',.999 2500 DPHi -999 2500 TENS IbM CALI RNRA FCNL TENS -999,2500 =999,2500 C~LI -999,2500 RNRA -999.2500 FCNL 32,9687 TEN~ SP ~PHI 210(.),0000 SFLU -999,2500 GR '999,2500 DRMO '999.2500 O MI -999.2500 Ib~ '999,2500 CALI -999,2500 RNRA -999,2500 FCNL 52,343~ TENS -999,2500 IbM -999,2500 C&bI -999,2500 RNRA -999,2500 FCNL 41,8437 TENS -999,2500 -999.2500 CALI -999,2500 RNRA -999.2500 FCNL 32,~437 -999,2500 ILL -999 -999 ~500 GR -999 -999:500 NRAT -999 -999 .~500 NCNb -999 -999'. 500 GR 36 -999 2500 -999 2500 GR -999 2500 NRAT ',.999 2500 NCNB -999 2500 GR 2500 ILL 2500 GR 2500 NRAT 2500 NCNB 2500 GR -999 -999 -999 -999 -999 -999 25~0 -999 25 0 ..999 2500 N~AT -999 2500 NCNb 2500 25OO 2500 RNRA 2500 3750 TENS -999.2500 Ib~ -999:2500 CAhI '999 !500 RNRA -999 500 FCNL 37:875 TENS -999,~500 IbM -999~ 500 CALI -999~:. 500 RNRA -999,2500 FCN~ 39,6875 TENS -999,2500 -999,2500 CALl -999,2500 RNRA '999,2500 FCNL 3440.0000 :999,]500 999, 500 '999,2500 '999,2500 3210,0000 '999 2500 "'999 2500 -999 2500 '999 2500 3140 0000 '999,2500 -999,2500 -999,2500 -99g,2500 30.30,0000 -999, 500 ,,,999, 500 '999,2500 '999,2500 2980,0000 -999 2500 -999 2500 -999 2500 · ,999 2500 2890 0000 -999 2500 -999 2680 0000 -999 2500 ,,999 2500 · ,999 2500 "999 2500 2714 0000 -999,~500 -999, ~500 -999 ,.2 0 .999;255(~0 2664 ' 0000 -999,2500 .999,2500 -999,2500 '999,2500 ,VP OIO,H02 VERIFICATIO~ LISTING PAGE 12 ~ENS -999.25(110 TENS :ZPT 2000 ~P -999 :NOB -999 iPH! -999 ENS ''999 0000 SFLU 2500 GR 2500 ORHO 250O DPHI 2500 TENS )EPT ~900,0000 5FbO ;P .999,2500 GR ~HOB .999,2500 DRHO ~PHI .999,2500 OPHI FENS 999,2500 TENS 1800 -999 -999 -999 -999 0000 SFb[! 2500 GE 2500 DRHO 2500 DPH[ 2500 TENS i 700,0000 SFLU EPT .1999,2500 ~OB -999,2500 DRHO ~PHI -999,~500 DPH! tENS -999, 500 TENS ~EPT .1600,0000 SFbO Dp ~999,2soo Ga ~HOB .999,2500 DRHO ~PHI =999,2500 ['ENS 999,2500 TENS 3EPT 1500 5P -999 RMOB -999 N P H I - 999 TENS -999 0000 2500 GR 2500 0~0 2500 DPHI 2500 TENS DEPT 1400 RHOB -999 NPHI -999 tENS -999 2500 GR 2500 DRHO 2500 DPHi 2500 TENS RHOB 999,2500 DRHO NPHI -999,2500 DPHI IENS -999,2500 TENS D~PT 1200,0000 SF5U 5P -999,2500 GR 2500 DRHU RHOB -999,. ') NPHI -999,25~0 DPHI -999,2500 GR -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 250O -999 2500 -999 2500 -999 2500 -999 2500 GR NRAT NCNb GR NRAT NCNb -.999,2500 -999~2500 GR -999,2500 NRAT -.999,2500 I~CNL 999,2500 GR -999 2500 -999 2500 -999 2500 '999 2500 -999 2500 -999 .2500 -999 2500 -999 2500 -999 2500 -999 2500 GR NRAT NCNb 1ED GR NRAT NCNb GR -999,2500 -999,2500 GR '-999 22500 NRAT -999:500 NCNb -999,2500 GR -999. 2500 IbD -99'_9,2500 GR -999,2500 NRAT · .999,2500 NCNL -999,2500 GR -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 GR NRAT NCNb 41,281] -999 2500 -99922500 '999,2500 '999,2500 38,5938 '999,2500 '999,2500 '999,2500 '999,2500 36,9375 '999,2500 '999,2500 '999,~500 '999. 500 42,5625 '999.2500 '99!12500 '99 2500 '99 2500 2 2969 -999 2500 -999 2500 -999 2500 '999 2500 4 t '6250 -999 2500 '999 2500 '999 2500 '999 2500 35 5313 RNRA FC~b TENS IbM RNRA FCNL RNRA FCNb TENS RNRA FCNE CAbI RNRA FCNb TENS '999 500 CAi~I ,,999 500 RNRA -999. O0 "999, O0 '999,~500 43'2500 '999,2500 IbD '999,2500 '999 500 NRAT '999,2500 "999,2500 NCNb .,999,2500 RNRA TENS RNRA 2554,0000 -999,2500 -999,2500 -999,2500 -999,2500 2544,0000 '-999,2500 -999,2500 -999,2500 -999,2500 2590,0000 -999 2500 -999 2500 -999 2500 -999 2500 2404 0000 '999,~ O0 '999, lO0 -999,~500 '999, 500 2~70,0000 -999,2500 -999,2500 -999,2500 -999,2500 2400,0000 -999 2500 ,,,999 2500 '999 2500 ,,,999 2500 2260 0000 '999 2500 .999 2:500 -999 O0 23.90 0000 '999,2500 -999, 2500 '999 '2500 "999,2500 2084,0000 "999,500 -99~, 1500 -999'2500 ,,999,2500 ~ G PAGE 13 VP OlO,H02 VERI~ICATIOi~ L1STI '' ,~ F. 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