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HomeMy WebLinkAbout195-0571. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10686'feet None feet true vertical 6089'feet 10470'feet Effective Depth measured 10370'feet 10101', 10171', 10178'feet true vertical 5849'feet 5654', 5703', 5708'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 10205' MD 5728' TVD Packers and SSSV (type, measured and true vertical depth) 10101' MD 10171' MD 10178' MD 506' MD 5654' TVD 5703' TVD 5708' TVD 506' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 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: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 346 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker FHL Packer Packer: NS Liner Top Packer Packer: Baker SAB-3 Perm Packer SSSV: Camco DS Nipple James Ohlinger james.j.ohlinger@conocophillips.com (907) 265-1102Staff CTD Engineer 10298-10306', 10349-10369', 10398-10416' feet 5795- 5801', 5833-5848', 5869-5883' feet measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 246 Gas-Mcf MD 1297 Size 121' 1563 1361194 80 224577 261 measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 195-057 50-103-20219-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025548 Kuparuk River Field/ Kuparuk River Oil Pool KRU 2T-30 Plugs Junk measured Length Production Liner 10638' Casing Structural 6082'10676' 4164' 121'Conductor Surface Intermediate 16" 9-5/8" 80' 4203' 2871' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Anne Prysunka at 10:59 am, Nov 16, 2022 DTTMSTART JOBTYP SUMMARYOPS 10/1/2022 ACQUIRE DATA TAG FILL @ 10,380' RKB. OBTAIN SBHPS @ 10,370' RKB (3031 PSI) DRIFT TBG W/ 2.62" X 15' BAKER DMY WHIP STOCK, DIDN'T GET PAST 4518' RKB. DRIFT TBG W/ 2.62 GAUGE RING TO 10,231' RKB. JOB IN PROGRESS. 10/2/2022 ACQUIRE DATA DRIFT TBG W/ 2.62" X 15' BAKER DMY WHIP STOCK DRIFT.TO 10,370' RKB, NOTE TIGHT SPOT IN TBG @ 4518' RKB (HAD TO TAP DRIFT BY) READY FOR COIL. 10/3/2022 ACQUIRE DATA MOVE FROM 2M PAD TO 2T PAD, SPOT CTU # 14, RIG UP AND INSTALL BAKER 2.80" MILL WITH 2.13" LEFT HAND MOTOR. RIH AND TAG D NIPPLE @ 10,193 RKB. P/U WEIGHT 24.7K, START PUMPING 1.4 BPM. START TIME MILLING D NIPPLE. JOB ONGOING. SLB TRACTOR 2 HOURS TROUBLE TIME, SLB PUMP REBUILT OFFLINE. 10/4/2022 ACQUIRE DATA MILL D NIPPLE @ 10,193' RKB. WITH 2.80" MILL. DRIFTED THROUGH 3X WITH PUMPS OFF. CLEAN. PERFORM FCO IN 7" FROM 10,370' TO 10,420' RKB USING MILLING BHA WITH GEL DIESEL & SSW. POOH, FREEZE PROTECT WELL & COIL. RDMO. JOB COMPLETED. 10/5/2022 ACQUIRE DATA CONVEY READ 24 ARM CALIPER FROM 10361.5' TO 9900' AT 50 FPM. REQUIRED PUMPING TO PASS 2240' AND GET TO BOTTOM, INCOMPLETE LOG (CALIPER ARMS NOT FULLY EXTENDING IN 7" CASING), BECAME TEMPERARILY DETAIN ON POOH @ 6960', PUMP TO GET FREE. NOTE: AT SURFACE CCL & CALIPER PACKED OFF WITH FINE METAL SHAVING. JOB COMPLETE. 10/6/2022 DRILLING SIDETRACK Waited on pad to be built up started move from 1D to 2T 10/7/2022 DRILLING SIDETRACK Continue move to 2T pad , spot over 2T-30 State witnessed BOP test completed @ 22:00 PT PDLS and hard line to tiger tank 10/8/2022 DRILLING SIDETRACK P/U clean out BHA #1 w / 2.45" DJN, pick up memory caliper, caliper F/10400 T/ 9742' M/U & RIH W / HEW tie into K 1 -8' correction set @ 10371.75' BOWS 10363' TOWS 10/9/2022 DRILLING SIDETRACK Set HEW at 10371.75' BOWS 10363' TOWS set 5 k down on HEW / P/U and deploy BHA #4 milling assembly // dry tag WS @ 10,368.8 mill from 10,368.22, exit bottom @ 10371' // Drill rat hole to 10398, perform reaming passes per plan // POOH for build assembly// Deploy build section assembly 10/10/2022 DRILLING SIDETRACK RIH w / Build section assembly 2.4° AKO & Dynamus bit finished build @ 10,485' P/U ER lateral assembly w / 0.5° AKO motor start drilling lateral F / 10.485 T/ 11,500' continue drilling 10/11/2022 DRILLING SIDETRACK 11,500' continue drilling lateral to 12,516', pull wiper to casing, jetted the 7", when RBIH, tagged at 10,398', attempt to work thorugh, unable to make progress, POOH, PU cleanout BHA, RIH, cleanout build section to 10,485', POOH, PUD CO assembly, PD lateral drilling assembly, RIH 2,361' 2T-30 CTD Summary of Operatons 10/12/2022 DRILLING SIDETRACK Continue IH, log formation for depth control, tag bottom of window 10,374', rotate mud pump, RIH through window with +/- 1k weight bobble, continued IH, drilled ahead from 12,503' to TD 13,380', chase sweeps to the window, jet 7 inch, POOH to surface, reset counters, RBIH 10,210' 10/13/2022 DRILLING SIDETRACK Log formation for depth control, obtain static, confirm TD, Lay in beaded LRP, displace well to KWF, LD drilling assembly over a dead well, MU Lower Liner segment w/42 slotted, RIH, release liner on depth/bottom 13,380', POOH, LD setting tools over a dead well, MU Upper Liner segment w/43 slotted, RIH to 6,415' 10/14/2022 DRILLING SIDETRACK Continue IH, correct to EOP flags, log K1 for depth, release liner on depth, TOL @ 10,710', drilled ahead to midnight depth 11,798' 10/15/2022 DRILLING SIDETRACK Continue drilling L1-01 lateral from 11,798' to midnight depth 13201', wiper to the window, jetted 7 inch, visual inspection of INJH found cracked peanut/link, repaired 10/16/2022 DRILLING SIDETRACK Completed chain inspection, logged K1 for depth contorl, wiper back in hole, drill L1-01 lateral from 13,200' to 13,425', perform swab wiper, RBIH, logged formation for depth control, obtained SBHP 3,365 psi, KWF 11.8 ppg, continued IH confirm TD 13,425', Lay in LRP up to the window, displace well to 11.8 ppg completion fluid, LD tools, PU Lower L1-01 liner completion with 52 slotted, and non-ported BN 10/17/2022 DRILLING SIDETRACK Finish MU Lower liner segement w/60 slotted, RIH, work pipe pass 11,845' and 12,298', release liner on bottom 13,420', POOH, MU Upper liner segment 37 slotted, 6 solid, swell packer, and SBR, RIH, release liner on depth, TOL=10,178' BOL=13420', displace well to SW, freeze protect well from 2,500', PUD setting tools, FTP=972, IA=938, OA=118, *** Rig Released @ 23:59 10/17/22 10/21/2022 ACQUIRE DATA DRIFT W/ MAG STEM & 2.68" DOWN TO LINER TOP @ 10,178' RKB; MEASURED BHP @ 10,178' RKB; SET 2.812" DS-CSV @ 10,121' RKB; REPLACED OV @ 9953' RKB; REPLACED GLV'S @ 9105' & 7649' RKB. IN PROGRESS. 10/22/2022 ACQUIRE DATA REPLACED GLV'S @ 5562' & 3123' RKB (OBTAIN TBG TEST TO 2500 PSI); PULLED CSV @ 10,121' RKB; BRUSH n' FLUSH DOWN & INTO LINER TOP @ 10,184' RKB; SET 2.72" NORTHERN SOLUTIONS LINER TOP PACKER W/ 1.78" RX PLUG PTSA @ 10,171' RKB; OBTAIN TBG TEST TO 2000 PSI & PULLED 1.78" RX PLUG W/ RSG @ 10,185' RKB. JOB COMPLETE. C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-10-08_20250_KRU_2T-30_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 20250 KRU 2T-30 50-103-20219-00 Caliper Survey w/ Log Data 08-Oct-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:195-057 T37172 Kayla Junke Digitally signed by Kayla Junke Date: 2022.10.20 12:46:20 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-10-04_15874_2T-30_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 15874 KRU 2T-30 50-103-20219-00 Caliper Survey Log 04-Oct-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:195-057 T37151 Kayla Junke Digitally signed by Kayla Junke Date: 2022.10.14 11:29:36 -08'00' WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďLJĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϭϵϱϬϱϳϬͲ^Ğƚ͗ϯϲϮϱϰJRBy Abby Bell at 1:43 pm, Dec 21, 2021 3M-1750029217290000 KRU WLWFLFINAL FIELD24-Apr-213M-1950029217370000 KRU WLLDLFINAL FIELD25-Apr-213H-0150103200840000 KRU WLCHCFINAL FIELD26-Aug-213H-1250103200880000 KRU WLCCLFINAL FIELD23-Sep-213H-1250103200880000 KRU WLCHCFINAL FIELD29-Aug-213H-1250103200880000 KRU WLCUTTERFINAL FIELD23-Sep-213H-1250103200880000 KRU WLCUTTERFINAL FIELD24-Sep-211L-1250029220330000 KRU WLSBHPSFINAL FIELD6-Nov-213G-2450103201450000 KRU WLTBG CORRFINAL FIELD29-Oct-211A-2550029221160000 KRU WL WHIPSTOCKFINAL FIELD12-Oct-211A-2350029221310000 KRU WLRBPFINAL FIELD12-Jun-211R-2050029222070000 KRU WLPPROFFINAL FIELD2-Jun-212M-1150103201590000 KRU WLPPROFFINAL FIELD27-Aug-212M-0750103201780000 KRU WLBACKOFFFINAL FIELD5-Aug-211Y-1950029223910000 KRU WLPPROFFINAL FIELD31-May-212T-3050103202190000 KRU WLLDLFINAL FIELD2-May-211Q-20A50029225890100 KRU WLSET RECFINAL FIELD2-Aug-212M-3350103202400000 KRU WLLDLFINAL FIELD18-Oct-211F-03A50029208530100 KRU WLPERFFINAL FIELD19-Oct-211Q-08A50029212250100 KRU WLIPROFFINAL FIELD30-Apr-211E-3350029227970000 KRU WLPPROFFINAL FIELD26-Mar-211D-13550029228160000 KRU WLLDLFINAL FIELD16-Jul-213F-13A50029214990100 KRU WLGLSFINAL FIELD17-Jul-212N-318 50103203430000 KRU WLSCMTFINAL FIELD12-Nov-211C-12750029230240000 KRU WLIPROFFINAL FIELD17-Nov-213S-24A50103204560100 KRU WLCUTTERFINAL FIELD25-Oct-213S-0350103204580000 KRU WLIBPFINAL FIELD26-Oct-211B-2050029231640000 KRU WLPPROFFINAL FIELD22-Apr-211E-11950029231980000 KRU WLLDLFINAL FIELD26-Jun-212W-1750029233700000 KRU WLPPROFFINAL FIELD28-Aug-211H-11850029235780000 KRU WLIPROFFINAL FIELD4-Nov-211H-11450029235840000 KRU WLIPROFFINAL FIELD23-Jun-211H-11350029235880000 KRU WLWFLFINAL FIELD22-May-21 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beved~ncent Nathan Lowell Date: Is~ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 18, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: 2T -30 Run Date: 9/23/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T -30 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50 -103- 20219 -00 Production Profile Log 1 Color Log 50 -103- 20219 -00 NOV PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. i� 5 Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood_ @halliburton.com Date: Signed: ~.J ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 1, 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 r. s ,,s, - Commissioner Dan Seamount: `~,i~ ii? ~q5-~~~ aT- ~ ~~'~ ~r~~"~ '~ ~ 20~~, ~r~h,~r,g~ C's~:. 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 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 July 21St. The corrosion inhibitor/sealant was pumped July 30th, 31St 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/01/10 ~R ~K ~T pnn Well Name API # 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 2B-13 50029211380000 1841040 64" 0.4 11" 7/21/2010 1.7 7/31/2010 2K-16 50103201150000 1890940 SF n/a 19" n/a 2.8 7/31/2010 2K-20 50103201200000 1891180 10" n/a 10" n/a 2 7/31/2010 2K-23 50103201250000 1900140 SF n/a 18" n/a 2.6 7/31/2010 2K-24 50103201220000 1891300 SF n/a 18" n/a 2.6 7!31/2010 2T-07 50103200690000 1861080 17" n/a 17" n/a 5.1 7/30/2010 2T-19 50103202140000 1950260 18" n/a 8" n/a 2 7/30/2010 2T-20 50103202150000 1950290 SF n/a 23" n/a 2.6 7/30/2010 2T-21 50103202120000 1950130 SF n/a 21" n/a 3.4 7/30/2010 2T-26 50103202230000 1950820 SF n/a 27" n/a 4.3 7/30/2010 2T-29A 50103202220100 2091360 SF n/a 29" n/a 7.7 7/30/2010 2T-30 50103202190000 1950570 SF Na 30" n/a 6 7/30/2010 2T-31 50103202260000 1950990 30" n/a 30" n/a 6 7/30/2010 2T-36 50103202280000 1951020 SF 0.40 12" 7/21/2010 2.6 7/30/2010 2T-39 50103203920000 2011830 30" 0.54 14" 7/21/2010 4.3 7/30/2010 2T-201 50103202300000 1951220 60" 1.57 32" 7/21/2010 7.7 7/30/2010 2T-204 50103203270000 2000160 SF n/a 24" n/a 5.1 7/31/2010 2T-209 50103202810000 1982430 40" 1.20 19" 7/21/2010 4.8 7/31/2010 2T-218 50103204490000 2030170 31" 0.73 9" 7/21/2010 2.6 7/31/2010 2T-220 50103202830000 1982530 38" 0.49 19" 7/21/2010 5.1 7/31/2010 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMIS~1 REPORT OF SUNDRY WELL OPERATIONS ~~~wE~ ~,«`y' ~. aw 7~1~ 1. Operations Performed: Abandon ]"`, Repair w ell ~ Plug Ft'rforations ~ Stimulate ~ Other ~0~$$10~ S ~ ' Qlk . ARer Casing Pull Tubing ~ F~rforate New Pbol Waiver 7ii18~il~t~§~h ~ Change Approved Program ~ Operat. Shutdow n Perforate Re-enter Suspended Wdkf19'1Qfi1 2. Operator Name: 4. Current Well Status: Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory ~ 195-0570 3. Address: Stratigraphic Service "`` API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20219-00 7. Property Design2t~on: 8. WeII Name and Nurr~ier: ADL 25548 2T-30 ~ 9. Field/Pool(s): ~ Kuparuk River Field /Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 10686 feet Plugs (measured) 10170', 10193' true vertical 6092 feet Junk (measured) 10470 Effective Depth measured 10589 feet Packer (measured) 10101, 10178 true vertical 6017 feet (true verucal) 5656, 5711 Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 16 121 121' SURFACE 4165 9.625 4203 2875 PRODUCTION 8588 7 10676 6084 Perforation depth: Measured depth: 10298'-10306', 10349'-10369', 10398'-10416' True Vertical Depth: 5804'-5809', 5839'-5854', 5875'-5888' ,~?~~,,~4~;, i ti~~' _ Io,~!+ ~ ~' (~ ~( Tubing (size, grade, MD, and TVD) 3.5, L-80, 10094 MD, 5652 TVD Packers & SSSV (type, MD, and TVD) PACKER -BAKER FHL PACKER @ 10101 MD and 5656 TVD PACKER -BAKER SAB-3 PERMANENT PACKER @ 10178 MD and 5711 TVD NIPPLE - 2.875" CAMCO "DS" Nipple @ 506 MD and 506 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation SI Subsequent to operation SI 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run Exploratory "" Development Service . Well Status after work: Oil ~ Gas WDSPL Daily Report of Well Operations XXX GSTOR WAG ~'! GASINJ ~""` WINJ SPLUG 16. 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: 310-095 contact Erik Q. Nelson t~ 263-4693 Printed Name Eril Q. Ison Title Wells Engineer Signature \ ,% Phone: 263-4693 Date /~/ y .~yL,.'7 ~~~ ~ ~~d! L v t Form 10-404 Revised 7/2009 RB~S MAY 2 6 y~,,',,, ~ ~ Z ' ~ ~ Submit Original Only ~~ --„ Canocaphiltips ~. -~. ..5 ,Yweil c _fi3 zoo arzsna v 3' o su r>7 __ _. Schbneac -Actual HANGER, 31 - coNOUCroR.-.__ a1 1z1 NIPPLE. 506 I 7"Tie Aack PRODUCTION, 38-2,068 GAS LIFT, 3,123 SURFACE. 35-0,203 GAS LIFT, 5.563 GAS LIFT, 7,669 GAS LIFT, 9.105 GAS LIFT. 9,953 SEAL ASSY, 10,072 PBR, 10.075 PACKER, 10.101 NIPPLE. 19.121 OVERSHOT, 19,141 CATCHER, 10,163 PLUG, 10,170 NIPPLE. 10.170 ANCHOR, 10,177 PACKER. 10.178 • ~ KU P 2T-30 Well Attributes Max Angle & MD TD _ Wellbore APl/UWI Fieltl Name _ Well Status Intl(') MD (kKB) Act Btm (kKB) I SOtf1'8Cf121t1f111 KIIPA1211K RI\/FR IINIT PRn(1 fh fiS -ri 4D531 10-6860 Comment KB-Grd (ft) Rig R lease Date Date 'Annotat on ~ End Data ~ H25 (ppm) '. SSSV~ NIPPLE i I 1 100 1/11/2009 Last WO. 4/27/2010 5113/1995 Annotation De th ftK6 End Date Annotation Last Mod ... i End Date Last Tag RKB ~1 0,330.0 I 5/3/2009 (Rev Reason WORKOVER I Imosbor ~ 4129/2010 CaSing $tnn S Casing Des ription String 0... String ID ... Top (kKB) Set Depth (f... Set Depth (ND) ..'String WL.: Str ng .. String Top Thrtl CONDUCTOR 16 15.062 405 121.0 121.0 62.58 H-00 _ I Casing Description String 0... String ID ... Sbing Wt... Strmg ... String Top Thrtl Top (RKB) Set Depth (f... Set Depth (ND) ... SURFACE 9 5/8 8.679 38.5 4,203.4 2,874.5 40.00 ~ L-80 BTC _ Casing Description String O... String lD ... Top (kKB) Set Depth (f... Set Depth(ND)...'String Wt... (String ... String Top Thrd 7" Tie-Back 7 6.276 37.S 2,088.0 1,909.3 ~ 26.00 I L-80 TC 2 PRODUC l ION I ' Casing Descnption String 0... Sbing ID ... Top (kKB) Set Depth (f.. Set Depth (ND) .. ~IString Wt... Str ng ... (String Top Thrd PRODUCIICN 7 6.151 2,088.0 10,616.0 6,084.2 26.00 L80 I _ BTCMOD - Tubing Strinys __ Tubing Description '.String 0... 'String ID ... Set Depth (ND) . Strmg Wt... (Str g ...String Top Thrtl Set Depth (f... Top (kKB) 1 UBING ( 31/2 1~ 2.592 l ( 31.0 10,093) 5,651.8 9 30 L 80 EUE M _ Completion Det ails _ _ , Top Depth I (ND) Top Intl Nomi_. Top (ftK6) (kKB) l°) Item Description Comment ID (in) 31.0 31.0 -2.96 HANGER Tubing Hanger 2.992 506.3 506.1 3 81 NIPPLE 12.875" CAMCO "DS" Nipple ~ 2.875 10,072.0 5 63fi.2 45.40 SEAL ASSY (Seal Assembly Locator wl19.35'stroke w/T Space Out. 2.990 Tubing Descr ption 'String 0... String ID ._ Top (RKB) Set Depth (f... Set Depth (ND) . Strmg Wt... IStr g ... String Top Thrd I Stacker Packer _ 5.67 L_ 4.0.00 l 10,078__6 _l_1q.149.0 I 5,692.0 _~... _-.1 ___ Completion Det ils a Top Oepth _ _ __ 1 I (ND) Top Intl Nomi... Top (kKB) (kKB) (°) Item Description Comment ID (in) 10,078.6 5,640.9 45.32 PBR 80-00 PBR 4.000 10,101.4 5,657.3 45.O61,PACKER - Baker FHL Packer 2.94011 10,121.2 5,671.7 44.84~NIPPLE 2.813" Camco "DS" Nipple EUE 8rd w/RHC Plug "G-Fishing Neck" 2.812 10,140.6 5,685.9 44.62OVERSHOT BOT Poorboy Overshot 3.620 Tubing Des cription String 0... String ID ... ___ Top (RKB) Set Depth (t... Set Depth (ND) ... Sbing Wl... String ... String Top Thrd TUBING O riginal 31/2 2.992 10,143.6 10,2055 5,734.1 9.30 L-80 ABM-E UE Com letion Det ails i I Top Deplh ~, (ND) ' Top Inel Nomi... Top (kKB)' (ftK6) (°) Item Description Comment ID (in) 10,169.6; 5, 707.3 ~;, ~ 44.29 NIPPLE CAMCO W-1 SELECTIVE LANDING NIPPLE 2.812 10, 17Z2 5,1129 44.20 ANCHOR K-ANCHOR, RUN w/PACKER 3.250 10,178.1 5,713.6 44.19 PACKER BAKER SAB-3 PERMANENT PACKER (SEAL ATTACHED) 3.250 10,193.3 5,724.9 44.02 NIPPLE CAMCO'D' LANDING NIPPLE w/2.795" NO GO 2.750 10,204.6 5,733.41 43.89 SOS - BAKER SHEAR OUT SUB 2.992 Other In Hole ( Wireline retrievabl eplugs, valves, pumps, fish, etc.) _ - - _ - -_ ___ Top Depth (TVDI Top Intl Top (ftK6) (kK6) (°) Description Comment Run Date ID (in) 10,163 5,7024 44.36 CATCHER 2.71"x87.5" CATCHER SET ON PLUG 3/28/2010 0-000 10,170 5,707.5 44.28 PLUG 2.81" N1A-2 PLUG 10/12/2009 0.000 10,193 5.724.7 44.02 PLUG 2.75" CA-2 PLUG 8/17/2009 0.000 10,470 5,927.1 40.87 FISH 1 1/2"DV DROPPED 6/26/981N RAT HOLE 6/26/1998 0.000 i P rf rati ns 8 Slots i e o o Shot Top (TVD) Btm (TVD) Dens Top (kK6) Btrn (RKB) (kKB) (ttK6) Zone Date (sh... Type Commerd 10,298 10,306 5,8037 5,809.2 C-0, 2T-30 7/5!1998 4.0 APERF 25" H.C. B.H., 180 deg ph, 90 deg. orient 10,298 10,3061 5,803.7 5,809 2 C-0, 2T-30 7112/1998 4 0 RPERF BH, 180 deg. ph, 90 deg. orient 10,349 10,3691 5,839.4 5,853.7 A-3, 2T-30 9/17/1995 4 0 IPERF 2 1]8" EJ, 180 deg ph; oriented (+/-) 90 deg. lowside. 10,39fl1 10,416 5,874.5 S,fl8Z5'A-22T-30 6/9/2002 6.OIAPERF 2.5"PJ, 60 deg phase (Notes: General __ 8 Safety _ __ End Date Annotation - 10/22009 NOTE: LDL FOUND LEAK @ 10,158' ELMD 4/29!2010 NOTE: VIEW SCHEMATIC w/Alaska Schematlc9.0 Mandrel Details , -- _ Top Depth Top PoR I (TVD) Intl OD Valve Latch Size TRO Run ' Stn Top (kKB) (kKB) (°) Make Model (in) Serv TYPe TYPe (In) (Psi) Run Date i Co_m... 1 3,123.0 2 404.8 62.50 Camco KMBG 1 GAS LIFT DMY BK 0.000 0.0 4/26/2010 -2 5,562.6 3,503.9 64.79 Camco KMBG 1 GAS LIFT DMY BK 0.000 0.0 4/26/2010 3 7,649.2 4,406.6 64.74 Camco KMBG 1 GAS LIFT DMY BK 0.0001 0.0 4/26/2010 4 9,105 0 5,060.7 64.97 Camco jKMBG 1 GAS LIFT DMY BK-5 0.0001 0.0 4/26/2010 ~ 1 --. -_ ._ - _ 5 9,953.2 5,553.3 46.75 Camco KMBG 1 GAS LIFT SOV DCK-2 0.000 0 0 4/26/2010 FISH, 10,470 'RODUCTION, 2,088-10.676 \ TD, 10,686 ~30 Pre and Post Workover Summery DATE SUMMARY 3/13/10 PERFORM A SLIM RADIAL CEMENT BOND LOG (1 11/16") TO DEPTH OF 2~' TO SURFACE. OBJECTIVE OF LOG IS TO CHECK FOR POSSIBLE CASING IMPINGEMENT BEFORE THE WORKOVER RIG MOVES ONTO LOCATION. NO FIELD INTERPRETATION DONE ON LOCATION. 3/21/10 (PRE RWO) T-POT (PASSED), T-PPPOT (PASSED), IC-POT (PASSED), IC- PPPOT (PASSED), FUNCTION TESTED LDS'S 3/27/10 PRE-RWO BLEED T/IA/OA TO 0 PSI 3/28/10 SET CATCHER ON PLUG @ 10170' RKB. PULLED DV @ 10124' RKB. READY FOR E/L. 4/3/10 CUT 3.5" TUBING WITH RCT-2500-200 AT 10153' USING ELECTROMAGNETIC ~ ANCHOR SYSTEM. TOOLSTRING STUCK AFTER TUBING CUT. UNABLE TO JAR UP; PULLED OUT OF WEAKPOINT TO GET OUT OF WELL. 4/4/10 FISHED E/L TOOLSTRING WITH RCT LOST 4/3/2010. COMPLETE. 4/5/10 DISPLACED TUBING AND IA TO 9.6# NaCI BRINE. PUMPED 350-BBL BRINE DOWN TUBING, THROUGH OPEN MANDREL AT 10124' , UP IA, AND OUT JUMPER TO 2T-31 FLOWLINE. PUMPED 50-BBL DIESEL FREEZE-PROTECT DOWN TUBING. RIGGED IA JUMPER BACK ON 2T-30 TUBING FOR U-TUBE OF DIESEL TO IA. BLED TUBING & IA TO 0-PSI; LOST LESS THAN 1-BBL DIESEL DURING BLEED. REQUESTED BPV BE LEFT OUT TO MONITOR PRESSURE FOR A DAY. LIKEWISE, REQUESTED WORK PLATFORM STAY FOR NOW. 4/8/10 ELINE UNIT 3030- STANDBY WAITING FOR NORDIC 3 TUBING PULL- TUBING CUT PLANNED IF UNABLE TO PULL. 4/9/10 STANDBY WHILE NORDIC 3 PULLS TUBING AND MAKES A SCRAPER RUN ON 2T-30. µ 4/10/10 LOG PDS 40 ARM CALIPER FROM TD TO RIG FLOOR, LOG RADIAL CEMENT BOND LOG FROM TD TO SURFACE WITH TOP OF CEMENT FOUND AT 2174', CORRELATE STRING SHOT FOR CASING BACKOFF. 4/11/10 FIRE STRING SHOT OVER CASING COLLAR AT 2090' FOR CASING BACKOFF, HOIST GYRODATA TOOLSTRING FROM TD TO SURFACE 4/14/10 PERFORMED FREE POINT SERVICE, APPEARED TO BE A 7" CASING COLLAR AT 415' CATCHING ON 9.625" CASING DAMAGE AT 394'. ON STANDBY TO HOIST PDS CALIPER AFTER 7" CASING IS CUT. 4/15/10 PERFORMED GAMMA/CCL CORRELATION PASS. PERFORMED MIT 40 ARM CALIPER LOG FROM A DEPTH OF 500' TO SURFACE 4/19/10 PERFORMED CALIPER SURVEY WITH PDS 40 ARM EXTENDED REACH CALIPER AND GYRO SURVEY WITH GYRODATA GYRO TOOL. PERFORMED BOTH SURVEYS FROM 2200' TO SURFACE. COST CAPTURED IN DAILY DRILLING REPORT 5/2/10 PULLED BALL & ROD @ 10121' RKB. PULLED SOV @ 9953' RKB & REPLACED WITH DV. MIT IA 2500 PSI, PASSED. IN PROGRESS. 5/3/10 PULLED DVs @ 9953', 9105', 7649', 5562' & 3123' RKB. SET 1/4" OV @ 9953', GLVs @ 9105', 7649, 5562' & 3123' RKB. BLED IA TO VERIFY GLVs SET. IN ~os~ PROGRESS. Q-~~ 5/4/10 PULLED RHC PLUG BODY @ 10,121' RKB. PULL CATCHER SUB @ 10,163' ~` RKB. BAILED FILL f/ TOP OF MA-2 PLUG @ 10,170' RKB. IN PROGRESS 5/6/10 ATTEMPT TO LATCH MA-2 PRONG @ 10170' RKB.IN PROGRESS 5/7/10 PULLED 2.81" MA-2 PLUG FROM 10170' RKB.IN PROGRESS 5/8/10 PULLED 2.75" CA-2 PLUG FROM 10193' RKB.TAGGED FILL @ 10277' SLM.SAMPLE OF FRAC WITH LITTLE FORMATION SAND OBTAINED.MEASURED SBHP @ 10300' RKB (3212 PSIA, 155 DEGF), PUH 15 MIN GRADIENT STOP @ 10146' RKB (3160 PSIA, 151 DEGF). COMPLETE Conoc©Phi[lips Time Log & Summary iNellview 4Veb ReporYi~g Report Well Name: 2T-30 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 4/8/2010 12:01:00 AM Rig Release: 4/27/2010 10:00:00 AM Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 4/07/2010 2a hr summary Completed Well 2A-12. Moved to 2T-30 21:30 23:30 2.00 COMPZ MOVE MOB P Move Nordic Rig 3 from 2A-Pad to 2T-Pad 2 Miles . 23:30 00:00 0.50 COMPZ RPEQPI RURD P Move over 2T-30 Well Slot. Level Ri . 4/08/2010 MIRU at 2T-30 Well Slot. Circulate and kill Well with 9.6 Ib/gal Brine. Nipple down Production Tree. Nipple u BOPE. Test BOPE. 00:00 03:00 3.00 COMPZ RPEQPI RURD P Rig accepted at 00:01 on 04/08/2010. Berm up Cellar. Spot Tanks and support equipment. Rig u Hard Line. 03:00 04:00 1.00 COMPZ RPEQPI RURD P Pull BPV with Lubricator. 04:00 05:30 1.50 COMPZ WELCTL RURD P Rig up lines. Pressure test lines at 250/3,000 psi. Good. Continue to load 9.6 Ib/gal Brine in Plts. Open Well. Est 10 psi on Tubing and Annulus. 05:30 09:00 3.50 COMPZ WELCTI KLWL P Pumped 35 bbls dwn tbg to displace diesel taking returns to kill tank. Switched around and pumped 115 bbls reverse to displace diesel from tubing. Pumping @ 3 BPM w/340 si. SD, blow down hard line. 09:00 14:00 5.00 COMPZ WELCTI KLWL P Switch to taking returns back to pits thru De-Gasser. Pumped @ 4 BPM 570 psi. 352 bbls. (hole volumn). Shut down check pressures. Tubing 0. Annulus 0. but well unbalanced. Pumped another hole volumn around 352 bbls, 4 BPM w/500 psi. RU ~um er hose and let a ualize. 14:00 16:00 2.00 COMPZ WELCTL KLWL P Set IS-A BPV. ND hoses and hard lines. ND tree, inspect lift threads in tbg hanger for damage. Install blankin lu in lift threads. 16:00 00:00 8.00 COMPZ WELCTI BOPE P NU 11" 5M BOPE. Function and pressure test BOPE and choke manifold to 250/3000 psi. Perform Koomey draw down test. Witnessing waived by John Crisp @ 20:03 hrs 4-7-2010. 4/09/2010 Pull Hanger to Floor. Circulate Well. Lay down 3 1/2" Completion. Make-up Bit and Casing Scraper. Attem t to et assed 7" Casin roblem at 28.5-ft with no success. 00:00 02:30 2.50 COMPZ WELCTI BOPE P Completed ROPE test. Page 1 of 21 i Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 02:30 04:00 1.50 COMPZ WELCTL BOPE P Pull Blanking Plug. Pull Back Pressure Valve. Make up Landing Joint. BOLDS. 04:00 04:30 0.50 COMPZ RPEQPI PULL P PJSM. Pull Tubing hanger free at 110K. Tubing Hanger to floor with 90K - 100K dra . 04:30 06:30 2.00 COMPZ RPEQPI CIRC P Circulate bottoms up at 5 BPM w/570 si. 06:30 20:00 13.50 COMPZ RPCOM PULL P TOOH laying down tubing, removing all jewelry strapping and marking any abnormalities in tubing, unloading from pipe shed and putting in lay down containment area for corrosion Inspection. Recovered 318 full joints of tubing and a 13.70' cut-off stub. Also recovered 6 ea GLM Assemblies, and 1 ea Landing Ni le. 20:00 21:00 1.00 COMPZ RPCOM PULL P Kick out remaining 3 1/2" Tubing in Pi a Shed. Clear and clean floor. 21:00 23:00 2.00 COMPZ RPEQPI PULD P Load and tally remaining 3 1/2" Drill Pipe in Pipe shed. Load and tally Drill Collars. Rig up handling equipment to handle Drill Pipe. Bring BHA to floor. Install Wear Bushin . 23:00 00:00 1.00 COMPZ RPEQPI PULD T PJSM. Start to make-uq BHA #1 as follows: 6 1/8" Bit, 7" Casing Scraper, Bit Sub, Bumper Sub. Pick up first 4 3/4" Drill Collar. RIH and tagged up at 28.5-ft. (Note: Distance from rig floor to upper lock-down-screws is 27.1-ft). Pulled Wear Bushing. Tagged at same s ot. Removed the 6 1/8" Bit. Tagged up at 30.0-ft. Attempt to rotate throu h. No-Jo . 4/10/2010 Attempt to get 5 1/2" Mult-String Cutter through 7" Casing problem. Run Drill Pipe to 3,000-ft. Stand back in Derrick. Ri u E-Line Unit. Com lete Cali er Lo and Strin Shot run. 00:00 00:30 0.50 COMPZ RPEQPI PULD T Discuss problem with the 7" Casing and plan forward with Anchorage En ineer. 00:30 02:30 2.00 COMPZ RPEQPI PULD T Pick-up Baker 5 1/2" Multi-String Cutter. Run in on a joint of Drill Pipe. Once again tagged at 29.5-ft. Lay down MS-Cutter. 02:30 04:30 2.00 COMPZ RPEQPI PULD T Pick-up Mule Shoe. Single in with 6- 4 3/4" DC's and 3 1/2" Drill Pipe to 2000' while waiting on E-Line to log Well. 04:30 06:30 2.00 COMPZ RPEQPI SVRG P Rig service. Cut and Slip Drilling Line 84-ft . 06:30 07:30 1.00 COMPZ RPEQPI CIRC P Ran another 1000' of drill pipe down to 3000'. Circulate hole clean. 07:30 09:30 2.00 COMPZ RPEOPI TRIP P POOH staning back drill pipe and drill collars. Page 2 of 21 i • Time Lo s 'Date Frame To Dur S. De th E. De th Phase: Code Subcode T Comment 09:30 15:30 6.00 COMPZ RPEQPI ELOG P RU 7" Otis Shooting Nipple. Hold PJSM w/HES and PDS crews. RU HES E-line and PDS Casing Caliper. RIH and run casing caliper log from 10150' to surface. 15:30 21:30 6.00 COMPZ RPEQPI ELOG P Down load info. from PDS. RD caliper tools. RU RCBL. Run RCBL log from 10,150-ft back to surface. Rig down Cement Bond Logging Tool. Top of Cement at 2,180-ft. Discuss Log with Anchorage En ineer. 21:30 00:00 2.50 COMPZ RPEQPI ELOG P Rig up to run Gyro Log. Discovered that the signal to the Gyro Tool is to weak due to line length (25,000-ft). Decide to run the String Shot while waiting for aback-up Unit with a shorter length line to arrive from Deadhorse. Rig up to run String Shot. Run String Shot and make tie-in pass. ,Center String Shot cross Collar at 2,090-ft and fire. Good. 4/11 /2010 Complete Gyro Log. Set Inflatable Bridge Plug with top at 2,616-ft. Swap wellbore over to Sea Water. 00:00 01:00 1.00 COMPZ RPEQPI ELOG P Finish String Shot run. Lay down Tools. 01:00 03:00 2.00 COMPZ RPEQPI ELOG T Switch from the 7/32" line over to the 3/8"line in an attempt to get enough signal to fully power up Gyro SurveyTool. No-Joy. Continue to wait on second logging unit to arrive on location. 03:00 06:00 3.00 COMPZ RPEQPI ELOG T Spot second logging unit, sort out lines. Re-head and RU Gyro tools. Warm u on surf. 06:00 15:00 9.00 COMPZ RPEQPI ELOG P RIH wlGyro Tool on E-line to 10,150'. Lo out of hole to surface. 15:00 15:30 0.50 COMPZ RPEQPI ELOG P RD HES and load out all E-line e ui ment. 15:30 19:00 3.50 COMPZ RPEQPI PACK P MU Baker Thru-Tu~it~,yln at le Bridge Plug, 5520# pull release, w/ a 5847 psi pressure rating, Gw 1.38" Fish Neck. RIH on 3 1/2" drill pipe fill pipe every 3 stands. Stop at 2,616-ft.Up weight = 65K. Down wei ht = 60K. 19:00 20:15 1.25 COMPZ RPEQPI PACK P Drop IBP 1/2" setting ball. Wait on ball to fall. Pressure up on Drill Pipe to 500 psi. x 5 minutes. Increase pressure to 1,000 psi x 10 minutes. Slack off on string weight x 1 K and increase pressure to 1,500 psi. x 10 minutes. Good set. Increase pressure to 2,100 psi and shear release Setting Tool. Too of IBP = 16-ft. enter Element = 2,625-ft. Page 3 of 21 c~~ r~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 20:15 21:30 1.25 COMPZ RPEQPI TRIP P Trip out with 3 1/2" Drill Pipe and Setting Tool. Lay down Setting Tools and recover settin ball. 21:30 22:30 1.00 COMPZ RPEQPI TRIP P Make-up 3 1/2" Bullnose. Trip in with 3 1/2" Drill PI a to 2,511-ft. 22:30 00:00 1.50 COMPZ RPEQPI CIRC P Circulate and condition Well over to 8.6 Ib/ al Sea Water. 4/12/2010 Dumped and tagged Sand. Nlpple down BOP Stack. Nlpple down Tubing Spool in progress. Using "long bolts" to allow casin to row as bolts are backed off. 00:00 02:30 2.50 COMPZ RPEQPI CIRC P Dump 24 sks (1,200 Ibs) of 20/45 Mesh Sand down Drill Pipe while trickling in Sea Water. Flush Drill Pipe at 1.0 bpm. Wait on Sand to settle 1 hr . 02:30 06:30 4.00 COMPZ RPEQPI OTHR P Run in hole looking for Top of Sand. Saw a few bobbles (sand bridges). Hole angle 63 degs, sand laying on low side of hole. Lightly tagged the top of the IBP at the orignal set depth. Found no solid TOS. Pull back up to 2,030-ft. Rotate back down. Bring pump on intermittently at min rate in an effort to stir up sand to move down hole. Stopped at 2,607-ft. Back ream while pulling up hole. Observe drag and torque when first start back up hole. Pulf up hole to safety at 2,100-ft. Circulate hole while crew chan a 46PM 160 si. 06:30 08:30 2.00 COMPZ RPEQPI OTHR P Attempt to tag top of sand again, no sand, soft tagged top of IBP @ 2616'. PU to 2,119' wait for sand to fall. 08:30 12:00 3.50 COMPZ RPEQPI OTHR P POOH, remove bullnose. MU double box Xver and 6' drill pipe pup jt w/box down. RIH to push sand down hole from low side of hole. Tagged top of saner) X593' PU 60' lowered back and tagged @ 2583', PU 60' again, lowered back and tagged @ 2073' setting down 10K each tag. PU to 2513'. MU top drive, pressure up to 3000 psi and pressure dropped off immediately to 2500 psi. Held 2500 psi for 5 min. Bled pressure to 0. Lowered back down and tagged top of sand @2589' giving us 27' of sand on to of IBP. 12:00 13:30 1.50 COMPZ RPEQPI TRIP P Blow down top drive. Set up rig floor for POOH. POOH standing back drill i e and ND Xover and u . Page 4 of 21 Time l.o s Date From To Dur S. De th E. De th Phase Gode Subcode T Comment 13:30 00:00 10.50 COMPZ RPEQPI NUND P ND and remove BOPE. Install long thread bolts on tbg head x csg head flange. Break remaining bolts. Loosen nuts on long bolts and allow casing to grow as we back out on bolts: Casing appears to be rolled over to the inside creating restriction at top of casing stub. Continue backing out bolts as casing grows. Casin has " rown" - 11" so far. 4/13/2010 Complete Nipple down Tubing Spool. Cut 7" Csg at surface. Spear Csg and pull 50 K. Set Slips.NU BOP Stack and install 7" Pi a Rams. Cut Cs at 2,067-ft corr kb and with Baker Multi-Strip Cutter. 00:00 08:00 8.00 COMPZ RPEQPI NUND P Continue using long bolts and pneumatic impact wrench to control casing growth. Swap out 3-ft bolts for 4-ft bolts. Casing finally quit growing at 29 5/8". POOH with 1 jt of Drill Pipe, Test Plug and Drill Collars. 08:00 12:00 4.00 COMPZ RPEQPI NUND P Rig up to cut 7" Casing at surface. Pull Tubing Spool off. Pull Pack-off. Land Slips. Observe the lip of the 7" Casing was swedged inward and the leading edge slightly rolled over (pits in S Drive under 2T-30 2010 RWO - Subsidence Repair~2T-30 Nordic Rig 3 Files). Set up WACHS Cutter and cut off 7" Casing. PU 50k over and set slips. (seen 29 5/8" in growth during flange back off & 9.5" during Wt ick-u Total= 39 1/8" rowth. 12:00 12:30 0.50 COMPZ RPEQPI SFTY P Held PJSM w/ crew on NU BOPE 12:30 18:30 6.00 COMPZ RPEQPI NUND P NU Tubing Spool & Bop Stack. Install 7" Pipe Rams in lower BOP and func. test w/ 7" test jt. and Function test and pt choke & treating iron 250/3,000 si . 18:30 20:30 2.00 COMPZ RPEQPI TRIP P PJSM. Make up Baker 5 1/2" Multi-String Cutter as follows: 5 1/2" M-S Cutter, 6 1/16" Stabilizer, 6 ea 4 3/4" Drill Collars. Secure Knives in closed position. Trip in with BHA and 3 1/2" Drill Pipe to 1,733' Caught a 7" Collar (hard) with the Cutter Knives. 20:30 22:00 1.50 COMPZ RPEQPI TRIP P Trip out with BHA. All three knives, pins, and all of the alien screws still there. However, two knives had minor damage (chipped) to the leading cutting edge. Replace both damaged knives. Double secure Knives in the closed osition. 22:00 23:00 1.00 COMPZ RPEQPI TRIP P Trip in with M-S Cutter and 3 1/2" Drill Pipe. Up weight = 63K. Down wei ht = 61 K. Page 5 of 21' Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 23:00 23:30 0.50 COMPZ RPEQPI CPBO P Locate collar at 2,087-ft Corr kb and (2,090-ft on log). Pick up 20 -ft and locate Knives at 2 067-ft. Bring pump rate up to 4.0 bpm/680 psi. RPMs = 60. RWT = 63K. Made cut in 5 minutes. Pressure dropped to 120 si. 23:30 00:00 0.50 COMPZ RPEQPI CIRC P Gas from the 9 5/8" x 7"Annulus at surface. Close in Well. Line up Well through Choke Manifold to Open Top Tank. 4/14/2010 Circulate out Arctic Pack. Attempted to pull 7" Casing. No-Joy, due to a problem with the 9 5/8" Surface Casing. Rig up E-line and free-point 7" Casing. Free-Point Log indicates that the 9 5/8" Casing is parted or buckled at 394-ft corrected elmd and a 7" Collar with not ass throu h this area. Cut 7" Casin at 414-ft. 00:00 01:30 1.50 COMPZ RPEQPI CIRC P Omen Well and record 80 psi on the 9 5/8" x 7" Annulus. Bring Pump on line at min rate. Crack open Choke. Increase Pump rate to 2,0 bpm/120 psi. Gradually increase Choke to full open. Circulate a total of 90 bbls 60 deg F Sea Water to clear gas cap. Returns =Gas cap then turned to dirty fluid cut Diesel. Monitor Well static. 01:30 03:00 1.50 2,067 0 COMPZ RPEQPI TRIP P Blow down Top Drive. Trip out with 3 1/2" Drill Pipe and M-S Cutter BHA. La down BHA. 03:00 03:30 0.50 COMPZ RPEQPI FISH P PJSM. Make up 7" Casing Spear. Plant Spear in top of 7" Casing. Pick Casing up 2-ft.. Up weight = 83K. 03:30 06:00 2.50 COMPZ RPEQPI CIRC P Circulate down the 7" Casing with 90 deg F. Diesel to recover Arctic Pack at 8.0 bpm/630 psi. Total diesel pumped = 200 bbls. Swap over to 170 deg F. Sea Water and continue to flush Arctic Pack from the 9 5!8" x 7" Annulus. Total Sea Water pumped = 270 bbls. Final circulating rate was 8.0 bpm/525 psi. Returns through out the displacement was most) a Diesel/Gel a fluid. 06:00 08:00 2.00 COMPZ RPEQPI NUND P RU Slings to make surface break on stack to remove slips from 7" casing han er. 08:00 09:00 1.00 COMPZ RPEQPI NUND P Done removing slios. NU Boo's. 09:00 09:15 0.25 COMPZ RPEQPI SFTY P PJSM with all parties involved in ullin 7" Casin . 09:15 10:00 0.75 COMPZ RPEQPI PULL P Made several attempts to retrieve 7" ca~ing.with no ~ cc Seen about 20' of movement before'tagging up. Appears that the 9 5/8" is parted and the 7" Centering Guides are catching on the parted stub. Cycle 7" several more times with no luck getting assed. Page i of 21 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 10:00 11:00 1.00 COMPZ RPEQPI OTHR T Call and discuss options on plan forward with Town En ineer. 11:00 13:00 2.00 COMPZ RPEQPI OTHR T Call For IBP. Call out for E-Line crew for a free point log. Order sand for ossible sand lu if IBP is set. 13:00 15:30 2.50 COMPZ RPEQPI OTHR T Remove spear. Swap out bells on rig floor 15:30 16:00 0.50 COMPZ RPEQPI OTHR T Halliburton E-Line Checked in and s ottin unit. 16:00 18:30 2.50 COMPZ RPEQPI OTHR T PJSM. Plant Spear in 7" Casing. Ri u E-Line to free- oint 7" Casin . 18:30 23:00 4.50 COMPZ RPEQPI OTHR T RIH with free point tool and magnetize 7" Casing down to 600-ft at 30 fpm. Park Tool. Lift BOP Stack and hold Stack with the Bridge Crane. Remove Slips. Pull Casing to 175K (85K over string weight). Hold for 5 minutes. Stack back down to normal string weight. Log up at 30 fpm back to surface. First pass inconclusive. Run back down to 600 ft at 20 fpm. Again Pull up to 175K. Hold for 5 minutes. Slack back off. Log up at 20 fpm. Observe a separation between the down pass and the up pass overlay starting at 416-ft. From 416-ft to surface the separation remains indication free pipe. Made a third repeat log again pulling the casing up to 175K, holding for 5 minutes and then slacking off to string weight. This pass was also logged at 20 fpm. Same findings as the second log pass. Above 416-ft the Casing is free. Note: the depth of 416-ft is not a corrected de th, et. 23:00 00:00 1.00 COMPZ RPEQPI OTHR T Discuss findings with Anchorage Engineer. Set Slips and leave the 7" Casing with 4K tension. Set BOP Stack back down. 4/15/2010 Run GR/CCL Log to tie-in Free-Point data. Cut 7" Casing at 414-ft with Baker Multi-String Cutter. Lay down Casin from 414-ft. Perform Weekl BOPE test. 00:00 00:30 0.50 COMPZ RPEQPI OTHR T Lay down Free-Point Tool. Release and la down Casin Sear. 00:30 01:30 1.00 COMPZ RPEQPI OTHR T Pick-up and RIH with CCUGR Tool. Log collars and over lap free-point log data. Correct free-point log to CCUGR log. 7" Casing free-point is 394-ft corrected elmd with the 7" Collar pulled up against the 9 5/8" Casing problem. The 7" Collar at 416-ft is the collar that is ulled u hole 21-ft and stopping at the 9 5/8" Casin roblem at 394-ft. Page 7 of 21 r Time Lo s rDate From To Dur S. De th E. De th Phase Code Subcode T Comment 01:30 04:30 3.00 COMPZ RPEQPI OTHR T Lay down CCUGR Tool and E-Line Sheaves. PJSM. Finish NU BOP Stack. Pick up Baker 5 1/2" Multi-String Cutter as follows: 5 1/2" Cutter, 6 1/16" Stabilizer, 6 ea 4 3/4" Drill Collars. RIH with BHA and 3 1/2" Drill Pipe. Up Weight 45K. Down weight = 45K. Bring Pump on line to open Knives. Locate the 7" Collar at 416-ft. Pick up 2-ft and position Knives at 414-ft. RPMs = 60. Torque = 2K. Final Pump Rate = 770 psi/4.0 bpm. Differential pressure dropped off by 350 psi after cut was made. Cut made in 15 minutes. Continue for 5 additional minutes. 04:30 05:00 0.50 COMPZ RPEQPI OTHR T Trip out and lay down M-S Cutter. 05:00 06:00 1.00 COMPZ RPEQPI OTHR T MU BHA W/Spear. Latch into 7" casing and p/u to 90k. Appears 7" is not cut. LD s ear and BHA. 06:00 08:00 2.00 COMPZ RPEQPI OTHR T P/U 5.5" MSC BHA and TIH to cut depth @ 414' .Located cut area and perform another cut. Seen good indication that 7" is cut. 08:00 08:45 0.75 COMPZ RPEQPI OTHR T Pooh and lay down 5.5" cutter and bha. Spear 7" P/U to 50K, seen good movement ,stop movement and make surface break to remove Sli s. 08:45 10:00 1.25 COMPZ RPEQPI OTHR P Spear 7" P/U to 50K, seen good movement ,stop movement and make surface break to remove Sli s.Start ullin 7" casin . 10:00 12:00 2.00 COMPZ RPEQPI PULD P Done pulling 10 joints of 7" casing 414'). Lay down tool string and prep for Lo in tools. 12:00 15:00 3.00 COMPZ RPEQPI ELOG P RU and run PDS Caliper Log on 9-5/8" casing down to 500' and back to surface. Down Load and confirmed ood data from to . 15:00 00:00 9.00 COMPZ RPEQPI BOPE P Perform Weekly BOP pe ConocoPhillipslAOGCC requirements at 250/3,000 test while waiting on data from Caliper log. The State's right to witness the test was waived by C. Sheve. Note: The 3 1/2" VB Pipe Rams, failed to test. Replace with 3 1/2" Ram Blocks. Test 3 1/2" Plpe Rams. No test. Door Seal leaking. Change Door Seal. 4/16/2010 Continue to Swedge 9 5/8" Casing at 392-ft with 7 3/4"and 7 7/8" Swedges. 00:00 01:00 1.00 COMPZ RPEQPI BOPE P Complete Weekly BOPE test. Perform Koomey draw down test. Good. Ri down test a ui ment. Page 8 of 21 • Time. Lo s Date From To Dur S. De th E. De th Phase Cade Subcode T Comment 01:00 03:30 2.50 COMPZ RPEQPI FISH P PJSM. Bring next BHA to the Rig Floor. Make-up BHA as follows: Bull Nose, 5" Pup Joint, XO, 7 5/16" Swedge, XO, Bumper Sub #1, Bumper Sub #2, Oil Jar, XO, 6 ea 6 3/4" Drill Collars, XO, Intensifire, XO, 3 ea 4 3/4" Drill Collars. 03:30 04:30 1.00 394 394 COMPZ RPEQPI SWDG P RIH to 394-ft. Swedge open the 9 / wed e. 04:30 05:30 1.00 394 0 COMPZ RPEQPI FISH P POOH & lay down the 7 5/16" Swed e. 05:30 07:00 1.50 0 392 COMPZ RPEQPI FISH P Crew Change / PU 7 3/4" Swedge & Rlh to 392' 07:00 13:00 6.00 392 392 COMPZ RPEQPI SWDG P Continue to Swedge on 9 5/8" Casing.Seen very little progress with 7 3/4" Swed e. 13:00 14:00 1.00 392 0 COMPZ RPEQPI TRIP P Pooh to change out BHA. 14:00 14:30 0.50 0 0 COMPZ RPEQPI OTHR P Set wear ring. 14:30 15:30 1.00 0 408 COMPZ RPEQPI TRIP P RIH W/ 7 5/16" Swedge down passed bad section w/ very little si ns to 408'. 15:30 16:30 1.00 408 0 COMPZ RPEQPI TRIP P POOH to change over to 7.5" Swed e. 16:30 17:00 0.50 0 408 COMPZ RPEQPI TRIP P RIH w/ 7.5" Swedge down passed problem area. Seen very little sign of dams a area. 17:00 20:30 3.50 408 0 COMPZ RPEQPI TRIP P POOH and Lay down 7.5" Swedge and PU 7 3.4" Swedge and add 2- 6 3/4" collars to next BHA for added wei ht. 20:30 23:30 3.00 0 394 COMPZ RPEQPI SWDG P Trip back into 394-ft. Continue to work on tight area in the 9 5/8" Casing with a 7 3/4" Swedge. Got the 7 3/4" Swedge through every so often (20 times). However had to jar back out. Restricted area still not ironed out with the 7 3/4" Swedge. TOH to than a to the 7 7/8" Swed e. 23:30 00:00 0.50 394 0 COMPZ RPEQPI TRIP P Trip out and lay down the 7 3/4" Swed e. 4/17/2010 Continue to Swedge 9 5/8" Casing at 392-ft with 7 7/8"and 8" Swedges. 00:00 01:00 1.00 0 394 COMPZ RPEQPI TRIP P Make-up a 7 7/8" Swedge. Trip into 392-ft. 01:00 02:30 1.50 394 394 COMPZ RPEQPI SWDG P Continue to swedge the 9 5/8" Casing at 392-ft with a 7 7/8" Swedge. Unable to aet the 7 7/8" . S h 02:30 04:30 2.00 394 394 COMPZ RPEQPI TRIP P Trip out and lay down the 7 7/8" Swedge. Perform a Derrick inspection. Pick the 7 3/4" Swedge back u and tri in hole to 392-ft. 04:30 05:30 1.00 394 394 COMPZ RPEQPI SWDG P Continue to swedge the 9 5/8" Casing at 392-ft with a 7 3/4" Swed e. :Page 9 of 21 • Time Lo s Date From To Dur S. De th E: De th Phase Code Subcode T Comment 05:30 06:30 1.00 394 0 COMPZ RPEQPI TRIP P POOH and Change out from 7 3/4" to 7 7/8" 06:30 07:00 0.50 0 392 COMPZ RPEQPI TRIP P RIH w/ 7 7/8" to 392'. 07:00 14:00 7.00 392 392 COMPZ RPEQPI SWDG P Continue to swage w/ 7 7/8" csg swa e. 14:00 14:30 0.50 392 392 COMPZ RPEQPI CIRC P Spot 10 bbl tube pill on bottom. 14:30 17:30 3.00 392 408 COMPZ RPEQPI SWDG P Continue to swage w/ 7 7/8" csg swage @ 392', fell thru after 30 minutes of swaging and worked till able to slide through @ 10k OSW up and down. 17:30 18:00 0.50 408 0 COMPZ RPEQPI TRIP P POOH and change to 8 1/8" CSG Swed e. 18:00 19:00 1.00 0 392 COMPZ RPEQPI TRIP P Perform Derrick and Top Drive ins ection. RIH to 392' 19:00 23:00 4.00 392 392 COMPZ RPEQPI SWDG P Begin swedging with 8 1/8" Ca 392'. No real progress. 8" Swedge arrived on location. 23:00 00:00 1.00 392 0 COMPZ RPEQPI TRIP P Trip out to lay down 8 1/8" Swedge and make-u 8" Swed e. 4/18/2010 Continue to Swedge Casing with a 8 1/8" Swedge. Lay down BHA. Make up 8 3/8" String Mill. Mill through with little roblem. Continue down to 7" Casin at 414-ft and dress inside of 7" with a 6 1/8" Ta ered Mill. 00:00 01:00 1.00 0 392 COMPZ RPEQPI TRIP P RIH with 8" Swedge to 392-ft. Passed through after several attem ts. 01:00 02:30 1.50 392 392 COMPZ RPEQPI TRIP P Trip out and lay down 8" Swedge. Make up 8 1/8" Swedge. Trip in to 392-ft. 02:30 04:30 2.00 392 392 COMPZ RPEQPI SWDG P Continue to Swedge 9 5/8" Casing at 392-ft with a 8 1/8" Swed e. 04:30 05:00 0.50 392 392 COMPZ RPEQPI CIRC P Spot 5 bbl slick pill on bottom 05:00 10:00 5.00 392 392 COMPZ RPEQPI SWDG P Continue to swage @ 392' w/ 8 1/8" CSG Swa e. 10:00 10:30 0.50 392 0 COMPZ RPEQPI TRIP P POOH with 8 1/8" OD Swage 10:30 11:00 0.50 0 0 COMPZ RPEQPI PULD P Change out 8 1/8" OD CSG swage with 8 3/8" OD CSG Swa e. 11:00 11:30 0.50 0 392 COMPZ RPEQPI TRIP P RIH to 392' with 8 3/8" OD CSG Swa e. 11:30 15:00 3.50 392 392 COMPZ RPEQPI SWDG P Continue to swage 9 5/8" CSG with 8 3/8" OD CSG swa e 15:00 15:30 0.50 392 0 COMPZ RPEQPI TRIP P POOH with 8 3/8" OD CSG swage. 15:30 16:00 0.50 0 392 COMPZ RPEQPI TRIP P RIH w/ 8 1/8" CSG Swage to 392'. 16:00 19:30 3.50 392 392 COMPZ RPEQPI SWDG P Continue to swage at 392' with 8 1/8" CSG Swage. Slow progress. Discuss plan forward with Anchorage En ineer. 19:30 20:00 0.50 392 0 COMPZ RPEQPI TRIP P Trip out and lay down the 8 1/8" Swed e. Page 10 of 21 • r Time. Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 20:00 21:45 1.75 0 378 COMPZ RPEQPI TRIP P Make up BHA to mill as follows: 6 1/8" Tapered Mill, XO, Pup Joint, Double Pin, Sub, 8 3/8" String Mill, 2 ea Bumper Subs, OII Jar, XO, 6 ea 6 1/4" Drill Collars, XO. Total BHA = 228.53-ft. Tri into 378-ft 21:45 23:00 1.25 378 414 COMPZ RPEQPI MILL P Up weight = 50K. Down weight = 50K. RTW = 50K. RPMs = 40. Pump Rate 1.0/3.0 bpm at 40 - 60 psi. Rotate and wash down from 387-ft through three bobbles. Tagged damaged area in 9 5/8" Casing at 394-ft. Mill through to 398-ft in 10 minutes. Back ream and work area several times. Stop rotation and pass through with no problems. Continue down to the top of the 7" Casing at 414-ft. Entered the top of the 7" with a 6 1/8" Tapered Mill and dress off the inside to clean-up for the S ear. 23:00 23:30 0.50 414 0 COMPZ RPEQPI TRIP P Trip out and lay down Mill assembly. 23:30 00:00 0.50 0 COMPZ RPEQPI TRIP P Make-up 8 3/8" Swedge. 4/19/2010 Lay down 7" Casing from 2,067-ft. Dress restriction in the 9 5/8" Casing to 8 1/2" and the inside of the 7" Stum at 2,067-ft with a 6 1/8" Ta ered MIII. Ri u E-line Run Cali er Lo in the 9 5/8" Casin . 00:00 01:00 1.00 0 392 COMPZ RPEQPI TRIP P Trip in 8 3/8" Swedge to 392-ft. 01:00 02:00 1.00 392 392 COMPZ RPEQPI SWDG P Attempt to drift the 9 5/8" damaged area dressed with the 8 3/8" String Mill with the 8 3/8" Swedge. However, while attempting to work Swedge through it became stuck. Cock Oil Jar and un-load at 150K. Then had to pull 200K to pull Swedge free. Abort any further attempt to swedge through. (Due to total length and O.D. of the Swedge and XO, 4.33-ft vs the total length of the cutting surface on the String Mill witch is 2-ft and only 6" of that measurement is full gauge. The short 8 3/8" section of the String Mill will pass through where as the longer 8 3/8" Swed a will not . 02:00 04:00 2.00 392 0 COMPZ RPEQPI TRIP P Trip out with BHA. Break out and lay down BHA. Stand back Drill Collars. 04:00 04:30 0.50 0 414 COMPZ RPEQPI TRIP P Make up 7: Casino spear as follows: Bull Nose, ITCO Spear, Extension, Stop Sub, Bumper Sub. Total lenght = 17.22-ft. Trip in on 3 1/2" Drill Pi e. Page 11 of 21 ` • Time Lo s -Date From To Dur S. De th E. De th Phase Gode Subcode T Comment 04:30 05:30 1.00 2,067 1,653 COMPZ RPEQPI FISH P Up weight = 40K. Down weight = 40K. Plant Spear in 7" Casing at 414-ft. Pull 75K. Continue pulling 7" Casing to surface, standing back 3 1/2" Drill Pipe in Derrick. Taking 1K ~- - 2K to pull Collars through restriction in the 9 5/8" Casin a 392- 05:30 05:30 0.00 1,653 1,653 COMPZ RPEQPI OTHR P 7" Casing at surface. Rig up to handle 7" Casin . 05:30 06:00 0.50 1,653 1,653 COMPZ RPEQPI SFTY P Held PJSM with GBR CSG tong hand 06:00 09:00 3.00 1,653 0 COMPZ RPEQPI PULL P Lay down 38 jts of 7" 26# BTC 75k up wt. Taking 1 to 2k to pull through tight spot with casing collars. 1st Mechcanical @ 2,067' is split from making second cut @ 414' and the remaining 1,653' dropped 2' and en a ed the other. 09:00 10:30 1.50 0 0 COMPZ RPEQPI OTHR P RD CSG equipment, clean and clear ri floor. 10:30 11:30 1.00 0 0 COMPZ RPEQPI OTHR P Bring BHA Tools to rig floor 11:30 12:30 1.00 0 0 COMPZ RPEQPI SVRG P Conduct full derrick inspection. 12:30 13:30 1.00 0 239 COMPZ RPEQPI PULD P PU and MU Milling Assy and RIH to 239'. 13:30 14:00 0.50 239 392 COMPZ RPEQPI TRIP P RIH f/ 239' to 392' 14:00 15:30 1.50 392 395 COMPZ RPEQPI MILL P Gather Parameters: 50k up, do and ROT. RPM's @ 40k w/ 1 k Free Torque. Circulating @ 4 bpm @ 50 psi. Ream and back ream through tight spot @ 392' to 395'. Slide throu h with no roblem. 15:30 16:30 1.00 395 1,987 COMPZ RPEQPI TRIP P Continue to RIH to 2,067' and Dress off 7" CSG stub with 6 1/8" OD Ta ered mill. 16:30 17:30 1.00 1,987 2,080 COMPZ RPEQPI Tagged at 2,068', Gather Parameters: 65k up, do and ROT wts. @ 40 RPM's w/ 1 k free torque. Circulating @ 4 bpm @ 100 psig. Dress off 7" CSG stub with 6 1/8" OD Ta ered mill down to 2,080'. 17:30 18:30 1.00 2,080 343 COMPZ RPEQPI TRIP P POOH with milling BHA to 343'. 18:30 19:30 1.00 343 343 COMPZ RPEQPI SLPC P Slip and Cut Drilline (84-ft) 19:30 20:30 1.00 343 0 COMPZ RPEQPI TRIP P Finish trip out from 343-ft. Break out and la down Millin Tools. 20:30 23:30 3.00 COMPZ EVALWE ELOG P PJSM. Rig up HES E-Line Unit. Run in hole with Caliper tool. Log Well from 2,200-ft to surface. 23:30 00:00 0.50 COMPZ EVALWE ELOG P Lay down Caliper Tool. Pick up Gyro Tool 4/20/2010 Make up and run 9 5/8" GYRO run. POOH. MU 7" Casing backoff tools. RIH to locates and back off casing stub at 2078' DPM. POOH lay down tools. CBU and POOH. MU and RIH with dummy run to casing stub at 2058'. POOH. Lay down tools. MU and run spear assembly. Tag casing stub, engage and backout 12 LH turns with slight overpull until free. POOH, lay down spear assembly & 7" casing stub. Casing stub recovered = 20.29'. Clean & clear ri floor. Ri u to run 7" Casin . Page 12 of 21 :Time Lo s Date From To Dur S. De'th E. De th Phase Code Subcode T Comment 00:00 04:30 4.50 COMPZ EVALWE ELOG P Run in with Gyro Tool from 2,200-ft to surface. Ri down E-Line Unit. 04:30 05:00 0.50 COMPZ RPEQPI SFTY P PJSM with Baker Fishing and Rig crew 05:00 05:30 0.50 COMPZ RPEQPI OTHR P Load and Off load Baker fishing tools 05:30 07:00 1.50 0 284 COMPZ RPEQPI PULD P Make up Back-Off BHA as follows: Bull Nose, 5 ea 4 3/4" Drill Collars, Ported Sub, Blanking Sub, XO Sub, Lower Anchor Section, Back Off Tool Power Section, Upper Anchor Section, Pump-Out Sub, 3 ea 4 3/4" Drill Collars to 284'. 07:00 09:00 2.00 284 2,238 COMPZ RPEQPI TRIP P Continue to RIH w/ Back off BHA # 22 to 2,238'. 09:00 10:30 1.50 2,238 2,238 COMPZ RPEQPI BKOF P MU head pin and set Lower slip assy @ 2,088' and Upper Slip assy @ 2,069'. Pressure up to 1,100 psig and break conn. @ Calculated 6,600 ft/Ibs continue to function tool for 4.5 rounds lowest pressure senn was 600 si = 3,600 ft/Ibs. 10:30 11:00 0.50 2,238 2,238 COMPZ RPEQPI CIRC P Drop ball and rod, Pressure up to 2,250 psi and shear out PO Sub. Circulate 1 hole volume of 148 bbls 6 b m 100 si. 11:00 12:00 1.00 2,238 284 COMPZ RPEOPI TRIP P POOH to 284' w/ 3 1/2 DP 12:00 13:30 1.50 284 0 COMPZ RPEQPI PULD P POOH laying down Back off assy and stand back DC's 13:30 14:00 0.50 0 0 COMPZ RPEQPI SFTY P Held PJSM w/ Baker Fishing and Rig Crew 14:00 14:30 0.50 0 0 COMPZ RPEQPI OTHR P RU Casing Tongs 14:30 15:00 0.50 0 0 COMPZ RPEQPI SFTY P Held PJSM with Rig crew, Baker Fishing, and GBR on MU of Screw in Ass . 15:00 15:30 0.50 0 346 COMPZ RPEQPI PULD P MU and RIH w/ 8 3/8" OD Dummy BHA to 346' 15:30 17:00 1.50 346 2,055 COMPZ RPEQPI TRIP P Run thru tight spot w/ Triple connect and HES Cementer taking 9k slack off to push through tight spot @ 392'. Continue to RIH to 2,055'. 17:00 18:00 1.00 2,055 346 COMPZ RPEQPI TRIP P POOH w/HES Cementer and Triple connect through tight spot @ 392' w/ 9k over ull. 18:00 19:30 1.50 346 0 COMPZ RPEQPI PULD P Breakout & lay down dummy run assembl . 19:30 20:00 0.50 0 0 COMPZ RPEQPI PULD P Make up BHA # 24, Spear assembl . 20:00 20:30 0.50 0 2,058 COMPZ RPEQPI TRIP P Trip in hole with spear assembly to tag top of casing stump at 2058' DPM. UP WT = 60K, SO WT = 60K. 20:30 21:00 0.50 2,058 2,058 COMPZ RPEQPI FISH P Tag & engage fish. Pull slight overpull on stump. Rotate a total of 12 LH turns to observ ulled free. Page 13 of 21 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 21:00 22:30 1.50 2,058 0 COMPZ RPEOPI TRIP P POOH with assembly. Breakout & lay down spear assembly. Lay down recovedred 7" casing stub = 20.29'. Observed stub came out with the bos, we have a pin looking up in the hole. 22:30 23:00 0.50 0 0 COMPZ RPEQPI PULD P Clean & clear rig floor. Send out BOT tools. 23:00 23:15 0.25 0 0 COMPZ RPEQPI SFTY P Held PJSM with crew &GBR reps. Discuss safety & hazard recognition issues. Discuss rigging up and runnin 7" tieback casin strin . 23:15 00:00 0.75 0 0 COMPZ RPEQPI RURD P Rig up GBR casing equipment, and ull tools to floor. 4/21 /2010 Continue rig up. BOLDS, and pull wear bushing. MU Triple connection sub with cut lip casing collar, and RIH with 7" casing. MU TO = 10K ft/Ibs. Tag casing collar at 2078'. Roatate casing string with 3K TO at 12 RPM's to screw into casing stump. Work string to apply 8K ft/Ibs in casing. Pressure test to 1000, 2000, and 2500 PSI. RU cement head & lines. RU Schlumberger Cement crew & trucks, Held PJSM. Mlx & pump 144.7 BBLS of 15.7 PPG Arctic Set 1 cement. Bump plug & check flow back. ~hcaryed 20 BBLS of cement to surface, squeezing 40 BBLS away. ND BOP's. Set emergency slips and cut casing. Pull & lay down cut 'oint. Install tb head & ackoff, & test to 3000 PSI. NU BOP's. Installed VBR;s in lower set of i e rams. 00:00 00:30 0.50 0 0 COMPZ RPEQPI PULD P BOLDS, rig up and pull wear bushin . 00:30 04:00 3.50 0 2,078 COMPZ RPEQPI RNCS P Held PJSM. Make up Triple connection sub with cutlip casing collar. Baker Loc all connections. Continue make up ES cementer with pups, and RIH picking 7" TC II casing to tag casing sub at 2078'. Make up Torque = 10K fUlbs. Observed little or no issues when going through spot at 393'. 04:00 05:30 1.50 2,078 2,078 COMPZ RPEQPI OTHR P Obtain Parameters: 80k ROT wt, 2k free torque. Screw in to exsisting 7" 26# L-80 BTC-M CSG @ back off point of 2,078' and Torque up to 8,000 ft/Ibs. PT CSG 2,500 PSI. 05:30 07:30 2.00 2,078 2,078 COMPZ CEMEN" CMNT P RU cement head, Long Bales, and hoses. S of CMT E ui ment. 07:30 08:00 0.50 2,078 2,078 COMPZ CEMEN" SFTY P Held PJSM w/ HES, SLB, ASRC and Rig crew. Review all stages of the cement 'ob. 08:00 09:00 1.00 2,078 2,078 COMPZ CEMEN" OTHR P Offload 190 bbls of 170 degree sea water to rig pits and take 190 bbls of 70 degree sea water to lower temperature of remaining 100 bbls of 170 degree sea water to 90 degrees for pre heat of csg prior to pumping cmt. Spot Vac trucks in needed areas. Page 14 of 21 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 09:00 11:30 2.50 2,078 2,078 COMPZ CEMEN" CMNT P Fluid pack lines. PT pump lines to 4,000 psig. Pressure to 3,800 psig and open HES Cementer w/ 2.8 bbls pumped. Circulate 98 bbls of 92 degree Sea water @ 5 bpm @ 200 psig, followed by 10 bbls of 80 degree Fresh water @ 5 bpm @ 210 psig. Mix and pump 48 bbls of 144.7 bbl 15.7 ppg Arctic set 1 slurry @ 6.6 bpm @ 800 psi, slow rate to 5 bpm @ 374 psig for 10 bbls, continue to pump another 21 bbls for a total 79 bbls = 7" Vol. of the 144.7 bbls of Slurry. Continue to Mix and pump another 67.5 bbls @ 4.2 bpm @ 352 psig for total of 146.5 bbls. of 15.7 ppg Arctic set 1 slurry pumped. Drop plug and Displace with 9 bbls of 80 degree Fresh Water and seen 14.8 ppg returns @ well head. Continue to pump 1 bbl of Fresh water, followed by 73 bbls of 90 degree Sea water for @ total volume pumped of 341 bbls. At 305 total bbls pumped began pinching back CSG valve and squeezing away cmt w/ starting pressure of 736 psig and increasing to 1,707 psi before bumping plug. Continue to pressure up to 2,700 psig and shut cementer, increase pressure to 3,020 psig and held pressure. Bleed off pressure and recover 1.5 bbls. Cement in place @ 10:44 hrs. 500 psi compressive strength reached in 4 hrs. RD Cement a ui ment. 11:30 16:30 5.00 2,078 2,078 COMPZ RPEQPI NUND P While WOC, ND BOPE. ,Open all ram cavities and clear of cement and change LPR's from 7" to 2 7/8 x 5" Variable rams. Close all doors. ND Spacer spool and lift BOP's. Clean and clear slip bowl for landing 7" x 10.86" Emer enc sli s. 16:30 17:00 0.50 2,078 2,078 COMPZ RPEQPI SFTY P Held PJSM w/ FMC and Rig crew on installing slips and cutting of 7" CSG. 17:00 18:30 1.50 2,078 2,078 COMPZ RPEQPI CUTP P PU on 7" CSG and land in slips with 50k overpull. RU Wachs cutter and cut 7" CSG. Pull & lay down cut joint & u .Cutoff 'nt = 21.50' 18:30 21:00 2.50 2,078 COMPZ RPEQPI NUND P Nipple down BOP's set back on stum . 21:00 23:00 2.00 COMPZ RPEQPI NUND P Install packoff & tubing head. Test same to 3000 PSI. 23:00 00:00 1.00 COMPZ RPEQPI NUND P Nipple up BOP stack & lines. Page 15 of 21 • Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 4/22/2010 24 hr Summary Continue NU BOP's. Body test BOP's & VBR's 250 / 3500 PSI. Install WB. MU 6 1/8" Bit BHA, TIH to tag Green Cement @ 2027'. Drill out cement & plug to 2061'. Pump Hi Visc Sweep. PT casing to 3000 PSI - on chart. 15 minutes. POOH lay down drilling assembly MU Reverse basket BHA 7 TIH. Circulate down to retrieve junk. Rerun assembly down to sand top @ 2609'., @ 6 bpm - 540 psi. POOH lay down assembly recovering 1/4 cup of iron debris. MU BHA # 28, guide shoe and IBP retrieving head. RIH to 2559'. Displace well with 9,6 brine 10 BPM - 1100 PSI. 00:00 01:30 1.50 0 0 COMPZ RPEQPI NUND P Continue nipple up BOP's & lines. 01:30 03:00 1.50 0 0 COMPZ RPEQPI BOPE P Rig up test equipment. Body Test BOP's & VBR's to 250 / 3500 PSI. 03:00 03:30 0.50 0 0 COMPZ RPEQPI RURD P Install wear bushing. RILDS. 03:30 04:00 0.50 0 0 COMPZ RPEQPI RURD P Clean & clear rig floor. Pull tools to floor for BHA. 04:00 05:00 1.00 0 389 COMPZ RPEQPI PULD P Make up BHA #26.6 1/8" Bit and JB assembly. Pick up 3 extra DC's for needed WOB. 05:00 06:00 1.00 389 2,027 COMPZ RPEQPI TRIP P Trip in hole with BHA #26. Tag @ 2,027' 67k u wt and 65k do wt 06:00 06:30 0.50 2,027 2,058 COMPZ RPEQPI DRLG P Drill out cmt to 2,058' to To of Plu with 16k WOB @ 60 rpms circulating 6 b m 480 si . 06:30 07:30 1.00 2,058 2,061 COMPZ RPEQPI DRLG P Drill out plug and cmtr. Chase strip ers to 2,061' 07:30 09:00 1.50 2,061 2,590 COMPZ RPEQPI TRIP P RIH to 2,590' 09:00 09:30 0.50 2,590 2,596 COMPZ RPEQPI DRLG P Dry drilled on sand to 2,596' 09:30 10:00 0.50 2,596 2,585 COMPZ RPEQPI CIRC P PU 2,585' and CBU 10:00 10:30 0.50 2,585 2,585 COMPZ RPEQPI PRTS P Pressure test 7" 26#, L-80 to 3,000 `/ ' si or 15 minutes. ~{ 10:30 12:00 1.50 2,585 0 COMPZ RPEQPI TRIP P POOH and lay down BHA#25 12:00 12:30 0.50 0 0 COMPZ RPEQPI OTHR P Load and ofFload fishing equipment 12:30 13:30 1.00 0 400 COMPZ RPEQPI PULD P PU and MU BHA #26 to 400' 13:30 15:00 1.50 400 2,592 COMPZ RPEQPI TRIP P RIH w/ BHA #26 to 2,592' 15:00 16:00 1.00 2,592 2,601 COMPZ RPEQPI FISH P Reverse circulate to 2,596' and Dry drill to 2,601'. PU to 2,596' and Reverse circulate @ 8 bpm @ 600 psi. -packing off slow pump rate - shut pump off and dry drill back to 2,601'. PU to 2,596' and Reverse circulate bottoms up @ 6 bpm @ 900 prig- returning sand and rubber. BDTD. 16:00 17:00 1.00 2,601 400 COMPZ RPEQPI TRIP P POOH to 400' 17:00 18:00 1.00 400 0 COMPZ RPEQPI TRIP P POOH w/ BHA #26 and empty reverse basket -recovered small feces of aluminum 18:00 19:30 1.50 0 2,603 COMPZ RPEQPI TRIP P Run BHA # 26 Run 2, tripping to 2603'. 19:30 20:30 1.00 2,603 2,609 COMPZ RPEQPI WASH P Reverse circulating down to sand top at 2609'. UP WT = 65K, SO WT = 60K. Pum sat 6 BPM - 540 PSI. Page 16 of 29 P~ Time Lo s Date From To Dur S. De th E. De th Phase ' Code Subcode T Comment 20:30 22:30 2.00 2,609 0 COMPZ RPEQPI TRIP P Blow down top drive. POOH lay down BHA, recovering 1!4 cup of iron debris. 22:30 23:30 1.00 0 2,559 COMPZ RPEQPI TRIP P MU BHA #27, guide shoe & retrieving head assembly for IBP. Trip in hole to 2559'. UP WT = 65K, SO WT = 60K. 23:30 00:00 0.50 2,559 2,614 COMPZ RPEQPI CIRC P RU & displace well with 9.6 PPG at 10 BPM - 100 PSI. Washing down from 2559' - 2614' 4/23/2010 Continue displace well to 9.6 PPG Brine. Attempt to engage IBP at 2616', chasing down to 2639'. No success in engaging IBP. POOH inspect guide shoe indicating shoe going along side of IBP. Load, rack *& tally 3 1/2" completion tbg, service top drive while wait on tools from BOT. Pull tools to floor. MU BHA #29, Overshot assembly. RIH, tag & engage fish. Allow IBP to relax, POOH lay down same. Fish recovered on second run with OS & 1 3/8" Grapple. Pull wear bushing, Install test plug. RU & test BOP's. AOGCC rep BOB NOBLE waived witness of test. Observed upper pipe rams, VBR's and Annular failed. Troubleshoot & Ins ect. 00:00 00:30 0.50 2,614 2,614 COMPZ RPEQPI CIRC P Continue displace well with 9.6 PPG Brine 10 BPM - 1130 PSI. 00:30 02:00 1.50 2,614 2,639 COMPZ RPEQPI FISH P Attemot to tag IBP at expected depth of 2616'. No tag, continuing down hole to 2639' DPM. Tag & attempt to engage IBP. Repeat attempts with no success. UP WT 65K, SO WT 650K. Pumps at 3 BPM - 1130 PSI. Circulate bottoms up observing sand returns. Suspect 'unk on to of IBP. 02:00 03:00 1.00 2,639 0 COMPZ RPEQPI TRIP P POOH with BHA, breakout & lay down BHA, observing guide shoe damaged with marks on the OD indicating 4 7/16" Guide shoe going beside the fish neck of IBP. Mule shoe indicated set down on outside of IBP. Observed proper dis lacement. 03:00 06:30 3.50 0 0 COMPZ RPEQPI OTHR T Rack & Tally 3 1/2" tubing in pipe shed. Service Top Drive. While waitin on Overshot tools form BOT. 06:30 07:00 0.50 0 0 COMPZ RPEQPI OTHR T Bring Fishing Tools to rig floor 07:00 10:00 3.00 0 2,640 COMPZ RPEQPI TRIP T MU BHA # 28 5 3/4 OS w/ 1 3/8" Grapple, LBS and RIH on 3 1/2 DP to 2,527'. Bring pump on line @ 8 bpm @ 630 psi. Circulate down to 2,624', PU single and RIH with charge pump on for 15' to 2,639' and Engage fish -set 3k down - no charge pump increase. PU w/ no overpull. RIH to 2,638', rotate 1 full turn and take wt @ 2,639', rotate 1 full turn and RIH to 2,640' - no pressure increase. PU to 3k OSW of 63k allow to equalize for 30 minutes. PU to 6k OSW and Shear out IBP - allow toe ualize for 30 minutes. 10:00 11:30 1.50 2,640 0 COMPZ RPEQPI TRIP T POOH and had no fish. Page 17 of 21 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 11:30 13:00 1.50 0 2,715 COMPZ RPEOPI TRIP T Inspect grapple -scarring on face, Run back in the hole with the same BHA to 2,640' engage fish -slip off @ 5k OSW of 65k. RIH and set 20k down and engage fish @ 2,645' and POOH to 2,625'. Run back in the to 2,715' - BDTD. 13:00 15:00 2.00 2,715 0 COMPZ RPEQPI TRIP P POOH and Recovered IBP, Break down fishing tools and offload the same. 15:00 16:00 1.00 0 0 COMPZ RPEQPI OTHR P Pull wear ring. Install test plug. 16:00 17:00 1.00 0 0 COMPZ RPEQPI OTHR P Clean & clear tools & equipment from ri floor. 17:00 18:00 1.00 0 0 COMPZ RPEQPI BOPE P Install VBR's in upper pipe rams. 18:00 22:30 4.50 0 0 COMPZ RPEQPI BOPE P RU & test BOP's. AOGCC rep Bob Noble waived witness of test. Test choke manifold and all valves. Test manual & HCR valves, and rig floor safety valves. Observed VBR's in u er rams failed. Annular ba failed. 22:30 00:00 1.50 0 0 COMPZ RPEQPI BOPE T Trouble shoot & inspect. Open doors. 4/24/2010 Continue trouble shoot testing problems with the upper set of rams with VBR's. Annular bag failed as well. Remove & Clean VBR's. Function Annular flushing cement out of same. Re-test to successful 250 / 3000 PSI test. AOGCC rep Bob Noble waived witness of test. Install WB. RILDS> MU Overshot & scraper BHA. TIH to tbg stump at 10134' DPM picking up singles from shed. UP WT 155K, SO WT - 85K. Reverse circulate hole clean pumping a Hi Visc sweep @ 6 BPM - 2200 PSI. POOH. Breakout & lay down BHA. Rig off of Hi Line ower at 0700 HRS. 00:00 05:00 5.00 0 0 COMPZ RPEQPI BOPE T Continue trouble shoot testing problems with the upper set of rams with VBR's installed and the annular bag. These tests failed initially. Redress upper rams VBR's. successful retest. Function annular, observed successfil retest. Perform Koomey test. Initial 200 PSI - 200 Secs, with full 3000 PSi in 88 seconds. 4 Nitrogen bottles with an av PSI of 2,500. 05:00 06:00 1.00 0 0 COMPZ RPEQPI BOPE P Pull & lay down test plug. Install wear bushin .RILDS. 06:00 07:30 1.50 0 402 COMPZ RPEQPI PULD P Make up BHA #30. Wash over assy with scra er assembl . 07:30 09:30 2.00 402 2,250 COMPZ RPEQPI TRIP P RIH w/ BHA #30 on 3 1/2 DP f/ derrick to 2,250' 09:30 15:00 5.50 2,250 10,143 COMPZ RPEQPI PULD P Begin RIH f/ 2,250' to 10,125' picking up 3 1/2 DP singles. 155k up wt, 85k do wt. Wash down @ 5 bpm @ 950 psig. and Tag TBG stub w/ 18' on jt 302 @ 10,143' and PU and ather arameters. Page 18 of 21 l Time Lo s Date From To Dur S. De th _E. De th Phase Code Subcode T Comment 15:00 17:00 2.00 10,143 10,156 COMPZ RPEQPI WASH P Gather parameters: 100k ROT wt. @ 15 rpms @ 6k torque circulating @ 5 bpm @ 950 psig. Wash down to 10,158'. Pu above 10,143' DPM and slide over w/ no problems to 10,158'. PU to 10,156'. CBU @ 10 bpm @ 2,600 psig. NOTE: Original RKB de the included in these de ths. 17:00 18:30 1.50 10,156 10,156 COMPZ RPEQPI CIRC P Reverse circulate 30 hi visc sweep @ 6 b m 2200 si 18:30 22:00 3.50 10,156 0 COMPZ RPEOPI TRIP P POOH from 10156'. Rack back DP. 22:00 00:00 2.00 0 0 COMPZ RPEQPI PULD P Breakout & lay down 4 3/4" DC's. 4/25/2010 Clean & clear floor of tools. RU to run Lower completion assembly. MU FHL packer assembly with pups and 2.813" DS nipple. Crossover to DP, and TIH at 90' / Minute.Tag top of stump @ 10134. Work OS over stump to space out with guide at 10140' DPM. Spot 15 BBLS of CI fluid on annulus. Drop ball & rod, set PKR at with top of PBR at 10068' DPM. Shear out. Test backer to 2500 PSI to verify set POOH lay down DP. Continue POOH rack back 78 stands. Pull wear bushing. Slip & cut drilling line. RU & run 3 1/2" completion string with Seal assembl and GLM's s aced out as er ro ram. De th at midni ht = 4572'. 00:00 00:45 0.75 0 0 COMPZ RPEQPI PULD P Clean & clear rig floor area. Send out all BOT a ui ment. 00:45 01:00 0.25 0 0 COMPZ RPEQPI SFTY P Held PJSM with Crew & BOT rep. Discuss safety & hazard recognition issues. Discuss procedure to pick up and run Lower com letion assembl . 01:00 01:30 0.50 0 77 COMPZ RPCOM RCST P Make up FHL packer assmbly with , pups and 2.813" DS nipple, with RHC plug. Crossover to 3 1/2" DP MU for ue on EUE = 2500 FUlbs. 01:30 06:30 5.00 77 10,149 COMPZ RPCOM TRIP P Trip in hole with FHL packer assembly at 90 tt/min as per BOT rep. to 10,143' and shear out pins @ 10k slack off, continue to RIH and nogo @ 10,151'. PU 2' over pick up wt to 10,149'. 155k u wt 80k do wt. 06:30 07:30 1.00 10,149 10,149 COMPZ RPCOM CIRC P Pump 10 CI 9.6 ppg Brine followed by 73 bbls 9.6 ppg @ 2.5 bpm @ 350 si . 07:30 09:00 1.50 10,149 10,029 COMPZ RPCOM PACK P Set FHL 10,101' w/ to of PBR 10,079' and mule shoe of Poor bob! OS @ 10,149' @ 2,300 psig and continue to bring pressure up to 2,500 psig. Attempt to PT IA to 2,500 psig and loose pressure w/ small amount of returns to pits. Shut in DP and monitor pressure while pressuring up on the IA, seen increase on SIDPP and losses on the IA pressure, bleed off pressure. Pressure DP to 1,500 psig and shear out of PBR w/ seals. Bleed off pressure and POOH laying down 2 jts. Shut in DP and Pressure IA to 2,500 si for 10 minutes. 09:00 13:00 4.00 10,029 7,515 COMPZ RPCOM PULD P POOH @ 150k up wt. Laying down 77 'ts of DP to 7,515'. Page 19 of 21 LJ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 13:00 16:30 3.50 7,515 0 COMPZ RPCOM TRIP P POOH standing back DP and rackin for ri move. 16:30 17:00 0.50 0 0 COMPZ RPCOM OTHR P Pull wear ring 17:00 18:30 1.50 0 0 COMPZ RPCOM SLPC P Slip and Cut Drill line. Change oil and Service of To Drive. 18:30 19:30 1.00 0 0 COMPZ RPCOM SVRG P Rig up to run 3 1/2" Completion strin . 19:30 00:00 4.50 0 4,572 COMPZ RPCOM RCST P Make up Seal Assembly with locator, continuing with SOV GLM, and GLM's spaced out as per program. MU TQ = 1800 ft/Ibs Mldni ht de th - 4572'. 4/26/2010 Continue rin in hole with 3 1/2" completion string from 4572' - 10089'. UP WT 103K, SO WT 65K. Sting into packer verify no-go depth. Install space out pups, tbg hanger & landing joint. Mix & spot 275 BBLS of 9.6 PPG brine with CI. Land tbg hanger. RU to PT TBG and IA. PT tBG to 2,500 psig -after 2.5 minutes showed to be loosing pressure, Pressure back to 2,500 psig and held for 15 minutes -lost 100 psi in 15 minutes. Bleed back to 1,500 psig. Pressure IA to 2,500 psig for 30 minutes - no losses. Bleed IA down and follow with the bleeding of the TBG - at 750 psi had pressure spike to 1,750 psig and bled off to 0 psig. Pressure IA to 2,700 psig and shut down, valve sheared and dump pressure. SOV was verified as white (1,500 psi Shear) prior to picking up. Rig down lines. Install BPV. ND Bo Stack. Pull rams out of double ates. NU FMC ada ter, & tree. Test void to 5K. 00:00 07:00 7.00 4,572 10,079 COMPZ RPCOM RCST P Continue to RIH w/ 3 1/2" completion string from 4,572' to 10,079'. No go w/ 4' in on jt 313. MU TQ = 1800 FT/LBS. 07:00 08:30 1.50 10,079 10,077 COMPZ RPCOM PULD P Pick up 7', mark pipe and POOH. PU space out pups and hanger, RIH and locate top of PBR w/ charge pump on -seen pressure increase from 60 psi to 100 psi @ 12' in on landing jt. PU 2' for circulating CI 9.6 Brine. 08:30 09:30 1.00 10,077 10,077 COMPZ RPCOM CIRC P Begin reverse circulating 275 bbls of CI 9.6 ppg brine, followed by 10 bbls 9.6 brine 5 b m 500 si . 09:30 10:00 0.50 10,077 10,094 COMPZ RPCOM THGR P RIH 5' for seals to be in place and drain stack. Continue to RIH and land TBG hanger with 15' of seals inserted into PBR. 10:00 10:30 0.50 10,094 10,094 COMPZ RPCOM OTHR P RILDS and prepare for annular and TBG testin . 10:30 13:00 2.50 10,094 0 COMPZ RPCOM PRTS P RU to PT TBG and IA. PT tBG to 2,500 psig -after 2.5 minutes showed to be loosing pressure, Pressure back to 2,500 psig and held for 15 minutes -lost 100 psi in 15 minutes. Bleed back to 1,500 psig. Pressure IA to 2,500 psig for 30 minutes - no losses. Bleed IA down and follow with the bleeding of the TBG - at 750 psi had pressure spike to 1,750 psig and bled off to 0 psig. Pressure IA to 2,700 psig and shut down, valve sheared and dump pressure. SOV was verified as white 1,500 siShear riorto ickin u . Page 2Q of 21'_ n L_J r~ Time: Lo s Date From To Dur S. De th E. De th`Phase Code Subcode T Comment 13:00 13:30 0.50 0 0 COMPZ RPCOM MPSP P Pull landing jt and set BPV. 13:30 21:30 8.00 0 0 COMPZ RPCOM NUND P ND BOPE and remove rams from double ate Shaffer 21:30 00:00 2.50 0 0 COMPZ RPCOM NUND P Nipple up FMC adapter flange & tree. Test void to 5000 PSI. 4/27!2010 Continue test tree to 5000 PSI. Attempt to pull BPV. Pulling tool sheared. Repeat attempt to pull. FP well and allow to U-tube. Set BPV and secure well w/ 0/0/0 pressures. Pull rig off well and clean cellar and wellsite. Release Nordic Rig 3 @ 1000 hrs on 4-27-10. Well Com lete. 00:00 01:30 1.50 0 0 COMPZ RPCOM NUND P Nipple up FMC adapter flange & tree. Test void to 5000 PSI. - 10 Minutes. 01:30 04:30 3.00 COMPZ RPCOM OTHR T Attempt to pull BPV. Observed valve stuck. Pulling tool shearing the pins. Repeat attempt to pull BPV. Nipple down tree to the master valve. Flush & clean BPV. Pull BPV. Nippe up the tree again and test same to 5000 PSI. 04:30 04:45 0.25 COMPZ RPCOM SFTY P Held PJSM with crew & Little Red. Discuss safety & hazard recognitio issues. Discuss procedure to RU, test and um freze rotect diesel. 04:45 06:15 1.50 COMPZ RPCOM FRZP P RU Little Red Hot Oil. Test lines to 2000 PSI. Pump 75 BBLS of freeze rotect diesel down IA at 2 BPM. 06:15 07:45 1.50 COMPZ RPCOM OTHR P Allow IA to U-tube to TBG and RD Lines. 07:45 08:15 0.50 COMPZ RPCOM MPSP P Set BPV 08:15 09:00 0.75 COMPZ RPCOM OTHR P Dressed Tree 09:00 10:00 1.00 COMPZ RPCOM OTHR P Pull rig off well and clean cellar. Dress wellsite. Release Nordic Rig 3 @ 1000 hrs on 4-27-10 Page 21 of 21 ::. ~~. PeoA-crive Diagnosric SeRVicFS, INC_ • ALL L ~"~lf1/~f~tAL To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 s RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 , ' ;° ~ ; i 1 ~ ~ _~~ ~~ ~ ~' Fax: (907) 245-8952 1) Caliper Report 2) 19 Apr-10 2T-30 ~g5,~~~ 1 Report / EDE 50-103-20219-00 `~ 5 ~ ~( Signed Print Name: i~{~ ~~° ~~~~ ~ ~ ~~ ~ _~ _ ,®-' ~~~ ~'~ ~" Date ,: -3 .'. 'fir. ~ ~~ , PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : ~dsarachorage~rraern®rr9oa.cmrsl WEBSITE : v.lserrlor~r9o~.c®rs~e C:\Documants and Settings\Diane Williams\Desktop\Transmit_Conoco.docx ~~ la. PrtoAcrive Diaynosric SERVICES, INC. ~~~ ~~i ~~4~/~4L Ta: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C ,, ~ !?.,~..~;.~ ` ~ ~ `'' ~~ ~: Anchorage, AK 99518 '- Fax: (907j 245-8952 1) Caliper Report 2) 15 Apr-10 2T-30 ''_~~ ~~S Signed Print Name: -.J PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-88952 E-MAIL : Cds~nC~~r~s~e(c~rraem®rAl!®a ~Crts WEBSITE : vv~nrav.rrcerracarV9®G.~araa 1 Report/ EDE 50-103-20219-00 C:\Documents and Settings\Diane Williams\Desktop\Trens~nit_Conoco.docx ~~ PROACTIVE DiACINOSi1C SERVicES~ INC_ ~~~ +~~E. ~~~~i~f • To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 [907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection[Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the fallowing ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 ,~=-r, ~- w? ,~,•:~ ' ', ~ "~ ~~ k; s h Fax: [907) 245-8952 1 J Caliper Report 10-Apr-10 27-30 2) 1 gS- c~s~- ~~s~s~ Signed Print Name: 1 Report / EDE 50-1 03-202 1 9-00 ,- --~ y a a ~ i- :~ Date : ~~ ~ ~'~' ~. s ' tip Y'ei . ~3 § ~ ~ ~ . PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907)245-88952 E-n~Ilaa : ~dsanc3tor~~eCa7s~?erssssr~~log.~r~s~ WEBSITE : ~vvv.r~EanOfvlog.La~s~t C:\DocumeMS and Settings\Diane Williazns\Desktop\Transmit_Conoco.docx • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Free Point Log: 2T-30 Run Date: 4/14/2010 Apri123, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T-30 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20219-00 x ,~~' y i iii; ~ ;?~~E .v PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barr c ~ .~ ~ ~' Date: ~ ~~ ~ ~ / l~il~v5 Signed: • .. ~ ~:> • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Apri123, 2010 RE: String Shot Record: 2T-30 Run Date: 4/11/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T-30 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20219-00 ~i E~~' x ~ ~~~ y~ I ~~ ' 1 ~~o`f PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto hallibu c _~ i Date: ~~~ ;~c ~!s~?; \, I Signed: `A ~46d .. C~ WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log: 2T-30 Run Date: 4/10/2010 • Apri123, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T-30 Data in LAS format, Digital Log Image files 1 CD Rom 50-103-20219-00 Cement Bond Log 1 Color Log 50-103-20219-00 3 ~ S. ~: z a f - PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax:907-273-35 5~ rafael.ba Et` , . ~~ ~~"ds~ Date: ~;. ~0~~~3 Signed: i • Memory Mufti-Finger Caliper S Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 2T-30 Log Date: Aprit 19, 2010 Field: Kuparuk Log No.: 7841 State: Alaska Run No.: 3 API No.: 50-103-20219-00 Pipet Desc.: 9.625" 40 Ib. L-80 Top Log Intuit.: Surtace Pipet Use: Surface Casing Bot. Log Intuit.: 2,074 Ft. (MD) ~' Inspection Type ; Buckling 8 Restriction inspection ' COMMENTS This caliper data is correlated to the PDS Caliper Log (April 75, 2090). This log was run to assess the condition of the 9.525" surface easing following milling operations to alleviate ' LD. restrictions. The caliper recordings indicate a bend in the surface casing from ~38T to --394', with an obstruction at 393' restricting the LD. to 8.43". No other significant LD. restrictions are recorded throughout the surface casing logged. Comparison 3-D log plots pre and post milling of the centered and off-center caliper recordings of the top 430', and post milling 3-D log plots of the centered and off-center caliper recordings of the top 1,700' are included in this report. A graph illustrating minimum recorded diameters on a joint-by joint basis is included in the report. This is the third time a PDS Caliper has been run in this well and the second time the 9.625" surface casing has been logged. ~~?~a.~"~,i ~.~;. Field Engineer. J. Halvorsen Analyst: C. Wakiro Witness: L. Hinkei ProActive Diagnostic Services, Inc. f P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax; (2$i) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 f~5 • • PDS Multifinger Caliper 3D Log Plot L~ . _ ~~, Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2T-30 Date : April 19, 2010 Description : Detail of Centered Caliper Recordings Across Bend in Surface Casing Pre- 8Post-Milling. Comments Depth Max. I.D. (04-15) 3-D Log (04-15) Image Map (04-15) Max. I.D. (04-19) S-D Log (04-19) Image Map (04-19) ~ 1ft:800ft 7.7 9.7 207° 0° 90° 180° 270° 0° 7.7 s 9.7 337° 0° 90° 180° 270° 0° Min. I.D. (04-15) Min. I.D. (04-19) 7.7 9.7 7.7 9.7 Nominal I.D. / O.D. Nominal I.D. / O.D 7.7 9.7` 7.7 9.7 50 ---- - -- --" ,;. :: r 100 ,~ z .- Joirt 3 150 i s - Joint 4 200 - : `, j - ~ _: _ :..: I '~ Joint 5 Joint 8 250 - Joint 7 -... . . 300 .. .. .. _.. ... . Joint 8 SOgM Ovd DsTormation. 5 I ~~ ~, ~ ~ ~, I I ~ _ - f ~~ `, ` ~ Jdns obstr~ctionn Band Min. 1. D.=8.43" 3 0 -. 9 .. - ~ ,. a ti :., .. .-..: _ .. ..~ - .... ,,. .. ; ?;p' ~ '4~., :- ... .,o---_._ _ - Joint 10 400 i ~ ~~ i i - 7" Prod. Casing ~. -- '"~ I -.~ Nominal I.D. / O.D. Nominal I.D. / O.D 7.7 9.7 7.7 9.7 Min. I.D. (04-15) Min. I.D. (04-19) ~ F 7.7 9.7 7.7 9.7 Comments Depth Max. LD. (04-15) 3-D Log (04-15) Image Map (04-15) Max. LD. (04-19) 3-D Loy (04-19) Image Map (04-19) 1ft:800ft 7.7 9.7 207° 0° 90° 180° 270° 0° 7.7 9.7 337° 0° 90° 180° 270° 0° PDS Multifinger Caliper 3D Log Plot ~, _ S Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2T-30 Date : April 19, 2010 Description : Detail of Off-Center Caliper Recordings Across Bend in Surface Casing Pre- 8 Post- Milling Comments Depth Max. I.D. (04-16) 3-D Log (04-15) Image Map (04-15j Max. I.D. (04-19) 3-D Log (04-19) Image Map (04-19) 1ft:800ft 7.7 9.7 9° 0° 90° 180°270° 0° 7.7 9.7 0° 0° 90° 180° 270° 0° Min. I.D. (04-15) Min. I.D. (04-19) 7.7 9.7 7.7 9.7 Nominal I.D. / O.D. Nominal I.D. / O.D :............................ I............................ + 7.7 9.7 7.7 9.7 - ___ ~ _ t ~, Pup Joint. 0 .. s. - ..... sew' '. ~ . ,~ ._ .. _ .~;;-3 Jain, _. .. _ Y, 1 0 - JaiK 2 0 „.° ; ~ ~ r ~ _ a _ ~ _ ~ i°~1 . I ,, 1; :: -- i I I JoIeY 3 - - j ~ - t t ! ^' 150 ~ ~ _..~ „ ~, ., ,..e: ~. s ~ _ Ja11Y 4 • ~. _ .. _; .: 200 . ~, a- n~~ . -. . ~e:: f Joint 5 •t - ~' i < ..~ ~'- ~ • I. I ' 250 ' , - Joint 8 - I Iilt~: Jaint ~ 300 - ~ .>, - _ . .# '. .. .a _ . .. - - . .z, _ ~ Joint B ,~ "'. . fir.. ~~ 31ipM Oval n ~ ~• Deformation. 350 ~. ~~ y _ gym. _ Joinl B Obstruatlon'vi ~ __.. s ~,: Bend g ~ Mh LD.=8.43" "y~ ~'f~ ~ __ _. -_ JoirR,O 400 .. - _ _. - -` ., .. , _ ~._ 7" Prod. Casing Nominal I.D. / O.D. Nominal I.D. / O.D 7.7 9.7 7.7 9.7 Min. I.D. (04-15) Min. I.D. (04-19) I 7.7 9.7 7.7 9.7 Comments Depth Max. I.D. (04-15) 3-D Log (04-15) Image Map (04-15) Max. I.D. (04-19) 3-D Log (04-19} Image Map (04-19} 1~~~~ 7.7 9.7 9° 0° 90° 180° 270° 0° 7.7 -~ 9.7 0° 0° 90° 180° 270° 0° PDS Multifinger Caliper 3D Log Plot ~., . _,~. Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2T-30 Date : April 19, 2010 Description : Detail of Centered Caliper Recordings Across Bend in 9.625" Surface Casing. Comments Depth Max. I.D. (ins.) 3-D Log Image Map 1ft.800R 7.7 9.7 0° 0° 90° 180° 270° 0° Min. I.D. (ins.) 7.7 9.7 Nominal I.D. / O.D 7.7 9.7 Pup Jt. 50 Joint 1 100 ` Joint 2 . - -- - - Joint 3 _ --~-~-i- -~ 150 Joint 4 ~ _ -- -r~ _ i ~~ ~ i 200 _ _ i i Joint 5 -~- - - - -- ~~ - - - -~ -. 250 JoirR 6 Joint 7 00 3 Joirh 8 SIigM Oval {- - Deformation ~ e _. .. _ Joint 9 350 - F- _. s - _._ - - _ - ,. _, ., - _ Bend Min. LD. = 8A3" ,.- i ~ . -, ~- 400 - Joint 10 • • _ a ' ... ,. . _ -, ,.., - - fi 1--' 5 Joint 11 4 0 ~ ; Joint 12 . -- _- . } SIigM Oval Deformation t---' - - i 500 Joint 13 f -- - _. . _ __ , SIigMOval Detormaton _ _ - - - _ -_ _ _~ _ _ int 14 J 550 o sngM oval Deformation -- Joint 15 600 SIigM Oval Deformation Joint 16 SIigM Oval Deformation 650 Joint 17 SIigM Ovai Deformation 700 Joint 1s SngM Oval Deformation 750 JaM 19 Joint 20 Slight Oval 800 Deformation Joint 21 Slight Oval Deformmation 850 Joint zz Slight Oval Deformation Joint 23 0 9 0 SIigM Oval Deformation Joint 24 SIigM Oval 950 Deformation Joint 25 SngM Oval - Derormaton ~ 1000 Joint 26 I SIigM Oval Deformation Joint 27 1050 SIigM Oval Deformation Joint 28 0 SIigM Oval 11 0 Deformation Joint 29 SNgM Oval Der°""ati°" 1150 Joint 30 SIigM Oval ~_~ Deformation ~" rr~~~ .~ u3?'° SNgM Oval - ? --- -'~ Deformation - ~ . 1250 Joint 32 i Joint 33 1300 ~ ~ Joint 34 ~ I i I SIigM Oval f ti D I ~ orma e on 1350 ~ ' ~ ~ Joint 35 .., I I -- - ~ __' i SIigM Oval Deformation _' Joint ~ 1400 _~ +- 1 ; SIigM Ovai _ ~ '~ _' Deformation ~ ~ ~ Joint 37 1450 ._ _ _ SIigM Oval _ " Deformation ' ~'°`" . Joint 38 ~~~ - - SNgM Oval 1500 ~ Deformation I -, - _ - _ . Joint 39 ,- 1550 - - Joint 40 l - I - ~ - 60 0 1 Joint 41 Joint az 1650 i ~ - • ~ , i S Joint 43 Nominal LD. ! O.D ' • 7.7 9.7 . Min. I.D. (ins.) 7.7 9.7 Comments Depth Max. I.D. (ins.) 3-D Log Image Map 1~~~~7.7 9.7 0° 0° 90° 180° 270° 0° • • PDS Multifinger Caliper 3D Log Plot ~. . , Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2T-30 Date : April 19, 2010 Description : Detail of Off-Center Caliper Recordings Across Bend in 9.625" Surface Casing. Comments Depth Max. I.D. (ins.) 3-D Log Image Map ~ 1ft:800ft 7.7 9.7 0° 0° 90° 180° 270° 0° Min. I.D. (ins.) 7.7 9.7 Nominal I.D. ! O.D 7.7 9.7 i P Jt ' ~^ - - _ - - up . 50 , - -~- ~ 1 ~. JarR 1 . i° ~~.,_ ,~- 'k+:' _ '- - a ~ -~ : - , Jatmt 2 100 °"~"'~_ °~ r <. _ _ Jarmt 3 - ~ ~, ... 1 -.. 50 F , ~-- ... Jant a _ z -~-~~ _ .~ - 200 ° z _ JantS Y S . . .. __ ~. ;., 250 Joint 6 - ,~ . Joint 7 ~" . _ -- - - ,.. 300 _. ~ . ..- ,-- ~ Joimrt8 ,_ i ~ ~« ~.-.y SIigM Oval T .-._- ~ ~ Deformation 5 3 0 • ~ ,..~ Joint 9 f r ~~ ~ ' ""' _ Obstruction in L_ : ... _. _ Bend Min. LD. = 8A3" . 4 ~..~. °--^ = ~ ~~ _ .s 400 - - _ Joint 10 -- _ .- i _ ~ ~~ ,. _. " ~ .~ ...._ _ `~ - _ Joint 11 450 -- ~. ~ - - Joint 12 ? ,, yfi, I SIigM Oval Deformation '- 500 _ Joint 13 SIigM Oval i - - F;; Deformation • • • SIigM Oval Defornation Joirn 32 1250 Joirn 33 1300 Joint 34 SIigM Oval Deformrtion 1350 Jolrn 3s SBgM Oval Deformation Joirn ~ 1400 Slight Oval Deformation Joint 37 1450 Slight Oval Deformation Joirn 38 SIigM Oval 1500 Deformation Joint 39 1550 Joirn 40 1600 Joirn 41 Joint 42 1 s5o Joirrt 43 .. _. i .-_'~ T .° ~' ~;" iiiie- i Nominal LD. ! O.D 7.7 9.7 Min. I.D. (ins.) 7.7 9.7 Comments Depth Max. I.D. (ins.) 3-D Log Image Map 1ft:800ft 7.7 9.7 0° 0° 90° 180° 270° 0° • ~~ Minimum Diameter Profile Well: 2T-30 Survey Date: April 14, 2010 Field: Kuparuk Tool: UW MFC 40 Ext. No. 218451 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 inches Country: USA Tubing I.D.: 8.835 inches • • PDS Report Overview ~~.__ ~,w Body Region Analysis Well: 2T-30 Survey Date: April 14, 2010 Field: Kuparuk Toot Type: UW MFC 40 Ext. No. 218451 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Anal st: C. Waldro Tubing: Nom.OD Weight Grade &Thread Norn.ID Norri. Upset Upper len. Lower len. 9.625 ins 40 f L-80 8.835 ins 9.625 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body r:., metal loss body 60 50 40 30 20 10 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of'oints anal sed total = 54 pene. 0 0 32 21 0 1 loss 0 3 50 1 0 0 Damage Configuration (body ) 60 - - w 40 20 0 is~Aated general line ring hole/poss pitting corrosion corrosion corrosion ible hole Number of'oints dama ed total = 54 0 53 0 0 1 Damage Profile (% wall) ~ penetration body , metal loss body 0 50 100 0 20 40 Bottom of Survey = 53.1 Analysis Overview page 2 • PDS REPORT JOINT TABI, Pipe: 9.625 in 40.0 ppf L-80 Well: Body Wall: 0.395 in Fietd: Upset Wall: 0.395 in Company: Nominal I.D.: 8.835 in Country: Survey Date: • ELATION SHEET 2T-30 Kuparuk ConocoPhillips Alaska, Inc. USA April 19, 2010 Joint No. Jt. Depth (Ft) I'~~n. t 11 net fln~.} Pen. Body (Ins.) Pen. % :Metal I vss `;4, Min. LD• (Ins.) Comments Damage Profile (% wall) 0 5D 100 .1 42 u.U~ 0.08 20 It) 8.86 PUPA a ent Erosion. 1 47 U.Ub .09 22 13 8.86 ha w anent Er Sion. li ht ucklin . 84 t1.1)r; ,08 ZO 14 8.87 A arentEr Sion. 3 122 t).t)£3 0.08 2U I ~ 8.86 A anent Erosion. 4 161 (1.Ob 0.08 ~ I I .t 8.85 Shallo A anent Erosion. Sli ht B lin . 5 200 O.O(, 0.08 19 I _' 8.84 Sh Ilow A anent Erosion. 6 239 t ~.t )b .07 1 t3 1 1 8. 5 hallow A anent Erosion. Sli ht Bucklin . 7 277 tr.O6 .08 2U I i 8.88 A arentErosion. 8 315 ! ).t )£i 0 09 2 I .~ 8.85 A anent Erosion. Sli ht Ova Deformation. 9 356 l1.1 S 0.09 22 1 ~ .43 Obstruction with I. . of 8.43". Bend. 10 393 t~. I I 0.39 1OU t I 8.87 A . Dama e from 7" Prod. Casin Cu . 11 432 t).t)b 0.09 '2 I ~ 8.88 A a ent Ero ion. 12 470 O.U6 0.08 19 1 ~ 8.87 Sli ht Oval Deformation. 13 505 t).US 0.0 1 V I -1 8.85 Sli ht Ov Deformation. 14 542 U.U£3 0.08 2O i ~ 8.83 A anent Erosion. Sli ht Oval Deformation. 15 5 0 U.U' OA9 ZZ !. 8.83 A are Erosi n. Sli ht Oval Deform tion. 16 619 i.).t)5 0.08 'l) i # 8.85 A anent Erosion. Sli ht Oval Deformation. 17 6S8 t).l)7 0.08 Z 1 I _' 8.81 A anent Erosion. Sli ht Oval Deforma ion. 18 697 U.U7 0.08 19 i ~ 8.83 Sli ht Oval Deformation. 19 7 U.Ub 0.07 19 i ' .84 20 771 O.O(> 0 9 ~2 1 ~ 8.80 A anent ro i n. Sli ht val eformatior . 1 811 O.Ui .08 20 1 8.75 A are t Erosion. Sli ht val eformation. 2 848 U.O£i 0.08 19 11 8.75 Sli ht Oval Defor ation. 2 887 O.O£~ 0.0 19 1 ? 8.84 Shall w A r nt rosion. Sli ht Ov I Defor 24 925 u.O£, 0.0 16 I I 8.81 Sli h Oval Deformaton. 25 964 U 0.08 ~' 1 ! . 8.79 A ar t Erosion, Sli ht Oval Deformation. 26 1002 U.t)t3 0.09 ~_> 1 _' 8.83 A anent Ero ion. Sli ht Oval Deformation. 27 1040 t).U8 0.09 Z~ I ~ 8.79 A anent Erosion. Sli ht Oval Deformation. 28 1077 (r.Ub 0.08 ZO ! -i 8.79 A anent rosion. Sli ht Ov I Deforma ion. 29 1116 U.O~r 0.08 t ~? f . 8.77 Sli ht Oval Deformation. 30 1155 U.O> 0.08 19 I Z 8 72 Sli ht Oval efor alto . 31 1192 1) 0.08 Z 1 1 Z 8.79 A anent Erosion. Sli ht Oval Deformation. 32 1231 O.UE~ 0.07 19 11 8.84 33 1271 t).U6 0.08 21 1 I 8.83 A anent Erosion. 34 1310 U.UB 0.08 ~ 1 1 _' 8.79 A anent rosion. Sli ht Oval Deforma ~on. 35 1352 ).t?7 0. 8 I9 1,? 8.80 Sli ht Oval Deformation. 36 1389 (1 0.09 ~,' I I 8.81 A ar nt Erosion. Sli ht Ova Deforma ion. 37 1431 r).O(~ 0.08 ~'O Iii 8.7 A arentEro ion. Sli ht Oval eformatio . 38 1474 U.l~- 0.0$ 1O 8.71 A anent Erosion. Sli ht Oval Defor atio . 9 1514 O.1)i 0.08 i i l 8.81 A ar nt Eros~on. 40 1553 i1 0.06 i5 li1 8.78 41 1589 U.US 0.06 16 I 1 2 Sh Ilow A r nt Erosi n. 42 16 9 U.U' 0.07 18 1 ' 8,83 43 167 O.ut~ 0.08 19 II 8.83 44 1708 U.i)t> 0.08 21 I s 8.85 A anent Erosion. 45 1746 a 0.07 17 1I 8.84 46 1784 ! ).t u, 0.07 1 £3 . I 8.85 Shallow A anent Erosion. 47 1822 t).U(~ 0.08 19 I! 8.86 48 1862 U.U7 0.0$ Z 1 I< 8.84 A anent Erosi n. 49 1900 U.U£3 0.0 Z2 I3 8.84 __AppaCent Erosion.____ __ _ Penetration Body Metal Loss Body Page 1 • • PDS REPORT JOINT TABULATION SHEET Pipe: 9.625 in 40.0 ppf L-80 Well: 2T-30 Body Wall: 0.395 in Field: Kuparuk Upset Wall: 0.395 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 8.835 in Country: USA Survey Date: April 19, 2010 Joint No. Jt. Depth (Ft) I'rn. Upset (lns.) Pen. Body (Ins.) Pen. % Metal I osti °.;. Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 50 1939 U.U6 0.07 18 1 ~! 8.85 51 1976 U.(16 0.09 22 12 8.84 A arent Erosion. 52 2016 l).Ub 0.08 ZU I 1 8.84 A arent Erosion. - 53 2054 l1.Oi 0.08 ' I 13 8.85 A arent Erosion. 53.1 2073 ~~ 0 U u N A To of 7" Production Casin . _ Penetration Body Metal Loss Body Page 2 w~ ~w ~ ~ ~ ~ ~ ~ ~ ~ ~ r ~ r ~ ~ ~ ~^~- ~ ~ _ ~ PDS Report Cross Sections Well: 2T-30 Survey Date: April 19, 2010 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 218451 Company: Conoco Phillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 9.625 ins 40 ~ f I_-80 Anal st: C. Waldro Cross Section for Joint 10 at depth 411.77 ft Tool speed = 43 Nominal ID = 8.835 Nominal OD = 9.625 Remaining wall area = 69 Tool deviation = 1 ° Finger 33 Penetration = 0.394 ins ~ App. Damage from 7" Prod. Casing Cut 0.39 ins = 100% Wall Penetration / 31%Cross-Sectional Wall Loss HIGH SIDE = UP • Cross Sections page 1 ~ ~ ~ r ~ ~ i ~ ~ a^~ ~ ~ ~ r i ~ ~ ~ ~ PDS Report Cross Sections ~~1~~ ~.~ Welt: 2T-30 Survey Date: April 19, 2010 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 218451 Company: Conoco Phillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 9.625 ins 40 f L-80 Anal st: C. Waldro Cross Section for Joint 8 at depth 346.34 ft Tool speed = 43 Nominal ID = 8.835 Nominal OD = 9.625 Remaining wall area = 86 Tool deviation = 1 ° Finger 9 Penetration = 0.13 ins Apparent Erosion 0.09 ins = 23% Wall Penetration HIGH SIDE = UP Cross Sections page 2 ~ PDS Report Cross Sections Well: 2T-30 Survey Date: April 19, 2010 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 218451 Company: Conoco Phillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 9.625 ins 40 f L-80 Anal st: C. Waldro Cross Section for Joint 9 at depth 393.0667 ft Tool speed = 44 Nominal ID = 8.835 Upset OD = 9.625 Remaining wall area = 100 In upset region Tool deviation = 1 ° Finger 7 Radius = 4.2 ins Obstruction in Bend Minimum I.D. = 8.43 ins HIGH SIDE = UP i Cross Sections page 1 ~,. ~ KUP 2T-30 ConoeoFl'liliips ~ II Attributes An le & Ivy TD dl•.1~c... , ' .... .. WNlbore APINWI 501032021900 FlNd Name WNI Status Ind l°) KU PARUK RIVER UNIT PRODUCING 65.65 ND IrtKB) 5405.31 Act Btm IRICB) 10,686.0 - Well nfi -2 3 1 1 0923E U PM Comment H2S (ppm) Date SSSV: NIPPLE 100 1111/2009 Amotffilon E Last WO: nd Date KB-frd lRl Rlg Release ate 5!13(1995 Smem ti c- ual Amotatlon Depm IIDB) F]ad Dale Amotatlon Last Nlotl By End Date last Tag: RKB 10,330.0 5/3/2009 Rev Reason: LDL found leak @ 10,158' ELMD Imosbor 10/10/2009 Casin Strin s I Casing Descriptlon Sdng O (ml D Sdng ID gnl Top gbc61 Set f>epM (ftiCBl Set Depth (TVD) (rtxel Sdng Wt pbs/Rl Sdng trade Sdng Top 7hrtl ooNDUC1oR, CONDUCTOR 1 6 15.062 0.0 121.0 121.0 62.58 H-40 121 SURFACE 9 5 18 8.679 0.0 4,203.0 2,874.3 40.00 L-80 PRODUCTION 7 6.151 0.0 1Q676.0 6,084.2 26.00 L-80 NIPPLE s,o Tubin Strin s , Tubl Descrlptlon stdrg o Ilnl D stdng ID (Inl To B) set Depth (RKB) set Deptn IrvD) (fl1CB) swing wt Ilbsnq stdry Qadr Sri T ThN TUBING 31/ 2 2992 0.0 10,204.0 5,732.9 9.30 L-80 ABM-EUE Other I n Hole A ll Jewe l :Tubin Run 8 Retrievabl Fish etc. GAS LIFT, 1.oe1 To B Top epth IT/DI (RKB) Top and (°) Des on Comment Run Date ID n 510 509.8 3.86 N IPPLE Camco'D5 Landing NO GO 9/1/1995 2.812 SURFACE, 4 2,081 1.904.7 50.39 G AS LIFT CAMCO/MMM/1.5/GLVlRK/.188/1281/Comment STA 1 7/28/2009 2.920 z63 4,896 3,191.5 58.42 G AS LIFT CAMCO/MMM/1.5/GLV/RK/.188/1267/ Comment: STA 2 7/28!2009 2.920 6,706 4,001.6 63.54 G AS LIFT CAMCO/MMM/1.5/GLV/RK/.188/1253/ Comment: STA 3 7/27/2009 2.920 GAS uFr, 8.324 4.697.9 6248 G AS LIFT CAMCOIMMM/1.5/GLVlRK/.25/1282/ CommenT STA4 7/ 011998 2.9201 a,6ss 9,538 5,279.1 52.35 G AS LIFT CAMCO/MMM/1.5JGLV/RK/.188/1225/ Comment: STA 5 7/28/2009 2.9:0 10,124 5,673.7 44.81 G AS LIFT CAMCO/MMM/1.5/OV/RK1.25//Comment: STA6 7/31/2009 2.920 10,170 5,707.5 44.28 N IPPLE Camco'W-1' Selective Landing Nipple 9/1/1995 2.812 eAS UFr, s ]os 10,177 5,712.7 44.20 A NCHOR Baker K-Anchor 9/1/1995 3.250 . 10,178 5.713.5 44.19 P ACKER Baker SAB-3 Penn. 9/1/1995 3.250 10,193 5,724.7 44.02 N IPPLE Camco'D' Nipple NO GO 9/1/1995 2.750 10,204 5,732.9 43.90 S OS Baker 9/1/1995 2.992 cns ur 1, 8,314 10.205 5,733.7 43.88 T TL ELMD @ 10198' per SWS PERF 9!17/1995 9!111995 2.992 10.470 5,927.1 4087 FI SH 11/2"DV DROPPED 6/26/981N RAT HOLE 6/26/1998 0.000 Pertorations & Slots GAS LIFT. s s3s Top e) BOn 1mcB1 Top (TVD) nd(B) Sm ITVDI (IIKB) Zone Date sn« Dens (~°• lype CommeK 10,298 10,306 5,803.7 5,809.2 C-0, 2T-30 7/5/1998 4.0 APERF 2.5" H.C. B.H., 180 deg ph, 90 deg. orient 10,298 10.306 5,803.7 5,809.2 C-0, 2T-30 7/12/1998 4.0 RPERF BH. 180 deg. ph, 90 deg. orient GAS LIFT 10 1zq 10.349 10,369 5,839.4 5 B53.7 A-3. 2T-30 9/17/1995 4.0 (PERF 2 1/8" EJ. 180 deg ph; oriented (+!-) 90 deg. lowside. 10,398 10,416 5.A74.5 5,887.5 A-2, 2T-30 6/9/2002 6.0 APERF 2.5" PJ, 60 deg phase Notes: f3eneral 8r Safe Ertl De<e Amotatlan NIPPLE, 10.170 10/2/2009 NOTE: LDL FOUND LEAK @ 10,158' ELMD ANCHOR, 10,1]] as ar PACKER, i0.17S NIPPLE 1 1 . 0, 93 SOS, 10,204 TTL. 10.105 AarcRF 10,298-10,306 RPERF 10,19&10,306 (PERF, 10,34510,369 APERF 10 39fl-10,41 F FISH, 10,4 ]0 PRODUCTION, 10,6]6 TD. 10,660 ~ • • Memory Multi-Finger Caliper S Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 2T~0 Log Date: April 15, 2010 Field: Kuparuk Log No.: 7837 State: Alaska Run No.: 2 API No.: 50-103-20219-00 Pipet Desc.: 9.625" 40 Ib. L-80 Top Log Intvl1.: Surface Pipet Use: surtace Casing Bot. Log Intvl1.: 413 Ft. (MD) Inspection Type : Buckling 8 Restriction Inspection COMMENTS This caliper data is correlated to the Halliburton Free Point Log (April 14, 2010). This log was run to assess the condition of the 9.625" surtace casing with respect to buckling and I.D. restrictions. The caliper recordings indicate a bend in the surtace casing from -387' to --394', with an obstruction at 393' restricting the I.D. to 7.04". Across-section view of the obstruction is shown below. 3-D log plots of the centered and off-center caliper recordings across the bend and obstruction recorded in the 9.625" surface casing are included in this report. A graph illustrating minimum recorded diameters on a joint- by-joint basis is included in this report. Field Engineer: J. Halvorsen Analyst: C. Waldrop Witness: D. Rowell Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS~imemorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-~1~4~~~~ ~~,;,;1 ~ 2 200 This is the second time a PDS Caliper has been run in this well and the first time the 9.625" surface casing has been logged. • • PDS Multifinger Caliper 3D Log Plot L. _.- Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2T-30 Date : April 15, 2010 Description : Detail of Centered Caliper Recordings Across Bend and Obstruction in 9.625" Casing. Comments Depth Max. I.D. (ins.) 3-D Log Image Map (Centered) 1ft:~OR 7.7 9.7 0° 0° 90° 180° 270° 0° Min. I.D. (ins.) 7.7 9.7 Nominal I.D. / O.D. 7.7 9.7 _ . ~ -~ 1 ~ .. 40 _ Pup Joint. 1 __; . 50 -_ ~` Joint 1 60 _ . 70 ~. 80 b , 90 = ~ Joint 2 100 _ 110 _ ;. . 120 _ 130 e Joint 3 140 150 ~ _~ 160 170 Joint 4 180 190 200 210 • • 23 0 240 250 Joint 6 260 270 280 -_ 290 Joint 7 300 _~. -- 310 -_ 320 --,- Joint 8 Slight Oval D f ti 330 e orma on. 340 _ ~ _, 350 _ : - 360 _ _ ---- _.~.. , y - Joint 9 Bend 70 ' (-38T to -394') Obstruction 3 = '• ~-_ `` K (393') Min. LD. = 7.04" 380 • • ~. 390 . -~ ~ 0 ` ' -~ _- _ Joint 10 4 0 . . - -- - ~:,~ _ .. _ -- ..... ,: , . 410 7" Prod. Casing .~_..: `- _ . Nominal I.D. / O.D. :.....................................................................: 7.7 9.7 Min. I.D. (ins.) 7.7 9.7 Comments Depth Max. I.D. (ins.) 3-D Log Image Map (Centered) ---•- - - - - ,; i~ 1ft:300ft 7.7 9.7 0° 0° 90° 180° 270° 0° • • PDS Multifinger Caliper 3D Log Plot ~-, -- Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2T-30 Date : April 15, 2010 Description : Detail of Off-Center Caliper Recordings Across Bend and Obstruction in 9.625" Casing Comments Depth Max. I.D. (ins.) 3-D Log Image Map (Off-Center) 1ft300ft ~ 7.7 9.7 9° 0° 90° 180° 270° 0° Min. I.D. (ins.) 7.7 9.7 Nominal I.D. / O.D. 7.7 9.7 40 Pup Joint. 50 Joint 1 60 70 80 90 Joint 2 100 110 120 130 Joint 3 140 150 160 170 Joint 4 180 190 200 210 ~'F _._. _ F~ • ~~ Minimum Diameter Profile Well: 2T-30 Survey Date: April 15, 2010 Field: Kuparuk Tool: UW MFC 40 Ext. No. 218451 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 inches Country: USA Tubing I.D.: 8.835 inches 0.1 i 2 3 4 y 5 E 0 z C 6 7 8 9 10 10.1 Minimum Measured Diameters (In.) 2.75 3.25 3.75 4.25 4.75 5.25 5.75 6.25 6.75 7.25 7.75 8.25 8.75 PDS REPORT JOINT TABULATION SHEET Pipe: 9.625 in 40.0 ppf L-80 Well: 2T-30 Body Wall: 0.395 in Field: Kuparuk Upset Wall: 0.395 in Company: ConocoPhillips Alaska, Inc. Nominal LD.: 8.835 in Country: USA Survey Date: April 15, 2010 Joint No. Jt. Depth (Ft.) I'~•n. Ups<~I (Ins.} Pen. Body (Ins.) Pc n. % Metal I oss `~4, Min. LD• (Ins.) Cornments Damage Profile (% wall) 0 50 100 .1 43 u.t?9 0.09 24 1 S 8.85 PUPA arent Erosion. Sli ht Bucklin . 1 47 t).Ui, 0.08 ~'"I 13 8.86 A arent Erosion. 2 85 t).t1- 0.08 _' I 14 8.86 A arent Erosion. 3 123 (1.07 0.08 _' 1 1;3 8.85 A arent Erosion. Sli ht Bucklin . 4 161 U.07 0.09 24 14 8.85 A arent Erosion. 5 200 O.Ub 0.08 20 l a 8.87 Shallow A arent Erosion. 6 239 U.O(, 0.07 1 ~? 1 S 8.87 Shallow A arent Erosion. Sli ht Bucklin . 7 277 O.r-)~ 0.09 Z2 14 8.87 A arent Erosion. 8 315 U.~)7 0.09 Z2 13 8.85 A arent Erosion. Sli ht Oval Deformation. 9 356 U.U8 0.09 ~4 14 7.04 Obstruction with LD. of 7.04". Bend. 10 393 U.06 0.10 Z5 14 8.79 A arent Erosion. +~ 10.1 413 0 0 U l1 N A To of 7" Production Casin . _ Penetration Body Metal Loss Body Page 1 ~~, ~ PDS Report Cross Sections ,. -- „ Well: 2T-30 Survey Date: April 15, 2010 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 218451 Company: Conoco Phillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 9.625 ins 40 f L-80 Anal st: C. Waldro Cross Section for Joint 0.1 at depth 43.26 ft Tool speed = 43 Nominal ID = 8.$35 Upset OD = 9.625 Remaining wall area = 88 In upset region Tool deviation = 0 ° Finger 26 Penetration = 0.093 ins Apparent Erosion 0.10 ins = 25% Wall Penetration HIGH SIDE = UP • ~J Cross Sections page 1 PDS Report Cross Sections Well: 2T-30 Survey Date: April 15, 2010 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 218451 Company: Conoco Phillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 9.625 ins 40 t L-80 Anal st: C. Waldro Cross Section for Joint 9 at depth 393.04 ft Tool speed = 43 Nominal ID = 8.835 Nominal OD = 9.625 Remaining wall area = 100 Tool deviation = 1 ° Finger 31 Projection =-0.942 ins Obstruction Minimum I.D. = 7.04 ins HIGH SIDE = UP Cross Sections page 2 ~ ~\ ~ KUP ~ 2T-30 ConoeoPllilli ps } Attributes n le & IND TD ''' ' t ~ 1 Wdlbore API/UWI 501032021900 FlNd Name WNI Status KUPARUK RIVER UNIT PRODUCING Ind (°) ND (M(1 65.65 5.405.31 AR Btm (NCB) 10.686.0 Comment H2S lppm) Date Amotatlon SSSV: NIPPLE 100 7/17/2009 Wst WO: Fstl Date KB-Cr01R) Rig Release Date 5!73/1995 on ova ao w n orzo -zss ~, PM 5dtem u I Amotatlon Depth (BIB) Fntl Date Arcot on Last Mod ~ End Dale Last Tag: RKB 10.330.0 5/3/2009 Rev Reason: LDLfound leak @ 10,158' ELMD Imosbor 70!70/2009 Casin Strin s ~ I Casing ikscripdon Stdng W MI String ID Pn1 Top pt1CB) Set Depth (NCBI Set Depth INDI (NCB) Strang Wt phsrtq Strang trade Strang Top mrtl coNOUCrnR, CONDUCTOR 1 6 75.062 0.0 727.0 721.0 62.58 H-40 ,z9 SURFACE 9 5 /8 8.679 0.0 4,203.0 2,874.3 40.00 L-80 PRODUCTION 7 G.151 0.0 10.fi76.0 6.084.2 26.00 L-80 NPPLE s,o Tubin Strin s Tub/ Des on Stnr9g O Iln) D Slnng ID Iinl To 8 Se[ Depth (ItK6) Set Depth (ND) (NCB) Slrfr9g Wt IltrvRl S[drg tratle Std T mrd TUBING 3 i /2 2.992 0.0 10,204.0 5,732.9 9.30 L-80 ABM-EUE Other I n Hole All Jewel :Tubin Run 8 Retrievable Fish etc. SAS LIFT z psi To B lop DepM (TVD) (NCB) Top hrd (") Des on Comment Rta9 Date ID In 510 509.8 3.86 N IPPLE Camco'DS' Landing NO GO 9/1/1995 2.812 suRFACP s 2,081 1,904.7 50.39 G AS LIFT CAMCO/MMNV1.5/GLV/RK/.188/1281/Comment: STA 1 7/28/2009 2.920 a do 4,896 3,191.5 58.42 G AS LIFT CAMCO/MMMI7.5/GLV/RK/.188/1267! Comment: STA 2 7/28/2009 2.920 6,706 4,007.6 63.54 G AS LIFT CAMCO/MMM/1.5/GLV/RKl.188/1253/ Comment: STA 3 7/27/2009 2.920 i,AS LIFT. 8,324 4,697.9 62.48 G AS LIFT CAMCO/MMM/1.5lGLV/RKl.25l1282/ Comment STA4 7/20/1998 2.920 a,as6 9,538 5,279.1 52.35 G AS LIFT CAMCO/MMM/1.5/GLV/RK/.188/1225/ Comment: STA 5 7/28/2009 2.920 10,124 5,673.7 44.81 G AS LIFT CAMCO/MMM/1.5/OV/RK/.25//Comment: STAG 7/312009 2.920 10,170 5,707.5 44.28 N IPPLE Camco'W-1' Selective Landing Nipple 9/7/1995 2.812 cA5 uF7, 6 7n6 10,177 5.712.7 44.20 A NCHOR Baker K-Anchor 9/1/1995 3.250 , 10.178 5.713.5 44.19 P ACKER Baker SA&3 Perm. 9!1!1995 3.250 10,193 5,724.7 44.02 N IPPLE Camco'D' Nipple NO GO 9/1/1995 2.750 10,204 5.732.9 43.90 S OS Baker 9/1/1995 2.992 oAS LIFE. 8 324 10.205 5,733.7 43.88 T TL ELMD@10198'per SWS PERF 9/17/1995 9/1/1995 2.992 10.470 5,927.1 40.87 FI SH 1 1/2"DV DROPPED 6/26/981N RAT HOLE 6/26/1998 0.000 Perforations & Slots GAS LIFT, 9 538 lop IRICB) Btm INB ToP (TVD) (RKB) Btm ITVD) (NCB) Zane Date Dera (sh... Comment , 10,298 10.306 5,803.7 5,809.2 Cam, 2T-30 7/5!1998 4.0 APERF 2.5" H.C. B.H., 180 deg ph, 90 deg. orient 10.298 10,306 5,803.7 5.809.2 C~4. 2T-30 7/72/1998 4.0 RPERF BH. 180 deg. ph. 90 deg. odent cASO1 y 10.349 10.369 5,839.4 5,853.7 A-3, 2T-30 9/17/1995 4.0 IPERF 2 1/8" EJ, 180 deg ph; oriented (+/-) 90 deg. bwside. 10,395 10.416 5,874.5 5,887.5 A-2, 2T-30 6/9/2002 6.0 APERF 2.5" PJ. 60 deg phase Notes: General & Safe End Date Amatatlon NIPPLE. 10,170 702/2009 NOTE: LDL FOUND LEAK @ 10.158' ELMD ANCHOR, m,m a u PACKER. ,0,17a NIPPLE 193 10 . . 505,10,209 TTL, 10,205 APERF, 10 29B-10,306 RPERF, , 0 29&10 306 IPERF, 10 3d&'10.369 APERF, 10 agft90 A i6 FISH, ,Oa70 PROWCTtON, 10,6]6 TU. 10 ti8ti ~ WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cutting Torch Record: 2T-30 Run Date: 4/3/2010 Apri19, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T-30 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20219-00 ~_ o PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETL;JRNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barret 1 ~~,~~; ~~~ Date: ~ ~~ 1 ~ ss3 Signed: • • Memory Multi-Finger Caliper LQg Results. summary Company: ConocoPhillips Alaska, Inc. Well: 2T-30 Log Date: April 10, 2010 Field: Kuparuk Log No.: 7834 State: Alaska Run No.: 1 API No.: 50-103-20219-00 Pipet Desc.: 7" 26 Ib. L-80 Top Log Intvl1.: Surfiace Pipet Use: Production Casing Bot. Log Intuit.: 10,136 Ft. (MD) Inspection Type : Buckling 8 Restriction Inspection COMMENTS ' This caliper data is correlated to Schlumberger WLD /CDR Log (May 7-12, 9995). This log was run to assess the condition of the 7" production casing. The caliper recordings indicate the 7" ' production casing logged is in good to fair condition with respect to corrosive and mechanical damage, with maximum wall penetration of 29% recorded in joint 225 (9,624') and joint 237 (10,120'), respectively. Recorded damage appears as apparent erosion. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the production casing logged. The caliper recordings indicate slight ' buckling from -80' #o -180', -370' to -400', and -890' to -920'. Log plots of the centered and off-center caliper recordings across the top 500' are included in this report. MAXIMUM RECORDED WALL PENETRATIONS: Apparent Erosion (29%) Jt. 225 @ 9,624 Ft. (MD) Apparent Erosion (29%) Jt. 237 @ 10,120 Ft. (MD) Apparent Erosion (29°~) Jt. 97 @ 4,172 Ft. (MD) Apparent Erosion (29°~) Jt. 172 @ 7,352 Ft. (MD) Apparent Erosion (29%) Jt. 173 @ 7,392 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 14%) are recorded throughout the production casing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions,are recorded throughout the production casing logged. Field Engineer: J. Halvorsen Analyst: HY. Yang Witness: R. Overstreet ProActive Diagnostic Services, Inc. J P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888} 565-9085 Fax: (281} 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907} 659-2314 • • PDS Multifinger Caliper 3D Log Plot s~, _ .~. Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2T-30 Date : April 10, 2010 Description : Detail of Centered Caliper Recordings Across Top 500' in 7" Casing • • PDS Mu(tifinger Caliper 3D Log Plot ,~ ~ ~~ Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2T-30 Date : April 10, 2010 Description : Detail of Off-Center Caliper Recordings Across Top 500' in 7" Casing Comments Depth Max. I.D. (ins.) 3-D Log (Off-Center) Image Map (Off-Center) 1ft:800ft 6 7 0° ~ 0° 90° 180° 270° 0° Min. I.D. (ins.) 6 7 Nominal I.D. (ins.) i ...................................................................t 6 7 ---- Joint 1 50 Joint 2 Slight Buckling 1 ~~ Joint 3 Slight Buckling 150 Joint 4 Slight Buckling i i 1 Joint 5 200 Joint 6 250 Joint 7 300 Joint 8 350 Joint 9 Slight Buckling '400 Joint 10 450 Joint 11 :;w_ *cs ...._. --- --~° ~ .. ~~ • Correlation of Recorded Damage to Borehole Profile Pipe 1 7. in (39.5' - 10122.7) Well: 2T-30 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: April 10, 2010 A pprox. Tool De viation ^ A pprox. Borehol e Profil e 1 25 39 1063 5U 2132 75 3198 100 4263 0 v ~ .~ z 125 5334 ~ c ~ °- °' o 150 6401 175 7475 200 I r ~ I 8538 225 .~ 9586 238 10123 0 5 0 1 00 Da mage Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 238 • PDS Report Overview ~:__~~,, Body Region Analysis Well: 2T-30 Survey Date: April 10, 2010 Field: Kuparuk Tool Type: UW MFC 40 No. 217957 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Analyst: _ HY. Yan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 7 ins 26 f L-80 6.276 ins 7 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body metal loss body 250 200 150 100 50 0 0 to 1 to 10 to 20 to 40 tb over 1 % 10%~ 20%, 40% 85% 85% Number of'oints anal sed total = 238 pene. 0 0 116 122 0 0 loss 0 218 20 0 0 0 Damage Configuration (body ) 250 200 150 100 50 0 isolated gener,~l line ring hole/pons pitting corrosion corrosion corrosion ible hole Number of'oints dama ed total = 238 0 238 0 0 0 Damage Profile (% wall) ~ penetration body metal loss body 0 50 100 1 51 101 151 201 Bottom of Survey = 238 Analysis Overview page 2 • PDS REPORT JOINT TABI. Pipe: 7. in 26.0 ppf L-80 Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: • iLATION SHEET 2T-30 Kuparuk ConocoPhillips Alaska, Inc USA April 10, 2010 Joint No. Jt. Depth (Ft.) I'~~n. IJl~sc•t (In,.) Pen. Body (Ins.) Pen. % v1<•i•rl I+~s~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 1 39 U.f)(~ 0.06 17 lu 6. 8 2 77 ~ ~ 0.07 I ~) -1 6.22 Sli ht bucklin . 3 117 (? 0.05 1-~ ~ 6.22 Sli ht bucklin . 4 160 ~~ 0.07 1 ~) 6.25 Sli ht bucklin - 5 200 !~ 0.07 18 6.27 6 243 ~ ~ OA5 14 ti 6.28 7 287 I~ 0.05 1<1 ~ 6.27 8 330 It 0.05 I ~ is 6.28 9 373 U 0.06 i;; 6.27 Sli ht bucklin . 10 417 ~~ 0.05 i~ t~ 6.28 11 460 ~ ~ 0.07 1 ~l ~i 6.28 12 503 ~ ~ 0.05 i 4 t3 6.27 - 13 546 (1 0.05 1 i Y, 6.27 14 589 (1 0.06 1 ~ ~~~ 6.26 15 630 U 0.05 15 7 6.28 - 16 674 O 0.06 17 '~ 6.28 - 17 717 ll 0.06 1 i 8 6.28 18 761 tl 0.06 15 t~ 6.24 - 19 803 t) 0.06 15 i ~ ~ 6.29 20 847 U 0.05 14 is 6.27 21 890 ~~ 0.06 17 ~' 6.26 Sli ht bucklin . 22 934 U 0.05 I -k ~ i 6.2 7 23 978 U 0.05 1 i (~ 6.25 24 1020 t) 0.06 1 S ~ 6.27 25 1063 i ~ 0.05 ! 4 t; 6.28 26 1105 ~ ~ 0.05 14 €s 6.28 27 1146 U 0.06 17 + 6.23 28 1185 O 0.05 15 ti 6.27 29 1229 t~ 0.06 15 is 6.29 30 1272 it 0.06 1:> C 6.29 31 1316 t~ 0.06 1 ~ I U 6.29 32 1359 n 0.05 14 ~> 6.28 33 1402 t1 0.06 15 c; 6.26 34 1443 t~ 0.06 17 ri 6.27 35 1486 ri 0.05 14 ~ 6.23 36 152 7 n 0.06 16 I 1 6.31 37 1570 ~~ 0.06 1 i I Z 6.31 38 1614 U 0.07 18 12 6.31 39 1658 U 0.07 ZU 1t~ 6.27 40 1701 U 0.07 i~> 1O 6.29 41 1744 ~ ? 0.08 ~? i I ' 6.31 42 1788 ~ ~ 0.07 Its I I 6.30 43 1831 ~? 0.08 2 I Iii 6.30 44 1873 U 0.06 I t, I ~~ 6.30 45 1916 (~ 0.07 2i) I ~ 6.30 46 1960 U 0.08 ?2 12 6.30 47 2003 c? 0.08 2 I 1 ~ 6.31 48 2047 !) 0.08 Z1 lU 6.27 49 2090 ~ ~ 0.07 19 (~ 6.24 50 2132 U 0.07 19 tS 6.24 Penetration Body J Metal Loss Body Page 1 PDS REPORT JOINT TABI. Pipe: 7. in 26.0 ppf L-80 Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: • ELATION SHEET 2T-30 Ku paru k ConocoPhillips Alaska, Inc USA April 10, 2010 Joint No. Jt. Depth (Ft.) I'~~n. I Jlsct Ilns.j Pen. Body (Ins.) PE~n. °io ~~1~_~lal I ost °~~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 51 2174 t? 0.08 '~ l u 6.28 52 2216 U 0.08 Z 1 6.27 53 2256 O 0.06 17 <t 6.25 54 2298 i~ 0.07 1~) li? 6.28 55 2340 i ~ 0.07 ZU `~ 6.26 56 2384 t~ 0.07 Z(i _s 6.27 57 2426 ~ ~ 0.05 ! _t ~ ~ 6.23 - 58 2470 i ~ 0.07 'i ~ i ~ 6.26 - 59 2513 ii 0.07 (~ 6.27 60 2557 i ~ 0.08 ? l ~~~ 6.24 61 2600 i ~ 0.08 Z I £s 6.25 62 2642 ~.~ 0.06 17 '~ 6.27 - 63 2682 U 0.08 21 ~~ 6.27 - 64 2725 U 0.07 1 ti !~ 6.25 65 2769 i~ 0.09 24 5 6.25 A arenterosion. 66 281 1 i ~ 0.09 24 ~) 6.24 67 2853 t~ 0.08 Z1 7 6.25 68 2896 t~ 0.07 2tl - 6.25 69 2939 O 0.08 21 - 6.24 70 298 U 0.06 1? - 6.27 71 3026 (? 0.09 _' i ~ i ~ 6.27 A arenterosion. 72 3068 i) 0.07 _'ti - 6.20 Lt De osits. 73 31 1 1 (~ 0.09 Z~ is 6.28 A arent erosion. 74 3154 tt 0.07 I £3 ~ ~ 6.27 ~~ 75 3198 i 1 0.07 ~l) (> 6.25 76 3241 to 0.08 L3 t; 6.25 77 3284 . ~ 0.06 1 ' r, 6.25 78 3328 ti 0.08 l1 i, 6.24 79 3371 ti 0.08 ZZ '~ 6.26 80 3415 ! ~ 0.08 ~ 1 !, 6.24 81 3457 t) 0.08 Z1 7 6.25 82 3498 11 0.09 l ~ (~ 6.24 83 3539 U 0.09 2 5 ~~ 6.26 A arenterosion. 84 3581 U 0.07 19 £3 6.26 85 3624 t) 0.08 21 (, 6.22 86 3665 t~ 0.06 15 6 6.25 87 3707 t~ 0.08 21 5 6.24 88 3750 U 0.07 1 ~) 7 6.26 89 3789 t) 0.07 18 7 6.25 90 3832 U 0.07 20 ~ 6.27 91 3875 U 0.09 _'4 '~ 6.25 A arenterosion. 92 3918 tl 0.08 '1 <> 6.25 93 3959 t> 0.09 ~d <s 6.26 94 4003 U 0.09 '6 ~l 6.27 A arenterosion. 95 4046 U 0.09 ~4 £i 6.26 96 4089 (t 0.08 Z? lt) .29 97 4133 (1 0.11 <<) 1 6.28 A arenterosion. 98 4176 U 0.09 l~1 ti 6.26 99 4219 li 0.08 ?1 ~~ 6.27 100 4263 t~ 0.10 '7 '~ 6.22 A arenterosion. - _ Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABI. Pipe: 7. in 26.0 ppf L-80 Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: iLATION SHEET 2T-30 Kuparuk ConocoPhillips Alaska, Inc USA April 10, 2010 Joint No. Jt. Depth (Ft.) I'~•n. Ul~sc~i (Ins.j Pen. Body (Ins.) Pen. °i~ a1c~t,?I lass °,~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 101 4304 !) 0.09 24 6 6.23 A arenterosion. 102 4347 l) 0.07 1 £3 t1 6.28 103 4389 (1 0.07 l q ~) 6.27 104 4432 t! 0.08 21 ~~ 6.27 105 4475 a 0.07 1 ~) ~ 6.28 106 4512 (? 0.07 i ~> i ~,? 6.24 107 4556 U 0.10 :_; ~? 6.27 A arenterosion. 108 4598 t) 0.09 2~ i~ 6.26 109 4641 ~) 0.08 '1 6.28 110 4685 (1 0.08 21 1i) 6.29 111 4728 t! 0.07 20 ~) 6.27 112 4772 (? 0.08 >2 ii) 6.27 113 4815 a 0.08 2 i ~~ 6.27 114 4858 i) 0.08 ~3 F.~ 6.25 - 115 4901 O 0.08 Z2 t> 6.27 116 4945 t) 0.08 2 3 ~) 6.27 117 4988 (a 0.07 Zl) ,f 6.26 - 118 5031 t) 0.08 11 f i 6.29 119 5073 t) 0.09 2.1 I~) 6.28 A arenterosion. 120 51 16 U 0.06 17 I U 6.29 121 5160 a 0.07 19 ._ 6. 5 122 5203 tt 0.09 24 1 U 6.30 A arenterosion. 123 5247 t) 0.08 '' i_' 6.31 124 5291 (? 0.08 ~1 li) 6.28 125 5334 U 0.08 21 I i 6.30 126 5378 s) 0.08 1 ~ It) 6.28 127 5422 t? 0.09 ~' ~ ? 6.28 A arenterosion. 128 5465 t? 0.09 15 ~~ 6.27 A arenterosion. 129 5509 !? 0.08 ?1 '? 6.28 - 130 5552 t? 0.09 24 i i? 6.29 131 5595 t? 0.09 Z4 ~) 6.28 A arenterosion. 132 5639 c1 0.08 z2 6.24 - 133 5679 t) 0.09 ~'-t 6.28 A arenterosion. 134 5722 tt 0.08 ~' 1 '; 6.28 135 5766 U 0.09 24 ~! 6.27 A arenterosion. 136 5810 n 0.08 Z"i It) 6.26 137 5853 i) 0.08 ~ ~ 6.28 138 5897 n 0.06 1;" !, 6.24 - 139 5937 +? 0.06 17 ~ 6.25 - 140 5977 ;i 0.09 ~~~ l;~ 6.27 A arenterosion. 141 6020 tt 0.07 2t) IU 6.28 142 6060 t) 0.09 24 ii) 6.28 A arenterosion. 143 6103 tl 0.08 22 I(1 6.29 144 6145 tl 0.07 1 <i ~? 6.29 145 6188 (1 0.08 l2 I'? 6.27 146 6232 t) 0.08 22 !±? 6.27 147 6275 t) 0.09 25 6.25 A arenterosion. 148 6318 U 0.07 20 '? 6.27 149 6358 t? 0.07 :'i) 6.27 150 6401 U 0.08 « 6.27 _ Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINT TABI.. Pipe: 7. in 26.0 ppf L-80 Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: i iLATION SHEET 2-r-3o Kuparuk ConocoPhillips Alaska, Inc. USA April 10, 2010 Joint No. Jt. Depth (Ft.) Pcn. Upse£ (Ins.) Pen. Body (Ins.) Pen. % :Vlctal loss %~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 151 6445 O 0.09 24 ~) 6.25 A arenterosion. 152 6488 (1 0.06 1 S ~? 6.29 153 6531 r~ 0.07 21 C, 6.25 154 6574 (? 0.09 ~4 £3 6.24 A arenterosion. 155 6617 !) 0.07 ZO - 6.24 156 6660 a 0.07 1 ~) 6.26 157 6703 a 0.09 ~' i I ~ ~ 6.28 A arenterosion. 158 6747 U 0.07 ~'(~ ~~ 6.28 159 6790 t) 0.09 ~5 7 6.25 A arenterosion. 160 6831 U 0.07 19 6.25 161 6872 I) 0.08 23 ~) 6.26 162 6915 U 0.07 18 is 6.27 163 6959 U 0.09 ~'4 6.26 A arenterosion. 164 7001 U 0.07 19 (~ 6.25 165 7044 U 0.09 25 1t) 6.27 A arenterosion. 166 7088 t) 0.09 ~5 tt 6.26 A arenterosion. 167 7130 U 0.10 1Y, Itt 6.27 A arenterosion. 168 7173 U 0.08 ~~ ; ~~ 6.24 169 7217 t) 0.09 15 ~~ 6.22 170 7259 U 0.10 17 I u 6.25 A arenterosion. 171 7303 t~ 0.08 Z1 ~~ 6.26 172 7347 (~ 0.11 Z9 7 6.21 A arenterosion. 173 7390 (1 0.10 2f3 (~ 6.22 A arenterosion. 174 7432 U 0.09 24 £3 6.25 175 7475 (~ 0.08 > ~) £) 6.23 176 7519 U 0.08 ' n 6.23 177 7562 t) 0.09 ~~ £> 6.25 178 7605 t) 0.10 28 I t~ 6.27 A arenterosion. 179 7648 (~ 0.09 l4 (> 6.23 180 7690 t) 0.07 20 (~ 625 181 7733 i) 0.07 18 ~ 6.25 182 7776 n 0.06 17 £3 6.23 183 7819 (a 0.10 Z 7 t3 6.24 A arenterosion. 184 7862 U 0.07 2O £i 6.22 185 7905 U 0.08 > t (~ 6.20 186 7947 t ~ 0.06 15 <I 6.20 187 7989 U 0.06 1 E, ~~ 6.18 188 8032 ~) 0.06 I i> - 6.24 189 8075 a 0.06 17 4 6.23 190 8116 tt 0.07 Z 1 i 6.22 191 8158 U 0.06 1(~ t: 6.25 192 8202 a 0.07 ZU - 6.24 193 8244 ti 0.08 12 'i 6.25 194 8287 O 0.08 2Z ~> 6.24 195 8330 t ~ D.OS Z t I ~' 6.25 196 8373 i? 0.07 1 £3 6.23 197 8414 l~ 0.05 14 P; 6.26 198 8457 i) 0.09 ~~ " 6.25 199 8498 t? 0.09 24 6.23 A arenterosion. 200 8538 O 0.07 19 ~> 6.25 _ Penetration Body Metal Loss Body Page 4 • PDS REPORT JOINT TABI. Pipe: 7. in 26.0 ppf L-80 Well: Body Wall: 0.362 in Fie-d: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: ILATION SHEET 2T-30 Kuparuk ConocoPhillips Alaska, Inc USA April 10, 2010 Joint No. Jt. Depth (Ft) f'e'n. Upset (Ins.) Pen. Body (Ins.) Pen. % Utc~t,~l Loss ",'~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 201 8581 U 0.08 22 - 6.25 - 202 8623 ~t 0.09 24 lil 6.21 A arenterosion. 203 8665 U 0.06 16 t3 6.25 204 8707 tt 0.07 1 £~ 8 6.25 205 8748 (> 0.06 t ,' £~ 6.25 206 8791 U 0.06 1 => ~; 6.26 207 8831 ~) 0.05 L3 (, 6.22 208 8871 U 0.06 1' £> 6.27 209 8913 U 0.07 l r3 ~~ 6.27 210 8954 U 0.06 16 7 6.25 211 8995 t) 0.07 18 1(1 6.28 212 9038 U 0.07 1 ~> f9 6.26 213 9078 t) 0.07 2U '> 6.28 214 9120 O 0.07 18 £3 6.25 215 9163 c) 0.08 ~3 £5 6.20 _ 216 9204 t) 0.07 1 ~) I U 6.28 217 9246 U 0.07 i ~) 6.27 218 9289 U 0.07 1 ~) 1 tt 6.26 219 9331 0 0.09 ~'4 iS 6.27 A arenterosion. 220 9374 It 0.09 24 f tt 6.25 221 9417 t) 0.08 Z 1 £i 6.25 222 9459 U 0.08 22 Ill 6.29 223 9503 U 0.10 17 ! 1 6.26 A arenterosion. 224 9544 (t 0.09 ~4 lt) .28 225 9586 U 0.11 ~~t I a 6.29 A arenterosion. 226 9628 i t 0.08 ~? l l 6.28 227 9669 U 0.09 '4 7 "3 6.30 228 9713 t1 0.09 Z5 1 1 6.29 A arenterosion. 229 9751 a 0.08 23 I ~ 6.29 230 9793 ~! 0.10 Z7 I_' 6.27 A arenterosion. 231 9831 n 0.07 19 1(! 6.27 232 9872 U 0.08 ? 1 ~~ 6.26 233 9914 U 0.09 ~4 ~~ 6.27 A arenterosion. 234 9954 i> 0.08 ~' 3 Ii) 6.27 235 9996 t? 0.07 ~'t) I{~ 6.27 - 236 10039 U 0.09 25 It) 6.27 A arenterosion. 237 10082 tt 0.11 29 ~i 6.23 A arenterosion. 238 10123 tt 0.10 28 ~1 6.15 A arenterosion. I_t. De osits. _ Penetration Body Metal Loss Body Page 5 PDS Report Cross Sections ~ ~ Well: 2T-30 Survey Date: April 10, 2010 Field: Kuparuk Tool Type: UW MFC 40 No. 217957 Company: Conoco Phillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 7 ins 26 f L-80 Anal st: HY. Yan Cross Section for Joint 225 at depth 9623.88 ft Tool speed = 43 Nominal ID = 6.276 Nominal OD = 7.000 Remaining wall area = 88 Tool deviation = 60 ° Finger 5 Penetration = 0.106 ins Apparent Erosion 0.11 ins = 29% Wall Penetration HIGH SIDE = UP • Cross Sections page 1 ~5.. Well: Field: Company: Country: 2T-30 Kuparuk Conoco Phillips Alaska, Inc. USA Survey Date: April 10, 2010 Tool Type: UW MFC 40 No. 217957 Tool Size: 2.75 No. of Fingers: 40 Analyst: HY. Yang Cross Section for Joint 237 Tool speed = 43 Nominal ID = 6.276 Nominal OD = 7.000 Remaining wall area = 92 Tool deviation = 50 ° PDS Report Cross Sections at depth 10120.08 ft ~J • Finger 5 Penetration = 0.106 ins Apparent Erosion 0.11 ins = 29% Wall Penetration HIGH SIDE = UP Cross Sections page 2 ~\ ~ KUP ~ 2T-30 ConoeoPhilli ps a Amibutes An le 8 f1AD Tn AI'I~'-'~'~ '~~ Wellbore APYNWI Fleld Name W 1 Status Ind (') ND (RKB) 501032021900 KU PARUK RIVER UNIT PRODUCING 65.65 5405.31 Act Btm (RIB) 10,686.0 omment H2S (ppm) to S.SSV: NIPPLE 100 1/11/2009 Amotatlon Lass WO: End ate KB-Drd (R) RIg Release Date 5/13!1995 ax ova - - 0 1 t z o9-'ss of ~ rn ~--- me c -A ual Amotetlan Depm pUB) 6ttl Date Amotallan last Sbd By End Date last Tag: RKB 10,330.0 5!32009 Rev Reason: LDL found leak @ 10,158' ELMD hnosbor 10110!2009 Casio Strin s q k ~ Casmg cescrlpuon stung Do Pn) stung to Pn) rop ptlc~ sot Depth (~B) set Deem (lv) (RKB) string wt Pbsttq smug 67atle semy rop mra CoNDDrTOR, CONDUCTOR 16 15.062 0.0 121.0 121.0 62.58 H-40 121 " i SURFACE 9 5B 8.679 0.0 4,203.0 2.874.3 40.00 L-80 ii PRODUCTION 7 6.151 0.0 10.676.0 6,084.2 26.00 L-80 wPP~E s,6 Tubin Strin s , rua cesM on stung DD PM smog ID On) r B set cepm IRKS) see cepm ItvD) IM(B) staktg wt pbsRry siring crane std r mm TUBING 31/2 2.992 0.0 10,204.0 5,732.9 9.30 L-80 ABM-EUE Other I n Hole A ll Jewel : Tubin Run 8 Retrievable Fish etc. GAS UFT. 2 oe1 To B Top epm (T11D) l~Bl Top Inc! (') Des on Comment Rrn Die ID n 510 509.8 3.86 NIPPLE Camco'DS' Landing NO GO 9!1/1995 2.812 SURFACE. 2,081 1,904.7 50.39 GAS LIFT CAMCO MM/1.5/GLV/RK/.188/1281/Comment: STA 1 7/282009 2.920 a.263 4,896 3,191.5 58.42 GAS LIFT CAMCO/MMM/1.5lGLV/RK/.188/1267/Comment: STA2 7/28/2009 2.920 6,706 4,001.6 63.54 GAS LIFT CAMCO/MMM/1.5/GLV/RK/.188/1253! Comment: STA 3 727/2009 2.920 cos uFr, 8.324 4,697.9 02.48 GAS LIFT CAMCO/MMNV1.5/GLV/RK1.25/1282/ Comment: STA 4 720/1998 2.920 a.a9s 9,538 5,279.1 52.35 GAS LIFT CAMCO/MMM/1.5/GLV/RK/.188/1225/ Comment: STA 5 7/282009 2.920 10,124 5,673.7 44.81 GAS LIFT CAMCO/MMM/1.5/OV/RKl.25// Comment: STA 6 7/312009 2.920 10,170 5,707.5 44.28 NIPPLE Camco'W-1'Selective Landing Nipple 9/1/1995 2.812 cAS LII r s 10,177 5,712.7 44.20 ANCHOR Baker K-Mchor 9/1/1995 3.250 6,]o 10.178 5,713.5 44.19 PACKER Baker SAB-3 Perm. 9/1!1995 3.250 10,193 5,724.7 44.02 NIPPLE Camoo'D' Nipple NO GO 9/1/1995 2.750 10,204 5,732.9 43.90 SOS Baker 9/1/1995 2.992 cos uFr. B 324 10,205 5,733.7 43.88 TTL ELMD @ 10198' per SWS PERF 9!17/1995 9/1/1995 2.992 10 470 5,927.1 40.87 FISH 1 12"DV DROPPED 026l981N RAT HOLE 626/1998 0.000 Perforations 8 Slots GAS LIFT. 9s3s TOP IRK Blm (RKB Top ITVD) IRKB) etm (Tw) (RKB) Zone Date sna Dens (sh... CommerR 10,298 10,306 5,803.7 5,809.2 C am, 2T-30 7/5/1998 4.0 APERF 2.5" H.C. B.H., 180 deg ph, 90 deg. orient 10298 10.306 5,803.7 5,809.2 C -0, 2T-30 7/12/1998 4.0 RPERF BH, 180 deg. ph, 90 deg. orient G~iol Z 10,349 10,369 5,839.4 5.853.7 A -3. 2T-30 9/17/1995 4.0 IPERF 2 1/8" EJ, 180 deg ph; oriented (+/-) 90 deg. bwside. 10.398 10 416 5.874.5 5,887.5 A -2, 2T-30 6/9/2002 6.0 APERF 25" PJ, 60 deg phase Notes: General 8 Safe Fsd Date Amo[atlan NIPPLE, 10,1]0 102/2009 NOTE: LOL FOUND LEAK @ 10,158' ELMD ANCHOR, 101]] as as PACKER. 101]8 NIPPLE 10 183 . . sos zo ~ , l9, a ra.1°.z°s PPERF, 10,298-10,308 RPERF 10,298-10,306 IPERF, 10,34310,369 APERF, 10 398-10 416 FISH, 10470 PRODUCTION, 10,676 TD, 10,686 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, April 07, 2010 4:40 PM To: 'Nelson, Erik Q' Subject: RE: PBTD#195-0570 Sundry Request Submittal... ,~--.__ Thanks for the reply.... I will make the noted changes in the wellfile copy of our procedure. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) F~,~xA ~~ ~.~~l~d f ~ ~~ .i a From: Nelson, Erik Q [mailto:Erik.Nelson@conocophillips.com] Sent: Tuesday, April 06, 2010 3:22 PM To: Schwartz, Guy L (DOA) Subject: RE: PBTD#195-0570 Sundry Request Submittal... Guy, Page 1 of 3 My apologies for the delay in getting back to you. I spoke with the rest of the ConocoPhillips RWO team and reiterated the AOGCC's desire for a proper review time consisting of 10 - 14 days. I shoulder the responsibility for the delay in my submittal of the Sundry for 2T-30 (PTD #195-0570). Our group learned some lessons from the first subsidence RWO of 2A-16 and some lessons were realized again during the RWO of 2A-12. In my attempts to provide the mast up-to-date and accurate information in my Sundry Request I delayed it's submittal to the AOGCC. In addition, the rig was progressing rapidly through the 2A-12 RWO and looked to finish up at the end of last week. As it turns out though, 2A-12 decided to throw a few curve balls our way and progress slowed resulting in the completion of the RWO probably being tomorrow, 07 April 2010. Our group is in full agreement that we will strive to get our Sundry Requests to you in a timely manner and I, personally, apologize for any inconvenience it may have caused. Regarding the 2T-30 Sundry Request there are two inaccuracies that I thought need to be brought to your attention: • Upon further review it seems that I made a mistake in step #7 of the General Workover Procedure. I stated that we would PT the 11" 5M BOPE after nippling it up to the 11" 3M casing head. Upon further review I realized will be unable to perform this pressure test due to the fact we suspect the 9-5/8" surface casing to be compromised at ~ 228 ft MD. Thus the 11" 5M BOPE will be utilized as a diverter stack as previously discussed. • Also, in step #15 it is stated that we will pump 50% excess cement into the 9-5/8" x 7" annulus. In review of the previous RWO mentioned above we have decided to bump this to 100% excess which will raise the estimated volume from the previously stated ~ 89 bbls to ~ 112 bbls. Please let me know if you need anything from me regarding these changes or if you have other questions and/or comments. Erik Erik Q. Nelson ~iorkover~Wells Engineer ConocoPhillips Alaska, Inc. 4/7/2010 Page 2 of 3 office # i s9o 700 G. Street Anchorage, AK 99501 Office (907) 263 - 4693 Fax (907) 265 - I535 Cell (907) 903 - 7407 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, April 01, 2010 4:37 PM To: Nelson, Erik Q Subject: RE: PBTD#195-0570 Sundry Request Submittal.., Erik, Please remember, normally at least 10-14 days is needed to review and approve Sundries. Could you make sure the remaining subsidence Workover Sundries are submitted in a timely manner. Additionally, could you send me an email explaining the close timing on this sundry. I know you mentioned the preceding Workover was going better than expected. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Nelson, Erik Q [mailto:Erik.Nelson@conocophillips.com] Sent: Tuesday, March 30, 2010 2:04 PM To: Schwartz, Guy L (DOA) Subject: PBTD#195-0570 Sundry Request Submittal... Mr. Schwartz, I just hand delivered and dropped off the Sundry Request for the upcoming RWO of 2T-30 (PTD#195-0570). I just wanted to make sure that you got it and let you know that 1 am available for any questions pertaining to the documentation. Any expediency you could afford me would be much appreciated as the current RWO is going quite well. Thank you very much for your time and please let me know if you have any questions and/or comments. Also, attached is a copy of the documentation submitted this afternoon. Erik Nelson Erik Q Nelson Workover/Wells Engineer ConocoPhillips Alaska, Inc. Office #I590 700 G. Street Anchorage, AK 99501 Office (907) 263 - 4693 Fax (907) 265 - I535 Cell (907) 903 - 7407 4/7/2010 • • ~~Q~~ 00 ~ p~Q~~Q /,E,...w.E..~o~..~ Erik Q. Nelson Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, 2T-30 Sundry Number: 310-095 Dear Mr. Nelson: ay. ~~~ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~„ Chair S DATED this ~ day of April, 2010. Encl. • • • • IConocoPh i I I ~ ps Alaska R.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 RECEIVED MAR302010 ~Ska0B8Ga~~, ~d~aage 29 March, 2010 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7'h Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: r ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 2T-30 (PTD 195-0570). 2T-30 was originally completed in September of 1995. The well is a gas lifted producer that failed a'tubing integrity/fluid-level (TIFL) test in July of 2009. AOGCC was notified that this failure may be due to a leaking gas lift valve and that the well would be repaired or shut-in by 16 August, 2009. All gas lift valves were replaced but the well failed another TIFL on 07 August, 2009. The well was shut-in at this time and further diagnostic tests reveal the leak to be somewhere near the packer. Numerous combined mechanical integrity tests (CMIT) have also failed since the shut-in. Additionally, the well is in an area with surface subsidence due to permafrost thawing. ConocoPhillips plans to take proactive measures to mitigate future potential subsidence related ~ problems. The purpose of this workover is to repair the tubing leak, cut & pull a portion of the 7" casing, re- run new 7" casing, and circulate cement into the 9-5/8"x7" annulus. New 3-1/2" L-80 tubing along with a stack packer will be run into the well to repair the tubing leak. Ifi you have any questions or require any further information, please contact me at 263-4693. Y. rik Q. Nelson tells Engineer PAI Drilling and Wells l STATE OF ALASKA ~~'~ bC~ 1 ALF~ OIL AND GAS CONSERVATION COMMISSION. APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ~ Rug for Redrill '~", Perforate New Pool Repair w ell ~ Change Approved Program ~~~t. )~ Time Extension r"' Suspend ~ Rug Perforations ~ Perforate "~" Pull Tubing ~ " f Operational Shutdow n ~ Re-enter Susp. Well ~""" " Stimulate Alter casing ~ O Cher: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. ConocoPhillips Alaska, Inc. Development ,~ Exploratory ~" 195-0570 ' 3. Address: Stratigraphic ~ Service 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50-103-20219-00 7. If pertorating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes No ' 2T-30 9. Property Designation: 10. Field/Pool(s): - ADL0025548 Kuparuk River Field / Kuparuk Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 10686 6092 Casing Length Size MD ND Burst Collapse CONDUCTOR 121 16 121' SURFACE 4203 9.625 4203' PRODUCTION 10676 7 10676' Pertoration Depth MD (ft): Pertoration Depth ND (ft): Tubing Size; Tubing Grade: Tubing MD (ft): 1 ,298 - 10,306; 10349 - 10416 5803 - 5809; 5839 - 5888 3.5 L-80 10204 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) NIPPLE - CAMCO 'DS' LANDING NO GO MD= 510 ND= 510 CATCHER - 2.71"X87.5" CATCHER SET ON PLUG MD= 10163 ND= 5700 NIPPLE - CAMCO'W-1' SELECTIVE LANDING NIPPLE MD= 10170 ND= 5705 PLUG - 2.81" MA-2 PLUG MD= 10170 ND= 5705 ANCHOR -BAKER K-ANCHOR MD= 10177 ND= 5710 PACKER -BAKER SAB-3 PERM. MD= 10178 ND= 5711 NIPPLE - CAMCO 'D' NIPPLE NO GO MD= 10193 ND= 5722 PLUG - 2.75" CA-2 PLUG MD= 10193 ND= 5722 SOS -BAKER MD= 10204 ND= 5730 TTL - ELMD @ 10198' PER SWS PERF 9/17/1995 MD= 10205 ND= 5730 12. Attachments: Description Summary of Proposal ~', 13. Well Class after proposed work: Detailed Operations Program BOP Sketch ~~ E~loratory Development Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/2/2010 Oil Gas ~ WDSPL Plugged 16. Verbal Approval: Date: 11MNJ ~ GINJ "~`" WAG r Abandoned Commission Representative: GSTOR SPLUG I 17. I hereby certify that the f egoing is true an ect to the best of my knowledge: Contact: Erik O. Nelson Printed Name c Nels n Title: Wells Engineer ~ //~ // Signature ~ Phone: 263-4693 Date ~/ ~'/L(~ zLi( Sundry Number:~lo ! - // t . Conditions of approval: Notify Commission so that a representative may witness Plug Integrity BOP Test Mechanical Integrity Test ~" Location Clearance ~ 3~r~ ~s~ /3~P ~.~~~- Other . ~' ZSoo Pry ~4 ~ w~.,~~.-~ Ts ~ ~'~) Subsequent Form Required: / A*~ LJ APPROVED BY ~ ~~~ ~~ A t COMMISSIONER THE COMMISSION Date: Approved b ~i7.~ ~ ~ ~ ~r /L3 3 . ~,~C~MS APR 0 2 1010 Form 10-403 Revised 12/2009 ~ c~~~ Submit in ~~d OR~Gi~AL • • 2T-30 General Workover Procedure 29 March, 2010 1 Install 2.85" CA-2 plug in Camco `D' nipple at 10,193 ft RKB. Set catcher sub on top of CA-2 plug. Bleed Tbg and IA to zero and monitor. Pull GLV's at 2081 ft RKB, 4896 ft RKB, 6706 ft RKB, 8324 ft RKB, and 9538 ft RKB. Replace with DV's. Pull DV at 10,124 ft RKB and leave pocket open. Cut tubing at ~ 10,153 ft RKB (middle of first full joint above Baker K-Anchor). Load well with 9.6 ppg brine. Set BPV. 2. MIRU Nordic 3. S~-~ J~41~,L~~4 a~u~ 3. •RatF~i/. Verify well is dead. ND tree. NU 11" 5M BOPE. Pressure test BOPE including annular to 250/3000 psi. Maximum potential surface pressure is estimated at 1956 psi based on SBHP of 2540 psi @ 10,350' MD (5836' TVD) recorded on 23 November, 2006. Latest SITP before tubing plugs were installed was 250 psi on 19 July, 2009. The FMC Gen IV casing head maximum working pressure is 3000 psi. Anew MPSP will be calculated after obtaining the SBHP during pre-rig work as. 4. Pull blanking plug .Circulate hole clean. TOOH laying down tubing. 5. RU E-Line. Run caliper log, gyro survey, and cement bond log in 7" casing from tubing stub to surface. RD E-Line. 6. Set retrievable bridge plug below top of cement. Pressure test to 3000 psi and drawdown test to 0 psi. Dump sand on top of RBP. 7: ND BOPE and tubing head. Re-land 7" casing in tension. NU 11" 5M BOPE on 11" 3M casing head. Remove casing packoffs and slips. PT break to 3000 psi. 8. Cut 7" casing with multi-string cutter on drill pipe above TOC. Circ 9-5/8" x 7" annulus clean. 9. Spear and POOH laying down 7" casing. 4- 'ti'-ZZ~ `n..~(C 4 10. Run 9-5/8" casing scraper to top of 7" stub. Circ clean. 11. RU E-Line. Run caliper log and gyro survey in 9-5/8" casing. RD E-Line. 12. Run back off tool and back off casing stub. 13. Spear and recover casing stub. 14. TIH with new 7" casing and Halliburton ES cementer. Screw into top of 7" casing. Pressure test casing to 2500 psi. 15. Open ES cementer and pump cement (estimated 89 bbls includes 50% excess) into 9-5/8" x 7" annulus. Squeeze remaining cement into surface casing leaks after obtaining cement circulation to surface. Close cementer. 16. WOC. ND BOPE and land 7" on slips. Cut 7" casing and install packoff. NU tubing head. 17. NU 11" 5M BOPE and test break to 3000 psi. 18. Drill out cement and plug. Pressure test casing to 3000 psi. 19. TIH with wash shoe and circulate out sand on top of RBP. TOOH. TIH w/ retrieving tool on work string. Release RBP and TOOH. 20. TIH with poorboy overshot, packer, and PBR on 3-1 /2" drill pipe. Go over tubing stub. Circ in corrosion inhibited fluid. Set packer. TOOH laying down drill pipe. 21. TIH with new 3-1/2" tubing and seal assembly. Load tubing and IA with corrosion inhibited seawater. Stab into PBR and space out. Pressure test tubing and IA to 3000 psi. Shear SOV. 22. Set 2-way check. ND BOPE. NU tree and pressure test tree and packoffs to 250/5000 psi. 23. Pull 2-way check. Freeze protect well. Set BPV. 24. RDMO Nordic 3. 25. Pull ball and rod. Pull RHC body. Pull SOV and run new gas lift design. Pull catcher sub. ~gVRP. Tag fill 26. Return well to production. N~gsP ,q,~ ~ Pe Gl~ i >'oc~~ Zzzr~=~ a.3r-rv WELL LOG TRANSMITTAL To: Alaska Oil and G s Conservation Comm. March 17, 2010 Attn.: Christine ahnken 333 West 7th Av nue, Suite 100 Anchorage, Alas a 99501 RE: Cement Bond Lo : 2T-30 Run Date: 3/13/2 10 The technical data listed elow is being submitted herewith. Please address any problems or concerns to the attention Rafael Barreto, Halliburtc~n Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T-30 Data in LAS format, 50-103-2021 Cement Bond Log 50-103-20219-00 Log Image files 1 CD Rom 1 Color Log ~~~~~ AFr~ ~ ~ ~~J 6 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-353 rafael.barreto@ha a ~--~ MAR ~ 3 2Q1Q Date: ~s R ~ ?,~ t r l~~' ~~ i ,l ~ ~l~'S P. Signed: !TELL LQG S TRAlVS~49lFTA! PrtoAcrive Diaglvosric SErtv~s, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing fnspection(Caliper/ MTTj The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C j4~!. ;~.,:~ t'L .~ Anchorage, AK 99518 Fax: (907) 245-8952 1 j Leak Detection - WLD 30-0ct-09 2) 19 ~ - OS 2T-00 r9r5~( Signed Print Name: EDE 50-029-20219-00 C J j r Date : ~~ ~~~~~~ ~~' PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : ~- -- - ~ __ - ---- WEBSITE „-' - - -- ---- C:'~DocumenLs and Settings~Diane Williams\Desktop`.Transmit_Conoco.docx WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 6, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detection Log: 2T -30 Run Date: 10/10/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T -30 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -103- 20219 -00 t fi NO Y 2 7 200S PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline Perforating Attn: Rafael Barreto 5 �S 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 273 -3527 Fax: 907 273 -3535 rafael.barreto @halliburton.com. Date: NOV 6 2003 Signed: WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 4, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detection Log: 2T -30 Run Date: 10/2/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T -30 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20219-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 159'-6-3 Office: 907 273 -3527 Fax: 907 273 -3535 rafael.barreto @halliburtb b`.coi r Dater c Signed: w" 02/16/07 Schlumbel'gel' NO. 4142 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 A TTN: Beth 2 0 2007 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 (:fm1mi~i'ìiflfi SCANNED FEB 2 1 2007 /C)S=os? Field: Kuparuk Well Date Color CD BL Job# Log Description 1D-111, 11638816 INJECTION PROFILE 01/24/07 1 1H-19 . 11663824 INJECTION PROFILE 01/25/07 1 2T -30 . 11663825 PRODUCTION PROFILE 01/26/07 1 2K-02 11663829 PRODUCTION PROFILE 01/30/07 1 3J-02 11632653 INJECTION PROFILE 01/30/07 1 3J-08 11632657 INJECTION PROFILE 02/03/07 1 2M-OS 11632658 SBHP SURVEY 02/04/07 1 1A-19· 11632660 PRODUCTION PROFILE 02/05/07 1 3J-04 . 11628963 INJECTION PROFILE 02/08/07 1 1C-09 . 11638818 INJECTION PROFILE 02/09/07 1 2M-26 11638819 INJECTION PROFILE 02/10/07 1 1D-03 11628967 PRODUCTION PROFILE 02/11/07 1 1 C-20 N/A RSTIWFL 02/12/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ¡,If . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _XX Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 41 feet, 81' Pad 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchora~le, AK 99510-0360 Service__ Kuparuk Unit 4. Location of well at surface 8. Well number 4740' FNL, 4723' FEL, Sec. 1, T11 N, R8E , UM (asp's 498945, 5970518) 2T-30 At top of productive interval 9. Permit number / approval number 2256' FNL, 303' FEL, Sec. 35, T12N, R8E, UM 195-057 / At effective depth 10. APl number 50-103-20219 At total depth 11. Field / Pool 1996' FNL, 315' FEL, Sec. 35, T12N, R8E, UM (asp's 498069, 5978541) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 10686 feet Plugs (measured) true vertical 6092 feet Effective depth: measured 10441 feet Junk (measured) 1.5" DV in rathole true vertical 5904 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 80' 16" 255 sx AS 1 121' 121' SUR. CASING 4165' 9-5/8" 840 sx AS III & 670 sx Class G 4203' 2873' PROD. CASING 10638' 7" 224 sx Class G 10676' 6084' Perforation depth: measured 10298' - 10306', 10349' - 10369', 10398' - 10416' RECEIVED true vertical 5804'-5810', 5841'-5856', 5872'-5886' JUL 2 ~ 2002 Naska 0il & Gas Cons. C0mm~ssmr, Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 10204' MD. Anchorage Packers & SSSV (type & measured depth) BAKER SAB-3 PERM. @ 10178' MD. CAMCO 'DS' LANDING NO GO @ 510' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 641 1168 618 306 Subsequent to operation 621 1033 577 332 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ X Gas __ Suspended __ Service _Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mike Mooney 263-4574 Signed /~ff~~ Title: Wells Team Leader Date '~'/~: ~.~/~ ~_~. Michael Mooned, Prepared b~/ Sharon Al/sup. Drake 263-4612 ' G/ NED JUl_ 3 :[ 2002 ORIGINAL Form 10-404 Rev 06/15/88 · SUBMIT IN Date Comment 2T-30 Event History 06/01/02 06/06/02 06/08/02 06/09/02 PUMP 10 BBLS SW W/30 GALS OF WAW-5206 OF PRE-FLUSH: PUMP 20 BBLS OF SW W/110 GALS OF S0W-4004 OF TREATMENT: CHEMICAL COSTS: WAW-5206=$425 SCW-4004=$1023 [SCALE INHIBITOR] FCO COMPLETED, CLEANED DOWN TO 10508' CTM USING DIESEL W/N2 ASSIST. MAINTAINED 1.3 TO1 RETURNS DURING CLEANOUT. FREEZE PROTECTED TBG W/25 BBLS OF DIESEL. NOTE: WELL TO STAY SHUT IN FOR TAG & PERF JOB. [FCO] TAGGED FILL @ 10,441' RKB, DRIFTED W/13' OF 2.55" [TAG] SHOT 18 FT 2.51N 2506 POWER JET @ 6 SPF, 60 DEG PHASING, TOTAL OF 109 SHOTS (PENETRATION 25.21N, ENTRANCE 0.321N). PERF INTERVAL, 10398-10416FT, CORRELATED TO SWS PERF RECORD RAN 17 SEPT 1995--- RETURN WELL TO OPERATOR - RETURNED TO PRODUCTION. SCANNED JUL 3 1_ 2002 Page 1 of I 7/18/2002 PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 July 23, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite t00 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 2T-30 (195-057) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforation operations on the KRU well 2T-30. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Wells Team Leader Phillips Drilling MM/skad ORIGINAL SCANNED JUL :3 1 2002 RECEIVED JUL 2 4 2002 Naska Oil & Gas Cons. C0mmissio~ Anchorage THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ! ON OR BEFORE JANUARY 03 2001 M PL ATE, E IA L U N D W E R T H IS M A R K E R C:LORIkMFILM~ STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X__~. 41' RKB, 81' Pa( 3. Address: Exploratory__ 7. Unit or Property: P.O. Box 10036[] Stratagrapic__ Anchorage, AK 99510-0360 Service _ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 538' FSL, 556' FWL, Sec 1, T11 N, R8E, UM 2%30 At top of productive interval: 9. Permit number/approval number: 2256' FNL, 303' FEL, Sec 35, T12N, R8E, UM 95-57 Af effective depth: 10. APl number: 2053' FNL, 314' FEL, Sec 35, T12N, R8E, UM 50-103-20219-00 Af total depth: 1 I. Field/Pool: 1992' FNL, 316' FEL, Sec 35, T12N, R8E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 10686 feet Plugs (measured) None true vertical 6092 feet Effective Deptl measured 10589 feet Junk (measured) 1.5" DV in rathole true vertical 6017 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 255 Sx AS I 121' 121' Surface 4165' 9,625" 840 Sx AS III & 4203' 2873' 670 Sx Class G Production 10638' 7" 224 Sx Class G 10676' 6084' Liner Perforation Depth measured 10298'-10306'; 10349'-10369' true vertical 5804'-5810';5841'-5856' .~.l jr%/~//~//4L'/"~."_ Tubing (size, grade, and measured depth) 3.5", 9.3 Ib/ft, L-80 @ 10204' Packers and SSSV (type and measured depth) Pkr: Baker SAB-3 @ 10178'; SSSV: None, nipple @ 510' ''-: 13. Stimulation or cement squeeze summary [., ~ ~ -- -- ' Reperforate 'C' sands on 7/12/98. Intervals treated (measured) (.)~T Z "iz 10298'-10306' Treatment description including volumes used and final pressure n!~.~.q r!i[ ~. GEs 00,,s. Perforated using 2.5" HC guns w/BH charges @ 4spt, final pressure was 750 psi?''~m'~- 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1064 838 53 1082 240 Post fracs and perfs - both sands Subsequent to operation 1588 1076 154 1130 363 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _~X Oil X Gas Suspended Service 17. I hereby cedify that the foregoing is true and correct to the best of my knowledge. Signed ~/~----- Title: Production Engineering Supervisor Date f-~rr.~ 1~A~AI~,-,,~,/t'I~AI~q ~/GG ~',[ [l'~k ~lIT Ik[ I-~l li'~NI I~TI SUBMIT IN DUPLICATE ,., Alaska, Inc. ~-" KUPARUK RIVER UNIT ~[ ~ ."LL SERVICE REPORT ~ K1(2T-30(W4-6)) WELL JOB SCOPE JOB NUMBER 2T-30 FRAC, FRAC SUPPORT 0621982019.3 DATE DAILY WORK UNIT NUMBER 07/12/98 REPERFORATE "C" SAND DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 10 (~) Yes O NoI (~ Yes O No SWS-STEPHENSON SCHWEN~I'E.~AN FIELD AFC# CC# DAILY COST ACCUM COST S/i~l.n. ed/ ESTIMATE KD2314 230DS28TL $7,862 $307,003 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial/O~(erAnn I Final Ou~er Ann 700PSI 750PSI 130PSI 13oPs~I // 5oPs~I 5oPs~ DALLY SUMMARY RAN 2'1/2'' HC' 8' GUN' 4 SPF' 18° DEG PHASING' 9° DEG °REINT FROM LOW SIDE: TIE IN WITH SCHLUMBERGER PERFORATION CCL LOG DATED 7/4/98. REPERF F/10,298' - 10,306'. [Ped] TIME LOG ENTRY 13:30 MIRU SWS (STEPHENSON AND CREW) TGSM HEAVY OBJECTS. NOTIFIED PERSONNEL OF RADIO SILENCE. M PERF ASSEMBLY 8' HC 2-1/2" 4 SPF, BH, 180 DEG PHASING, 90 DEG ORIENT F/LOW SIDE. MPD, CCL, WT. TL 24'. PT LUB TO 3000 PSI. 15:30 RIH. TAG 10,328' RKB TIE IN WITH SCHLUMBERGER PERFORATING, CCL LOG DATED 7/4/98. REPERFORATED 7" LINER F/10,298' - 10,306' RKB. 2-1/2" HC,BH 4 SPF, 180 DEG PHASING, 90 DEG ORIENT F/LOW SIDE. GOOD SURFACE INDICATIONS. POH. 18:30 AT SURFACE RD. ALL SHOTS FIRED. RETURN WELL BACK TO DSO. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $1,130.00 APC $200.00 $38,950.00 DIESEL $0.00 $2,150.00 DOWELL $0.00 $221,923.64 DRILLEX $0.00 $892.00 HALLIBURTON $0.00 $11,700.00 LITTLE RED $500.00 $10,980.00 SCH LUM BERG ER $7,162.00 $19,277.50 TOTAL FIELD ESTIMATE $7,862100 $307,003.14 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate~X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 16. Datum of elavation (DF or KB feet): ARCO Alaska. Inc. Development X. 41' RKB, 81' Pad 3. Address: Exploratory ~. 7. Unit or Property: P.O. Box 100360 Stratagrapic Anchorage. AK 99510-0360 Service ~. Kuparuk River Unit 4. Location of well at surface: 8. Well number: 538' FSL, 556' FWL, Sec 1, T11N, R8E, UM 2T-30 At top of productive interval: 9. Permit number/approval number: 2256' FNL, 303' FEL, Sec 35, T12N, R8E, UM 95-57 At effective depth: 10. APl number: 2053' FNL, 314' FEL, Sec 35, T12N, R8E, UM 50-103-20219-00 At total depth: 11. Field/Pool: 1992' FNL, 316' FI=L, Sec 35, T12N, R8E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 10686 feet Plugs (measured) None true vertical 6092 feet Effective Deptt measured 10589 feet Junk (measured) 1.5" DV in rathole true vertical 6017 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 255 Sx AS I 121' 121' Surface 4165' 9.625" 840 Sx AS III & 4203' 2873' 670 Sx Class G Production 10638' 7" 224 Sx Class G 10676' 6084' Liner Perforation Depth measured 10298'-10306'; 10349'-10369' true vertical 5804'-5810'; 5841'-5856' 0F IGiNAL r'~ .*" ,,'", i-;; '"-' Tubing (size, grade, and measured depth) 3.5", 9.3 Ib/ft, L-80 @ 10204' Packers and SSSV (type and measured depth) "",$~:a ° r.'-,,--. CoDs, Co. rnrnissior~ Pkr: Baker SAB-3 @ 10178'; SSSV: None, nipple @ 510' .~J,~. ~ ~,. 0il et ~¢..-~ Anchorago 13. Stimulation or cement squeeze summary Fracture stimulate 'C' sands on 7/5/98. Intervals treated (measured) 10298'-10306' Treatment description including volumes used and final pressure Pumped 2124 lbs of 16/20 ceramic proppant into form., final pressure was 8000 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1064 838 53 1082 240 Post fracs and perfs - both sands Subsequent to operation 1588 1076 154 1130 363 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _~X Oil X Gas Suspended. Service 17. I here, b~certify that the foregoing is true and correct to the best of my knowledge. Signed/}'//'~i~ Title: Production Engineering Supervisor Date Form 10-404 ~i!¢v (J6/"l 5/88 St IRMIT IN iDI JPl I(":.ATF Alaska, Inc. --~' .KUPARUK'RIVER UNIT ~,~ ,.ELL SERVICE REPORT '~:~' K1 (2T-3Q(W~-6)) 2T-30 FRAC, FRAC SUPPORT 0621982019.3 DATE DAILY WORK UNIT NUMBER 07/05/98 "C" SAND FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPEJRVISOR 7 (~ Yes 0 NOI O Yes (~ No DS-GALLEGOS C_C.H~.~~ ESTIMATE KD2314 230DS28TL $49,243 $264,546 _ Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Out~r"Ann" [-Final Outer~,~-r"~- 175 PSI 500 PSI 50PSI 500 PSII 140 PSI ! /150 PSI DALLY SUMMARY "C" SAND FRAC SCREENED OUT AS 2# PPA SCOUR STAGE WAS GOING THRU PERF'S. NOTED VERY HIGH PERF FRICTION. INJECTED 2124 LBS OF PROP IN THE FORM W/2# PPA OF #20/40 @ THE PERF'S.MAXIMUM PRESSURE 8000 PSI & F.G. (.81). UNABLE TO FREEZE PROTECT TBG. [Frac-Refrac] TIME LOG ENTRY 08:30 MIRU DOWELL FRAC EQUIP, LRS HOT OIL UNIT, & APC VAC TRUCK. HELD SAFETY MEETING (15 PEOPLE ON LOCATION). 11:45 PT'D BACKSIDE LINES AND EQUIP TO 4000 PSI. RAISED INNER CSG AS REQUIRED. SET TREESAVER AND PT'D THE HIGH PRESSURE LINES TO 11800 PSI. 12:15 12:45 13:35 PUMP BREAKDOWN'W/20# GW & 50# DELAYED XL GW @ 25 TO 15 BPM. SLURRY VOLUME PUMPED 280 BBL5 MAXIMUM PRESSURE 7200 PSI AND ENDING PRESSURE 4300 PSI. STEPPED DOWN RATE AND S/D. OBTAINEE ISIP OF 2105 PSI W/F.G. @ (.81). PULSED TO DETERMINE CLOSURE. MONITORED WHTP. CLOSURE TIME 3.4 MINS @ 1690 PSI. PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. SLURRY VOLUME PUMPED 154 BBLS. MAXIMUM PRESSURE 4800 PSI & ENDING PRESSURE 4100 PSI. S/D AND OBTAINED ISIP OF 2371 PSI W/F.G. @ (.85). MONITORED WHTP FOR CLOSURE. CLOSURE TIME 2.93 MINS @ 2124 PSi. PAD VOLUME = 157 BBLS. PUMP ADDITIONAL SCOUR W/50# DELAYED XL GW @ 25 BPM. SCREENED OUT AS 2# PPA WAS GOING THRU PERF'S. NOTED VERY HIGH PERF FRICTION. SLURRY VOLUME PUMPED 172 BBLS. USED 3598 LBS OF 316/20 PROP. INJECTED 2124 LBS OF PROP IN THE FORMATION W/2# PPA OF #20/40 @ THE PERF'S. LEFT 1474 LBS OF PROP IN THE WELLBORE. ESTIMATE FILL TO BE @ 10268' Wt BHP OF 2200 PSI. UNABLE TO FREEZE PROTECT TBG. STARTED R/D. DEPRESSURED THE INNER CSG BACK TO 500 PSI AND R/D LRS HOT OIL UNIT. 14:00 15:00 REMOVED TREESAVER (ALL CUPS RETURNED). 16:00 RDMO DOWELL EQUIP. WELL SECURED AND NOTIFIED DSO OF STATUS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $1,110.00 APC $5,100.00 $31,900.00 DIESEL $300.00 $2,150.00 DOWELL $41,863.85 $207,423.64 DRILLEX $0.00 $892.00 HALLIBURTON $0.00 $11,031.00 LI'I-FLE RED $1,980.00 $10,040.00 TOTAL FIELD ESTIMATE $49,243.85 $264,546.64 I ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, inc. Development X~. 41' RKB, 81' Pa( 3. Address: Exploratory__ 7. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service _~. Kuparuk River Unit 4. Location of well at surface: 8. Well number: 538' FSL, 556' FWL, Sec 1, T11N, R8E, UM 2T-30 At top of productive interval: 9. Permit number/approval number: 2256' FNL, 303' FEE, Sec 35, T12N, R8E, UM 95-57 Af effective depth: 10. APl number: 2053' FNL, 314' FEL, Sec 35, T12N, R8E, UM 50-103-20219-00 Af total depth: 11. Field/Pool: 1992' FNL, 316' FEL, Sec 35, T12N, R8E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 10686 feet Plugs (measured) None true vertical 6092 feet Effective Deptt measured 10589 feet Junk (measured) 1.5" DV in rathole true vertical 6017 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 255 Sx AS I 121' 121' Surface 4165' 9.625" 840 Sx AS III & 4203' 2873' 670 Sx Class G Production 10638' 7" 224 Sx Class G 10676' 6084' Liner Perforation Depth . measured 10298'-10306'; 10349'-10369' true vertical 5804'-5810'; 5841'-5856' · Tubing (size, grade, and measured depth) 3.5", 9.3 Ib/ft, L-80 @ 10204' Packers and SSSV (type and measured depth) Pkr: Baker SAB-3 @ 10178'; SSSV: None, nipple @ 510' !$. Stimulation or cement squeeze summary Perforate 'C' sands on 7/4/98. Intervals treated (measured) 10298'-10306' : Treatment description including volumes used and final pressure Perforated using 2,5" HC guns w/BH charges @ 4spf, final pressure was 100 psi, 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1064 838 53 1082 240 Post fracs and perfs - both sands Subsequent to operation 1588 1076 154 1130 363 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations ~X Oil X Gas Suspended _ Service 17. I herel)y cedify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rd 15/88 SUBMIT IN DUPLICATE Alaska, Inc. ~ ..... KUPARUK RIVER UNIT .~, '~ ..... ;LL SERVICE REPORT '~ K1(2T-30(W4-6)) WELL JOB ~COPE JOB NUMBER 2T-30 FRAC, FRAC SUPPORT 0621982019.3 DATE DAILY WORK UNIT NUMBER 07/04/98 PERF C SANDS 8305 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 7 (~) Yes (') NoI (!:) Yes (~) No THORNHILL JONES; FIELD AFC# CC# DAILY COST ACCUM COST ESTI MATE KD2314 230DS28TL $12,365 $227,668 Initial TbgPress Final TbgPress Initial lnnerAnn Final lnnerAnn i,n,,a, ,na, 1 O0 PSI 50 PSI 1 O0 PSI 1 O0 PSI SI DALLY SUMMARY SWS PERFORATED C SANDS FROM 10,298' TO 10306' W/2.5" HC, 4 SPF, BH, 180 DEG PHASED, 90 DEG ORIENT W/ 100 PSI WHP. TIME LOG ENTRY 15:45 SWS MIRU, HELD TGSM, OBTAINED RADIO SILENCE, ARMED GUN. 18:15 MIH W/10' (TOP 2' BLANK) 2.5" HC, 4 SPF, BH, 180 DEG PHASED, 90 DEG ORIENT, 2.5" PERTOLINE ROLLER, CCL, 2 1/8" WB. CORR TO SWS GR/CCL 9-17-95. PERFED FROM 10.298' TO 10,306' W/ 100# WHP. 19:45 POH & LD GUN, ALL SHOTS FIRED. 21:15 RIG DOWN. 21:45 RELEASED SWS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $1,110.00 APC $250.00 $27,050.00 DIESEL $0.00 $1,850.00 DOWELL $0.00 $165,559.79 DRILLEX $~).00 $892.00 HALLIBURTON $0.00 $11,031.00 LI']-FLE RED $0.00 $8,060.00 SCHLUMBERGER $12,115.50 $12,115.50 TQTAL FIELD ESTIMATE $12,365.50! $227,668.29 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate~X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X___~. 41' FIKB, 81' Pad 3. Address: Exploratory _~. 7. Unit or Property: P.O. Box 100360 Stratagrapic_~. Anchorage, AK 99510-0360 Service ~ Kuparuk River Unit 4. Location of well at surface: ~8. Well number: 538' FSL, 556' FWL, Sec 1, T11N, R8E, UM 2T-30 Af top of productive interval: 9. Permit number/approval number: 2256' FNL, 303' FEL, Sec 35, T12N, R8E, UM 95-57 At effective depth: 10. APl number: 2053' FNL, 314' FEL, Sec 35, T12N, R8E, UM 50-103-20219-00 At total depth: ! 1. Field/Pool: 1992' FNL, 316' FEL, Sec 35, T12N, R8E, UM Kuparuk Fliver Field / Oil Pool 12. Present well condition summary Total Depth: measured 10686 feet Plugs (measured) None true vertical 6092 feet Effective Depfl measured 10589 feet Junk (measured) 1.5" DV in rathole true vertical 6017 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 255 Sx AS I 121' 121' Surface 4165' 9.625" 840 Sx AS III & 4203' 2873' 670 Sx Class G Production 10538' 7" 224 ex Class G 10676' 6084' Uner Perforation Depth measured 10298'-10306'; 10349'-10369' true vedical 5804'-5810'; 5841'-5856' Tubing (size, grade, and measured depth) · 3.5'", 9.3 lb~fi, L-80 @ 10204' Packers and SSSV (type and measured depth) ., Pkr: Baker SAB-3 @ 10178'; SSSV: None, nipple @ 510' 13. Stimulation or cement squeeze summary Fracture stimulate 'A' sands on 6/29/98. , .... . ~ ~'.,.! /~-.~ ,..,.._~ Intervals treated (measured) 10349'-10369' Treatment description including volumes used and final pressure Pumped 263325 lbs of 20/40, 12/18, and 10/14 ceramic proppant into form., final pressure was 5434 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1064 838 53 1082 240 Post fracs and perfs - both sands Subsequent to operation 1588 1076 154 1130 363 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _~X Oil X Gas Suspended Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed i~~'"--- Title: Production Engineering Supervisor Date ~)/~/~t,6i -. I~nrm 1~_/1~/I F'~¢~P,~,/1 £/RR el IDI~41T I1~.1 r'~l I1~1 I/---AT[- SUBMIT DUPLICATE Alaska, Inc. --.. -' KUPARUK RIVER UNIT  WELL SERVICE REPORT K1(2T-30(W4,6)) WELL JOB SCOPE JOB NUMBER 2T-30 FRAC, FRAC SUPPORT 0621982019.3 DATE DAILY WORK UNIT NUMBER 06/29/98 A SAND REFRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 3 (~ Yes ('~ NoI {~ Yes O No DS-GALLEGOS JONE~j ~ /~ , FIELD' AFC# CC# DALLY COST ACCUM COST t~~u~~ r~Ann ESTIMATE KD2314 230DS28TL $153,566 $171,197 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Ou · 0 PSI 2527 PSI 440 PSI 500 P, SII 0 PSI 300 PSI DAILY SUMMARY I REFRAC THE A SAND' SCREENED OUT DURING FLUSH' PUMPED PLACED A TOTAL OF 263325 LBS OF PROPENT IN PERFS' TIME LOG ENTRY -' -- 06:00 MIRU TGSM PT TO 10450# 08:30 PUMPED BREAK DOWN STG. PER PROCEDURE @ 15 - 25 BPM PUMPED 452 BBLS 50# GEL ISIP 1547# 09:00 PUMPED DATA FRAC @ 5 - 15 BPM 206 BBLS ISIP 15844f 10:00 AJUST PAD VOLUME 11:00 PUMPED MAIN FRAC. TOTAL PROP 273700# PROP IN PERFS 263325# TOTAL SLURRY 2255BBLS SCREENED OUT 58.7 BBLS INTO FLUSH W? 14 PPG AT PERFS. LEFT 10375 # OF PROP IN TBG. W/TOP @ + - 6800' 13:00 RDMO SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $1,070.00 APC $5,800.00 $5,800.00 DOWELL $145,896.79 $145,896.79 HALLIBURTON $0.00 $10,371.00 LI-I-I-LE RED $1,870.00 $8,060.00 TOTAL FIELD ESTIMATE $153,566.79 $171,1 97.79 Da'Lcd" 07/08/97 .. ~1 If. ~ ,' 10~.-407 kiF'L. ETir. ON B, ATE ~//? /gJS" /C/?O,,'~J / ~A~L.¥ WELL OPS C 0 H H E N T S Rece'i ved? Y~ ARCO Alaska, Inc. Date: December 27, 1995 RETURN TO: Attn' Julie Nash Kuparuk Operations File Clerk ATe; 1119B P.O. Box 100360 Anchorage, AK 99510-0360 TRANSMITTAL #9313 Transmitted below are the following pressure items. Please acknowledge receipt and return one signed copy of this transmittal. 2W-05 , Well Pressure Report 11/09/95 2X-08 I~--J~'1 Well Pressure Report 11/09/95 2T-38 °l~"\¥"l~ell Pressure Report 11/11/95 2W-06 ~' q-I~i~ Well Pressure Report 11/11/95 2T-37 ~/~'--~(31 Well Pressure Report 11/11/95 2T-31 9~-.q¢~ Well pressure Report 11/12/95 2T-30 ~/~'-'- 57' Well Pressure Report 11/13/95 2T-38 ~.\~q/Well Pressure,l~eport / 11/26/95 Receipt Ack, nowle DISTRIBUTION: Petmtechnical Data Center BP Exploration (Alaska) Inc. MB 3-3 P.O. Box 196612 Anchorage, AK 99519-6612 AMERADA AMERADA AMERADA AMERADA AMERADA AMERADA AMERADA AMERADA Date: ! VED Fuller 4I~k~ (Ji/ ~ Gas Cons. Commission Holly c/o Chevron U.S.A., Inc AnChorage P.O. Box 1635, Rm 3008 Houston, TX ~251 Barbara Sullivan Mobil Oil Corporation 12450 Greenspoint Drive Houston, TX 77060 Mr. Vernon E. Pringle, Jr. DeGIoyer and MacNaughton One Energy Square Dallas, TX 75206 Debra Childers UNOCAL P.O. Box 196247 Anchorage, AK 99519-6247 Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Kuparuk-Well Pressure Report Well ,~ 7'-~0 Date Key Well ..'~ Satisfies ''' i:] Yes F-I No --~.'i"~' ~State I-1 Yes O No_ - . · - -_ . - .._ .- .-. .::~.:~-P~e~ure Measurement Device..~:~:.~... ~.::~:.~.:: _..:~:~ .. ........ '-~:~~~-'HP ~ AMERADA ~ LYNES ~ Torque Turn _ _.-~;-~ ..... ~:-'~37 ' .~ ~%~.-: ' . .... :.~,~'~:.::~:~.-~'~'--: ..... ~ :: .' '.; .~...~ '~':~:::~:~i~ ':-.~:'-..'-:'. 5' '5:.~ R~-~''':'-'''~ ~' ~-~ ~.~:-~. - ~:~. ~ - ~ .'-- ~ - ~. _~ : ~ -.~. ~ - ' -' -- ~.~:~V~- ~_- '--._"' · v ~ . ' ' ": - ,:P '"~ .~ ~:',.~ ~- -' :.;. ~,:~ ~ ' , ~-~ ' '~ '~.~'-' -~'~:-~"~*-.~"* ,a-ntificaflon No.''-- ~:~-~-.. '-..-'- ........ Calibration Date. · ~~~~:/. ~. . . - .... . ~' -.,: ...~ -.. ........ ~=~..._. (Upper Bomb) ~7~ Y - ~' ....... .' :.- .-~: .- ~ _.-._ ,. '-_ ~ · (~W6f Bomb) ~~g ~ ..... X~ ~~ ;~~:' ..... ' ' --"~:7'~- ': ....... ' ..... -" - ' "'-- ~''' ' "-" '~~~~;;:5'~?~-~' - ~e of Test: ~Static ~ PBU Sand: ~ A ~ C C Both "~5::;:;.:: --~--~:~.- · .'?~~nai , Datum ,, Wme-~ '.~-?.-: [ [ :[(~~S'urO' _i-~'--Pressure II D~' WL I MD-I ~D-':T':.Uppe~~]~'L0W6r"~"~:~_~WD-S.s. [! _.. ':"i'~;~"~¢':~; Maximum Recorded Temperature: Well ~! Prior to Pressure Measurement (Date/Time)C%~ "& ,~" ' ~,~. . . . Operations/Engineeh~. :~'! ._....., .... ' ~~-..q o o t'.~.. .... ':-~b-:., ,. :': ARCO Alaska, Inc. Date' December 26, !995 Transmittal #: 9310 RETURN TO: ARCO Alaska, inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATO-1119 B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. Please acknowledge receipt and return one signed copy of this transmittal. ~/F-~,(, 2T-27 CDR 04/17/95 REF #50-103-20217 ~ 2T-32 CDN 04/30/95 REF #50-103-20218-00 ¢.~-~ ~ ~ ~2T-32 CDR 04/30/95 REF #50-103-20218-00 ~.r--r? 2T-30 CDR 05/12/95 REF #50-103-20219-00 ~ .~..~..c( 2V-06 TDTP 06/11/95 REF #95219 'td"-~'[ 2T-31 CDR 0713/95 REF #50-103-20226-00 ~2T-36 CDR 07/25/95 REF #50-103-20228-00 ~/F~. ~ ~-'-2T-36 CDN 07/25/95 REF #50-103-20228-00 tC2T-38 CDR 08/03195 REF #50-103-20229-00 c~--.f I :~ )..2.T-38 CDN 08~03/95 REF #50-103-20229-00 ~(F- lo ~ 2T-37 CDR 08/10/95 REF #50-103-20227-00 ~_~ ~.~ 1 Q-24 ARC5 Array Resistivity Comp. 08~30~95 4206-7270 ~_ ~ × 1 Q-26 ARC5 Array Resistivity Comp. 09~22/95 3820-7010 1 Q-23 ARC5 Array Resistivity Comp. 09/30/95 5156-9982 Acknowledged: DISTRIBUTION: Mr. Vernon E. Pringle Jr. DeGIoyler and MacNaughton One Energy Square Dallas, TX 75206 Erickson/Zuspan NSK Central Files NSK 69 Sharon AIIsup-Drake DS Development ATO - 1205 Larry Grant AOGCC i~ 3001'-Porcupine Drive Anchorage, AK 9950!_., Date: ~!~ska 0ii & G~,s Cons. Ar~cr~or~.ge Clifton Posey Geology ATO - 1251 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9853 Company: 10/30/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 ~ ~'-,,~ ~'~ ¢ Field: Kuparuk (Open Hole) LIS Well Job # Log Description Date BL RF Sepia DIR MWD Tape 2T-30 95216 CDR 950512 I I 1 , SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 25, 1995 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2T-30 (Permit No. 95-57) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the recent operations on KRU 2T- 30. If there are any questions, please call 265-6206. Sincerely, Supervisor Kuparuk Drill Site Development MZ/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT'AND LOG , 1 Status of Well Classili'cat~op'(e! ~ervice Well ,- / /.¢-.,. OIL ~] GAS ~ SUSPENDED r--'J ABANDONED [] SERVICE , ,r 2 Name of Operator 7 Permit Number "' '/ 74~/ ?' ARCO Alaska, In¢ 95-57 "~-"'~ 3 Address 8 APl Number P.O. Box 100360, Anchoracje, AK 99510-0360 50-103-20219 4 Location of well at surface~! 9 Unit or Lease Name 538' FSL, 556' FWL, Sec. 1, Tll N, R8E, UM ~' ':¢~i"* '"~-~:'~ ~¢i:':' '~;~!~,"~ I Kuparuk River Unit At Top Producing Interval I ,.iL;, i'i-: i ~ 10 Well Number AtTolalDepth ! ~/~: ~ii:ii:f'} i 11 FieldandPool 1992' FNL, 316' FEL, Sec. 35, T12N, R8E, UM ...... '-~.'- ~ KUPARUK RIVER 5 Elevation in feet {indicate KB, DF, etc.) J 6 Lease Designation and Serial N°. Kuparuk River Oil Pool RKB41' Pad81'I ADL25548 ALK2662 - 12 Date Spudded 13DateT.D. Reaohed 14 OateComp.,Susp. orAband. 115WatorDepth, i, offshore 1~6 No. of Oorrl~otiorl$ Ma)/1, 1995 May, 11, 1995 17-Sep-95 (perf'd) NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set 21 Thickness of permafrost 10589'MD &6017'TVD YES ~XJ NO LJI NA feetUD = 1380'SS APPROX 10686' MD & 6092'TVD 22 Type Electric or Other Logs Run GPJCDR 23 CASING, LINER AND CEMENTING RECORD SE'I-rING DEPTH MD CASING SIZE ~ GRADE TOP BTM HOLE SIZE CEMENT RECOP~ 16" 62.5# H-40 Surf. 121' 24" 255 sx AS I 9.625" 40.0# L-80 Surf. 4203' 12.25" 840 sx AS III Lead, 670 sx Class G Tail --, 7" 26.0# L-80 Surf. 10676' 8.5" 224 sx Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 10204' 10178' 10349'- 10369' MD 4spf 5841'- 5856'TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10349' - 10369' 19169# 20/40, 180865# 12/18, 11235# 10/14 proppant 27 PRODUCTION TEST Date First Production JMethod of Operation (Flowing, gas lifl, etc.) I September 26, 1995 I Flowing Date of Test Hours Tested PRODUCTION FOR ;OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO October 8, 1995 11.90 TEST PERIOD ¢' 1 203 1375 1 9 0 1143 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press 342 581 24-HOUR RATE I¢ 2427 2773 38 24° 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. · :, .; . ~ .. · . . .. ~;',.::,' :.~; !'_.~_ ~;- Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS 30. FORMATION TESTS NAME Top Kuparuk C Bottom Kuparuk C Top Kuparuk A Bottom Kuparuk A MEAS DEPTH TRUE VERT. DEPTH 10291' 10308' 10320' 10501' 5799' 5811' 5820" 5953' Include interval tes~,eo, pressure data. all fluids recovered and gravity. GOR, and time of each phase. 31, LIST OF A'I-FACHMENTS Daily' Drilling Histow, Directional Survey' 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ,. Form 10-407 .,.. ,-- ., ~. . Date: 10/06/95 Page: 1 ~RCO Alaska Inc. DAILY DRILLING REPORT WELL:2T-30 RIG:PARKER 245 WI: 55% SECURITY:0 WELLID: AK8221 AFE: AK8221 TYPE:DEV AFE EST:$ 1349M/ 1760M AREA/CNTY:NORTH SLOPE STATE:AK API NUMBER:50-103-20219 FIELD: KUPARUK RIVER SPUD: START COMP: FINAL: 05/02/95 (1) TD: 2168' (2168) SUPV:RLM MW: 10.0 PV/YP: 28/28 APIWL: 9.2 DRILLING Move rig to 2T-30. Accept rig at 1300 hrs. 5/1/95. Spud well at 1800 hfs 5/1/95. Directional drill 12.25" hole from 121' to 2168'. DAILY:S90,326 CUM:$90,326 ' ETD:SO EFC:$1,439,526 05/03/95 (2) TD: 4225' (2057) SUPV:JT MW: !0.0 PV/YP: 25/22 CIRCULATING Drill from 2168' to 4225'. Run 9-5/8" casing. DAILY:S145,11! CUM:$235,437 ETD:SO APIWL: 7.6 EFC:$1,584,637 05/04/95 (3) TD: 4445'(220) SUPV:JT MW: 9.6 PV/YP: 16/11 APIW-L: 7.6 CIRCULATING Cement 9-5/8". Test BOPE. Test casing. Drill cement and 10' of new hole t/4235'. Drill from 4235 to 4445' DAILY:S271,553 CUM:$506,990 ETD:SO EFC:$1,856,190 05/05/95 ( 4) MW: 10.1 PV/YP: 14/10 APIWL: 7.0 TD: 4824' (379) CIRCULATING SUPV:JT Drilled from 4445' to 4824'. Shut in well. Circ out kick. ~. Monitor well~__Stab in floor valve and ibop. Circulate gas out through choke. Retrieve ibop and TIW valve. DAILY:S154,846 CUM:$661,836 ETD:SO EFC:$2,011,036 05/06/95 (5) TD: 4825'( 1) SUPV: JT MW: 9.8 PV/YP: 14/12 APIWL: 6.8 DRILLING TABASCO Pull out of hole to sidetrack. Sidetrack well from 4627' to 4825' DAILY:S141,625 CUM:$803,461 ETD:SO EFC:$2,152,661 05/07/95 (6) TD: 5467'(642) SUPV:JT MW: 9.8 PV/YP: 14/12 APIWL: 6.8 PU TURBINE & G417 BIT Drill from 4825' to 5467' Hole losing fluid. Circ and reduce mud weight. Monitor well. OK. DAILY:S173,176 CUM:$976,637 ETD:SO EFC:$2,325,837 05/08/95 (7) TD: 8260' (2793) SUPV: JT MW: 9.7 PV/YP: 12/ 9 APIWL: 6.8 DRILLING 8-1/2" HOLE Drilled from 5467' to 7108'. Lost 45 bbls in 10 min. Well flowing. Shut in well. Monitor well, no increase in pressure. Bled off csg pressure. Opened annular. Well dead. Drilled from 7108' to 8260'. DAILY:S146,908 CUM:$1,123,545 ETD:SO EFC:$2,472,745 05/09/95 (8) TD: 9821'(1561) SUPV:JT MW: 9.7 PV/YP: 13/12 DRILLING 8-1/2" HOLE Drilled from 8260' to 9821' DAILY:S75,967 CUM:$1,199,512 ETD:SO APIWL: 6.0 EFC:$2,548,712 Date:10/06/95 Page: 2 05/10/95 (9) TD:10087' (266) SUPV:PJmM 05/11/95 (10) TD:10565' (478) SUPV:R/_/~ 05/12/95 (il) TD:10686' (121) SUPV:RLM 05/13/95 (12) TD:10686' ( 0) SUPV:RLM 05/14/95 (13) TD:10686' ( 0) SUPV:RI24 ARCO Alaska inc. DAILY DRILLING REPORT MW: 10.6 PV/YP: 22/ 8 APIWL: 6.2 STAGE IN Directional drill 8.5" hole from 9821' to 10087' Weighted up, started taking mud. Increased pump rate and began losing mud. POOH to make up rotary drilling assembly with LWD. Stage in hole at 2000' intervals to 6000', no losses while circulating. DAILY:S134,957 CUM:$1,334,469 ETD:SO EFC:$2,683,669 MW: 10.7 PV/YP: 20/10 APIWL: 5.4 DRILLING Stage in hole to 10087'. Circulate with reduced pump rate to minimize losses while adding LCM. Rotary drill from 10087' to 10565'. DAILY:S101,603 CUM:$1,436,072 ETD:SO EFC:$2,785,272 MW: 10.7 PV/YP: 24/12 APIWL: 4.7 RLTL~ING CASING Rotary drill from 10565' to 10686'. Run 7" casing. DAILY:-$340,194 CUM:$!,095,878 ETD:SO EFC:$2,445,078 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 LAYING DOWN DRILL PIPE Ran 7" casing to 10676'. Cement casing, CIP at 1836 hfs 5/12/95. Freeze protected 9.625" x 7" annulus. DAILY:S217,605 CUM:$1,313,483 ETD:SO EFC:$2,662,683 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Lay down drill pipe. Release rig 1200 hrs. 5/13/95. DAILY:S17,226 CUM:$1,330,709 ETD:SO EFC:$2,679,909 Date'10/06/95 Page: 3 ARCO Alaska inc. DAILY DRILLING REPORT REMEDIAL AND COMPLETION OPERATIONS WELL: WELLID: AK8221 AREA/C~Y: FIELD: SPUD: RIG:NORDIC WI: 0% SECURITY:0 AFE: AK8221 TYPE:DEV AFE EST:$ 1349M/ 1760M STATE: API NUMBER: START COMP: FINAL: 09/01/95 (14) TD:10686' PB:10589' SUPV:MDD LOAD 3-1/2" COMPLETION TU MW: 8.6 SEAWATER Move rig from 2T-29 to 2T-30. Test casing. Load, strap, drift 3-1/2" completion tubing. DAILY:S19,100 CUM:$1,349,809 ETD:SO EFC:$2,699,009 09/02/95 (15) TD'10686' PB:10589' SUPV:MDD PREPARING TO SET PACKER MW: 8.6 SEAWATER Run in hole with packer and 3-1/2" tubing and GLMs. DAILY:S33,200 CUM:$1,383,009 ETD'SO EFC' $2,732,209 09/03/95 (16) TD:10686' PB:10589' SUPV:MDD RIG RELEASED MW: 8.6 SEAWATER Set packer. Freeze protect. Test packoff and tree. Release rig @ 1030 hrs 9-2-95. DAILY: $96,850 CUM:$1,479,859 ETD:S0 EFC: $2,829,059 9/17/95 Complete perf 'A' sand interval 10349' - 10369' (ref CDR dated May 7-12, 19~5) using 2-1/8" EJ with BH charges, 4 spf, 180° ph, oriented +/- 90° from lowside. End of WellSummary for Well:AK8221 !21.~ 0+0 121,0~ 377,51 25-~, ~ 5 377, ~7 i~7i+2D !937,61 2406,23 2A72.7~ 3060,70 3247+25 4~87 + 18 .~:/+£,~ 46~,37 4746.46 4925+10 50~,0! 5123,5~ 87+20 i5+67 4,70 93,2 -i/:: ~ '..-' £U i ,7=~ 204+67 23+4~ ,_. ,_; ~ 2~c~+-70 30,22 _. ~. - ~ ~.- ,. -:-86,9 2..,-7+8 E/-W it ft deo 0,00 0,00 0,00 .; Q, _.' .: / tx.,., a,A5 ,6,:-~3 5,43- 1, Z"d aa, .:-,' 7 :.-' z,c,, .-- 6,5: 333,9 ~';'.a.~ ~x~ ~':, 7 tr.:, i~.,49 !7E,27 15+40 9',,,._~.:.-,_,. 7,-:.. , ~+~,'., ?.7 c-c. ": ':'": ~" "~?' 9,5? 2¢3,1--:', ;'~-':..:.., bLS deg/ 0.,'.'.' 1:40 3,::': 3,2! Mil,73 52,08 ~=" ~' -~9,3.~. ..... -~=f~ ~ ~£ -.-...-~. ~/.~= ~.,17 35!,72 /'"":c ~ ~-:~ :, 815,92. :?+93 ~"='~ ,75 ~.16,0~_ , :q~ r:... 4~.4+_.,= 3::-,_- +~: 1648,E4 42,: 314,02 ' '~ " 4~,~',~ ;.~. :~. ~,~ ~:r,' +:,, e,:., ~q 252,!4 2148,79 65,50 350,6Z 2!52,05 .~.',90 64,28 62,35 61 60.' ... :6t 57,92 5%?? ~... j3/ e ~,'-..' · %; · '~ --.'".'" q'~7 : '-' -oc, ;," ,' c. 7, ii ~,' ,-.~ -47,45 8i7,42 356:-67 -57,86 ~.-._,, i~ o..-,= 756 ,.~,. iV J7 +-2:2 '.~.JJ+/ O 352,30 ~4~.,:. -262,51 245!,8/ ~J~,=.~ 353,22 2~0,22 -Z~9,33 2585,35 353,80 35!,47 Z734,~ -301,37 2750,81 353,71 354,7t ~870,12 -3!7,84 2887,67 SSS,OS 253.70 2896,40 -320o51 2914,08 353,69 2975.,+01 -326.95 2992,93 .353,73 ~5B,7~ -3'/9+6~ $076.46 353+B5 3140,!5 -230,0~ 3157,44 354~00 32!5,47 -~x/,!4 22~,26 ~+16 ~,85 -~o., ,.~n 3317,~'~, 354,33 a~.-'i,71 2,'50,70 2887,57 -~!3,97 89,1 3121,I6 ::~,D 94,4 .8164,.54 a076,26 94+2 37.I2+~. 31~,14 89,9 3~'?,60 ~2.gl 25%42 i,2... 2~94 0,5."_"- 0,55 i 0,76 0,48 0.70 1.34 1 ,I7 4,~ 4.73 3,69 3.22 1,!3 ~;-:-:.~:..= ......... TA::,'~: .... -., LA~ i fL:i::. :::::, c,-J .',;, 3 "'-::'._.,,, ._.,------ ................. _,-- 04.:::. ,,' ': c.:, -f£ c,~='~, '~",,, .......... "" '" 3~:.'% '" 35%,4i '~=".,65 354,47 2551- ~._e 5,_:75,.-3? ...... - ....... ,:_,.:-.-:.-o ~: ;:o~.'=' ::-5us,:'.-:' .~ ...... .: 64::_::i 353,56 751M;3£ 7846,39 /-. 4 --; ,F: b671116 10570,00 ...... '--.:-:.',:-"': "-q i'.;-'z:,<' 64~29 :.sS:':,',A~ ," -D L; {, '-:- -......'v ~ '? ...... i"- .... ..262,6 3143-:~,L 44'_-?'.;',29 63.:¥:-2 353,i0 ........ ; .....= _.--uu:,~9 '= "= '~=-"~ '-': ~..',':,+ :~, .:---:-_--.,'.,'o .--~-:oo 35~ -,-,---:'- £0-" ~, '- .-'/C~ * .:'i ,.~, 262:6 4.f,:2,2~: 6023-:40 64,45 c:.:', :: .... ': '"3 6273~76 ¢,,',a.-- -- ,-'.' -4137~0~ 42~.5,120 ........ -43~.,34 45(:,0,.'3'4 -4~-.~¢5 ,,,- _.,~ '-:' ,,~=...., 3N:95 ~'r,r, ~"a '- .-.r,m .~r x '5 ' - 2--"'51' ~ .J '. j .-_>,.: .~ ~! ! 1'.'--. 12., ...... ~ 7 -~o~,Yi is^'~ ,43 353o~z ~ ~ 7~7~i0 ..... -542.~-' ~9~,, . ., 353,63 -8,'5',Z7 ~"" '~ . . · o-~or,3u 353.7A rr' de-a/ I 1,4..:-. .':.',,22 0,26 0,57 0,14 0,72 0,37 3,58 2,:.7'} ! ',..",Sd ALAS OIL AND GtS / CONSERVATION COMi SSION April 25, 1995 TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Michael Zanghi Drill Site Development Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Prudhoe Bay Unit 2T-30 ARCO Alaska, Inc. Permit No: 95-57 Sur. Loc. 538'FSL, 556'FWL, Sec. 1, TllN, R8E, UM Btmhole Loc. 1914'FNL, 412'FEL, Sec. 35, T12N, R8E, UM Dear Mr. Zanghi: Enclosed is the approved' application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIO,'~ PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [-1 lb Type of Well Exploratory D Stratigraphic Test D Development Oil X Re-Entry [~ Deepen ["1 Service D Development Gas r-1 Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 81' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchora~le, AK 99510-0360 ADL 25548, ALK 2662 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.025) 538' FSL, 556' FWL, Sec. 1, T11N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 2140' FNL, 384' FEL, Sec. 35, T12N, R8E, UM 2T-30 #U-63061 0 At total depth 9. Approximate spud date Amount 1914' FNL, 412' FEL, Sec. 35, T12N, R8E, UM 4/27/95 $200,000 i 2. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'rVD) property line 2T-32 10792' MD 3366 @ TD feet 25.3' ~ 750' MD feet 2560 6129' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 500' feet Maximum hole angle 63.9° Maximums~rface 1700 pslg At total depth (TVD) 3200 pslg 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD linclude sta~le data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 12.25" 9.625" 40.0# L-80 BTC 4076' 41' 41' 4117' 2872' 840 Sx Arcticset III & HF-ERW 670 Sx Class G 8.5" 7" 26.0# L-80 BTCMOE 10751 41' 41' 10792' 6129' 210SxClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Surface Intermediate ProductionAPR 2 1 1995 Liner Perforation depth: measured A.I~$[/~ 0ii & Gas Cons. Commission true vertical Anchorage 20. Attachments Filing fee X Property plat [-1 BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [--] Refraction analysis D Seabed report r-~ 20 AAC 25.050 requirements X 21~,1 hereby certify, fl~at the foregoing is true and correct to the best of my knowledge Signe Title Drill Site Develop. Supv. Date , Commission Use Only Permit Number APl number I Approve, date,~/Z~,~ Ieee cover letter for ?,_~'-._~ -I 50./(~,~_ .~_.(~ ~. ~/ c~ /~ 5""-- other recluirements Condition~ of approval Samples required ~1 't~es r~ No Mud log required ~] Yes ~;~ No Hydrogen sulfide measures ~ Yes D No Directional survey required [] Yes [] No Required working pressure for BOPE E] 2M ~ 3M r'~ 5M D 1OM r'1 15M Other:Original Sign~o. ~ David W. Johnston byorder of Approved by Commissioner the commission Date'~,/'",,.~ ~"'-. Form 10-401 Rev. 7-24-89 in triolicate GENERAL DRIllING PROCEDURE KUPARUK RIVER FIELD 2T-30 · . . . . . . . . 10. 11. 12. 13. 14. 15. 16. 17. Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4,117')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (10,792') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & either full opening valve (if cased hole logging planned), or master valve and upper tree assembly (if no logging planned). Note: As a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. Secure well and release rig. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 7" casing to 3500 psi. Perforate and run completion assembly. Set and pressure test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVED APR 2 I 1995 AJ~ska 0il & Gas Cons. Commission Anchorage DRILLING FLUID PROGRAM Well 2T-30 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-4O 10-12 9.5-10 +10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 10.9 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated sudace pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1,700 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 2T-30 is 2T-32. As designed, the minimum distance between the two wells would be 25.3'@ 750' MD. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2T-30 surface/production casing annulus will be filled with diesel after setting. 7" and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface. Risks in the 2T-30 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. The 7" casing will be topset above the Kuparuk and a 5" liner run to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 10.9 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. RECEIVED APR 2 I 199,5 Oil & Gas Cons. Commission Anchora¢ ARCO ALASKA, Structure : Pad 2T Well : Field : Kuparuk River Unit Location : North Slope, Alaska jCrea[ed by : jones For: D PF. TRAS]:[ jDate plotted : 21-Apr-95 IPIot Reference is 30 Version #6. jCoordinates are in feet reference slot #30. iTrue Vertical Depths are reference wellhead. J 500 lOOO_ _ 15oo_ _ 2000_ -- 2500_ - 3000_ _ 3500_ _ 4000_ - 4500_ _ 5000. 5500_ N 6.8 DEG W ?938' (TO TARGET) ***PLANE OF PROPOSAL*** 6000_ -- 6500_ RKB ELEVATION: 122' 3.00 8.95 KOP TVD=500 TMD=500 DEP=O BEGIN TURN TO TARGET TVD=700 TMD=700 DEP=IO 14.90 3 DE(;; / 100' DLS 20.88 TD LOCATION: 1914' FNL, 412' FEL SEC. 35, T12N, RBE TARGET LOCATION: 2140' FNL, 384' FEL SEC. 35, T12N, RBE TARGET TVD=5858 TMD=10438 DER=7938 NORTH 7882 WEST 940 RECEIVED APR 2 1 1995 A!aska Oil & Gas Cons. Commission Anchorage 26.87 BT//PERMAFROST TVD=1502 TMD=1554 DEP=281 32.86 UGNU SNDS TVD=1547 TMD=1607 DEP=510 38.86 44.86 50.85 56.85 62.85 T/ W SAK SNDS TVB=2202 TMB=2595 DEP=1054 EOC TVD=2220 TMB-2655 DEP=1070 K-lO WD=3042 TMD=4504 DEP=2748 MAXIMUM ANGLE 63.9 DEG 1500 1000 500 I I I I I West 0 500 I I I _8500 _8000 HRZ _7500 _ _7000 _ _6500 _ _6000 _ _5500 _ _5000 _ _4500 _ _4000 Begin Angle Drop K-5 TARGET ANGLE 40 DEG SURFACE LOCATION: 538' FSL, 556' FWL SEC. 1, T11N, RBE B/ W SAK SNDS 'POD=2672 TMD=$662 DEP=1992 9 5/8" CSG PT TVD=2872 TMD=4117 DEP=2401 K-5 TVD=4542 TMD=7915 DEP=5810 9 5/8 Casing Pt Base West Sak Sands K-lO T EOC ap West $ok Sands Base Permafrost t Begin Turn to Targetsl~ _3500 _3000 _2500 _ _2000 _ _1500 _ _1000 _ _ 500 _ _ 0 500 I I 0 BEGIN ANGLE DROP TVD=5127 TMD=924.3 DEP=7004 62.oo 58.00 54.00 DROP 2 DEG / 100' 50.00 B/ HRZ TVD=5658 TMD=10165 DEP=7753 46.00 TARGET - T/ ZONE C (EOD) TVD=5858 TMD=10438 DEP=7938 42.00 T/ ZONE A TVB=5868 TMD=10451 BEP=7946 E~ A,3 SNDS TVD=5882 TMD=10469 DEP=7958 KUP SNDS TVD=5976 TMD=10592 DEP=8057 TD / 7" CSG PT TYD=Gi29 TMD=10792 DEP=BI65 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 500 0 500 1000 1500 2000 2500 5000 5500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 Scale 1 ' 250.00 Vertical Section on 353.20 azimuth with reference 0.00 N, 0.00 E from slot #50 I I ICreated by : jones Date plotted : 21-Apr-95 Plot Reference is 30 Version #6. iCoordinotes ore in feet reference slot True Ve~icol Depths ore reference wellhead. 0 ALASKA, Structure : Pad 2T Well : 30 Field : Kuparuk River Unit Location : North Slope, Alaska 360 320 280 240 200 160 640 , I I I I I I I I I I 600 220~0 560 520 2500 480 2100 2400 44O 400 560 320 28O 1800 240 2000 1500 200 140~ 1900 < West 120 80 40 0 40 80 120 160 1900 1800 1700 1900 ~  1600  1500 1800 17001 1400 16O 13OO 120 [~. ~0 200( ~o ~ ~~°° 40 l~O~b'~~140° ~ 1800 ' 0 ~200 40 ~100 ~ 360 80 1200 150( 1300 1200 240O 1100 2100 ~300 lO0O 320 280 240 200 160 120 80 < 0 40 80 Wesf 2OO Scale 1 ' 20.00 240 280 320 ~900 280O 270O ~500 120 RECEIVED APR 2 ~ 1995 ,A'~s~ 0it 1 6as Cons. Commission Anchora¢ 36oo ~ / oo / 160 200 240 280 320 Scale 1 · 20.00 64O 600 56O 520 _ 48O _ _ 440 _ 400 _ 360 _ 320 28O _ 240 _ 200 _ _ 160 _ _ 120 80 40 _ 0 40 80 I I Z 0 KUPARUK RIVER UNI'! 20" DIVERTER SCHEMATIC .I 6 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. . MAINTENAN(~E ~, OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) RECF. i¥£D 1. 16" CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. APR 2. 1 1995 0il & Gas C0ns. Commission Anohora,.¥.~ ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 11/9/94 7 6 5 4 13 5/8" 5000 PS, BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECKAND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOWAND 3000 PSI HIGH. TESTAS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOTA FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMSAND CLOSE Bo~-rOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILUNG POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12_ TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KQOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11' - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8"- 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR APR 2 1 'i995 0it & Gas Cons. Commission Anchor~ :c~, WELL PERMIT CHECKLIST F'rEL~ ~ ~'00,'. ~"?0/00 1. 2. 3. 4. COMPANY WELL NAME GEOL AREA UNIT# PROGRAM: exp [] dev~ redrll serv ON/OFF SHORE Permit fee attached .................. N Lease number appropriate ............... N Unique well name and number .............. N Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary.. N 6. Well located proper distance from other wells ..... N ' 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party .............. N 10. N N N N Operator has appropriate bond in force ......... 11. Permit can be issuedwithout conservation order .... 12. 13. Permit can be issued without administrative approval. Can permit be approved before 15-day wait.. . . . . ENGINEERING 14. Conductor string provided ............... 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved.-~----N/~-- 22. Adequate wellbore separation proposed ......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ............... _~ ..... 26. BOPE press rating adequate; test to ~c-~I~ psig.~ 27. Choke manifold complies w/API RP-53 (May 84) ....... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............ GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y/~ 32. Seismic analysis 9f shallow gas zones ........../Y/ N 33. Seabed condition survey (if off-shore) ........ N 34. Contact name/phone for weekly progress reports ..... ..'~ Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: DWJ Comments/Instructions: HOW~o - A:~FORMS~cheklist my 03/94 o 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. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA, INC. WELL NAME : 2T-30 FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-103-20219-00 REFERENCE NO : 95216 Date LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-0CT-1995 19:39 **** REEL HEADER **** SERVICE NAME : EDIT DATE : 95/10/26 ORIGIN : FLIC REEL NAME : 95216 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC.,2T-30 KUPARUK RIVER, API #50-103-20219-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 95/10/26 ORIGIN : FLIC TAPE NAME : 95216 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC.,2T-30 KUPARUK RIVER, API #50-103-20219-00 TAPE HEADER KUPARUK RIVER MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA BIT RUN I JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 2T-30 501032021900 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 26-0CT-95 # WELL CASING RECORD 1ST STRING 2ND STRING BIT RUN 2 95216 RUMINER MORRISON 1 11N 8E 538 556 122.00 122.00 80.70 BIT RUN 3 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) ........ .... PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-0CT-1995 19:39 3RD STRING PRODUCTION STRING REMARKS: THIS TAPE CONTAINS LDWG FORMATTED CDR DATA FOR ARCO KUPARUK 2T-30 DRILLED FROM 7-12 MAY 1995. **** FILE NEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 95/10/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : PAGE: FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH CDR 10686.0 $ curves; all bit runs merged. STOP DEPTH 4398.0 BIT RUN NO. MERGE TOP MERGE BASE ........... oo 7.o 2 10087.0 10686.0 THIS FILE CONTAINS THE MERGE OF ALL DATA, MAD PASS DATA, WASHDOWN DATA AND BIT RUNS #1 AND #2 TO GIVE A CONTINUOUS DATA SET. INTERVAL FROM 4398' TO 5321' IS MAD ACQUIRED DATA. INTERVAL FROM 5392' TO 10087' iS BIT RUN #1 DRILLING DATA. INTERVAL FROM 10087' TO 10686' IS BIT RUN #2 DRILLING DATA. NO DEPTH CORRECTIONS HAVE BEEN MADE AT ARCO'S REQUEST. $ MERGED DATA SOURCE LDWG TOOL CODE CDR CDR $ REMARKS: BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH CDR LIS Tape Verification Listing Schlumberger Alaska Computing Center # LIS FORMAT DATA 26-0CT-1995 19:39 PAGE: DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE --i .......... .......... .... 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG .TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 619191 O0 000 O0 0 1 1 1 4 68 --~~- RA MWD OHMM 619191 O0 000 O0 0 I I 1 4 68 0000000000 RP MWD OHMM 619191 O0 000 O0 0 1 I 1 4 68 0000000000 VRA MWD OHMM 619191 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD OHMM 619191 O0 000 O0 0 1 1 I 4 68 0000000000 DER MWD OHMM 619191 O0 000 O0 0 I I 1 4 68 0000000000 ROP MWD FPHR 619191 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 619191 O0 000 O0 0 I I i 4 68 0000000000 FET MWD HR 619191 O0 000 O0 0 1 i 1 4 68 0000000000 ** DATA ** DEPT. 10685.500 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD 29.507 GR.MWD FET.MWD -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center DEPT. 4398.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 ** END OF DATA ** 26-0CT-1995 19:39 -999.250 RP.HWD -999.250 VRA.HWD -999,250 ROP.MWD -999.250 GR.MWD PAGE: -999.250 88.952 **** FILE TRAILER **** FILE NAME : EDIT ,001 SERVICE : FLIC VERSION : 001C01 DATE : 95/10/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 95/10/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE CDR $ MERGED DATA SOURCE LDWG TOOL CODE CDR CDR $ REMARKS: curves; all MAD runs merged using earliest passes. START DEPTH STOP DEPTH 10087.0 4398.0 MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE 1 1 4398.0 5321.0 2 I 10046.0 10087.0 THIS F][LE CONTAINS THE MERGE OF MAD AND WASHDOWN ACQUIRED CDR DATA, NO DEPTH CORRECTIONS HAVE BEEN APPLIED AT ARCO'S REQUEST- S LIS Tape Verification Listing Schlumoerger Alaska Computing Center # LIS FORMAT DATA 26-0CT-1995 19:39 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** -~ ..... ~-~ ..... ~- 1 66 0 2 66 0 3 73 32 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** -~--~--~i~-~i~--~-~i--~i--~i-~i~--~--~--~i~--~---~~-~ ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) o~ ~ ~ ooooo ooo -z ~ ~ , ~ -6666666666 RA MAD OHMM 6~9~°i. ~J O0 nnn.~vO0 0 2 i I 4 68 0000000000 RP MAD OHMM 619191 O0 000 O0 0 2 i i 4 68 0000000000 VRA MAD OHMM 619191 O0 000 O0 0 2 i 1 4 68 0000000000 VRP MAD OHMM 619191 O0 000 O0 0 2 1 i 4 68 0000000000 DER MAD OHMM 619191 O0 000 O0 0 2 I i 4 68 0000000000 ROP MAD FPHR 619191 O0 000 O0 0 2 I 1 4 68 0000000000 GR MAD 619191 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 10087.000 RA.MAD 2.092 RP.MAD 2.045 VRA.MAD VRP.MAD 2.071 DER.MAD 61.013 ROP.MAD 90.736 GR.MAD 1.998 3.567 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-0CT-1995 19:39 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 95/10/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 95/10/26 ORIGIN : FLIC TAPE NAME : 95216 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC.,2T-30 KUPARUK RIVER, API #50-103-20219-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 95/10/26 ORIGIN : FLIC REEL NAME : 95216 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC.,2T-30 KUPARUK RIVER, API #50-103-20219-00