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Home My WebLink About185-0211. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Braden Head repair weld ConocoPhillips Alaska, Inc.Development Exploratory 3. Address:Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7122'feet 6376'feet true vertical 6209'feet 6917', 6925'feet Effective Depth measured 6960'feet 6321', 6471', 6705'feet true vertical 6072'feet 5541', 5665', 5861'feet Perforation depth Measured depth 6627'-6804' feet True Vertical depth 5795'-5943' feet Tubing (size, grade, measured and true vertical depth)3.5" L-80 6317' 5538' Packers and SSSV (type, measured and true vertical depth) Packer-Otis WD Perm Packer @ 6705' MD &5861' TVD. NO SSSV 12. Stimulation or cement squeeze summary:N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: 185-021 50-029-21284-00-00 ADL0025644 Kuparuk Riv Unit 2U-08 P.O. Box 100630, Anchorage, Alaska 99508 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator Name 4. Well Class Before Work:5. Permit to Drill Number: Packer measured true vertical Casing Length Size MD TVD N/A KUPARUK RIVER/KUPARUK RIVER OIL Plugs measured Junk measured Burst Collapse Conductor 79'16"116'116' Intermediate Surface 2986'9.625"3024'2929' Liner Production 7008'7"7043'6143" NA NA NA NA NA N/A Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Packer- Baker FHL @6321' MD & 5541'TVD, Packer- Otis RRH @ 6471' MD & 5665' TVD, N/A Authorized Name: Authorized Signature with date: Senior Engineer:Senior Res. Engineer: 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283 WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Roger Mouser / Roger Winter n1927@conocophillips.com 659-7506 Well Integrity Field Supervisor NA NA NA NA NA nttt e Fra O g g g l g y e 6. A y G L PG AAC 25 R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 10:35 am, Dec 14, 2020 Digitally signed by Roger Winter DN: CN=Roger Winter, E=n1927@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2020-12-14 10:16:36 Foxit PhantomPDF Version: 10.0.0 Roger Winter RBDMS HEW 12/14/2020 DSR-12/14/2020 SFD 12/16/2020VTL 2/17/21 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 14th day of December, 2020 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for surface casing repair KRU 2U-08 (PTD 185-021). Please contact Roger Mouser or myself at 659-7506 if you have any questions. Sincerely, Roger Winter Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Digitally signed by Roger Winter DN: CN=Roger Winter, E=n1927@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2020-12-14 10:15:35 Foxit PhantomPDF Version: 10.0.0 Roger Winter Date Event Summary Executive Summary Braden Head Repair 08/07/20 Identify Braden head leak. 12/09/20 Repair Braden head leak. 12/10/20 MITOA to 1800 psi passed. Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 6,896.0 5/17/2015 2U-08 smsmith Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: H2S Update, CORRECTED PATCH INFO, ADDED LEAKS and DELETED NOTES 8/23/2020 2U-08 pproven Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 37.0 Set Depth (ftKB) 116.0 Set Depth (TVD) … 116.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 37.1 Set Depth (ftKB) 3,023.5 Set Depth (TVD) … 2,929.4 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 34.7 Set Depth (ftKB) 7,043.0 Set Depth (TVD) … 6,142.8 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING - WO - 2015 String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 32.8 Set Depth (ft… 6,317.2 Set Depth (TVD) (… 5,538.0 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 32.8 32.8 0.04 HANGER CAMERON McEVOY GEN III HANGER 3.000 6,304.5 5,527.6 34.62 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 2.990 Tubing Description TUBING - WO - 2003 String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 6,307.6 Set Depth (ft… 6,399.3 Set Depth (TVD) (… 5,605.8 Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,307.6 5,530.0 34.60 PBR BAKER 80-40 PBR 2.990 6,320.9 5,541.0 34.52 PACKER BAKER FHL PACKER 2.970 6,375.9 5,586.5 34.17 NIPPLE CAMCO DS NO GO NIPPLE 2.812 6,392.9 5,600.6 34.06 OVERSHOT BAKER POOR BOY OVERSHOT 3.750 Tubing Description TUBING Original String Ma… 4 1/2 ID (in) 2.99 Top (ftKB) 6,397.5 Set Depth (ft… 6,727.8 Set Depth (TVD) (… 5,879.5 Wt (lb/ft) 9.30 Grade J-55 Top Connection FL4S Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,459.4 5,655.7 33.76 SBR OTIS SBR 2.813 6,471.0 5,665.4 33.71 PACKER OTIS RRH PACKER 2.970 6,588.1 5,762.9 33.58 BLAST RINGS BLAST RING JOINTS 2.992 6,704.0 5,859.6 33.31 LOCATOR OTIS STRAIGHT SLOT LOCATOR 2.970 6,705.4 5,860.8 33.31 PACKER OTIS WD PERMANENT PACKER 4.000 6,707.9 5,862.9 33.31 ADAPTOR PACKER ADAPTER 2.992 6,708.4 5,863.3 33.32 SBE OTIS SEAL BORE EXTENSION 4.000 6,719.5 5,872.5 33.34 NIPPLE CAMCO D NIPPLE NO GO 2.750 6,727.0 5,878.8 33.35 SOS SHEAR OUT SUB 3.015 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 6,373.0 5,584.0 34.19 CATCHER Set AVA catcher on plug (34" OAL) 11/30/2020 0.000 6,376.0 5,586.5 34.17 Tubing Plug Set 2.81" CA-2 plug 11/30/2020 0.000 6,476.9 5,670.3 33.68 PACKER - PATCH - UPR 3.5 WIDEPACE LE PACKER (UPPER ASSEMBLY), OAL=24.1' 10/18/2014 1.760 6,501.0 5,690.3 33.58 ANCHOR LATCH Spacer Pipe & SNAP Latch Sesl Assembly 10/18/2014 1.992 6,504.0 5,692.8 33.58 LEAK - GLM PPROF identified leak at 6504' RKB at GLM. 7/28/2014 0.000 6,517.8 5,704.3 33.58 PACKER - PATCH - LWR 3.5 WIDEPAC LE PACKER (LOWER ANCHOR), OAL=5.2' 10/17/2014 1.760 6,917.0 6,037.5 33.26 FISH 1 1/2" CV Dropped in Rathole 1/9/1992 0.000 6,917.0 6,037.5 33.26 FISH 1 1/2" DV Dropped in Rathole 1/23/1993 0.000 6,925.0 6,044.2 33.26 FISH 1 1/2" CV Lost in Rathole 10/27/1994 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,627.0 6,657.0 5,795.3 5,820.3 C-4, UNIT B, 2U -08 4/19/1985 12.0 IPERF 5" Dresser Atlas 6,755.0 6,761.0 5,902.2 5,907.2 A-4, 2U-08 4/19/1985 4.0 IPERF 4" Dresser Atlas 6,765.0 6,804.0 5,910.5 5,943.1 A-3, 2U-08 4/19/1985 4.0 IPERF 4" Dresser Atlas Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,506.9 2,489.9 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,211.0 5/13/2015 2 3,981.6 3,644.0 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,219.0 5/13/2015 3 5,041.6 4,496.5 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.188 0.0 5/13/2015 4 5,779.2 5,100.5 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/8/2015 5 6,247.9 5,481.0 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/1/2020 6 6,419.7 5,622.8 CAMCO KBUG 1 GAS LIFT DMY RK 0.000 0.0 9/21/2003 7 6,508.6 5,696.7 CAMCO MMG-2 1 1/2 PROD HFCV RKP 0.000 0.0 10/17/2014 Patch 8 6,580.0 5,756.1 CAMCO MMG-2 1 1/2 PROD DMY RK 0.000 0.0 11/4/1998 9 6,685.7 5,844.3 CAMCO MMG-2 1 1/2 PROD DMY RK 0.000 0.0 9/4/2010 2U-08, 12/2/2020 11:02:18 AM Vertical schematic (actual) PRODUCTION; 34.7-7,043.0 FISH; 6,925.0 FISH; 6,917.0 FISH; 6,917.0 IPERF; 6,765.0-6,804.0 IPERF; 6,755.0-6,761.0 SOS; 6,727.0 NIPPLE; 6,719.5 SBE; 6,708.4 PACKER; 6,705.4 LOCATOR; 6,704.0 PRODUCTION; 6,685.7 IPERF; 6,627.0-6,657.0 PRODUCTION; 6,580.0 PACKER - PATCH - LWR; 6,517.8 PRODUCTION; 6,508.6 ANCHOR LATCH; 6,501.0 LEAK - GLM; 6,504.0 PACKER - PATCH - UPR; 6,476.9 PACKER; 6,471.0 SBR; 6,459.4 GAS LIFT; 6,419.7 OVERSHOT; 6,392.9 Tubing Plug; 6,376.0 NIPPLE; 6,375.9 CATCHER; 6,373.0 PACKER; 6,320.9 PBR; 6,307.5 SEAL ASSY; 6,304.5 GAS LIFT; 6,247.9 GAS LIFT; 5,779.2 GAS LIFT; 5,041.6 GAS LIFT; 3,981.6 SURFACE; 37.1-3,023.5 GAS LIFT; 2,506.9 CONDUCTOR; 37.0-116.0 HANGER; 32.8 KUP PROD KB-Grd (ft) 41.79 Rig Release Date 3/29/1985 2U-08 ... TD Act Btm (ftKB) 7,122.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292128400 Wellbore Status PROD Max Angle & MD Incl (°) 44.42 MD (ftKB) 3,500.00 WELLNAME WELLBORE2U-08 Annotation Last WO: End Date 5/6/2015 H2S (ppm) 130 Date 12/13/2019 Comment SSSV: NIPPLE Notes: General & Safety End Date Annotation 8/23/2020 NOTE: 2U-08, 12/2/2020 11:02:19 AM Vertical schematic (actual) PRODUCTION; 34.7-7,043.0 FISH; 6,925.0 FISH; 6,917.0 FISH; 6,917.0 IPERF; 6,765.0-6,804.0 IPERF; 6,755.0-6,761.0 SOS; 6,727.0 NIPPLE; 6,719.5 SBE; 6,708.4 PACKER; 6,705.4 LOCATOR; 6,704.0 PRODUCTION; 6,685.7 IPERF; 6,627.0-6,657.0 PRODUCTION; 6,580.0 PACKER - PATCH - LWR; 6,517.8 PRODUCTION; 6,508.6 ANCHOR LATCH; 6,501.0 LEAK - GLM; 6,504.0 PACKER - PATCH - UPR; 6,476.9 PACKER; 6,471.0 SBR; 6,459.4 GAS LIFT; 6,419.7 OVERSHOT; 6,392.9 Tubing Plug; 6,376.0 NIPPLE; 6,375.9 CATCHER; 6,373.0 PACKER; 6,320.9 PBR; 6,307.5 SEAL ASSY; 6,304.5 GAS LIFT; 6,247.9 GAS LIFT; 5,779.2 GAS LIFT; 5,041.6 GAS LIFT; 3,981.6 SURFACE; 37.1-3,023.5 GAS LIFT; 2,506.9 CONDUCTOR; 37.0-116.0 HANGER; 32.8 KUP PROD 2U-08 ... WELLNAME WELLBORE2U-08 STATE OF ALASKA ALr..,r(A OIL AND GAS CONSERVATION COMIviiSSION r , REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r,; Operations Shutdown 1-- Performed Sus end Perforate Suspend r r Other Stimulate r Alter Casing r Change Approved Program'- Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: I- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r 185-021 3.Address: 6.API Number. Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-21284-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25644 KRU 2U-08 9.Logs(List logs and submit electronic and printed data per 20AAC25 071). 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7122 feet Plugs(measured) none true vertical 6209 feet Junk(measured) 6917, 6925 Effective Depth measured 6960 feet Packer(measured) 6321,6471,6705 true vertical 6072 feet (true vertical) 5541, 5665, 5861 Casing Length Size MD ND Burst Collapse CONDUCTOR 79 16 116 116 SURFACE 2986 9.625 3024 2929 PRODUCTION 7008 7 7043 61(11 y` RECEIVED JUN 0 2 2015 Perforation depth: Measured depth: 6627-6657,6755-6761,6765-6804 AOGCC True Vertical Depth: 5795-5820, 5902-5907, 5911-5943 Tubing(size,grade,MD,and TVD) 3 5, J-55,6317 MD, 5538 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER FHL PACKER @ 6321 MD and 5541 TVD PACKER-OTIS RRH PACKER @ 6471 MD and 5665 TVD PACKER-OTIS WD PERMANENT PACKER @ 6705 MD and 5861 TVD no SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mc( Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments(required per 20 AAC 25 070,25 071,&25.283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development I✓ Service r Stratigraphic r Copies of Logs and Surveys Run 16.Well Status after work: Oil F.7 Gas r WDSPL r Printed and Bectronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C O.Exempt none Contact Travis Smith @ 265-6450 Email Travis.T.Smithconocophillips.com Printed Name Tray.- Smith / Title Wells Engineer Signature Phone:265-6450 Date GWl.c._-- v'r i (,//13/,5- A7(9 0 RBDMS4 JUN - 3 2015 Form 10-404 Revised 5/2015 Submit Original Only KUP PROD 2U-08 ConocoPhillip5 '=' Wen attributes Max angle&MD TD ' Wellbore API/UWI Field Name Wellbore Status rax (°) MD(ftKB) Act Btm(ftKB) Alaska.inc. ' 500292128400 KUPARUK RIVER UNIT PROD 44.42 3,500.00 7,122.0 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 20-08,5120120151:25:36 PM SSSV:NIPPLE 78 12/14/2013 Last WO: 5/6/2015 41.79 3/29/1985 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date -- - - --- - a.I Last Tag:SLM 6,896.0 5/17/2015 Rev Reason:WORKOVER,GLV C/O,PULL smsmith 5/20/2015 i HANGER,32.8 I al CATCHER 8 PLUG,TAG ■ Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 37.0 116.0 116.0 62.50 H-40 WELDED �. y Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread mirmusiumeemammisaimm maSURFACE 9 5/8 8.921 37.1 3,023.5 2,929.4 36.00 J-55 BTC ICasing Description OD(m) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I.. Grade Top Thread PRODUCTION 7 6.276 34.7 7,043.0 6,142.8 26.00 J-55 BTC ^^^coNDUCTOR:37.a-ttso I^Tubing Strings Tubing Description I Strang Ma...I ID(in) I Top(ftKB) ISet Depth(ft. Set Depth(TVD)(...l Wt(Ib/ft) !Grade !Top Connection It TUBING-WO-2015 31/2 2.992 32.8 6,317.2 5,538.0 9.301L-80 EUE GAS LIFT.2,5069 Completion Details III Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 32.8 32.8 0.04 HANGER CAMERON McEVOY GEN III HANGER 3.000 6,304.5 5,527.6 34.62 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 2.990 SURFACE;37.1-3,023.5-A . Tubing Description 'String Ma...I ID(in) 'Top(ftKB) Set Depth(ft..f Set Depth(TVD)(...I Wt(Ib/ft) !Grade I Top Connection TUBING-WO-2003 31/2 2.992 6,307.6 6,399.31 5,605.8 9.30 L-80 ABM-EUE Completion Details GAS LIFT;3,981.6 11Nominal ID a Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) • 6,307.6 5,530.0 34.60 PBR BAKER 80-40 PBR 2.990 ■ 6,320.9 5.541.0 34.52 PACKER BAKER FHL PACKER 2.970 GAS LIFT;5,041.6 IC- 6,375.9 5,586.5 34.17 NIPPLE CAMCO DS NO GO NIPPLE 2.812 III 6,392.9 5,600.6 34.06 OVERSHOT BAKER POOR BOY OVERSHOT 3.750 Tubing Description !String Ma...I ID(in) I Top(ftKB) [Set Depth(ft..'Set Depth(TVD)(...IWt(Ib/ft) 'Grade 'Top Connection TUBING Original 4 1/2 2.992 6,397.51 6,727.8 5,879.5 9.30 J-55 FL4S GAS LIFT;5,779.2 ■. Completions Details II Nominal ID al Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) al 6,459.4 5,655.7 33.76 SBR OTIS SBR 2.813 GAS LIFT;6247.9 6,471.0 5,665.4 33.71 PACKER 'OTIS RRH PACKER 2.970 6,588.1 5,762.9 33.58 BLAST RINGS BLAST RING JOINTS 2.992 III • 6,704.0 5,859.6 33.31 LOCATOR OTIS STRAIGHT SLOT LOCATOR 2.970 SEAL ASSY,6,304.51I['-a 6,705.4 5,860.8 33.31 PACKER OTIS WD PERMANENT PACKER 4.000 PBR;6,307.5 - 6,707.9 5,862.9 33.31 ADAPTOR PACKER ADAPTER 2.992 PACKER;6,320.9 6,708.4 5,863.3 33.32 SBE OTIS SEAL BORE EXTENSION 4.000 6,719.5' 5,872.5 33.34 NIPPLE CAMCO D NIPPLE NO GO 2.750 6,727.0 5,878.8 33.35 SOS SHEAR OUT SUB 3.015 NIPPLE:6,3759 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) ITop(TVD) Top Incl Top(ftKB) (ftKB) (°) Des _ Com Run Date ID(in) OVERSHOT;6,392.9 IF 6,476.9 5,670.3 33.68 UPPER 3.5 WIDEPACE LE PACKER(UPPER ASSEMBLY), 10/18/2014 1.750 PATCH OAL=24.1' 1 6,517.8 5,704.3 33.58 LOWER 3.5 WIDEPAC LE PACKER(LOWER ANCHOR), 10/17/2014 1.810' GAS LIFT,6,419.7III PATCH OAL=5.2' 6,917.0 6,037.5 33.26 FISH 1 1/2"CV Dropped in Rathole 1/9/1992 0.000 SSR;6,459.4 Et i 6,917.0 6,037.5 33.26'FISH 1 1/2"DV Dropped in Rathole 1/23/1993 0.000 PACKER;6,471.0 '- 6,925.0 6,044.2 33.26 FISH 1 1/2"CV Lost in Rathole 10/27/1994 0.000 UPPER PATCH;6,476.9 I Perforations&Slots PRODUCTION,6.508.6IC Shot Dens Top(TVD) Btm(TVD) (shots/f LOWER PATCH:e517.8 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 6,627.0' 6,657.0 5,795.3 5,820.3 C-4,UNIT 8, 4/19/1985 12.0 IPERF 5"Dresser Atlas 2U-08 PRODUCTION;6,580.0 "8'. 6,755.0 6,761.0 5,902.2 5,907.2 A-4,2U-08 4/19/1985 4.0 IPERF 4"Dresser Atlas s IPERF:6,627.0-6,657.0-_ t 6,765.0 6,804.0 5,910.5 5,943.1 A-3,2U-08 4/19/1985 4.0 IPERF 4"Dresser Atlas Mandrel Inserts I St li PRODUCTION,6,685.] on NoTop(TVD) Valve Latch Port Size TRO Run 111 Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 1 2,506.9 2,489.9 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,211.0 5/13/2015 LOCATOR;6.704 MI, 2' 3,981.6 3,644.0 CAMCO MMG 11/2 GAS LIFT GLV RK 0.188 1,219.0 5/13/2015 PACKER;6,7054 . _ 3 5,041.6 4,496.5 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.188 0.0 5/13/2015 (.. 4 5,779.2 5,100.5 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/8/2015 SBE;6708.4 7 5 6,247.9 5,481.0 CAMCO MMG 1 1/2 GAS LIFT OV RKP 0.000 0.0 5/12/2015 a 6 6,419.7 5,622.8 CAMCO KBUG 1 GAS LIFT DMY RK 0.000 0.0 9/21/2003 1 _ 7 6,508.6 5,696.7 CAMCO MMG-2 11/2 PROD HFCV RKP 0.000 0.0 10/17/2014 NIPPLE;6.719.5 8 6,580.0 5,756.1 CAMCO MMG-2 11/2 PROD DMY RK 0.000 0.0 11/4/1998 9 6,685.7 5,844.3 CAMCO MMG-2 11/2 PROD DMY RK 0.000 0.0 9/4/2010 805:6727.0 -it- Notes:General&Safety r End Date Annotation IPERF;6,755.0-6761.0- 10/8/2011 NOTE:View Schematic w/Alaska Schematic9.0 1/13/2015 NOTE: FIND TBG LEAKS @ 5102.3'AND 5179.5'RKB IPERF;6,765.0-6 804 0 y 1 FFISISH;H691]6,91]..00, t : FISH:6,925.0 PRODUCTION;34.]-],043.0 ConocoPhillips Time Log & Summary Wellview Web Reporting Report Well Name: 2U-08 Rig Name: NABORS 7ES Job Type: RECOMPLETION Rig Accept: 5/6/2015 5:00:00 AM Rig Release: 5/9/2015 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/04/2015 24 hr Summary Demob Seperate sub and pits Begin moving rig equipment from 2E-15 to 2U pad 19:00 00:00 5.00 MIRU MOVE RURD P Demob from equipment 2E-15 05/05/2015 Continue to Mob to 2U pad from 2E pad. 00:00 10:00 10.00 MIRU MOVE MOB P Move in and spot office and shop. set pits out of the way for sub. 10:00 15:00 5.00 MIRU MOVE RGRP T Rig moving system broke down. (Drive motor) 15:00 18:00 3.00 MIRU MOVE MOB P Continue to move sub from 2C pad to 2U pad. 18:00 00:00 6.00 MIRU MOVE MOB P MI sub base. Stand up derrick. spot base over well. 05/06/2015 Continue to Rig up.. Rig accepted @ 05:00 hrs.Pulled BPV. RU kill lines. Circulated well with 302 BBL's of 8.5 sea water. Flow check. Install BPV. ND D tree NU bope. 00:00 05:00 5.00 MIRU MOVE MOB P Continue to move sub over well. Spot pits. and hook up.Take on sea water to pits. Rig accepted @ 05:00 hrs 05:00 09:30 4.50 MIRU MOVE RURD P Continue to rig up. Bridle down. Rig up floor. Install secondary Annulus Valve. Rig up circulating lines to kill manifold. Blow air through the line to the kill tank. 09:30 11:30 2.00 MIRU WELCTL MPSP P Pick-up Lubricator. Pressure test at 250/1,500 psi. Good. Pull the BPV. Record TP=500, IAP-400, OAP= 250. Lay down Lubricator and BPV. 11:30 12:15 0.75 MIRU WELCTL RURD P Rig up circulating line to the Tree. 12:15 12:30 0.25 MIRU WELCTL SFTY P Hold PJSM for well kill operations. 12:30 15:30 3.00 MIRU WELCTL KLWL P Pressure test line at 250/2,500 psi. Good. Kill Well with Sea Water at 3.0 blm/300 psi. Total volume pumped 300 bbls. 15:30 16:00 0.50 MIRU WELCTL OWFF P Monitor Well x 30 minutes. Static. 16:00 17:00 1.00 MIRU WELCTL RURD P RD circulation equipment 17:00 18:30 1.50 MIRU WHDBO MPSP P Install and test BPV to 1000 psi in flow direction. 18:30 20:30 2.00 MIRU WHDBO NUND P ND tree and adaptor 20 K to pull adaptor free. Inspected hanger good. 20:30 00:00 3.50 MIRU WHDBO NUND P NU BOPE and lines 05/07/2015 Test BOPE. Laid down current completion.Wait on new seal assembly from Baker 00:00 00:30 0.50 MIRU WHDBO NUND P Continue to hook up lines and riser on stack Page 1 of 4 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 06:00 5.50 MIRU WHDBO BOPE P Test BOPE 250/2500 psi:Test Gas alarms. Test waived By Lou Grimaldi AOGCC. Test: 1) BR, Choke 1,2,3,16, Rig floor kill, Outer Test spool, TD HCR, Passed. 2)Choke 4,5,6, HCR kill, Inner test spool.TD man. Pass. 3)Choke 7,8,9, Man kill, HT38 FOSV Pass. 4)Super choke. Man choke 1500 psi bleed down test. Pass 5)Choke 10,11, HT 38 dart. Pass. 6)Choke 12,13,15 Pass 7)Annular W/3.5"TJ , Choke 14, 3.5"8RD FOSV. Pass 8) UPR, Choke HCR, Pass. 9) Man Choke. Pass. 10) LPR, *Pass Perform the Koomey draw down test. 06:00 06:30 0.50 MIRU WHDBO RURD P Blow down lines. Rug down test equipment. Drain Stack. 06:30 07:00 0.50 MIRU WHDBO MPSP P Pull the Test Dart and BPV. Lay down same. 07:00 07:15 0.25 COMPZ RPCOM SFTY P PJSM to discuss the steps and safety concerns to pull the tubing Hanger to the floor. 07:15 08:00 0.75 6,307 6,277 COMPZ RPCOM PULL P Rig up GBR to handle 3 1/2"tubing. Pick-up Pup Joint landing assembly. Screw into the Tubing Hanger(10 1/4 turns). Screw into Top Drive. BOLDS. Saw the Hanger come off seat at 95K. Saw Seals pull free at 125K. Pull the Tubing Hanger to the floor at at—80K with no problems. 08:00 08:30 0.50 6,277 6,277 COMPZ RPCOM RURD P Rig up to circulate Well. 08:30 09:30 1.00 6,277 6,277 COMPZ RPCOM CIRC P Circulate bottoms up(+)at 5.0 bpm/490 psi. No gas/no losses. Monitor Well x 10 minutes. 09:30 14:30 5.00 6,277 1,255 COMPZ RPCOM PULL P Lay down the Tubing Hanger. Up weight=83K. down weight=37K. Single down the 3 1/2"Completion to 1,255-ft. Stop at GLM#3 for Hot Work Permit and picture of a corroded Tubing Collar. 14:30 16:30 2.00 1,255 0 COMPZ RPCOM PULL P Continue o single down the remaining 3 1/2"Completion from 1,255-ft. Up weight=37K. 16:30 00:00 7.50 0 COMPZ RPCOM WAIT T Wait on new seal assembly from _ Baker 05/08/2015 RIH with completion . space out&land . PT Tbg to 300 psi for 15 min's. PT IA to 2500 psi for 30 min's Chart. Shear SOV. IN stalled&test BPV. Inspect BOPE stack 00:00 01:00 1.00 COMPZ RPCOM OTHR P Load tally and drift GLM's and seal assembly Page 2 of 4 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 01:00 10:00 9.00 0 6,307 COMPZ RPCOM PUTB P PJSM RIH with New completion. seal assembly and GLMs.As per program 10:00 11:00 1.00 6,307 6,282 COMPZ RPCOM HOSO P space out well. 11:00 12:00 1.00 6,282 6,282 COMPZ RPCOM CRIH P Pumped 166 BBL's of Conqor treated seawater down IA @ 3 BPM @ 260 psi. 12:00 12:30 0.50 6,282 6,307 COMPZ RPCOM THGR P Engage seal assembly with charge pump.seals in. land hanger SILD. 12:30 14:00 1.50 6,307 6,307 COMPZ RPCOM PRTS P PT Tbg to 3000 psi for 15 min's chart. Bled preesure down to 2500 psi. PT IA to 2500 psi.for 30 min's chart.good test. Shear SOV. Checked circulation ok. 14:00 14:30 0.50 COMPZ RPCOM RURD P RD GBR tbg tongs and landing jt. 14:30 15:00 0.50 COMPZ RPCOM WWWH P Washed BOPE stack. prep for inspection 15:00 15:30 0.50 COMPZ WHDBO MPSP P Install and test BPV to 1000 psi for 5 min's in flow direction 15:30 00:00 8.50 COMPZ WHDBO SVRG P Complete BOPE inspection and change upper VBR to 3.5 X 6"& lowers to 7"Rams 35/09/2015 Fully land hanger. NU tree and adaptor. PT to 250/5000 psi. Freeze protect well to 2000+ft. Rig Released @ 12:00 hrs. 00:00 02:00 2.00 COMPZ WHDBO SVRG P Continue to inspect BOPE and change pipe rams to 7"lower and 3.5 X 6"VBR upper. 02:00 03:30 1.50 COMPZ WHDBO NUND P ND BOPE stack and rack back 03:30 05:30 2.00 COMPZ WHDBO THGR T Hanger was not fully landed. Screwed in landing jt and put 8K down weight on hanger full seated Hanger. RILDS. Removed landing jt. Note: Well head is leaning to the side hanger appeared to cocked to the high side. 05:30 06:00 0.50 COMPZ WHDBO NUND P Nipple up Tree Adaptor Flange. 06:00 06:30 0.50 COMPZ WHDBO PRTS P Pressure test Tubing Hanger void at 250 x 5 minutes. 5,000 x 10 minutes. Good. 06:30 08:00 1.50 COMPZ WHDBO NUND P Nipple up Tree(DSO verified alignment). 08:00 08:30 0.50 COMPZ WHDBO PRTS P Pressure test Tree at 250/5,000 psi. Good. 08:30 11:00 2.50 COMPZ WHDBO FRZP P PJSM. Rig up Lil' Red Services. Pressure test line. Freeze protect well with 75 bbls of diesel at 2.25 bpm/900 psi. Rig down Lil' Red. Allow Diesel to"U-Tube". Blow down lines. Page 3 of 4 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 12:00 1.00 COMPZ WHDBO MPSP P Final wellhead pressures: Tbg =0 psi, IA= psi, OA=0 psi. Set BPV. Secure Cellar. Release Rig at 12:00 hrs. Page 4 of 4 Image Project Well History File Cover Page. XHVZE This page identifies those items that were not scanned during the- initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ~~ - Q~ ~ Well History File Identifier Organization (done) ~ TWO-Sided RESCAN ^ Color items: ^ Grayscale items: ^ Poor Quality Originals: ^ Other: . 5~ TOTAL PAGES. ORGANIZED BY: BE Project Proofing DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type o Re,~~~eea~ uiiiiiuwiiui~i OVERSIZED (Scannable) ^ Maps:. ^ Other items scannable by large. scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds ^ Other NOTES: BREN VINCENT SHERYL MARIA LOWELL DATE: ~ s ~ e ~ ~. /S/ I~~N,~ PROOFED BY: BEVERLY BREN (VINCENTD SHERYL MARIA LOWELL DATE: ~~ ~/~ a~,ISI ',/~ ^ Staff -Proof By: Date: Scanned im..i ~ IIIIII I~ PAGES: ~~ (at the time of scanning) SCANNED BY. BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: ~ f J~, j~ °1 /S/ `~~ ReScanned (done) RESCANNED BY. BEVERLY BREN INCENT SHERYL MARIA LOWELL DATE: P)~ /~ s ~~- ISl ~~ General Notes or Comments about this file: ~r ~ +D~ PAGES:~'~ ~ Q, Quality CMCk11eIIO iao~•~ N IIIIIIIRI Rev1NOTScanned.wpd • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ~. 4;'~._~_ March 5, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 s~ty~~~~~ 1~A~ ~ ~ 20~ Dear Mr. Maunder: _ ~ ; ~~ .. .;... . .a _~yz 1g ~~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped January 18th and January 24th, 2009. The corrosion inhibitor/sealant was pumped February 21St through February 23rd , 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, i~ ~~G~ M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 3/5/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2U-01 185-004 50' 5.90 3'1" 1/18/2009 9.2 2/22/2009 2U-02 185-005 6' 1.20 22" 1/18/2009 3.4 2/22/2009 2U-03 185-006 34' 7.90 2' 1/18/2009 7.4 2!22/2009 2U-05 185-018 40' 6.50 3'S" 1/18/2009 9.4 2/23!2009 2U-06 185-019 54' 7.00 2' 1/18/2009 7.1 2/23/2009 2U-07A 185-091 6' 0.70 2'2" 1/18/2009 4.5 2/23/2009 2U-08 185-021 80' 11.40 2'10" 1/18/2009 5.2 2/23!2009 2U-09 185-038 12' 1.50 22" 1/18/2009 3.6 2/23/2009 2U-10 185-039 6' 0.80 22" 1/18/2009 3.5 2/23/2009 2U-12 185-041 18'6" 2.70 22" 1!18/2009 3.1 2/23/2009 2U-13 184-246 45' 6.50 2' 1/18/2009 5.9 2/23/2009 2U-14 184-247 22' 4.20 22" 1/18/2009 6.1 2/23/2009 2U-15 184-248 26' 3.90 2'2" 1/18/2009 3.6 2/23/2009 2U-16 184-249 64' 8.40 5'2" 1/18/2009 14.8 2/23/2009 2W-01 185-010 27' 3.50 3'9" 1/18/2009 5.2 2/21/2009 2W-02 185-016 12' 6.50 5'9" 1/18/2009 12.3 2/21/2009 2W-04 185-012 55' 8.10 5'4" 1/18/2009 15.1 2/21/2009 2W-05 184-191 22' 2.90 2'3" 1/18/2009 7.6 2/21/2009 2W-06 184-194 16" NA 16" NA 1.4 2/22/2009 2W-07 184-204 56' 6.60 21" 1/24/2009 5.6 2/22/2009 2W-09 184-219 16" NA 16" NA 3.4 2/22/2009 2W-11 184-222 49' 6.00 4'3" 1/18/2009 10.5 2/22/2009 2W-12 184-224 64' 10.00 22" 1/24/2009 2.1 2/22/2009 2W-13 184-236 6'6" 6.00 23" 1/18/2009 5.2 2/22/2009 2W-14 184-237 20'4" 3.30 22" 1/18/2009 3.7 2/22/2009 2W-15 184-238 41' 7.10 2'10" 1/18/2009 3.9 2/22/2009 2W-17 207-135 8" NA 8" NA 1.1 2/22/2009 `, ~ / / / I ((( %- p/// / - i~/ ~ ~. NO. 5005 Schlumberger -DCS • 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 ~ ,., , ~;: ~ ~''C~, Attn: Christine Mahnken ATTN: Beth ~~. ,, ~' ~. ,.% ~~~'+~`; ~- ~ ! l1 ~.~ ~ 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk 12/17/08 Well Job # Log Description Date BL Color CD ~~ 2X-10 11978476 PRODUCTION PROFILE / - ~ 08/17/08 1 1 2V-09 12100460 PRODUCTION PROFILE (p 11/16/08 1 1 1Y-06A 12100461 PRODUCTION PROFILE 11/17/08 1 1 2X-12A 12100464 PRODUCTION PROFILE q '^ 11/21/08 1 1 2U-08 12096574 PRODUCTION PROFILE ~- 11/28/08 1 1 3K-108 12100466 USIT 11/23/08 1 1 3K-30 12097433 LDL ~ - / _ 11/28/08 1 1 30-01 12097434 LDL -Q '~- 11/29/08 1 1 1E-04 12097436 LDL T 11/30/08 1 1 3A-04 12097432 INJECTION PROFILE ~ - 11/27/08 1 1 1 H-16 12096581 PRODUCTION PROFILE ~ - 12/05/08 1 1 3A-O6 12114994 BAKER LOWER STRADDLE PACKER 11/26/08 1 1 2U-14 12096578 INJECTION PROFILE C --- ~ 12/02/08 1 1 1G-06 12096580 INJECTION PROFILE 12/04/08 1 1 2V-10 12096582 PRODUCTION PROFILE - 12/06/08 1 1 3F-01 12086694 PRODUCTION PROFILE - -" 12/07/08 1 1 2W-14 12086695 INJECTION PROFILE 12/08/08 1 1 1J-102 12086701 INJECTION PROFILE 12/14/08 1 1 1D-07 12114999 USIT 12/i5/08 1 1 3C-02 12114997 INJECTION PROFILE - ~ 3 12/13/08 1 1 2T-18 12086703 INJECTION PROFILE ~ 12/17/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. al~~lr[I~II~~~~rl- Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~ , , ~ «~~~, tnAnmrsai~~i~~s AUG ~ ~ ~p7 ~". , . ~'' " ~~~ Log Description G~„~---- Date NO. 4384 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL Color CD 08/22/07 1R-27 11850425 FPIT /q/-/pa. 08/18107 1 31-08 11839638 LDL 07/28107 1 2M-19 11813070 INJECTION PROFILE 07/29/07 1 3G-26 11813071 LDL - 07/30107 1 1R-18 11837482 SBHPIDDL ~ 07131!07 1 1Y-01 11813072 INJECTION PROFILE UT.C ° 3 b 07/31107 1 2C-08 11813073 INJECTION PROFILE' ~ 08/01107 1 3H-32 11837483 LDL 08/01/07 1 1Y-10 11837485 INJECTION PROFILE ' (~~,~ / - 08/03107 1 3G-08 11813075 PRODUCTION PROFILE' _ (O 08/04107 1 1A-06 11837486 INJECTION PROFILE !_ 08/04107 1 2N-337B 11837489 PRODUCTION PROFILE 08106/07 1 2U-08 11813076 LDL - 08/06/07 1 1G-12 11837490 PRODUCTION PROFILE /~ - ~ 08107/07 1 2N-343 11745232 MEM INJECTION PROFILE ~ / 08/08/07 1 2N-327 11837491 SONIC SCANNER ~ 08/08/07 1 2N-327 11837491 SONIC SCANNER-FMI 08/08/07 1 3K-01 11632749 PRODUCTION PROFILE (o - 08/12107 1 2X-04 11846430 INJECTION PROFILE -j( 08/13107 1 2Z-29 11850419 SBHP SURVEY J'~ - 08/13107 1 2X-19 11850420 SBHP SURVEY ~- 08/13107 1 1A-20 11850421 SBHP SURVEY 08114/07 1 1F-13 11850422 SBHP SURVEY 08114/07 1 1H-10 11846432 SBHP SURVEY - 08/14/07 1 1Q-10 11846431 SBHP SURVEY - 08/14/07 1 2U-05 11846433 INJECTION PROFILE 08/15107 1 2D-12 11846434 PRODUCTION PROFILE c - 08/16107 1 2H-06 11846435 LDL 08/17107 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. a'~' • 12/30/05 Schlumber~er Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~~ ~~~ .~,".`~ ~ 9 ZD~b -'~ av~~ ~ ~ ~ ' ~S ~5. ~+?iTln#S.'siGli Log Description NO. 3638 Company: Alaska Oil ~ Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 2D-02 N/A SHUT IN BOTTOM PRESSURE 12!03!05 1 1A-07 N/A INJECTION PROFILE 12/06!05 1 1 H-21 11166748 PROD PROFILE W/DEFT 12/26/05 1 2X-12A 11166749 PROD PROFILE W/DEFT 12/27/05 1 2U-08 -~ ~ 11166750 PROD PROFILE W/DEFT 12/28/05 1 2X-13 11144057 GLS 12/25/05 1 2V-11 11166736 PROD PROFILE W/DEFT 12/16/05 1 3Q-09 11166737 LDL 12/17/05 1 3S-21 11166738 INJECTION PROFILE 12/18/05 1 3F-17 11144054 PROD PROFILE W/DEFT 12/22/05 1 2X-15 11144058 PROD PROFILE W/DEFT 12/26/05 1 3Q-09 11144055 LDL 12/23!05 1 2V-01 11144050 INJECTION PROFILE 12/24/05 1 SIGNED :~~~~~ ~~ ~ ~~~~ DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 06124/03 Schlumherger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well Job # Log Description N0.2879 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 3S-17A '' ~ ~ SBHP SURVEY 05107103 1 3S-06 •• ,~ PERF RECORD WISBHP & JEWELRY LOG 05/25103 1 3S-08B - ~~ PROD PROFILE WlTEMP SURVEY 05124103 1 3S-23 ~ ~~- ~ PRODUCTION PROFILE 05110103 1 1H-17 C ` ~ PRODUCTION PROFILE 05!14103 1 2U-08 SBHP SURVEY 05/09103 1 1 R-14 LDL 05!08103 1 3F-01 "-; ~ PRODUCTION PROFILE 05!19103 1 1 D-103 ~ MEM PSP INJECTION PROFILE 04104/03 1 3S-17A; ~ , " 23351 SCMT 05!07103 1 3S-06 , 23353 SCMT 05123/03 1 ~` SIGNED: ~~ ~ `~ ,~ ' 'i i ^1 '',fir M ~ '~• '~~S'V :~ DATE: _ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. :~~, ~ ~ ~ ;;; ~ ~ i. ; , , ;'.; ;~„?~,3~ic;,r; ~;, ~~r . ConoCOPhillips Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 October 6, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 2U-08 (APD # 185-021) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on the Kuparuk well 2U-08. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad ORIGiitAi, REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon [] Suspend [ Operation Shutdown [] Perforate ~] Variance Alter Casing r-'l Repair Well [-~ Plug Perforations [~ Stimulate r-~ Time Extension [-"] Other r-'l Change Approved Program r--] Pull Tubing r--I Perforate New Pool [--1 Re-enter Suspended Well 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development [-~ Exploratory r~ 185-021 / 3. Address: Stratigraphic ~] Service E~ 6. APl Number: P. O. Box 100360, Anchora~le, Alaska 99510 50-029-21284-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 106' 2U-08 8. Property Designation: 10. Field/Pool(s): ADL 25644 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7122' feet true vertical 6209' feet Plugs (measured) 6480' Effective Depth measured 6783' feet Junk (measured) 6917' true vertical 5926' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 116' 16" 116' 116' SUR. CASING 2990' 9-5/8" 3023' 2929' PROD. CASING 7010' 7" 7043' 6143' .. . ,. , ~ .,,., Perforation depth: Measured depth: 6627'-6657', 6755'-6761', 6765'-6804' . .......... ~ ...... .. . true vertical depth: 5795'-5820', 5902'-5907', 5911 '-5943' '~ ''~ '~- ~) Tubing (size, grade, and measured depth) 3-1/2", L-80/J-55, 6728' MD. " ' · ,. · Packers & SSSV (type & measured depth) pkr= Baker FHL, OTIS 'RRH' · OTIS 'WD' PERM. pkr= 6321" 6471' · 6705' SSSV=none SSSV= none 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin,q Pressure Tubin,q Pressure Prior to well operation SI Subsequent to operation 457 1484 3722 - 220 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run __ Exploratory ~ Development r~ Service [] Daily Report of Well Operations __X 16. Well Status after proposed work: Oi11-3-] Gas[]'-] WAG[-] GINJ r-1 WINJ r~ WDSPLE~ - i7. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name M,i,ke ~ooney Title Wells Group Team Leader Signature ET,_. j~, Phone Date /' · Prepared by ,~,ha ron A//sOp;Drake, 263.4612 Form 10-404 Revised 2/2003 · OR GtNAI SUBMIT IN DUPLICATE ConocoPhillips Alaska Page I of 9 Operations Summary Report Legal Well Name: 2U-08 :Common Well Name: 2U-08 Spud Date: 3/24/1985 'Event Name: WORKOVER/RECOMP Start: 8/25/2003 End: 9/5/2003 Contractor Name: nabors3scompanym@conocop Rig Release: 9/5/2003 Group: Rig Name: Nabors 3S Rig Number: Date From- To Hours Code Sub Phase Description of Operations Code 8/25/2003 19:30 - 00:00 4.50 MOVE RURD MOVE Prep for move. Scope mast down. Lay mast down. Separate modules. 8/26/2003 00:00 - 01:00 1.00 MOVE RURD MOVE Separate modules from carrier sub. 01:00 - 01:30 0.50 MOVE MOVE MOVE Move carrier sub away from 2U-02. Road rig around pad to 2U-08. 01:30 - 04:30 3.00 MOVE RURD MOVE Spot mats around wellhead. Back rig over well to check alignment. Pull forward. Lay out Herculite and mats. Back carrier over well. Mate up pipe shed and pit modules. Move rig camp. 04:30 - 09:00 4.50 MOVE RURD MOVE Positioned BOP's behind the rig. Raised derrick. 09:00 - 12:30 3.50 WELCTL NUND DECOMP Accept the rig. Nippled down the tree, found the flange on the tbg spool to be corroded and tubing head adapter also corroded badly. Both will have to be replaced, and and started Nippling up the BOP's.Shipped tree into valve shop for redress. 12:30 - 13:30 1.00 WELCTL SFTY DECOMP Pre-Spud Meeting Held w/Day Rig Crew, Day & Night Toolpusher, M-I Rep, Baker Rep, Cameron Rep, Rig Supv's, & Workover Eng. 13:30 - 15:30 2.00 WELCTL NUND DECOMP Finished NU BOP's. Pulled BPV and installed Test Plug. Well is dead. Function tested BOP's 15:30 - 16:30 1.00 WELCTL BOPE DECOMP Begin loading the Pipe shed. OA is at 400 psi, started bleeding this down to bleed tank. 16:30 - 22:00 5.50 WELCTL BOPE DECOMP Testing BOP had some pkg on lock down screws that had to be tightened. Continued loading the pipe shed, and bleeding the OA. Pre-Spud Meeting Held w/Night Rig Crew, Day Toolpusher, Rig Supv's, completed at 2100 hrs. BOP test complete @ 2200 hrs. 22:00 - 23:00 1.00 FISH PULL DECOMP Screw landing joint into hanger- back out LDS. Pull up on tubing string to 100K three times. Bounced back down to help break seals loose. Pulled up to max. pull @ 108k and set brake. Watched seals let loose. Pulled hanger to rig floor. Lay down landing joint and hanger. String weight approx. 65k. 23:00 - 00:00 1.00 FISH CIRC DECOMP Well unstable - start reverse circulating surface to surface @ 3 bpm to re-balance well. Gave AOGCC 24 hour notice of BOP test upcoming for casing packoff changeout. 8/27/2003 00:00 - 07:15 7.25 FISH ClRC DECOMP Continue circulating surface down tubing and up casing and reversing down casing and up tubing - worked pipe up and down. 3 bbl/min max rates. Pulled 80% of pipe strength. Held tension/bounced pipe/slacked off while pumping. Called in slickline/another pump truck and put eline on standby. Continue to circulate with the pipe under tension the long way. 07:15- 07:45 0.50 FISH ClRC DECOMP Pre-Job safety Mtg with LRS 07:45 - 08:50 1.08 FISH CIRC DECOMP Move in a LRS pump and begin circulating down the tubing @ 5 bpm. Tubing pressure 950 psi. Worked pipe free. Unable to move up past the initial sticking point. The pipe will move freely down. Pipe was worked between 6434' & 6440' 08:50 - 11:30 2.67 FISH ClRC DECOMP Continued circulating @ 5 bpm and working pipe. With the same results. Total fluid circulated 1300 bbls of 9.6# brine @ 5 bpm. 11:30 - 13:30 2.00 FISH PULD DECOMP Shutdown LRS Pump and RU s/line and installed 1-1/2" dummy valve in GLM #9 6389' wlm 6419' rkb. RD s/line. Nabors performing pump maintenance while s/lining. 13:30 - 14:45 1.25 FISH ClRC DECOMP Rigged back up LRS pump and pressured uP tubing to 1500 psi and unable to circulate. The pressure was bleeding back slowly. Pumped back up to 2000 psi and pressure continued to bleed back slowly. Pumped back up to 2300 psi and returns and bled back picked up. Continued to pump up on tubing and returns increasing but unable to maintain a rate. 14:45 - 15:30 0.75 FISH CIRC DECOMP Rig pump is down and due to the repairs being done unable to use the Printed: 9/12/2003 8:23:24 AM ConocoPhillips Alaska Page 2 of 9 Operations Summary Report Legal Well Name: 2U-08 Common Well Name: 2U-08 Spud Date: 3/24/1985 Event Name: WORKOVER/RECOMP Start: 8/25/2003 End: 9/5/2003 Contractor Name: nabors3scompanym@conocop Rig Release: 9/5/2003 Group: Rig Name: Nabors 3S Rig Number: SUb Date From-TO Hours Code Code Phase Description of Operations 8/27/2003 14:45 - 15:30 0.75 FISH CIRC DECOMP blocks. Continued pumping up on the tubing to 2300 psi, surging some, and monitoring returns. 15:30 - 17:15 1.75 FISH CIRC DECOMP Able to move the blocks again. Move pipe up with pressure on it. Made another 1' up to 6433' but hung up again and unable to move up or down. Bled pressure off of the tubing and worked the pipe free again back at 6434'. Hung off and attempt to circulate and surge the Csg by shutting in the returns and building pressure on Csg to 750 psi and dumping the choke. Rig had to take the blocks down again for repairs. 17:15 - 20:00 2.75 FISH CIRC DECOMP Able to maintain pump rate @ 1/10th bpm @ 2300 psi. Continue to circulate and waiting on rig repairs for the use of the blocks. 20:00 - 21:00 1.00 FISH CIRC DECOMP Blocks back on line - work pipe from 60,000# to 85,000# - hanging up but able to break loose going down. Worked pipe between 6434' & 6440' Unable to change cimulation. Rig up landing joint to attempt to go over slipstick. 21:00 - 22:00 1.00 FISH CIRC DECOMP Shut down LRS pump down tbg. Well started drinking immediately- :lost 47 bbls downhole in 10 minutes. Slacked off tubing to attempt to stab onto slipstick. Saw approx. 8 feet of travel over the 12 foot slipstick. Hole losses stopped and regained control of well. 22:00 - 23:30 1.50 FISH CIRC DECOMP Discussed with engineering - decided to pressure test and assure packer is intact. Line up LRS down tbg. and pressure up to 2000 psi - close annular bag and monitor pressure on casing. Casing pressure steadily increased. Bled tubing to zero and pressured up casing to 1000 psi. Equalized with tubing and held pressure for 15 minutes. Combo MIT passed. Packer seemed intact. 23:30 - 00:00 0.50 WELLSI; OTHR DECOMP Rig up eline for string shot and chemical cut. Held safety meeting concerning chemical cutter. 8/28/2003 00:00 - 03:00 3.00 LOG RURD DECOMP MIRU SWS Eline equipment for string shot and chemical cut. Slacked off blocks during rig up and tubing fell another 4 feet over slickstick. All 12' of slickstick now swallowed and tubing appears to be bottomed out on slickstick. 03:00 - 04:30 1.50 LOG RURD DECOMP Eline rigged up and lubricated above a full opening TIW valve - RIH w/ string shot to clear tubing of scale and debris in prep for a chemical cut. 04:30 - 06:00 1.50 LOG OTHR DECOMP Shot string shot mid joint above GLM #9 in prep for chemical cut. Good indication of proper fire. POOH to load 2 3/8" chemical cutter. 07:45 - 10:00 2.25! LOG OTHR DECOMP Make up the chemical cutter and hold a pre-job safety meeting with all involved. 10:00 - 11:30 1.50 LOG OTHR DECOMP Started in the hole with the chemical cutter. Tied in w/e/line. Pulled up on the tubing from 20K up to 70K picking up pipe weight, 4-1/2" and well started to drink fluid @ 5 bpm. slacked back off on the pipe and it gained control quit drinking fluid. 18 bbls total fluid loss. Called town to disuss the situation. 11:30 - 15:00 3.50 LOG OTHR DECOMP Had SWS pull the chemical cutter OOH. Called out Halliburton s/line. Rig off SWS to the side. 15:00 - 18:30 3.50 WELLSF OTHR DECOMP RU Halliburton S/line and pulled dummy valve from GLM #9 @ $403' wlm 6419' rkb. Drifted tubing w/2.775" down to the top of the WRP @ 6454' wlm 6478' rkb. RD S/line. 18:30 - 00:00 5.50 WELCTL CIRC DECOMP Watered back 9.6# brine to 9.2# brine - circulated surface to surface until wellbore entirely 9.2#. Picked up from 50K to 63K (total of 8') on tubing while watching hole - still 4' of seals engaged. Well started taking fluid rapidly (about 4 bpm). Slacked off tubing to sit back down on packer and slipstick @ 25K. Fluid loss went to minimal - still losing fluid (calculated 5 bbl/hour loss). Begin building bridging agent. 8/29/2003 00:00 - 05:00 5.00 WELCTL CIRC DECOMP Mixing bridging agent to attempt to seal packer/seal bore leak. Pumped Printed: 9/12/2003 8:23:24 AM ConocoPhillips Alaska Page 3 of 9 Operations Summary Report Legal Well Name: 2U-08 Common Well Name: 2U-08 Spud Date: 3/24/1985 Event Name: WORKOVER/RECOMP Start: 8/25/2003 End: 9/5/2003 Contractor Name: nabors3scompanym@conocop Rig Release: 9/5/2003 Group: Rig Name: Nabors 3S Rig Number: Sub Phase Description of Operations Date From -To Hours Code Code 8/29/2003 00:00 - 05:00 5.00 WELCTL ClRC DECOMP ,5 bbls HEC (2#bbl) - 3 bbls HEC w/100#/bbl Cal. Carbonate mixture - 5 bbls HEC followed by 43 bbls 9.2#. Picked up pipe and allowed well to swallow pill maintaining slight positive pressure on tubing side. 05:00 - 07:00 2.00 WELCTL ClRC DECOMP Pill was swallowed by well - slacked off pipe to attempt to reseal losses. Unable to shutdown fluid loss @ 90-100 bbl/hour. Gained another 1 foot down past last sit down (packer sliding downhole until lower packer seals seated?). Mix up another 5 bbl HEC pill with 100#/bbl Ca. Carb. chased by 9.2#. brine. Pumped to open GLM and slowed rate to 1/2 bbl/min to let pill fall. 07:00 - 08:00 1.00 WELCTLICIRC DECOMP Shut down pump and refilled backside to monitor losses. Watch well to see if Safe-Carb sealed leak. Fluid loss @ 1.30 bpm. 08:00 - 10:00 2.00 WELCTI. CIRC DECOMP Reduced brine weight to 9.1# and vis up fluid w/1/2# per bbl HEC. Pumping down the tubing and monitoring hole fill & returns @ 1 bpm maintain hole level. Fluid losses dropped to 1 bpm. 10:00 - 11:30 1.50 WELCTI. ClRC DECOMP Fluid losses dropped to 3/4 to 1/2 bpm. Reduced the brine weight to 9.0+# continued to add HEC @ 1/2# per bbl. Raised pump rate to 1-1/2 bpm. 11:30 - 13:30 2.00 WELCTL CIRC DECOMP Raised pump rate to 2 bpm. Started getting viscosified brine 9.2# in returns. 13:30 - 16:00 2.50 WELCTL CIRC DECOMP Raised the pump rate to 2-1/2 bpm. Consistently loosing 1/2 bpm at this rate. Continued circulating 9.0+# down the tubing and gettting 9.1# back. 16:00 - 17:00 1.00 WELCTI. OBSV DF:COMP Shut down the pump and monitor hole for static losses, when well is static with 9.0+# to 9.1# the fluid loss is 1/3 bpm. Monitored for I hour and it is consitently losing the same amount 1/3 bpm. Total fluid loss for the day at this point is 705 bbls. 17:00 - 21:30 4.50 WELCTL ClRC DECOMP Started pumping 8.9+# to 9.0-# vis¢osified brine down tubing at 2-1/2 bpm - losses at 6-7 bbl per 15 min. Circulating ECD~9.3# 21:30 - 22:00 0.50 WELCTL OBSV DECOMP Shut down pump. Monitor hole for 15 min. Lost 3.2 bbls or 12.8 bbl/hour. Picked up pipe from 15K (sitting on packer) to 55K (neutral weight of pipe) - refilled hole and monitored for 15 min. Lost 5 bbls in 15 min. Or 20 bbls/hour. Consult with Eng. and decided to chemical cut tubing. Sit back down on packer and circulate 8.9# heavy in with returns still 9.0# even. 22:00 - 00:00 2.00 WELLSR OTHR DECOMP MIRU Eline unit for chem. cut of tubing above bottom GLM @ 6402' ELM - stopped circulating and losses continue @ 12-20 bbls/hour. Filling backside using charge pump. Safety meeting on chemical cutter safety. Lost a total of 830 bbls to formation midnight to midnight. 8/30/2003 00:00 - 04:00 4.00 WELLSR OTHR DECOMP Eline chemical cut mid joint above bottom GLM @ 6381' ELM. POOH w/Eline. Sit 100' below top while regaining well balance - pumped 60 bbls down tubing to regain well balance. Broke out lubricator joint and installed TIW. Losing 20 bbls/hour to formation. Pulled up about 30 feet to assure we were free. RIH with pipe to slowly tag top of stub. Found stub 7.5' higher than where we left it. Pulled pipe up 18' above stub and set slips. Rigged down Eline equipment and prep to rekill well. 04:00 - 08:00 4.00 WELCTL CIRC DECOMP Circulate surface to surface 225 bbls to rebalance well. Currently 22 bph losses to formation. Pumping 8.9+ in and returning 9.0#. Decided to pump 5 bbl. pill 100#/bbl calcium carbonate downhole to slow losses in prep for storm packer installation. After pill initial losses increased to 32.4 bph. Over the course of 1 hour losses decreased to 18 bph. Call for MI to come up with another plan. 08:00 - 11:45 3.75 WELCTI. CIRC DECOMP Batch up 15 bbl Calcium Carbonate Pill 100# per bbl. Checked pipe weight 56K up and 47K down. Pumped the pill, layed in and let settle Printed: 9/12/2003 8:23:24 AM ConocoPhillips Alaska Page 4 of 9 Operations Summary Report Legal Well Name: 2U-08 Common Well Name: 2U-08 Spud Date: 3/24/1985 Event Name: WORKOVER/RECOMP Start: 8/25/2003 End: 9/5/2003 Contractor Name: nabors3scompanym@conocop Rig Release: 9/5/2003 Group: Rig Name: Nabors 3S Rig Number: Date From-To Hours Code Sub Code Phase Description of Operations 8/30/2003 08:00 - 11:45 3.75 WELCTL ClRC DECOMP out above stub. Moved pipe continuously during lay in and settle. 11:45 - 12:30 0.75 WELCTL CIRC DECOMP Monitor hole for fluid loss. Fluid losses ranging from 10 bph to 6 bph. 12:30 - 14:30 2.00 CMPLTN PULD DECOMP Removed 5 joints and a couple of 10' pups. Monitored hole for fluid loss. Fluid losses still bouncing between 10 bph and 6 bph. 14:30 - 16:30 2.00 WELCTL CIRC DECOMP ~ Pumped a 10 bbl Calcium Carbonate Pill 100# per bbl. Pulled up 1 joint and monitor hole for fluid loss. 7 bph to 5 bph. Circulate over top of the hole to keep the hole full. 16:30 - 17:00 0.50 CMPLTN PULD DECOMP Pulled 4 more joints monitoring fluid loss and keeping the hole full. 7 bph to 5 bph fluid loss. 17:00 - 00:00 7.00 CMPLTN PULD DECOMP Started pulling tubing and keeping hole filled. Pulled all control line and recovered 35 bands (one more than we were told were in the well). Layed down SSSV. Continued out of hole with tubing at approx. 25 joints/hour speed. 10 bbl/hour fluid loss at this point. 108 joints pulled at midnight with 387 bbls lost to formation over the last 24 hours. 8/31/2003 00:00 - 01:30 1.50 WELCTL OBSV DECOMP Noticed well bubbling gas while still taking 10 bbl/hour loss. Stopped pulling pipe to monitor well. 7 bbl pit gain with gas breaking out in 20 minute time frame. Gas kick in progress. Shut in annular bag and installed TIW valve. Monitored pressure under bag and gradual increase to 90 psi. Weighted up 8.9+# viscous brine to 9.1# in pits. Opened choke to bleed pressure off to 30 psi slowly. 01:30 - 04:00 2.50 WELCTL ClRC DECOMP Began cimulation @ 1/2 bpm @ 35 psi choke pressure. Gas and oil in returns to pits. 103 bbls volume around at this depth. Continue circulating 140 bbls around and circ'd out gas kick. Open bag to monitor well. 04:00 - 06:00 2.00 WELCTL CIRC DECOMP Losing 20 bbls/hour static - start cim 2.5 bpm 9.1# down tubing and up casing to check for another gas bubble. Monitor well static (flowing over the top) for loses. 06:00 - 08:00 2.00 WELCTL CIRC DECOMP Closed the annular bag and start to circulate w/9.1# @ 1.5 bpm. Crude and gas in the returns, routed returns through the gas separator. Fluid losses @ 25 bph. 08:00 - 12:00 4.00 WELCTL:ClRC DECOMP Batched up Calcium Carbonate Pill ( Carb 250 = 71#, Carb 40 = 48#, Plugit 500 = 15#) for a total of 134# per barrel. 35 bbl volume. 12:00 - 14:30 2.50 WELCTL:CIRC DECOMP Circulating down the tubing @ 2 bpm 9.1# brine. Shut in on tubing and started down the backside with 35 bbl 134# CC pil @ 1 tol.5 bpm. 152 bbls away started to pressure up 1500 psi. Shut down pump and bled back pressure. Swapped over to the tubing side and started pumping taking returns. Moved pipe up and down everything looks OK. Continued with bullheading the pill. 14:30 - 15:30 1.00 WELCTI. ClRC DECOMP Discovered pump not pumping at the rate it is showing. In fact the pump is not pumping at all. Bled all pressure off and moved pipe up and down. Using charge pump able to circulate down the tubing taking returns to pits. Go over pit volumes closely. 15:30 - 16:30 1.00 RIGMNT RGRP DECOMP Troubleshoot mud pump. Found suction screens plugged and junk caught under a valve. Called in LRS for pump back-up if needed. Rig mud pump repaired. 16:30 - 17:30 1.00 WELCTL ClRC DECOMP Circulated down the tbg and take returns on backside, surface to surface 103 bbls, looks good. Prepare to run in with tubing. 17:30 - 23:30 6.00 WELCTL TRIP DECOMP RIH with tubing very slowly monitoring hole closely. Normal displacement returns to the pits. Stopped every 10 joints to monitor hole. Did not see any bridges and well was stable. Stopped above stub with 109 joints added @ 6361' MD. Stub at 6381' MD - stayed 20' above stub to avoid damage. 23:30 - 00:00 0.50 WELCTL CIRC DECOMP Started circulation @ 2330 hrs. Circ'd out large gas bubble along with Printed: 9/12/2003 8:23:24 AM ConocoPhillips Alaska Page 5 of 9 Operations Summary Report Legal Well Name: 2U-08 Common Well Name: 2U-08 Spud Date: 3/24/1985 Event Name: WORKOVER/RECOMP Start: 8/25/2003 End: 9/5/2003 Contractor Name: nabors3scompanym@conocop Rig Release: 9/5/2003 Group: Rig Name: Nabors 3S Rig Number: Sub Phase Description of Operations Date From- To Hours Code Code 8/31/2003 23:30- 00:00 0.50 WELCTI. CIRC DECOMP crude oil. Continue circulation down tubing and up casing pumping 9.1# viscosified brine @ 3 bpm with 100% returns. No lost bbls. Formation appeared to be sufficiently plugged. Continue circulation for two bottoms up (334 bbls). 9/1/2003 00:00 - 02:15 2.25 WELCTL ClRC DECOMP Completed circulation of more than two bottoms up - 350 bbls total 3umped. No losses to formation. Well settled down to smooth returns with very little gas breakout. Shut down pump and watched hole for 15 minutes. No fluid loss. Slacked off tubing from 55K hanging weight to .50K. Decided not to tag stub. Possible fill 20' above stub. Checked for fluid level in tubing. Had to pump a dry job - 20 bbls 9.9 weighted up viscosified brine to assure dry tubing. 02:15 - 06:00 3.75 FISH PULL DECOMP Pull out of hole standing doubles in derrick with the new tubing that was run (54 stands). Layed down old tubing in pipe shed (2970'). 06:00 - 10:00 4.00 FISH PULL DECOMP Continued laying down singles in the pipe shed. NORM checking all tubing. Stub @ surface. Stub cut looks good. Measured OD of pipe @ cut 3.58". Found Jt #,s 200, 201,202 (1/2 jt) visibily corkscrewed. Very moderate corrosion seen on a few collars. 10:00 - 12:45 2.75 CMPLTN PULD CMPLTN Unload old tubing from the pipe shed. Strap and drift completion jewelry. 12:45 - 13:15 0.50 CMPLTN SFTY CMPLTN Held Pre-job meeting to go over completion run. 13:15 - 21:00 7.75 CMPLTN RUNT CMPLTN Run completion per procedure. 21:00 - 22:30 1.50 CMPLTN ClRC CMPLTN Sat down weight about 3 joints above stub - start reverse out with bag shut. Worked through hard spot and attempted to add another joint. Well unbalanced and elected to circulate surface to surface. 22:30 - 00:00 1.50 CMPLTN ClRC CMPLTN Broke connection and added joint #198 - shut bag and reverse circulate - work slowly down another 30' and started full bottoms up plus to clear tubing. Tubing stub at 6402' RKB - should be middle of joint #199. Procedure is shut down pump / break TIW valve out / add joint / open bag / and RIH past collar before shutting bag and circulating again. 9/2/2003 00:00 - 03:00 3.00 WELCTL ClRC CMPLTN Adding joint # 199 to attempt to get over stub. Reverse circulating and RIH slowly while cleaning pill from top of stub. Washed over stub and saw pressure increase from 300 to 400 psi on the backside. Washed over stub three times and pulled up 3 feet to circulate. Heavy calcium carbonate returns to the pits. Circulated until clean - 350 bbls. No losses no gains. 03:00 - 05:00 2.00 CMPLTI~ PCKR CMPLTN Drop ball and rod to RHC plug to set stacker packer (Baker FHL). Pressured up to 1600 psi and set packer - continued up to 2500 psi and watched pressure for 10 minutes. Bled off pressure to 1500 psi and pulled up on tubing to 62K (approx. 8K over tubing weight) Sheared out of PBR. Pulled up 20' and sat back down over PBR to same mark on pipe (21' up joint #199). 05:00 - 05:30 0.50 WELLSF PLGM CMPLTN Pulled three joints out to set storm packer. Ran and set storm packer top @ 35' below RKB (14' below Tubing Spool) 05:30 - 06:30 1.00 WELLSF DEQT CMPLTN Pressure tested to 1000 psi for 15 min. Drain stack and prep to pull BOP stack. 06:30 - 10:30 4.00 WELCTI. NUND CMPLTN ND the BOP's. Removed Tubing Spool. 7" csg stub rose about 2-3/4" due to trapped compression when tubing head was removed. Locate air saw to cut off 7" stub. Clean out old plastic packing, remove old 7" primary packoff, & install new 7" primary packoff while cutter being delivered to rig. Cut off 2-3/4" of 7" stub with air saw & dress off with grinder. 10:30 - 11:30 1.00 WELCTL NUND CMPLTN NU new ClW tubing head. Test packoffs & flange to 3000 psi, OK. Witnessing of test waived by Chuck Scheve, AOGCC Field Inspector. Printed: 9/12/2003 8:23:24 AM ConocoPhillips Alaska Page 6 of 9 Operations Summary Report Legal Well Name: 2U-08 Common Well Name: 2U-08 Spud Date: 3/24/1985 Event Name: WORKOVER/RECOMP Start: 8/25/2003 End: 9/5/2003 Contractor Name: nabors3scompanym@conocop Rig Release: 9/5/2003 Group: Rig Name: Nabors 3S Rig Number: Sub Phase Description of Operations Date From- To Hours Code Code 9/2/2003 11:30 - 14:30 3.00 WELCTL: BOPE CMPLTN NU BOP stack, choke & kill lines. Set test plug. Test breaks to 250 psi & 4000 psi, OK. Witnessing of test and requirement for full weekly test waived by Chuck Scheve. 14:30 - 15:30 1.00 WELLSF PLGM CMPLTN MU retrieving tool on joint of tubing. Engage storm packer at 35', rotate storm valve open and monitor well - static. Pull storm packer & LD. 15:30 - 17:00 1.50 CMPLTI~ SOHO CMPLTN MU joint #196. MU space out pups (7.97' btm + 8.07' mid + 10.10' top). MU joint #197 & tubing hanger. Land hanger. RILDS. 17:00 - 18:00 1.00 CMPLTI~ DEQT CMPLTN RU to test tubing & packer. Getting slow return from annulus with charge pump, possible expansion. 18:00 - 20:00 2.00 CMPLTN ClRC CMPLTN BOLDS. PU hanger to floor, unsting from PBR to verify circulation, pressured up to -700 psi, bleeds off slowly (possible LCM, CaCO3 fill). Slack off and tubing takes weight, possible fill. LD tubing hanger. Close bag & reverse circulate. Wash down, hole packed off at 6361', and pressured up to -2000 psi before pump quit rolling - acted like valve in bottom GLM sheared open. Resume reverse circulating, washed down about 1-1/2' and broke through bridge. Continued reversing and washing down to top of PBR barrel. 20:00 - 21:00 1.00 CMPLTN DEQT CMPLTN Stab into PBR. Set down 2' high. Could be CaCO3 fill in tubing. Close annular preventer. Pressure up on annulus. Tubing pressure rising equal to annulus. Pressure up to 1500 psi. Hold for 15 min. Good test. Bleed off pressure. 21:00 - 22:00 1.00 CMPLTN SOHO CMPLTN Pull space out pups to floor. Remove 8.07' pup and replace with 6.05' pup to make up for tagging 2' high in PBR. 22:00 - 00:00 2.00 CMPLTN ClRC CMPLTN Clean pits to remove CaCO3 in bottom of pits. Take on 9.6# brine in pit #2. Install 250 mesh screens on shaker. Mix 30 bbl 9.6# viscosified sweep. 9/3/2003 00:00- 00:30 0.50 CMPLTN ClRC CMPLTN Mix 30 bbl 9.6# viscous sweep. 00:30 - 02:30 2.00 CMPLTN ClRC CMPLTN Set hanger pup just above annular. Seal assembly is about 2' above PBR. Close annular. Start pumping reverse. Pressured up to 560 psi and broke back to 250 psi. Pump 30 bbl viscous sweep and chase with 290 bbls brine. Thick returns on bottoms up. Small amount of CaCO3 in returns (approx 3 gals) during entire circulation. Viscous sweep came back on time, but it was spread out over 65 bbls. Circ 25 bbls after gel returns cleaned up. 02:30- 02:45 0.25 CMPLTN SOHO CMPLTN Land hanger. RILDS. 02:45 - 03:00 0.25 CMPLTN RURD CMPLTN Decide to pull SOV and set DV to fix tbg x IA communication. Pull landing jt. MU 3-1/2" full opening 8rd TIW valve. 03:00 - 03:15 0.25 CMPLTN SFTY CMPLTN Pre job safety meeting. Discuss Halliburton rig up and safety concerns with running slickline. 03:15 - 05:00 1.75 CMPLTN RURD CMPLTN Rig up HES slickline unit and lubricator. 05:00 - 06:00 1.00 CMPLTN SLIN CMPLTN Zero tools at rig floor. RIH w/Kick over tool to retrieve SOV. Find bottom GLM at 6266' SLM. Pull SOV and POOH. SOV does not look to be sheared. RU kick over tool with 1" DV on BK latch. RIH and set DV at 6266' SLM. Shear off DV and PU hole. 06:00 - 06:25 0.42 CMPLTN DEQT CMPLTN RU test pump to HES pump in flange. Open up annulus. Bleed back about 8 gals fluid and IA returns stopped. Start pumping with test pump down tubing. Started getting returns on IA while pumping down tubing. Shut down test pump. Put gauge on IA. Pressure up on tubing to 250 psi. IA tracking tubing. Shut down and monitor pressure. Holding 250 psi. Bleed off pressure. I 06:25 - 06:45 0.33 CMPLTN SLIN ;CMPLTN POOH with slickline setting tool. Hot shot to Y-Pad for D&D hole finder. 06:45 - 14:30 7.75 CMPLTN SLIN CMPLTN RIH with D&D Hole Finder. Attempted to shear tool and set, could not shear. POOH replaced shear pins, ran back in hole and sheared, set Printed: 9/12/2003 8:23:24 AM ConocoPhillips Alaska Page 7 of 9 Operations Summary Report Legal Well Name: 2U-08 Common Well Name: 2U-08 Spud Date: 3/24/1985 Event Name: WORKOVER/RECOMP Start: 8/25/2003 End: 9/5/2003 Contractor Name: nabors3scompanym@conocop Rig Release: 9/5/2003 Group: Rig Name: Nabors 3S Rig Number: Sub Phase Description of Operations Date From To Hours Code Code 9/3/2003 06:45 - 14:30 7.75 CMPLTI~ SLIN CMPLTN D&D hole finding tool @ 6284' just below #5 GLM. Pumped down tubing got immediate returns out annulus. Pulled tool up to 5785' just below #4 GLM set D&D tool, pumped down tubing got immediate returns out annulus. Repeated steps of below GLM #3 #2 &#1 and every 500' to surface and got same results. Cups on tool had failed. 14:30 - 15:30 1.00 CMPLTI~ SLIN CMPLTN POOH with D&D Hole Finding tool. Replace rubber cup on tool. 15:30 - 18:00 2.50 CMPLTF, SLIN CMPLTN Ran back in hole to 6284, sheared tool and set at 6284'. Pumped down tubing pressured tubing up to 500 psi. Monitored annulus, no communication and press held for five minutes. 18:00 - 19:30 1.50 CMPLTN SLIN CMPLTN POOH with D&D Hole Finding tool, re-pinned and ran back in hole set tool at 6355', and 6345' pumped down tubing and got immediate returns. Move tool up hole and set tool at 6287' and 6282' and 6277' all failed, got cimulation. POOH, checked cup on tool and cup worn down again and had failed. 19:30 - 21:00 1.50 CMPLTN SLIN CMPLTN Rig down HES slickline. ~21:00 - 21:40 0.67 CMPLTN CIRC CMPLTN Call out SWS E-line for leak detect log. Call Chuck Sheave with AOGCC to discuss BOP testing. He said we could test after running E-line. Rig up to circulate down the tubing taking returns off annulus to the pits. Took 8 bbls to get returns to shaker through gas buster. Circulate at 61 spm and 770 psi. SD pump. BOLDS. PU 2' for hanger to clear bowl. Start pumping 60 spm and 690 psi. PU on tubing took 72K to move pipe. Broke back to 58K. PU while circulating looking for ~ressure decrease when seal assembly clears PBR. Pull hanger to floor (~24'). No change in circulating pressure. SD pump. LD hanger and 27' landing joint. PU full jt. MU TIW valve and headpin. RU hose to circulate. Start pumping 61 spm at 710 psi. PU 10' with no change in pressure. RIH 5'. Pressure started climbing to 1250 psi before we got pump shut down. Pressure bled off to 120 psi. PU 5' and pressure dropped to 60 psi. RIH and tag down with 23' in on top joint (6395' ~RKB). It appears that the packer is still on the tubing string. PU to string weight. Turn pipe 1/4 turn to see if we are over the tubing stub with the overshot. RIH and set down in same place. PU 10' and turn pipe 1/4 turn. RIH and set down in same place. 21:40 - 23:30 1.83 CMPLTN OTHR CMPLTN Verify space out and pipe tally figures. We are sitting down 5.25' higher than when packer was originally set. We could be tagging up on the tubing stub. Decide that we need to POOH. Call Chuck Sheave with AOGCC to discuss BOP testing now that we think packer is still attached. Chuck waived the BOP test requirements if we pull out with the tubing and run back in with the completion. 23:30 - 00:00 0.50 CMPLTN ClRC CMPLTN RU to circ reverse. Pump 60 spm at 500 psi. Lower pressure probably means we are circulating past packer and up the tubing tail. When pumping conventional, we are only pumping through the equalizing port on the packer. Another good indication that the packer is still on the tubing. 9/4/2003 00:00 - 01:00 1.00 WELCTL BOPE CMPLTN Hook up choke line back to HCR on flow cross. Pressure test choke line to 250/4000 psi. Good test. 01:00 - 01:30 0.50 CMPLTN ClRC CMPLTN Mix and pump 10 bbl dry job. Displace with 2 bbls 9.6# brine. 01:30 - 03:00 1.50 CMPLTN TRIP CMPLTN LD 2 jts and 3 pup joints. Pull 1st 10 stands. No drag while pulling. Having to pull slow to keep from pulling wet. Stop @ each connection to let fluid fall past collar. 0.3 bbls over on hole fill for 1st 10 stands. 03:00 - 06:00 3.00 CMPLTN TRIP CMPLTN Continue POOH. Started to pull dry on stand #23. No drag or over pull seen. Pulled dry for 5 stands and then caught up to fluid. Continue POOH with good hole fill. 1 bbl over for 50 stands pulled. Printed: 9/12/2003 8:23:24 AM ConocoPhillips Alaska Page 8 of 9 Operations Summary Report Legal Well Name: 2U-08 Common Well Name: 2U-08 Spud Date: 3/24/1985 Event Name: WORKOVER/RECOMP Start: 8/25/2003 End: 9/5/2003 Contractor Name: nabors3scompanym@conocop Rig Release: 9/5/2003 Group: 'Rig Name: Nabors 3S Rig Number: Sub Phase Description of Operations Date From- To HoUrs Code Code 9/4/2003 06:00 - 11:30 5.50 CMPLTN TRIP CMPLTN Continue POOH. 11:30 - 13:30 2.00 CMPLTN PULL CMPLTN Recovered and layed down FHL Packer, PBR, overshot and all associated pups, nipples and RHC dart (bar). Visual inspection of Packer and overshot. Concluded shear ring on Packer had vibrated and backed out leaving one shear thread or less instead of two allowing 3acker to shear and release prematurely. (Packer was set at one time). Overshot showed groves giving indications that we were over the stub and also had stacked out on stub several times. 13:30 - 14:30 1.00 CMPLTN TRIP CMPLTN Removed gallded pups, 1 GLM, 4 jts tubing. Loaded pipe shed with replacement jts and GLM., new packer, PBR, 3-3/4" overshot and prep to run back in hole. 14:30- 14:45 0.25 CMPLTN SFTY CMPLTN Pre-Job Safety meeting before running completion. 14:45 - 00:00 9.25 CMPLTN TRIP CMPLTN Run completion as per original procedure. Tubing tally with replaced joints and jewelry is same as previous tally. MU jts 198 and 199 to tag tubing stub. Drift TIW valve and headpin with ball and rod. MU TIW valve and head pin to joint 199. Up weight 57K. Down weight 48K. RIH w/jt 199. Tag 16-1/2' in on 199. This is 6396' RKB (Doyon 9). PU 5'. Appears to be a little sticky like there is fill down hole. Prep to reverse circulate. 9/5/2003 00:00 - 01:30 1.50 CMPLTN CIRC CMPLTN RU to reverse circulate. Start pumping 2.5 BPM at 300 psi. Wash down through fill. Tag up on tbg stub at 6396'. Rotate tbg with rotary table to work over stub. Had to rotate 2 times (1/2 turn each) to get over stub. Circ down over stub 6' to 6402' RKB. This is 22.5' in on jt 199. On .previous packer run, the packer was set 21' in on jt #199. Overshot showed marks from stub going inside, so we are over the stub at this depth. Cim 2 bottoms up to ensure well is clean. Recovered thick oily fluid with some solids on 1st bottoms up. Returns cleaned up good after 1-1/2 bottoms up. Pumping at 2.5 BPM and 260 psi at end of 2nd bottoms up. SD pump. Open annular preventer. PU to neutral plus 1'. PU weight 60K. RIH and tag down 21'+ in on jt 199. 50K down weight. Solid tag. PU to string weight plus 6". RU to pump corrosion inhibited brine down tubing and take returns up annulus. Well is drinking some fluid (approx 2 bph). Pump 10 bbls corrosion inhibited brine 2BPM at 160 psi. Displace with 9.6# brine 2.5 BPM and 250 psi. 02:15 - 03:10 0.92 CMPLTI~ PCKR CMPLTN Break off circ hose. Drop ball and rod. MU circ hose. Wait 15 min for ball and rod to hit. Begin pumping. Pressure up felt packer shift at 900 psi. Walk pressure up to 2500 psi. Hold for 8 rain. Pressure dropped to 2390 psi. Bleed pressure down to 1500 psi. PU and shear PBR @ 75K which is 26K including 8K from the pressure. Pressure fell off to 1300 psi and held steady. PU above PBR. Start circ with charge pump. RIH and engage seals. Pressure increase 50 psi and circ stopped. RIH and tag down 20-1/2' in on jt #199. PU to neutral weight and figure space out. 03:10-04:30 1.33 CMPLTk SOHO CMPLTN Pulljts 199, 198, and 197. MU 2-8' pups and 1-10'pup. MUjt197. MU hanger. RIH and land hanger. RILDS. 04:30 - 06:00 1.50 CMPLTI~ DEQT CMPLTN RU to pressure test. Open up casing valve. Small amount of flow while pressuring up tubing then flow stopped. PT tubing to 2520 psi for 15 min. Pressure dropped to 2450 psi. Bleed off pressure to 1500 psi. PT casing to 2500 psi. Tubing pressure rose to 2200 psi. Hold for 15 min. Pressure dropped 20 psi on casing. Would like to see a greater differential from tubing to casing. SI casing. Bleed off tubing pressure to 1100 psi. Open up annulus. Annulus pressure=2350 psi. Hold test for 15 min. No drop in pressure. Chart all pressure tests. Bleed off Printed: 9/12/2003 8:23:24 AM ConocoPhillips Alaska Page 9 of 9 Operations Summary Report Legal Well Name: 2U-08 Common Well Name: 2U-08 Spud Date: 3/24/1985 Event Name: WORKOVER/RECOMP Start: 8/25/2003 End: 9/5/2003 =Contractor Name: nabors3scompanym@conocop Rig Release: 9/5/2003 Group: Rig Name: Nabors 3S Rig Number: Sub Phase Description of Operations Date From- To Hours Code Code ,,. 9/5/2003 04:30 - 06:00 1.50 CMPLTN DEQT CMPLTN 3ressure on tubing and annulus. 06:00 - 06:45 0.75 WELLSR PLGM CMPLTN Pull landing joint. Set two way check in hanger. 06:45 - 11:00 4.25 WELCTL NUND CMPLTN ND BOP stack. Emptied and washed out pits. 11:00 - 15:00 4.00 WELLSR PLGM CMPLTN NU tree, test Tubing Hanger Adapter void to 5000 psi. Test tree to 5000 psi. Broke out blind flange on tubinghead and installed flange with tapped 2" bullplug and needle valve. 15:00 - 15:30 0.50 WELLSR DEQT CMPLTN SITP = 0 psi SICP = 0 psi SI outer annulus press = 50 psi. Release rig at 15:30. Printed: 9/12/2003 8:23:24 AM GConocoPhillips Alaska, Inc. Perf (6755-676~) KRU 2U-08 2U-08 APl: SSSV Type: Annular Fluid: Reference Log: Last Tag: Last Tag Date: Casing String 500292128400 NIPPLE 32.8' RKB 6783 01712002 Well Type:I PROD Orig 1312911985 Completion:I Last WlO:19~5~2003 Ref Log Date:~ TD:~7122 ftKB Max Hole Angle:J44 deg @ 3500 I Angle @ TS: Angle @ TD: 34 deg@6626 33 deg@7122 Last Update: Description ALL STRINGS Size Top Bottom Rev Reason: WORKOVER 913012003 TVD I Wt I Grade I 116 I 62.50 I H-40 I 2929 136.001 :-55 I 6143 ~ 26.00 [ J-55 J Thread CONDUCTOR 16.000 0 116 SUR. CASING 9.625 0 3023 PROD. CASING 7.000 0 7043 Tubing String - TUBING Size [ Top 3.500 0 3.500 6404 Bottom TVD 6399 5606 6728 5880 I Wt IGrade I 9.3o I L-80 I 9.30 I J-55 I Thread 8RDABMEUE -New 8RDEUE - Original PerfOrations Summary Interval TVD I Zone I StatuslEt ISPFI Date l Type I Comment 6627.6657 5795-5820 IC-4,UN~TBI I3° I 12 14119119891 IPERF 15" Dresser Atlas 6755-6761 5902-5907I A-4 I I 6 I 4 14119119851 IPERF 14" Dresser Atlas 6765-6804 5911-5943 ~ A-3 ~ I 39 I 4 14119119851 IPERF 14" Dresser Atlas :GaS Lift Mand~el~/Vai~es: :: : :: ::: :: :: :: i: ::: :: ii::::: ::: ::i : stI MD I TVDI Man I Man I VMfr I VType I VOD I Latchl Port I TROI Date I v~v I I IMfr I Type I I I I I I I Run I Cmnt 11 25341 25151CAMC01KauG I I DM¥ I1.0 I BE 10'0001 0 19/9120031 2 14090137301CAMCOI KBUG I I DMY I 1.0 I aK 10.0001 0 1919120031 3150461 45001CAMCO IKBUG I I DMY I 1.0 I aK 10'0001 0 191512O031 4197991 S0811CAMCOI KBUG I I DMY I 1.0 I BE 10.0001 0 191912003I 5 I 62511 54841CAMCOl KBUG I I OM¥ I 1.0 I BK I 0.000 I 019~5/2003 I ' 6 164201 56231CAMCOIKBUG I I DMY I 1.5 I RE 10.0001 0 14119119891 (1) 1. GL V #6~ 7rSt9 are Pre-Workover and below tbfl cut :Production. Mandrels/Valves: .... . . . . · .... St MD '"TVD Man I Uar~ I v M~r I v Type I V OD I'atch I Port I TRO I 'Date '1 wV I ] Mfr I Type ] I I I I I I Run ]Cmnt 7165O91 SS971CamcoI MMG-2 I IDMY I 1.5 I RE 10.0001 0 l~l~4119981Closed 8 169801 S7561CamcoI MMG-2 I IDMY I 1.S I RE 10.0001 0 1~114/19981C~osed 9 I 66861 98491 Camco I MMG-2 I MACCO I HFCV I 1.5 I RKP I 0,000 I 0 1819120o01 Open Other (plugs, equip., etc.i Depth lTVD I Type 528 15281 NiP 6305 I s928 I LOCATOR 6308 155301 PBR/SBR 6321 15541 I PACKER 6376 15587 I NIP 6393 I 5601 IOVERSHOT )ther (plugs, equip., etc. 3epth I TVD Type 6459 I 5655 SBR 6471 I 5665 PKR 6480 I5673 PLUG 6705 I5860 PKR 6719 I5872 NIP 6727 I5879 SOS 6728 I5880 TTL :ish ,: FISH - JEWELRY - Post Workover Description CAMBO 'DB' NIPPLE BAKER LOCATOR BAKER 80140 PBR/SBR 'BAKER FHL PACKER CAMCO 'DS' NO GO NIPPLE i BAKER POORBOY OVERSHOT ID 3.500 2.875 2.990 2.990 2.970 2.812 3.750 - JEWELRY - Original Description ID Otis 2.810 Otis 'RRH' 2.970 0.000 Otis 'WD' Perm. 4.000 2.750 Camco 'D' Nipple NO GO Otis 2.992 2.992 Description Comment I 1/2" CV Depth 6917 6917 6925 1 1/2" DV 1 1/2" CV Dropped in Rathole Dropped in Rathole Lost in Rathole MEMORANDUM TO: Julie Huesser, Commissioner State of Alaska Alaska Oil and Gas Conservation Commission / / DATE: December 2, 2000 THRU: Tom Maunder, P. I. Supervisor FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Kuparuk River Unit 2U Pad Saturday, December 2, 2000: I traveled to the Kuparuk River Field and witnessed the semi annual safety valve system testing on 2U Pad. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 11 wells and 22 components with three failures observed. The Iow pressure pilots on wells 2U-5, 2U-14 and 2U-16 tripped well below the required set point. These three pilots were adjusted and retested at the time of this test. In addition to the three failed pilots several other pilots tripped very near the minimum pressure, these were reset and operated-properly when retested. The 13.6% failure rate will require a retest of this Pads Safety Valve System in 90 days rather than the normal ~/~0Jay cycle. ' Earnie Barndt conducted the testing today he demonstrated good test procedure and was a pleasure to work with Summary: I witnessed the semi annUal SVS testing at 2U Pad in the Kuparuk River Field. KRU 2U Pad, 11 wells, 22 components, 3 failures 13.6% failure rate Attachment: SVS KRU 2U Pad 12-2-00 CS X Unclassified Confidential (Unclassified if doc. Removed) SVS KRU 2U Pad 12-2-00 CS.doc Alaska Oil and Gas Conservation COmmiSsion Safety Valve SYstem Test Report Operator: Phillips Submitted By: Chuck Scheve Date: 12/2/00 :OPerator Rep: Emie Bamdt Field/Unit/Pad: Kupamk / KRU / 2U Pad AOGCC Rep: Chuck ScheVe - Separator psi: LPS 96 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCL~ 2U-01 1850040 96 70 . ~50 P P OII 2U-02 1850050 96 70 60 P P OIL~ 2U-03 1850060' 2U-04 1850070 2U-05 1850180 3700 2000 500 3 P 12/2/00 WAG 2U-06 1850190 96 '70 50 P P OIL 2U-07A 1850910 2U-08 1850210 96 · 70 50 P P OIL 2U-09 1850380 2U-10 1850390 · 96 70 60 P P: OIL 2U-11 1850400 2U-12 1850410 . 961 70 55' P P OIL 2U-13 1842460 96 70 50 P P OIL 2U-14' '1842470 3700 2000 0 1 P 12/2/00 WAG 2U-15 1842480 96 70 60 P P OIL 2U-16 1842490 3700 2000 100 3 P 12/2/00 WAG Wells: 11 Components: 22 Failures: 3 Failure Rate: 13.6%~] 9o oar Remarks: Three failed pilots, repaired and retested Pad on 90 day test cycle 12/4/00 Page 1 of 1 SVS KRU 2U Pad 12-2-00 CS.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISUION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate X Plugging Perforate Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 662' FSL, 747' FWL, Sec. 32, T12N, R9E, UM At top of productive interval 1179' FNL, 1049' FEL, Sec. 6, T11N, At effective depth 1301' FNL, 1186' FEL, Sec. 6, T11N, At total depth 1360' FNL, 1252' FEL, Sec. 6, T11N, R9E, UM R9E, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 106 7. unit or Property name Kuparuk River Unit 8. Well number 2U-08 9. Permit number/approval number 85-21 10. APl number 50-029-21284-00 11. Field/Pool R9E, UM 71 2 2 feet 6208 feet Kuparuk River Field/Oil Pool feet Plugs (measured) None Effective depth: measured 6 9 6 0 true vertical 6 0 7 2 feet feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 240 Sx CS II 750 Sx PF E & 370 Sx PFC 250 Sx Class G & 250 Sx PFC 80' 16" 2986' 9-5/8" 7009' 7" measured Measureddepth 116' 3023' 7043' 6627' - 6657', 6755' - 6761', 6765' - 6804' true vertical 5795'- 5820', 5902'- 5907', 5911'- 5943' True vertical depth 116' 2928' 6143' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 6716' Packers and SSSV (type and measured depth) Packers: Otis RRH @ 6460' & Otis WD @ 6694'; SSSV: Camco TRDP-1A-SSA @ 1791' 13. Stimulation or cement squeeze summary Fracture Stimulate 'A' Sands on 9/18/96 Intervals treated (measured) ORIGINAL 6755'- 6761', 6765'- 6804' Treatment description including volumes used and final pressure ' Pumped 120 Mlbs of 20/40 and 12/18 ceramic proppant into formation, fp was 7200 psi 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2 5 1 289 371 1256 193 Subsequent to operation 315 377 839 1270 198 15. Attachments Copies of Logs and Surveys run __ Dally Report of Well Operations X~ 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sign ed ~~'/~',,¢~¢~ .. ~,/~~..~ Title Wells Superintendent ? SUBMI~ IN DUPLICATE ARCO Alaska, Inc~-~.~ Post Offic ~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DAT~: 10-22-85 TRANSMITTAL NO: 5410 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING kECORDS CLERK ATO-1115B -- P.O. VOX 100360 ANCHORAGE, AK 99'510 TRANSMITTED ki~',P, hWITH AK~ Tn~: FOLLOWING I'£~15. RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. FINAL PRINTS/ SCHL/ ONE * OF CEMENT. BOND LOG/ VARIABLE DENSITY :'~3B--8 06-06-85 RUN #1 5850-8369 11-07-.84 11-17-84 12-08-84 12-08-84 12-21-84 12-20-84 11-25-85 06-06-85 06-07-85 06-03-85 04-02-85 04-01-~5 03-31-85 04-01-85 03-02-85 12-19-84 12-18-84 11-03-84 06-17-85 06-08-~5 06-08-85 11-05-84 05-27-85 04-17-85 12-21-84 RUN RUN RUN RUN EUN RUN RUN -: RUN - RUN :- RUN RUN I~UN · }(UN .. :':.- 'i~UN. "~ ..... RUN kUN RUN RUN kUN i~UN i-(UN RUN RUN RUN i{UN CF24ENT EVALUATION TOOL ~ 1F-'16 03-12-85 RUN 06-26-85 06-27-85 03-25-85 03-07-85 06-30-85 06-29-.85 ~3C~12 ':' 06-29-85 RUN - RUN . .. }(UN }(UN RUN RUN - '. RUN .. . #1 #1 #1 #1 #1 #1 #1 #1 #1 Lo S / #1 - #1 #1 #1 i~SCEIPT ACKNOWLEDGED: · BPAE: "DRILLING*BL B. CURRIER" .. L. JOHNSTON. C ~ ~VRON t4OB I L . .. D & M NSK CLEgK*DL PLL,'A$L ACKNOWLEDGE 5900-8258 5896-8410 3050-7215 3100-6370 3350-6973 5100-8338 5700-7290 4550-710~ 4650-6428 6590-8553 4970-693~ 0070-~122 5600-8107- 5994-9161 -- ..,: .... ' " 6284-7850 ' 5200-74~9 3285-6454 5693-6652 5987-~324 4302-7028 6950-8628 4883-6600 6490-7566 8978-10744 2200-3856 _ Ct24ENT ~VALUATION LOGS 8269-8712 6974-8644 8254-8532 5790-9450' ' 6400-7002 6000-8246 6500-8726 5400-7457 W. EXXON PklILLIPS OIL J. RATHmELL UNION VAULT/~O*FIL~ ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany 3 t./ ARCO Alaska, Inc. Post Offic:'"~'~'~x 100360 Anchorage, ,.daska 99510-0363 Telephone 907 276 1215 tLETURN TO: DATE: 08-16-85 TRANSMITTAL NO: 5254 ARCO ALASKA, INC. KUPAi{UK OPERATIONS ENGINEERING ,, RECORDS CLERK ATO-1115B ' P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED hEREWITH ARE THE FOLLOWING RECEIPT AND RETURN ONE SIGNED COPY OF THIS PRESSURE FINALS CAMCO iB-3 1D-8 1E-5 1H-6 1L-2 1L-5' 12>-6 lQ-9 2A-5 2A-5 2C-4 2F-7 2F-8 2F-9 2G-! 2G-i 2U-5 2U-6 2U-7 2U-8 2X-!0 OTIS 2A-2 2o-14 2V-2 2V-5 2V-13 2V-14 2W-7 3B-3 3B-8 PBU 04-21/22-85 STATIC 04-29-85 PBU 04-26-28-85 STATIC 04-29-85 PBU 04-24/25-85 PBU 04-28/29/85 PRESSURE FALL OFF 05-07-85 PBU 05-12/13-85 PRESSURE FALL OFF 04-21/22-85 .' STATIC 05-05-85 PBU 04-24/25-85 PBU 04-14-85 PBU 04-19/20-85 PBU 04-13/14-85 STATIC 04-17-85 PBU 04-29-85 STATIC 05-02-85 STATIC '-05-03-85 STAT IC 05- 04- 8 5 STATIC 05-04-85 PBU 04-25/26-85 STATIC 07-04-S5 'PBU 06-30-85 PBU 07-27-85 PBU 06-25-85 STATIC 06-22-85 STATIC 06-22-85 PBU 07-26-85 STATIC. 06-28-85 STATIC 06-28-85 RECEIPT ACKNOWLEDGED: ~pkE*~ B. CURRIER CHEVRON* · D & M* DISTRIBUTION: DRZmLING W. PASHER L. JOHNSTON EXXON MOBIL* PHILLIPS OIL* NSK CLERK J. RATHMELL* IT~]S. PLEASE ACKNOWLEDGE TRANSMITTAL. \ IFA.TE: ~...,'~k~ ~Ji! ? ' ..... ' .... " r.,-. '.-.,,-;S Anchorapo STATE OF ~ASKA* SOHIO* UNION* K. TULIN/VAULT ARCP-~Jaska, Inc. .)st Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 PAGE RETURN TO: ARCO ALASKA, INC. . KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-Ill5B P.O. BOX 100360 A~HORAGE, AK 99510 ~.~TE: 06-19-85 TRANSMITCAL NO: 5230 2 OF 2 TRANSMITTED HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY ***CONTINUED. FROM PREVIOUS PAGE*** 2D-5 FLOWING BHP ETC 05-06-85 2D-3 2D-3 2E-9 2E-13 2E-14 2E-!5 2G-I 2H-1 2H-15 2H-1 2H-3 2H-4 2H- 14 2U-5 2U-6 2U-7 ACID JOB PREP 05-0 7-85 ACIDIZE 'C'SD 05-11-85 G.R. SBHP 06-11-85 SBHP 06-10-85 SBHP 06-10-85 SBHP 06-09-85 FLOWING BHP 04-29-85 BHP&TCL 05-27-85 SBHP & ETC. 04-29-85 BHP & ETC. 05-23-85 BHP & ETC. 05-23-85 COMP BHP 05-23-85 INT. SBHP&ETC 04-28-85 SBHP 05-02-85 SBHP & TCL 05-03-85 SBHP PRE PROD 05-04-85 SBHP & ETC. 05-04-85 PRESSURE TEST 05-27-85 BHP SAMPLE 06-05-85 'A'SD FLUID ID 06-09-85 PBU 06-07-85 BHP & ETC. 05-17-85 S TAT IC ' 05-! 2 - 8 5 STATIC 05-23-85 'C'SD ACID STIM 05-20-85 'C'SD ACID JOB 05-12-85 E/LINE FLUID ID 05-03-85 OF THIS TRANSMITTAL. CAMCO BAKE R DOWELL OTIS OTIS OTIS OTIS CAMCO OTIS OTIS CAMCO OTIS OTIS OTIS CAMCO CAMCO CAMCO B ARE R/C~CO OTIS OTIS OTIS OTIS OTIS OTIS OTIS DOWELL DOWELL OTIS/CAMCO 2U-!0 2U-16 2U-16 2V-10 2V-fl 2V-Ii 2W-13 2X-12 2Z-2 RECEIPT ACKNOWLEDGED: B PAE * B. CURRIER CHEVRON* D & M DATE DiS TRIB UT ION: DRILLING W. PASHER L. JOHNSTON EXXON MOBIL* PHILLIPS OIL* NSK CLERK J. RATHMELL STATE OF ALASKA SOHIO* UNION* K.TULIN/VAULT ARCO Alaska. Inc. is a Subsidiary Of AtlanlicRichfieldComDany ARCO Alaska, Inc. Post Office Bo,, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 24, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton: Enclosed are Well Completion Reports the following wells: 2U-8 2V-9 If you have any questions, Sincerely, Gruber Associate Engineer JG/tw GRU9/Li03 Enclosures please and call me gyroscopic surveys for at 263-4944. RECEIVED JUN 2 ] 185 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA;,._ AND GAS CONSERVATION CC ,vllSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] · 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-21 3. Address 8. APi'Number P. 0. Box 100360, Anchorage, Al( 99510 50- 029-21284 ,_ 4. Location of well at surface 9. Unit or LeaSe Name 662' FSL, 747' FWL, 5ec.32, T12N, RgE, UM Kuparuk River Unit At Top Producing Interval~.H '~] 10. Well Number 1179' FNL, 1049' FEL, Sec.6, T11N, RgE, UN 2U-8 At Total Depth 1360' FNL, 1252' FEL, Sec.6, TllN, RgE, UM ~'~I~/~ ! ll. Field and Pool ?c,~,~..~,_~w.~r~.l. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No..i~:.~'~JZ~'~'/~''~--L' ' Kuparuk River 0i l Pool 106' RKBI ADL 25644 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 03/24/85 03/28/85 03/29/85*I N/A feet MS L 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD~TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 7122'MD,6208'TVD 6960'MD,6072'TVD YES [~X NO [] 1802 feet MD 1500' (approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/Cal, FDC/CNL/GR, GR/CBL/VDL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H,40 Surf 116' 24" 240 sx Cold Set II 9-5/8" 36.0# J-55 SUrf 3023' 12-1/4" ~750 sx PF "E" & 370 sx PF "C" 7" 26.0# J-55 Surf 7043' 8-1/2" 250 sx Class "G" & 250 sx PF "C" 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) 6804' - 6765' w/4 spf, 120~ phasing 3-1/2" 6728' 6471' & 6705' 6761' - 6755' '26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 6657' -6627' w/12 spf, 120~ phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See Well History, completion) for frac information. ,., 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE . 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED J U N 198,5 Alaska OJJ & Gas Cons. Commission Anchorage Form 10-407 * NOTE: Tubing was run and the well perforated 4/19/85. TEMP/WC34 Submit in duplicate Rev. 7-1180 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 Upper Sand 6626' 5794' N/A Base Upper Sand 6658' 5820' Top Lower Sand 6739' 5888' Base Lower Sand 6870' 5997' -- 31. LIST OF ATTACHMENTS Well History (eom,nletion details); Addendum. Cvroscooie Survey (2 copie~) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ .~~ Title Associate Engineer Date ~'~-~ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and Icg 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 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, JAccounting cost center code State Alaska Well no. 2U-8 District ICounty or Parish Alaska I North Slope Borough Field ~hease or Unit Kuparuk River I ADL 25646 Auth. or W.O. no. j Title AFE 603651 I Completion WWS #1 Operator I A.R.Co. ~CO Alaska, Inc. Spudded or W.O. begun J Date I Comple t ion Date and depth Complete record for each day reported as of 8:00 a.m. 4/18/85 4/19/85 4/20/85 5/08/85 API 50-029-21284 W.l. ri'otal number of wells (active or inactive) on this [cost center prior to 15lugging and I 56.24% labandonment of this well I IHour I Prlor status if a W.O. 4/17/85 / 1830 hrs. I ND tree, NU & tst BOPE. 7" @ 7043' 6960' PBTD, Tst lubr f/perf'g 10.1 ppg NaC1/NaBr Accept rig @ 1830 hrs, 4/17/85. to perf. RU WL 7" @ 7043' 6960' PBTD, Lnd tbg 10+ NaCl/NaBr RIH w/4" csg guns, 4 SPF, 120° phasing. Perf 6804'-6765', 6761'-6755'. RIH w/12" csg guns, 12 SPF, 120° phasing. Perf 6657'-6627'. RIH w/pkr, set @ 6694~. RIH w/3½" compl string. 7" @ 7043' 6960' PBTD, RR Crude/Diesel Space out, lnd tbg. Set pkr. Tst tbg to 2500 psi. Shear SBR. Tst ann to 2500 psi. Close SSSV. ND BOPE, NU & tst tree to 5000 psi. Displ well w/30 bbls diesel & 185 bbls crude. Tst SSSV. Tst orifice vlv to 2000 psi. Shear ball. Set BPV. RR @ 1700 hfs, 4/19/85. Frac well w/313 bbls of gelled diesel in 7 stages w/700# of 100 . mesh & 15,100# of 20/40 mesh. 6960' PBTD Rotary Old TD I New TD PB Depth I Released rig I Date Kind of rig 1700 hrs. I 4/19/85 Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single . Producing.method I Official reservoir name(s) Flowing I Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Al---t .. . - . Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity A~I~I~,~ L/Il ~ ~ct~e C0m~ corrected gnchorago ssi0n The above is correct For form preparation and distribution, see Procedures Manual, Secti"'on 10, Drilling, Pages 86 and 87. Drilling Superintendent ADDENDUM WELL: 4/02/85 4/03/85 2U-8 Press up 9-5/8" x 7" ann to 1000 psi. Lost 25 psi after 1 hr. Rn GR/CBL/VDL f/6938'-5750'. Rn GR to surf. Rn gyro f/6904'-surf. Drilling ~uperintendent $ UB-$ URFA CE DIRECTIONAL SURVEY [-~ UIDANOE J'~'J ONTINUOUS ~"100 L Company Well Name Field/Location ATLANTIC RICHFIELD COMPANY 2U-8 (662' FSL. 747' FWL. S32. TI2N. Rq~.. ~) KUPARUK, NORTH sLOPE, ALASKA' Job Reference No. 70339 Loooed By: MCBRIDE RECEIVED JUN 2 5 ~1~85 Alaska, Oii & Gas Cons. Commissior~ Anchorage Date ,= 25-APRIL- 1985 Computed By: CUDNEY SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 2U-8 F I ELD. KUPARUK COUNTRY USA RUN ONE DATE LOOOED 2 APR 8S REFERENCE 000070999 WELL NAME: 2U-8. 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O0 '106..00 100,00 200.00 300.00 4O0 O0 500 O0 600 O0 700 O0 800 O0 900.00 1000.00 1000 O0 094.00 1~00 O0 1100 O0 994.00 1200 O0 1200 O0 1094.00 O0 O0 !30O nO 1400 O0 1500 O0 1600 O0 1699 O0 1709 O0 1899 0 6 5 23 17 W O.~B 0 5 S 54 6 w 0 4 5 59 4 w 1.22 O0 1294.00 0 ~ S ~8 15 W 1.40 00 1~94;00 0 ] " 4 47 ~ t.44 oo o 4, gq 159~.g9 0 50 N 34 37 E -0.14 . ~793~92 3 29 S 59 59 W 0.89 1300 1400 150o 1600 1700 000 2000 O0 1999 54 1893.54 6 42 2100:00 ~Og8 41 109~.41 10 18 2200.00 2106 10 2090.10 14 2300 O0 2292 85 2186.~5 14 46 :. ~9 17 4 2400 nO ~3 11 2283.11 1 2600~00 ~5.o 46 246q.'46 ~4 50 2700~nO ~664 90 255~.90 78 24 2800.00 ~751 15 2645'15 ]2 25 2900.00 ~833 54 2727.54 50 2~05 50 40 45 94 2~7~:94 42 29 3~ 2953']2~ 43 07 ]026.07 43 34 24 ]09~.24 44 83 3169.83 44 25 65 3242.65 41 56 77 3317.77 40 36 1~ 3394.12 39 50 50 3472,.50 37 19 S 43 26 w 9.47 $ 42 34 w 24.t3 s 38 2 W 45.54 5 30 46 W 70.~8 $ 35 45 W 96.74 $ 38 12 W 120.40 5 39 28 W 168.44 5 40 16 W 21~.96 $ 40 29 W 263,37 $ 40 33 W 319.85 S 40 53 w 382.27 S 40 56 w 448.88 5 40 47 W 516.66 S 40 37 W 585.09 S 40 28 W 654.i3 $ 40 20 W 723,74 S 40 42 W 792.06 S 41 5! w R57.92 ~ 44 2 W 92~.47 S 44 24 W 984.$5 3000.00 291t 3100.00 29R 3200.00 3059 3300 O0 3131 3400~00 320 3500,00 3275 360~.00 3348 370 .00 3423 3800 O0 3500 3900:00 3578 0.00 0 8 0 49 0 ]0 0 30 o 0 O8 0.13 0.11 0 06 0i03 0 07 0 31 0,63 0,14 ,24 ~.74 3 99 3 87 3 26 0 69 3 91 413 3 O5 3 80 4 2O 413 3,46 0,86 0 6O 0 5O 0 41 0 52 I 93 3 01 0.00 0.12 O,li 0,23 0,16 0.21 0,02 28 0 O0 E 0 04 w 0 56 W ,6~ ~ 0,57 W 106.00 FT 0695 83 $ 0,95 S 0,75 $ 41 ~ 55 W 67 w 81 W 90 W 96 w 98 w 78 W 05 w 67 W 0,89 S 38 27 W 1,06 S 3~ 55 W 1,22 $ 41 48 W 1,31 S 43 23 W 1,40 S 43 27 w 1,44 S 42 44 W 1,08 S 45 55 w 0,26 N 1 54 W 16 34 E 1, 5 21 $ 16 102 132 167 205 248 06 S 1~ $ 4 13 $ 60 24 $ ~ 84 S 1o~ 07 $ 13~ 59 S 16 66 S 201 36 W 24 05 w 45 94 W 70 62 W q7 69 W 130 26 W 16 99 W 2t~ 75 W 264 51 w 321 $ lq W 9 71 S 57 32 w 39 S 48 49 w 54 S 44 43 W 46 S 40 41 w 39 S 38 31 w 24 S 38 16 W 49 S 38 ~ ) I1 $ 39 w $ 39 17 , 296 12 $ 24 346 55 $ 280 397 93 $ 332 449 91 S 377 502 50 $ 422 555 66 $ 467 607 86 $ 511 657 63 $ 55 704 60 $ 599 749,01 $ b42 31W 3~3 89 S 39 31 W 07 w 450 64 S 39 44 W 52 W 518 57 $ 39 52 w 2~ w 587 17 S 39 58 'w 30 W 656 39 S 40 2 ~ 56 W 726 20 S 40 4 W 96 w 794 73 S 40 b W 30 w 860 72 S 40 10 W 6~ W 925,20 S 40 23 w 99 W 987,14 S 40 38 k 0,00 N 0 0 g 0,13 N 18 59 W 024 N 62 53 W 0 45 N 60 0 W 0 48 N 70 34 w 0 60 N 69 39 ~ 0 68 $ 87 ') 66 $ 64 W 0 77 S 47 28 w ARCO AbASKA, TNC. KUPARUK MEASURFD VER?ZCA[,, VEPTTCAb DEVIATIOH AZIMUTH DEPTH D~PTH DEPTH D~G H~N DEG ~N CO~PU?A?ION DATE~ 25-APR-85 PAGE 2 DATE OF SURV£¥~ ~ APR 85 KE~6Y BUS~ZNG EbEVAT~ONI ENGINEERt M~BRIDE [,TERPO~A?ED VALUES FOR EVEN tOO FEET OF NEASUE£D DEPT, 106,00 F~ 4000 O0 ]658,1~ 3557,12 37 10 5000 nO 4461.98 435~,98 35 29 5100 O0 4543.55 4437.55 35 5200 O0 4625 42 4510.42 34 53 5300 O0 4707~44 4601.4.4 34 5500 O0 487~,86 4765,86 34 5500 O0 495~ 9~, 4847o~9 '~4 46 5700 O0 503 ,8~ 4929 ~9 ~5 50 5~00 O0 5116,54 5010:54 36 590~ O0 5197,28 5091'2'8 36 ? 6000 O0 ~278 20 517~,2.0 ~5 45 6100 O0 5359 6200 O0 5440 6]00 O0 5522 640n 00 5605 6~00.00 5688 6600,00 5771 6700,00 5855 6800.00 5938 690O.OO 60~2 44 525].4'4 t5 33 99 5334.99 35 96 5416.96 34 39 49 5490,49 ]4 bO 5587.60 33 35 8 7000,00 6105.97 7100.00 6189.55 7122.00 6207.94 5999,~7 33 6083.55 33 18 6101,94 33 18 $ 44 23 w 1045 05 5 44 w I 65 63 S 44 37 W 1225 77 S 44 54 W 1~85 74 S 44 5q W 1345 43 S 45 6 w ~404 80 S 45 13 W 1463 94 S 45 20 W 1522 81 S 45 26 ~ 15~1 ~8 $ 45 41W 1639.80 S 45 51 w ~697 62 $ 46 6 W 1755:05 S 46 31W 1812.24 S 46 50 W 1869 13 S 47 8 W 1926 O1 S 47 q W 1983 01 $ 4828 ~ 2!58 ~5 $ 48 33 w 2216 86 $ 48 ~ w 2275i07 S 48 W 23-32 82 S 48 35 W 2389 96 S 48 42 W 2446 30 $ 48 44 W 2501 80 ~ 48 3~ W 2557 O0 $ 48 25 W 2611 94 ~ 48 ~4 W 2666 91 S 48 16 w 272! 75 S 48 lO W 2776,56 $ 48 10 W 2831,]7 $ 48 lO w 284],43 0.48 0~41 8 0 ! 9~ 0,.42 i005 0,19 1047 o 0:28 11 0,22 1 17 0.57 12i3 0,58 1253 0 6~ 1293 0,20 137 0.34 1410 0,26 1449 ~,42 1488 14 1527 o:45 0,35 0 67 0 46 0 59 0 74 0 6 ! 11 2 lO 0.00 0,00 0,00 792 25$$ 68!72 79 32 WW 1047 8 $ 76 It S 812 71 $ 854 95 $ 896 89 S 938 58 $ 980 Oi $ t022 13 S 1063 57 W 1107 1167 23 w 1 40 W 1347 43 w 1406 38 W 1465 20 W 1524 91 w 1582 53 S 40 51 w 75 $ 41 3 w 89 S 41 14 k 93 S 41 23 W 81 $ 41 33 w 39 S 41 42 w 6? S 41 ~0 ~ ')~ 72 S 41 58 ~ 49 S 42 6 w 97 S 42 t] W 10 4 $ 114~ ~7 $ 1 32 S 1188 85 $ 1229 59 $ 13 31 $ 1354 26 $ 139b 64 $ i 44 82 $ ! 485 62 w 1641 OB w 1699 34 w 1756 69 w 1813 20 w 18'/0 88 W 1.927 7~ W 1983 93 W 2041 0 S 42 20 w 4 $ 4~ 27 w 37 S 47 34 w 46 $ 42 41 w 25 $ 42 49 w 02 $ 42 56 W 92 8 4] 3 W 16 $ 43 11 W 05 $ 4319 ~ 83 $ 43 28 W 1005 71 $ 1529.15 W 2217 34 $ 43 3b . 17 17 18.~ 19 ~940 39 $ 1572.81 W 2275 69 $ 1616,21 W ~333 56 S 1659.17 w 2390 86 $ 1701,56 w 2446 60 $ 1743,32 W 250i 17 ~ 1784,84 W 2557 68 $ 1826.04 W 2612 26 $ 1867.2~ W 2666 71 $ 1908,34 ~ 2721 47 8 43 43W $ 4350 h 15 22 8 43 57 w 50 $ 44 4 W 95 S 44 10 w 11 $ 44 15 ~ 02 S 44 21 , 96 S 44 26 W 78 $ 44 31 w 197], 33 $ 1949,25 W 2776,58 95 $ 1900,16 W 2831,38 O0 $ 1999.16 W 2843,44 S 44 35 W S 44 39 W $ 44 40 W ARCO AbASKA~ TNt, KUPARUK NORTH SLOPE,ALASKA TRU~ SUR-~g~ COURSK MEASURKD VKRTICAL VE~TICAb DEVIATION AZIMUTH DEPTH DKPTH ~EPTH D~G MIN DKG COMPUTATION DATE~ 25-APR-B5 PAGE 3 DATE OF SURVEy: 2 APR 85 KELLY BUSHING FLEVRTION~ ENGINEER{ MCBRIDE INTKRPOLATED VA'LUK$ FOR EVEN JO00 FEET OF MKASURED DEPT VERTYCAb DOGbEG RFCTANGUbaR COORDINATES HO~IZ,: DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/JO0 fEET FEET FE~T DEG MIN N 0 0 E 0,00 S 43 26 w g 47 S ~0 53 w $ 44 2] w 1045.05 S 45 4! w i639.80 S ~8 33 W 2216.~6 S 48 {0 W 2776,56 S 48 ~0 W 284].43 0 O0 0.00 -106.00 0 0 1000 O0 1000.00 894.00 O' 6 2000 O0 1999 54 1893,54 6 4~ 300~ O0 ~911 ~ 2805.50 40 45 400. O0 ]658 3~52 12 ,7 10 5000 O0 4461 9~ 435':~8 ]5 29 6000 O0 5278 20 5,77,2.0 ]5 4' 7000 ~0 6105 97 5999.97 ]3 18 712~.00 6207 94 6,01.94 ]3 18 0,00 57 0,35 0,00 0,00 0 O0 M 0 5 296 792 1977 ~0~2 0.00 69 S 0.55 W 0 12 $ 2 ,3J W 383 25 $ 6 ,32 W 1047 04 S 1105,62 W ~64! 1 $ 1529,15 W 22~ O0 $ 19 ,16 W 2843 IOU,O0 F1 ARCO ALASKA, TNC, 2U-8 KUPRRIIK NORTH SLOPE,ALASKA Cn~PU?ATION DATE~ 25-APE-85 DATE OF SURVEY{ 2 APR 85 KELLY BUSHING ELEVATION{ ENGINEERI MCBRIDE INTERPOLATED VALUES FOR EVEN {00 FEET rjr SUB-SEA DEPTH MEASURED VERTICAl. VERTTCtL DEV]ATIOW AZIMUTH DEPTR DEPTH DEPTH D~G ~IN DEG ~IN VERT{CAL DOGLEG SECTION SEVERITY FEET DEG/IO0 0.00 6 O0 ~o~:oo O6 O0 o !oo 406 oo 506,00 06.nO ~06.00 806.00 0.00 0 On "0,05 0 4 0,08 0 7 0,13 0,56 0 ~0 0.20 0~26 0 ,23 0,50 0 ]~ 0 43 O~ 9 0:64 0,1~ O 00 -106.00 6 O0 0,77 0,89 1 07 li~2 i 32 1.40 1.43 "1, lO OO 20~ oo 306 O0 406 O0 5O6 O0 606 OO 706,00 806,00 906 oo 906.0o ~0o oo 0 7 s 24 1o z 1006:00 lOOb. O0 ooo:oo 0 6 s ~b 44 w i~§~ oo ,106.00 looo.oo 0 s s sb o w ~00 1206 On llOn.O0 o 4 $ 60 o W 1306.o0 1]06~00 1~00 O0 0 2 S 53 36 W 1406.00 t406,00 1300:00 0 2 S 25 40 w 1,06.00 1506,00 1400'00 0 3 , 22 57 ~ 1606 .00 1606.00 1500,00 0 32 N ~6 3 g 01 1706, 60 O0 0 51 N 34 31 ~ , 70 .00 0 25 N 8 39 W 1906.09 1906 O0 lfiO0,O'O 3 4~ 200~ ,1 2006100. ' lq00.!0 6 57 10 72 ~lo~ oo 2000 0 ~0 36 ]2lO. ~2 220 O0 2100:0 14 1~ 2313 ~0 2306,00 2~00,'00 !4 52 2417 72 2406,00 2]'00,00 t7 54 2524 ?1 ~506.00 2400,00 22 11 2633 80 ?606.00 2500,00 ~5 55 2747 12 ~706,00 2600.00 30 15 2865 97 2806.00 2700,00 35 11 ~ 58 57 w S 43 12 w S 42 11 w S t7 10 w $ 31 Ow .q ]6 4O w $ 39 53 w S 40 20 w ~q 4027 w 2992 75 2906,00 2800.00 40 30 3127 25 3006,00 2aon.o0 42 40 ,00 ]00o.00 , 310n. O0 52 3406. PAGE 4 1.25 10,23 25,72 48.03 73.66 102 02 138 30 182 86 235 95 999 92 106,00 FT 08 3106 43 27 45 3206 O0 44 2 02 ~o6 o~ 3~oo oo 4~ ~o 06 3~oo:oo 41 ~7 ~so6 oo 3400.00 ~9 ~ ~6 3606:00 3~00,00 37 14 o~ 3706:00 360~.00 37 s ]$ 3~06 o~ 37~o.00 37 3~64 340~ 3807 3934 4060 4185 $ 40 51 w 377 55 $ 40 53 w 467 28 S 40 42 w 560 45 $ 4O 2R w 655 83 S aO 17 w 752 90 S 41 14 w 842.60 ~ 44 4 W 927.39 S 44 22 W 1005,48 S 44 27 W 1081.3! $ 44 3] W 1156.80 RECTANGULAR COORDINATES HORIZ, DEPARTURE NORTH/SOUTH EAST/WEST DIET, IZTMIITH FEET FE~T FEET DEE MIN 0,00 0,00 0,~3 0,11 0,23 0,~6 O, 0 0,04 0.09 0,30 0 O0 E 0 O0 E 0 05 W 0 45 W 0 58 w 0 67 W 0 53 w 0 60 w 0 O0 N 0 0 g O0 N 90 0 E W 14 N 2~ 43~ W 25 N 6 w 48 N 6047 48 N 69 61 N 70 34 , ) 67 S 8647 w 54 S 80 37 w 67 S. 63 43 W 0 08 0 11 0 O8 0 O7 0 04 0 07 0 28 0 57 0 10 3 14 0,53 S 0,56 W 0,70 ~ 0,56 W 0,83 S 0,68 W 1 91 $ ,8~ W 1 0 :96 $0 90W ~ 1,02 $ 0~96 W 1,05 $ 0:97 W 1 0,71 $0 75 W 1 0.33 N 0,00 W 0 1,40 N 0,70 E I 0 77 S 46 32 w 090 638 17 w 07 S 39 8 w 22 S 41 53 W 43 $ 42 4 w 03 S 46 ' W 33 N 0 w 57 N 26 E 3 04 3 91 4 0 3 76 3 55 4 10 4,41 0 22 N 5 17 34 56 80 109 143 ~3 2 O0 w 2 76 $ $ 71 w 10 08 $ 19 30 w 25 34 8 3) 59 W 48 41. $47 7~ W 73 44 S 63 79 w 102 28 $ 86 24 w 139 98 $ 114,52 W 1~3 65 S 148,90 W 237 47 S 190,53 W 301 O1 N 83 37 w 44 $ 5631 w 77 S 48 29 w 03 $ 44 21 w 89 S 40 13 w 66 S 38 24 W 21 S 38 16 I 97 S 3~ 29 w $391 w 3.21 0.58 0,40 0,43 2 93 2 O4 2 26 0 8 0,28 609254 S 24~ 22 W 379 17 S 39 30 W ~ 48 $ 30 15 W 469 08 S 39 46 W 4,~{~ 18 W 562 46 S 3~ 57 W 7 97 47 W 5 5 646 708 763 8t8 871 17 $ 36 80 $ 421 $ 4~6 13 S 545 14 $ 6n 97 S 65{ 13 S 71~ 99 $ 76 40 W 658 755 14 W 845 03 W 930 63 W 1008 70 w 1083 60 w 1159 09 S 40 2 W 45 S 4O 5 W ]7 $ 40 9 w 11. S 40 25 w 3 S 40 43 w 71 S 40 58 w 07 S 41 12 w ARCR AbASKA, .THC. KUPAR!!K NORTH SLOPE,AbASKA COMPUTATION DATEI 25-RPR-85 DATE OF SURVEY1 2 APR 85 KELb¥ BUSHING EbEVATIONI '" ENGINEgRI MCBRIDE · iNT~RPO[.ATED VABUE$ FOH EVEN 100 FE~T OF SUB-SEA DEPTH VgRTTCAb DOC~EG RECTANGUbAR COOROINAT£8 HORIZ, SECTION SEVERITY NORTH/SOUTH ER$?/WEST DIST, FEET DE~/IO0 FEET FEE~ FEET T~U~ SU~-SE~ COURSg ~E~$IIR~D VERTiCAl, VERTICAD DEVIATION AZIMUTH DEPTH DEPTH 4310 ~4 ~906,00 3gO0,O0 ]6 54 4435'43 4006 OO 3qOO,O0 t6 3o O0 4nOn,O0 36 24 0 4t00.00 36 lO 0 4200.00 35 5~ O0 4~00,00 35 51 O0 4400,00 35 18 O0 450o.00 34 55 O0 4600.00 34 45 O0 470n.:O0 34 4! 44 37 w 123~ 10 44 58 w 1306:91 45 3 w 1381,00 45 13 W 1454.52 45'21W 1527,33 45 3! W 1590,58 45 4~ ~ 1671.07 45 57 W 174i.53 46 30 W 2811,24 47 2 w 1880.45 0,18 10 ~ ,94 10 0,3~ ll 4 0,46 12~4 0,85 1283 0.61 133~ 0,26 137 ! 8 816 47 W 1 925 ~0 $ 869 19 W 1~0384 08 $ 921 94 $ 97 19 $ 102 90 $ 1076 86 $ 1128 94 $ 1178 17 $ 122 54 $ 127~ 58 W 1382 69 W 1456 41W 1529 89 w 160 03 W t67~ 61 w 1742 97 W 1812 48 W 18~1 4550 88 4106 .07 70 4306 4931 07 4406 5054 O0 4506 5176 ]4 a606 5298 75 4706 5410.89. 4806 5541 ":;3 4906 O0 4900 O0 34 47 5663 ~5 ~006 O0 4900;00 35 4 5786 ~3 5!06 O0 36 1~ mo 52n6 ~4 5306 !7 5406 37 5506 5606 87 5806 5000:,00 O0 5100,00 36 O0 5700.00 35 4~ O0 5300,00 35 20 O0 5400.00 34 47 O0 5500.00 34 1 O0 5600,00 33 3] O0 5700,00 33 15 S 47 9 w 1949 65 S 48 21 W 20§- $ 48 32 W 2164.60 S 48 32 W 2236 gl $ 48 35 W 2308 S 48 35 w 2378 ~4 $ 48 42 w 2446 64 S 48 44 W 25 S 48 30 w 2579 48 1.83 0.11 152~ 0,46 157 0,22 1618 0,~4 1666 O, ] 1712 ,72 1758 ,0~ 1802 0,27 1846 5910 6034 6t57 6979 6400 652O 6640 s ~8 22 w 2645,27 S 48 30 w 2711.05 S 48 10 w 2776 S 48 lO W 2842,16 S 48 10 W 2~43.43 9 !i° O0 O0 6760 64 5906 O0 SRO0 O0 33 26 6880 41 6006 O0 5900:00 ~3 000 03 6106 O0 6000.00 33 1R ~1i9 68 6206 O0 6100.00 33 iR 7122 O0 6207 94 6101,94 33 67 $ 1330 98 $ 138i 51 $ 1435 04 $ i489 5 $ 1544 ]6 $ 1597 78 S 1650 08 $ 170~ 22 $ 175 O8 $ ~801 PAGE 106,00 : DA~ARTUREMuTH DEG MIN 26 $ 41 24 ~ 94 $ 4i 36 W 91 $ 4i 47 W 3! $ 41 57 W O0 S 42 6 W 14 $ 42 15 W., 52 $ 42 2~ ~ ) $ 42 3~ ~ 88 47 $ 42 41 w 54 $ 4~50 W W 1950 62 $ 4~ 59 W 2] W 2020 O1 S 4 B W ~4 W 2092 35 S 43 18 W 91 w 2165 14 W 2~37 65 W ~ 08 36 w 2378 82 w 2446 O0 W 2513 72 w 2579 17 S 43 28 W 26 S 43 38 W 52 $ 43 47 W 51 S 43 56 W 84 $ 44 4 w 46 $ 44 11 W 57 S 44 18 ~ 1889 86 $ 1851 O0 W 2045,33 S 44 2~ W 1933 61 S 1900 30 W 2711,00 .S 44 30 W 1977 34 $ 1949 26 W ~776,60 S 44 35 W 202~ ~06 $ 199~ 22 W 2842,17 S 44 40 w 202 $ ]99 16 W 2843,44 $ 44 40 W ARCO ALASKA, INC. 2U-B KIIPARUK NORTH SLOPE~AT.ASKA TOP UPPER SAND BASE UPPER SAND TOP bOWeR 5AND BASF E, OWER 5A~D P~T~ C~PUTATION DATE~ 2$-APR-~5 PAGE 6 DATE OF SURVE¥I 2 APR 85 106,00 FT IN'~ERPObA?ED VA[.UFS FOR CHOSEN HORIZONS MEASURED DEPTH SURFACE I~OCAT[ON AT ORTGIh: 6t~2' F$6,747' FWt,.SEC 32,Tt2N TVD RECTANGULAR_ COORdINATeS FRO~ KB SUB-SEA NORTH/SOUTH 662b.00 6658,00 67]9,00 6870.00 6960 O0 579~.56 5~R7.56 5~20,32 5714,~2 5887.94 5781.94 5997.~8 58ql.2~ 607~ ~4 5966,54 6207294 6101,94 1~40 68 $ 1795 1~8t $ 1 192q ~ $ 1896 202~ O0 $ 199 04 W ARCO ALA~KAw TNC, KUP~RIIK ~A~K~R TOP UPPmR SAND BASF ~!PPER SAND TOP bnWER SAND BAS? bOWER SA~D PBTD T~ COMPUTATION DA~BI 25-APR-B5 6626,00 6 58 O0 6~9 O0 6870 O0 6960 O0 7122 O0 PAGE DATE OF SURVltYt 2 AP[~ 85 KEbbY BUSHING EbEVAT~ON~ ENG~NEERI MCBRIDE ORTGIN= 662' rSb,747' TVD E*~O~ KB SUB-SEA 579~,56 5687,56 5~87,g¢ 5 .94 5997.28 5891,28 6072 54 5966,54 6~07:9~ 6101,94 106.00 1 W 1795 ?5 W 808 g42 08 W 1B96 04 W 1932 ~8 W 1999 1~ W 1840 68 S 1859 3t S 188~ 95 S 1929 83 $ 1962 68 $ 2022 O0 S TRUE SUB-SEA MEASURED VERTICAL', VERTICAL DEPTH DEPTH DEPTH DEPARTURE DEG 7122.00 6207,q4 6101,94 2843.44 $ 44 40 W Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. OPERATOR, WELL ~AME~ AND NOMBER Reports and Materials to be received by: q~-~ ~ '~ Date Required Date Received' Remarks Completion Report Samples Mud Log ~:~-~Pf dlf Core Chips Core Description Registered Survey Plat Inclination Survey .... Directional Survey lex Drill Stem Test Reports _Production Test Reports .~ .... ~r~ ......... d~ _ ARCO Alaska, Inc. Post Oflice Eox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE:05-29-S5 TRANSHITTAL NO: 5199 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-!i!5B P.O. BOX 100360 A[KiHORAGE, AK 99510 TIL\NSMITTED tIEKEA~ITIi ARE TiIE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF TI{IS TRANSMITTAL. KUPARUK I~ELL PRESSURE REPORT ENVELOPE DATA: (ONE COPY OF EACH) 2A-4 04-22-85 2A-7 04-23-85 2F-6 03-21-85 2G-8 03-21-85 2G-12 03-23-85 2H-13 04-26-85 2ti-14 04-28-85 2H-15 04-29-85 2U-I 04-11-8'5 2U-2 04-11-85 2U-3 04-11-85 2U-4 04-11-85 2U-5 05-02-85 2U-6 05-03-85 2U-7 05-04-85 2U-8 05-04-85 2U-13 03-09-85 2U-14 03-21-85 2U-!5 03-20-85 2U-!6 03-15-85 2V-2 03-23-85 2V-SA 03-17-85 2V-SA 01-24-85 2W-4 04-13-85 2X-! 04-14-85 2X-3 04-13-85 2X-13 03-30-85 STATIC-'C' SAND STATIC-'A' & 'C' SAND STATIC-PBU-'A' SAND PBU-'A' SAND STATIC-PBU-'A' SAND STATIC-'A' SAND STATIC-'A' SAND STATIC-'A' SAND PBU-'A' SAND PBU-'A' SAND STATIC-'A' SAND STATIC-'A' SAND STATIC-'A' SAND STATIC-'A' SAND ST%"~!C-'A' SAND STATIC-'A' SAND STATIC STATIC-'A' & 'C' SAND STATIC-'A' &'C ' SAND STATIC-'A' &'C' SAND STATiC-'C' SAND STATIC-'C' SAND STATIC-'A' &'C' SAND STATIC-'A' SAND STAT!C-'A' &'C ' SAND' STATIC-'A'&'C' SAND PBU-'A' SAND ~ECEIPT ACKNOWLEDGED: ;PAE* ~. CUKR!ER* ·IIE~" ,-, ~-~, ) & M* DRILLING MOD I L ~ NSK CLERK DISTRIBUTION: W. PASHER EXXON PHILLIPS OIL* J. RATHMELL* STATE OF ALASKA* SOiiiO* U ~ I O N * K. TULiI~/VAULT ARCO Alaska, ' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 05-2 3-85 TRANSMITTAL NO: 5197 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HERE%[ITH ARE Tile FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. FINAL PRINTS OPEN HOLE/SCHLUMBERGER (ONE * OF EACH LISTED.) 2V-~9 ~" 5" DIL/SFL-GR 03-24-85 RUN ~1 3617-8089 2" 'DIL/SFL-GR 03-24-85 RUN ~,1 3617-8089 5" DEN/NEU-GR (PORO) 03-24-85 RUN #1 5700-8064 2" DEN/NEU-GR (PORO) 03-24-85 RUN #1 5700-8064 5" DEN/NEU-GR (RAW) 03-24-85 RUN ~1 5700-8064 2" DEN/NEU-GR (RAW) 03-24-85 RUN #1 5700-8064 CYBERLOOK 03-24-85 RUN #! 5700-8064 !L-15 · ~' 5" D!L/SFL-GR 10-23-84 RUN ~1 3477-6694 2" DIL/SFL-GR 10-23-84 RUN ~! 3477-6694 5" FDC/CNL-GR (PORO) 10-23-84 RUN #1 6000-6654 2" FDC/CNL-GR (PORO) 10-23-84 RUN #1 6000-6654 5" FDC/CNL-GR (RAW) 10-23-84 RUN #1 6000-6654 2" FDC/CNL-GR (RAW) 10-23-84 RUN ~1 6000-6654 5" BHC SONIC 10-23-84 RUN ~1 6000-6684 2" BHC SONIC 10-23-84 RUN ~1 6000-6684 CYBERLOOK 10-23-84 RUN #1 6000-6654 2U-8 5" DIL/SFL-GR 03-28-85 RUN ~1 3025-6934 2" DIL/SFL-GR 03-28-85 RUN 91 3025-6934 5" DEN/NEU PORO 03-28-85 RUN ~1 3025-6910 2" DEN/NEU PORO 03-28-85 RUN ~1 3025-6910 5" DEN/NEU RAW 03-28-85 RUN #1 3025-6910 2." DEN/NEU RAW 03-28-85 RUN 91 3025-6910 CYBERLOOK 03-28-85 RUN ~1 6590-6880 2D-1 5" DIL/SFL-GR /7[ 2" DIL/SFL-GR 5" DEN/NEU PORO 2" DEN / NE U PORO 5" DEN/NEU RAW 2" DEN / NE U RAW CYBERLOOK RECEIPT ACKNOWLEDGED: BPAE *DRILLING-BL B. CURRIER L. JOHNSTON CHEVRON MOB I L D & M*-BL *NSK CLERK-BL 10-27-85 RUN 10-27-85 RUN 10-27-85 RUN 10-27-85 RUN 10-27-85 RUN 10-27-85 RUN 10-27-84 RUN W. PASHER EXXON PHILLIPS OIL *J. RATtIMELL-BL ~,2 2469-6748 2469-6748 2649-6722 2649-6722 264~9~7672~ DATE: *nTATE ~ U N I O N *K. TULIN/VAUL~V~,L~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 D A'T E ' 0 ':";. '-' 9 ,~. ''~ -85 'f'RANSHIT'I"AI_ NO'5'I 70 !:~ETUI?N TO' ARCO AI...A£14A, INC. ~. · · -~ .. ,r.i A T T N: RI::. C 0 I'., I,',.~ . C L. Ii.": A'1" C)- 'l t i 5 B F',O,, B.r.)x t 00:360 A/~CI"IOI"<AE['", Al( 995 FRAN~'NiTTITD I-'II=-.I:;:E]WITH ARE THE r"ol...l. OW ':;ii..".CI::7IPT AND RETURN ONE .?I(.~Nii.".D C, OPY OF .~F:'[:'.N HOLE LIS TAP'~'' "' ~" E.,~ I--I...U,.~ I...]; TIN C; ?;'CI-ILUNBERGEr~ (ONE C, OF:'Y 01-- EACH) f 0,3-..:>0-,.1_;,RUN I '":'")t 0 0-1 081.5 .5 i~ Q :.f -- c ,:' :..: ..,,.,... . ~l.J'-'8 03-,.._ 8-'b.:;,RUN · t .,...~9., ~. ,, 5-696,:~, 5 ,.2.':LJ-'9~'~0'1-04-85 RUN .".':t LI..687 ~l..J--t,..~ 01-2~-li.,'5 RUN :I~:t 7'5. t t6,5-7'(')38,5 '_';3 B .... t 1,.' 04 - 1 3-' 8.5, R IJ N:,'I: t 3328.. ~ '- 7'? 03. (') 5 '~0,'3-29'"'85 RL!N :,'I: t 3992 ,. 0-8463,0 ~'.~B- 1 6'04-06-85' RUN :::t 3'.38t, .5-'7846.0 · ]:TEN,.?, I::'I...E A 5'E ACI(NOWLEI)fJE THIS 'FR~NSHITTAL, R 17 F" :,'I: 7 O 2.30 ", --fi. '~') I.T ~ R E F :Il: 70 277 · , '- :-.11.. ,.)-? ,~- F, EI .,. Ff.),.., I t'-'"~' / R 1:'- F -,. 70... ~ t F::EF-II:702 76 ARCO Alaska, Inc. Post Office Bo J0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 12, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton: Enclosed are the March monthly reports for the following wells' 1Q-3 2u-6 3B-13 17-11 1Q-4 2U-7 3B-14 L1-9 1Q-5 2U-8 3B-15 L2-28 2C-9 2V-9 3-16(W/0) L2-30 2U-5 2W-4 9-27 If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU5/LI06 Enclosures RECEIVED APR 1 6 1985 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ---- STATE OF ALASKA " ALASKA C._ AND GAS CONSERVATION CO. AISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] X Workover operation [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well at surface 662 ' FSL, 747' FWL, Sec.32, T12N, RgE, UM 6. LeaseDesignationandSerialNo. ADL 25644 For the Month of Ma rch ,19 85 5. Elevation in feet (indicate KB, DF, etc.) 106' RKB 7. Permit No. 85-21 8. APl Number 50-- 029-21 284 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2U-8 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 01830 hfs, 03/24/85. Drld 12-1/4" hole to 3050'. Ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 7122'TD as of 03/28/85. Ran OH logs. Ran, cmtd, & tstd 7" csg. PBTD = 6960'. Displ to brine. ND BOP. NU tree. Secured well & RR ¢ 1700 hfs, 03/29/85. Arctic packed 7" x 9-5/8" annulus, 03/29/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16" 62 5#/ft, H-40, weld conductor set ~ 116' Cmtd w/240 sx CS II ~ · · · 9-5/8" 36 O#/ft, J-55, BTC csg w/FS ~ 3023' Cmtd w/750 sx PF "E" & 370 sx PF "C" , · · · 7" 26 O# J-55 BTC csg w/FS @ 7043' Cmtd w/250 sx Class "G" cmt + 250 sx PF "C" , · , , · · 14. Coring resume and brief description NONE 15. Logs run and depth where run DIL/SFL/GR/Cal f/6934' - 3025' FDC/CNL/GR f/6910' - 6420' 16. DST data, perforating data, shows of H2S, miscellaneous data NONE R k. Li V LI./ APR t 6 1985 Alaska Oil & 6as Cons. 6ommissior~ Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED &~/~ )~JJ_~4.~ TITLE Associate Engineer DATE NOTE--Repot n this form is required for each calendar month, re§ardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 ........... Submit in duplicate MEMORANDUM State of Alaska TO: THRU: ALAS~ OIL AlqD GAS CONSERVATION CO}~ISSION .'- /? C. V~'~/~te~rton DA/E: March 28, 1985 Chai~~ Lonnie C. Smith Co~issioner FILE NO: D.HRH. 25 TELEPHONE NO: FROM: Harold R. Hawkins ~, ~ .~, SUBJECT: Petroleum Inspector~/?'~'~;~ Witness BOPE Test on ARCO Alaska, Inc., KRU 2U-8 well, Sec. 32, T12N,R9E,UI, i, Pemit No. 85-21. Tuesday, March 26, 1985: I left Conoco's "C" Pad, subject of ano-~e~-'-~p~-rt, to~'s 2U-8 well at the KRU to witness a BOPE test. I witnessed the BOPE test on 2U-8 KRU. There were no failures. I filled out an AOGCC report which is attached. In s~ary, I witnessed the BOPE test that Doyon 9 performed for ARCO's 2U-8 KRU. .The BOPE tests were satisfactory. Attachment (~?-G01A(Rev. 10/79~ O&G #4 5/84 Inspector STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report' Date Well Location: Sec.32 T/gJ/R ~M Drillin8 Contractor p~V,,4 ~,",~ Ri Location, General _ ACCUMULATOR SYSTEM General Housekeeping ,_..?/~. _Rig, C~ Reserve Pit /.9 [~ Mud Systems Visual Audio Trip Tank PitGauge Flow Monitor Gas Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Results: Failures Test Pressure Yoc s ..70o. Full Charge Pressure ~,.~'-~ psiR -- ..__ Pressure After Closure / ~ ~"-~? psig --- Pump incr. clos. pres. 200 psiR ..~- min.~_M~sec. Full Charge Pressure Attained: ~ min~ sec. Controls: Master /(f/~' Remote 0~' Blinds switch cover ~/'75 Kelly and Floor Safety Valves Upper Kelly Lower Kellx Ball Type Inside BOP Choke Manifold N°. Valves/~ No. flanges .~ Adjustable Chokes /9/~.<q- ~'// ~erated choke Test Time / , hrs. Test Pressure,. Test Pressure,., Test Pressure_. Test Pressure Test Pressure Repair or Replacement of failed equipment to be made within'~--~ days and Inspector/ Commission office notified. Remarks:j~ ~ ~/ z~7 B/> /b '~-~-:, / '~ Distribution orig. - AG&GCC cc - Operator cc - Supervisor February 19, !985 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Kuparuk River Unit 2U-8 ARCO Alaska, Inc. Permit No. 85-21 Sur. Loc. 662'FSL, 747'~, Sec. 32, T!2N, RgE, UM. Btmhole Loc. 1477'FNL, 1377'FEL, Sec. 6, T!IM, RgE, UM. Dear Mr. Kewin- Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of dril!~cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their .drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereUnder (Title 18, Alaska Administrative Code., Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Jeffrey o. Kewzn Kuparuk River Unit 2U-8 _9_ February 19, 1985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. 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. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Ver~y--~ !y ~~s..~ ~ C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COt~ISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o enc!. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. ~ Post Office Bo,. ,00360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 31, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Kuparuk 2U-8 Dear Mr. Chatterton' Enclosed are' o We estimate spudding this well on March 25, 1985. questions, please call me at 263-4970. Sincerely, A;e;' D~/~'i ing Engineer JBK/HRE/tw PD/L31 Attachments An application for Permit to Drill Kuparuk 2U-8, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plat A diagram and description of the surface hole diverter system A diagram and description of the BOP equipment If you have any RECEIVED F E B 0 5 1985 Oii & Gas b[m$."'~ Con, mission ~ . ~ , ~,~cnorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA~ ~"~-~ ALA6KA O~L AND GAS CONSERVATI..~ CO,...~IlSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL E~X REDRILL [] DEEPEN [] 1 b. Type of well EXPLORATORY [] DEVELOPMENT OIL E~x DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [~X 2. Name of operator ARCO Alaska, Inc. 3. Address ~C~/~./~ P. O. Box 100360, Anchorage, Alaska 99510 ~ 662' FSL, 747' FWL, Sec.32, T12N, RgE, UM 4l~8~ 0S At top of proposed producing interval a 0// & ~ At total depth 1477' FNL, 1377' FEL, Sec. 6, T11N, R9E, UN 5. Elevation in feet {indicate KB, DF etc.) 6. Lease designation and serial no. RKB 106', PAD 69' ADL 25644 ALK 2575 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 9. Unit or lease name Kuparuk River Unit lO. Well number 2U-8 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool Amount $500,000 13. Distance and direction from nearest town 30 mi. NW of Deadhorse miles 16. Proposed depth(MD & TVD) 7260' MD, 6256' TVD feet 14. Distance to nearest property or lease line 662' ~ surface feet 17. Number of acres in lease 2560 t15. Distance to nearest drilling or completed U-7 Well 60~ ¢ surface feet 18. Approximate spud date 03/25/85 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 1806 feet. MAXIMUM HOLE ANGLE 20. Anticipated pressures (see 20 AAC 25.035 (c) (2) 27!9 3!25 psig@~0oF Surface psig@ 5100 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE Hole I Casing Weight 24" I 16" 62.5# 12-1/4" 9-5/8" 36.0# 8-1/2" 7" 26.0# 22. Describe proposed program'. CASING AND LINER -- Grade Coupling H-40 Wel HF-ERW HF-ERW Length 80' 35' I 3056' 35' i 35' 7226' SETTING DEPTH MD TOP TVD I 35' 34' 134' I M D BOTTOM TV D 115'I 115' 3091' I 2996' 7260' I 6256' 1 __ QUANTITY OF CEMENT (include stage data) 650 sx Permafrost "E" 740 sx Permafrost "C" 250 sx Class G neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7260'MD (6256'TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through the West Sak Sands at approximately 3091'MD (2996'TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5~' surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psi O0 ps;~ for annular). Expected maximum surface pressure is 2719 psi. Pressure calculations are based On la~es~c~mbS~rvoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged. The well will be completed, using the workover rig, with 2-7/8", 6.5#, J-55, EUE 8rd tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be (see attached sheet) hereby that the foregoing is true and correct to the best of my knowledge SIGNED TITLE Area Drilling Engineer The spac~.D~V ,o~t.~slon use CONDITIONS OF APPROVAL Samples required [~YES '~-N O Permit number APPROVED BY Form 10401 Mud log required []YES E~O Approval date (HRE) PD/PD31 Directional Survey required I APl number [~ES E~NO I 50- O~/'- SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE February 19, 1985 by order of the Commission Submit in triplicate PERMIT TO DRILL 2U-8 installed and tested upon completion of the job. 2U-8 will be the twelfth well drilled on the pad. It is ± 60' away from 2U-7 at surface. There are no other close wellbores anywhere downhole. Top of cement for the production string will be placed at 5750'MD, approximately IO00'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. After the completion rig has moved off location, the well will be fracture stimulated. ~NNN , f 1 ,. 3 ~tr~ mrna 1806 :,, TFID-' '- -T-T-, 'SAK ; 2 TVD'2? 8O6 lee ?T TVD, w2456 rldO.-~469 TI11D=284; DEP,2?~' IiIN F :CO { . Alaska Oil & Gas Cons. Cornmissiort Anchorage 190 5 ¸. · i II Surface Oiverter System I. 2. 3. ¢. . . e 16" - 2000 psi Tankco starting head. Tankco quick connect assy. 16" x 20" 2000 psi double studded adapter. 20" 2000 psi drilling, spool w/lO" side cull ets. 10" ball valves, hydraulically actuated, w/lO# lines to rese~/e pit. Valves to open automat'ically upon closure of annular preventer. 20' 2000 psi annular'preventer. 20" bell nipple. · Maintenance & Operation 1. Upon initial installation close annular preventer and verify tha: ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines 'every 12 hours. 3. Close annular preventer in the event-that gas or fluid flow to surface is detected. If necessary, manual ly override and close ball valve to upwind diverter line. Do not shut in well under an), circumstances.,. · 16" Conductor RECEIVED AlasKa Oil & Gas Cons· Commission A~chorage 7 6 2 i .i Bas Cons, gommtssmn Anchorage ARCO Alaska, Inc. '~ Post Office Bu,, 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 25, 1985 Mrs. Elaine Johnson State of A1 aska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: Conductor As-Built Location Plats - 2U Pad Wells 1-8, 9-16 Dear Elaine' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer OG/tw GRU3/L77 Enclosure If RECEIVED ,,t A F! 2 9 1985 0~J & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany WELL 1 Y = 5,975,841.16 LAT. 70°20'42.7599'' × = 509,642.25 LONG. 149°55'18.2508'' PAD =_LEV. 68.4 - C.G. ELEV. 64.2 FSL i75 FWL 1,096 I · WELL 2 Y = 5,~75,782.54 LAT. 70°20'42.1835" × = 509,627.77 LONG. 149055' 18.6762" " PAD ELEV. 68.4 C.G. ELEV. 64.1 FSL 517 FWL 1,O81 i WELL 3 Y = 5,975,724.43 LAT. 70o20'41.6122'' X = 509,613.34 LONG. [49055' 19.0999" PAD ELEV. 65.3 C.G. ELEV. 64.0 FSL 458 FWL 1,O66 WELL 4 Y = 5,975,666.21 LAT. 70°20'41.O397'' X = 509,599.09 LONG. 149055' 19. 5187" PAD ELEV. 68.4 C.G. ELEV. 63.9 FSL 400 FWL 1,052 WELL 5 Y = 5,975,753.43 LAT. 70o20, 41.902" X = 509,249.86 LONG. 149°55' 29.720" PAD EhEV. 68.6 C.G. ELEV. 64.4 FSL 488 FWL 703 WELL 6 Y = 5,975,811.41 LAT. 70°20' 42.472" · t X = 509,264.30 LONG. 149°55' 29. 296" · ~ PAD ELEV. 68.6 C.G. ELEV. 64.4 , · 3 FSL 546 FWL 718 WELL 7 Y = 5,975,869.59 LAT. 70°20' 43.044" X -- 509,278.75 LONG. 1~+9°55' 28.87t" PAD ELEV. 68.6 C.G. ELEV. 64.3 FSL 604 FWL 732 WELL 8 Y = 5,975,927.80 LAT. 70°20' 43.616" X = 509,293.26 LONG. !4~°55' 2~.445 51 ~_ PAD ELEV. 68.5 O.G. ELEV. 64.2 FSL 662 FWL 747 ~ 5 ~ ~.......,. LOCATED IN PROTRACTED SECTION 32 ~%~.....:.,._. --]1[-o,,~,.,4.-i,_ -,_- TOWNSHIP 12 ,, RANGE 9 E, UMIAT MER. · NOTE: BASIS OF BEARING IS PAD PILING CONTROL BASIS OF ELEVATION IS 2U-5 AND 2U-4 PER '~,"?Of£,,r$1ONl[~.~,_ ~--'~'~ LHD ~ ASSOCIATES. , LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARE CORRECT AS OF .-~-~:> '" ." ' ARCO Al(:;sko, Inc. ~ ~~_f7~ Kuparuk Project North Slope Drilling I1~,~,-'~ ' DRILL SITE 2U i lUll ' " LOCATIONS illS[& / ...~SCALE: I = '"-' Drawn By' HZ Dwg. No. NSKO.O5.221dl i i ii i i i CHECK LIST FOR NEW WELL PERMITS DATE ITEM APPROVE (1) Fee (2) Loc (3) (13 thru ~1)-- (5) (22 th~u-~-~- ~-~&o Lease & Well No. Company YES NO 3. 4. 5. 6. 7. 8. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. Is well located proper distance from property line .................. Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is wellbore plat included ................ Is operator the only affected party .................................. Can permit be approved before ten-day wait .......................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..... i ........... ~J~/ Will surface casing protect fresh water zones ............ iid°ii Will all casing give adequate safety in collapse, tension Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................. .~./~ 22. Is a diverter system required ....................................... 23. Are necessary diagrams of diverter and BOP equipment attached ....... 24. Does BOPE have sufficient pressure rating - Test to ~-~Z~ psig 25. Does the choke manifold comply w/API RP-53 (Feb.78) .................. 26. Is the presence of H2S gas probable ................................. 27. Additional requirements ............................................. ~ Ceology: ~, EngineeriJ~g:, LeS ~ev: 10/29/84 6.CLOT INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. C~SZNG V?' .,,. )C ,3 .S ~: T '¥ ~J E ~ 'T CPS ~0 330 30 O i 68 OOOO000000000~} I 68 0000000000000~) SP -SZ. 5000 ~3R i0~. 962~ uR RnS~ OR~ '].159Z NEAT N P ~I N C ~'; t 2 O 90.00 00 ~ C ~ t 5. Z539 Z.L.M 2. 5977 10~.06 ~_~ C.~,z :~. 5000 5513 -,5879 RNRA 3. 7891 .:5 O00 2- 534.8 NP~i -; 9':~. 2500 - 99':~..]5 O0 NRaT -999. '~500 NFn~ --~9'9. Z 500 NCNL :~ P - Z '7 · .~. I .Z 5 3 R RH08 -J99. ZSOG DR;~O 3.~551 iLD 3. 2168 .iL',~ B..~t477 102.3750 ~R 102.3750 CALl I0.35~4 -99~$' !500 :~R~T --99'~-Z500- RNRA -999.2590 · S P 9766' RH38 -999. :ZSO0 ~ R ,,,i [1 -99'9.2500 NR~AT -99'9.2.500 ;';Pal -99.9.~0u i-.,iC NL -9S3.Z500 =C.'~L - ~'97~. ZbDO 3.3252 3.5721 -~99.2500 ~?T 3300.OOgg .~- LU 3,5~_50 ZLD 3. ~73% £LM 3.72o6 9.?I09 -R99.2.500