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195-026
1. 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: IA Cement 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 9845'feet 9284'feet true vertical 6164' feet 9653' feet Effective Depth measured 9284'feet 9328'feet true vertical 5776' feet 5786' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 9359' MD 5827' TVD Packers and SSSV (type, measured and true vertical depth) 9328' MD N/A 5786' TVD N/A 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: 3722' 2872' Burst Collapse Production Liner 9783' Casing 6167'9821' 3682' 121'Conductor Surface Intermediate 16" 9-5/8" 81' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 195-026 50-103-20214-00-00 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: ADL0025568 Kuparuk River Field/ Kuparuk River Oil Pool KRU 2T-19 Plugs Junk measured Length 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) ~ Gas-Mcf MD ~ Size 121' ~~~ Well Remains Shut-In ~~ ~ 323-201 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker SAB Packer SSSV: None Katherine O'Connor katherine.oconnor@conocophillips.com (907) 263-3718Well Intervention Engineer 9435-9455',9500-9542', 9568-9588' 5880-5894', 5926-5957', 5977-5992' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O= ConocoPhillips, OU=Wells Group, E= katherine.oconnor@conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2024.01.08 13:27:16-09'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor N NS By Grace Christianson at 3:16 pm, Jan 08, 2024 DSR-1/26/24 RBDMS JSB 011124 DTTMSTARTJOBTYP SUMMARYOPS8/21/2022REPAIR WELLDRIFT TBG W/17' X 2.625''DMY TOOLS, TAG @ 9513' RKB (EST 74' OF FILL). READY FOR E-LINE8/31/2022REPAIR WELLRUN 1: PERFORM BAKER MICROVERT LOG FROM 9289' - SURFACE (UNABLE TO PASS NIPPLE AT 9289' RKB). RUN 2: PERFORM READ 24 ARM CALIPER LOG FROM 9350 - SURFACE. JOB IS COMPLETE9/10/2023REPAIR WELLRUN D&D HOLEFINDER TO IDENTIFY DEPTH OF TBG INTEGRITY ABOVE KNOWN HOLES. GOT A GOOD TEST @ 5207' SLM, FAILURE @ 5271' SLM. IN PROGRESS9/11/2023REPAIR WELL PULL DMY FROM STA #6 @ 9242'RKB. E-LINE UP NEXT.9/18/2023REPAIR WELLPUMP 90 BBLS DIESEL WHILE RIH TO FLUID PACK TBG. SET 3.5" NINE ENERGY MILL E-Z COMPOSITE BRIDGE PLUG MID-ELEMENT AT 9285'. LRS PERFORMED 25 BBL CIRCULATION TEST PUMPING DIESEL DOWN TBG TAKING RETURNS UP IA AT 2 BPM, 1700 PSI. JOB COMPLETE, READY FOR COIL1/2/2025REPAIR WELLCOP decided no longer wants to proceed with IA cement. Email notify Victoria Leopp.2T-19 IA Cement Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 9,513.0 2T-19 8/21/2022 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set CBP 2T-19 9/18/2023 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 12/8/2010 ninam NOTE: LDL FOUND LEAK @ 7444' ELMD 7/17/2009 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 40.0 121.0 121.0 62.58 H-40 WELDED SURFACE 9 5/8 8.68 39.9 3,722.0 2,872.4 40.00 L-80 BTC PRODUCTION 7 6.28 38.5 9,821.4 6,167.5 26.00 L-80 BTC-mod Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 36.7 Set Depth … 9,359.4 Set Depth … 5,826.8 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-abm ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 36.7 36.7 0.00 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500 500.6 500.5 0.85 NIPPLE 3.850 CAMCO DS NIPPLE CAMCO DS 2.812 1,969.0 1,895.9 36.34 GAS LIFT 5.620 MERLA TMPD MERLA TMPD 2.920 4,410.0 3,225.7 57.83 GAS LIFT 5.620 MERLA TMPD MERLA TMPD 2.920 6,032.6 4,014.0 60.36 GAS LIFT 5.620 MERLA TMPD MERLA TMPD 2.920 7,414.6 4,708.7 59.92 GAS LIFT 5.620 MERLA TMPD MERLA TMPD 2.920 8,541.1 5,317.5 56.39 GAS LIFT 5.620 MERLA TMPD MERLA TMPD 9,242.8 5,748.7 48.98 GAS LIFT 5.960 MERLA TPDX MERLA TPDX 2.920 9,289.6 5,779.6 48.27 NIPPLE 4.540 CAMCO W-1 Selective Landing Nipple CAMCO W-1 Selectiv e 2.812 9,297.7 5,785.0 48.08 SEAL ASSY 4.750 BAKER KBH-22 Anchor Seal Assy BAKER KBH-22 3.000 9,298.6 5,785.6 48.06 PACKER 5.750 BAKER SAB PACKER BAKER SAB 4.000 9,311.9 5,794.4 47.75 NIPPLE 4.540 CAMCO D NIPPLE CAMCO D 2.750 9,327.1 5,804.7 47.40 LOCATOR 3.500 BAKER GBH-no seal BAKER GBH 3.000 9,328.1 5,805.4 47.38 PACKER 5.875 BAKER FB-1 BAKER FB-1 4.000 9,331.4 5,807.6 47.30 SBE 5.062 BAKER PACKER *FAILED* BAKER 4.000 9,340.7 5,814.0 47.09 SBE XO 5.563 BAKER SBE XO 3.500 9,349.4 5,819.9 46.87 NIPPLE 4.540 CAMCO D NIPPLE (Unuseable for TBG P/T) NO GO CAMCO D 2.795 9,358.5 5,826.2 46.64 SOS 3.500 BAKER SHEAR OUT SUB. ELMD TTL @ 9350' during PERF REC on 06/03/95 BAKER 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,610.0 4,301.0 59.51 LEAK IDENTIFY POSSIBLE TBG LEAK WITH RELAY 1/1/2018 0.000 7,429.0 4,715.9 60.27 LEAK - TUBING Relay identified leak just above Weatherford patch @ 7436' RKB. Leak between patch top @ 7436 & where spinner top was @ 7425' RKB. 9/6/2021 2.990 7,434.0 4,718.4 59.95 LEAK FOUND LEAK TO BE @7434' BELOW GLM 7/16/2009 0.000 9,284.5 5,776.2 48.38 TUBING PLUG 3-1/2" NINE ENERGY MILL E- Z COMPOSITE BRIDGE PLUG MID-ELEMENT AT 9285' RKB, OAL 1.3' NINE ENERG Y MILL E-Z N/A 9/18/2023 0.000 9,653.0 6,040.3 41.38 FISH 20' PERF gun Lost in rathole; Guns appeared to not have fired; SEE WSR 6/3/95 6/3/1995 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 1,969.0 1,895.9 36.34 1 GAS LIFT GLV BK 1 1,307.0 5/22/2021 3:00 0.188 4,410.0 3,225.7 57.83 2 GAS LIFT GLV BK 1 1,289.0 5/22/2021 6:30 0.188 6,032.6 4,014.0 60.36 3 GAS LIFT OV BK 1 0.0 9/6/2021 0.188 7,414.6 4,708.7 59.92 4 GAS LIFT DMY BK 1 0.0 2/4/2007 5:00 0.000 8,541.1 5,317.5 56.39 5 GAS LIFT DMY BK 1 0.0 1/30/2007 0.000 9,242.8 5,748.7 48.98 6 GAS LIFT OPEN 1 1/2 0.0 9/11/2023 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,435.0 9,455.0 5,879.6 5,893.9 C-4, UNIT B, 2T- 19 5/17/1998 6.0 APERF 60° Phasing; 2 1/2" HC 9,500.0 9,542.0 5,926.5 5,957.4 A-4, A-3, 2T-19 6/3/1995 6.0 IPERF 90° Phasing; (+/-) 45° from lowside; 2 1/8" Enerjet 9,500.0 9,515.0 5,926.5 5,937.5 A-3, 2T-19 6/16/1995 2.0 RPERF 0° Phasing; Orientated 90° CCW; 2 1/8" Enerjet 2T-19, 1/8/2024 12:56:46 PM Vertical schematic (actual) PRODUCTION; 38.5-9,821.4 FISH; 9,653.0 APERF; 9,568.0-9,588.0 APERF; 9,515.0-9,535.0 IPERF; 9,500.0-9,542.0 RPERF; 9,500.0-9,515.0 APERF; 9,435.0-9,455.0 PACKER; 9,328.1 PACKER; 9,298.6 TUBING PLUG; 9,284.5 GAS LIFT; 9,242.7 GAS LIFT; 8,541.1 LEAK; 7,434.0 LEAK - TUBING; 7,429.0 GAS LIFT; 7,414.6 LEAK; 6,610.0 GAS LIFT; 6,032.6 GAS LIFT; 4,410.0 SURFACE; 39.9-3,722.0 GAS LIFT; 1,969.0 NIPPLE; 500.6 CONDUCTOR; 40.0-121.0 KUP PROD KB-Grd (ft) 47.69 RR Date 5/28/1995 Other Elev… 2T-19 ... TD Act Btm (ftKB) 9,845.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032021400 Wellbore Status PROD Max Angle & MD Incl (°) 62.59 MD (ftKB) 5,375.00 WELLNAME WELLBORE2T-19 Annotation Last WO: End DateH2S (ppm) 100 Date 12/14/2019 Comment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,515.0 9,535.0 5,937.5 5,952.2 A-3, 2T-19 6/13/1995 4.0 APERF 0° Phasing; Oriented (+/-) 90° from lowside; 2 1/8" Enerjet 9,568.0 9,588.0 5,976.8 5,991.7 A-2, 2T-19 2/5/2003 6.0 APERF 2.5" HSD 2506 PJ NMX, 60° phase 2T-19, 1/8/2024 12:56:46 PM Vertical schematic (actual) PRODUCTION; 38.5-9,821.4 FISH; 9,653.0 APERF; 9,568.0-9,588.0 APERF; 9,515.0-9,535.0 IPERF; 9,500.0-9,542.0 RPERF; 9,500.0-9,515.0 APERF; 9,435.0-9,455.0 PACKER; 9,328.1 PACKER; 9,298.6 TUBING PLUG; 9,284.5 GAS LIFT; 9,242.7 GAS LIFT; 8,541.1 LEAK; 7,434.0 LEAK - TUBING; 7,429.0 GAS LIFT; 7,414.6 LEAK; 6,610.0 GAS LIFT; 6,032.6 GAS LIFT; 4,410.0 SURFACE; 39.9-3,722.0 GAS LIFT; 1,969.0 NIPPLE; 500.6 CONDUCTOR; 40.0-121.0 KUP PROD 2T-19 ... WELLNAME WELLBORE2T-19 1 O'Connor, Katherine From:Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent:Thursday, January 4, 2024 8:42 AM To:O'Connor, Katherine Cc:Hobbs, Greg S Subject:[EXTERNAL]RE: 2T-19 IA Cement Change Request CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Katherine, If work was complete on the sundry, please submit a 10-404. This will document the results of the holeĮnder and determining that the holes were shallower than previously expected and the reasons for canceling the remainder of the sundry. Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 From: O'Connor, Katherine <Katherine.OConnor@conocophillips.com> Sent: Tuesday, January 2, 2024 2:46 PM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: RE: 2T-19 IA Cement Change Request Hi Victoria AŌer evaluaƟng the uƟlity of the well at year end, and discussing our comfort with bringing cement that high in an annulus, COP has decided not to proceed with the IA cement job. The work that has been completed was se ƫng a plug at 9285’ KB and running a D&D holeĮnder & determining there were holes shallower than previously known. Because of those holes, we would have had to bring cement up higher than originally planned (see email request sent 9/18/23). Since none of the current that has been done would have required a sundry, wondering if we should just cancel the IA cement sundry 323-201 or submit a 404? Thank you Katherine O’Connor Katherine O’Connor CPF2 Interventions Engineer CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 907-263-3718 (O) 214-684-7400 (C) From: O'Connor, Katherine Sent: Monday, September 18, 2023 10:37 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: 2T-19 IA Cement Change Request Hi Victoria In our pre-cement tesƟng we found a hole shallower than expected, somewhere below 5207’ KB (it was found with DND holeĮnder). The original planned top of cement was 6100’ KB. Conoco’s request is to bring TOC up to 4600’ KB. Thanks, Katherine O’Connor CPF2 Interventions Engineer 907-263-3718 (O) 214-684-7400 (C) Surface Loc: ADL0025569 MDG 4/10/2023 VTL 7/19/2023 X DSR-4/6/23 10-404 TPI & BHL: Submit CBL and interpretation(TOC) to AOGCC as soon as available. GCW 07/19/2023JLC 7/19/2023 07/20/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.07.20 00:07:52 -05'00' RBDMS JSB 072023 C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-08-31_21095_KRU_2T-19_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21095 KRU 2T-19 50-103-20214-00 Caliper Survey w/ Log Data 31-Aug-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:195-026 T36972 Kayla Junke Digitally signed by Kayla Junke Date: 2022.09.07 09:52:24 -08'00' 19SO2 � WELL LOG TRANSMITTAL #904531718 2 9 3 6 To: Alaska Oil and Gas Conservation Comm. June 14, 2018 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED JUN 202018 AOGCC RE: Leak Detect Log and Packer Set Record: 2T-19 Run Date: 01/01/2018 and 03/04/2018 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRSANC@halliburton.com 2T-19 Digital Data in LAS format, Digital Log file 1 CD Rom 50-103-20214-00 Leak Detect Log and Packer Set Record 1 Color Log-each 50-103-20214-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 SCANNED JUN ZU Office: 907-275-2605 FRS_ANC@halliburton.com Date: COOZON / Signed: _ L- // • STATE OF ALASKA 0 MAR 0 8 2018 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AOG C 1.Operations Abandon LJ Plug Perforations U Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend H Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑✓ Re-enter Susp Well❑ Other: _tbg patch_ ❑J 2.Operator ConocoPhillips Alaska, Inc 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development 0 Exploratory ❑ 195-026 3.Address: P.O.Box 100360 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage AK 99510 50-1032021400 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25568 KRU 2T-19 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 9821 feet Plugs measured n/a feet true vertical 6168 feet Junk measured 9653' feet Effective Depth measured 9526' feet Packer measured 9299 feet true vertical 5946' feet true vertical 5786 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 81' 16" 121' 121' Surface 3682' 9-5/8" 3722' 2872' Intermediate Production 9783' 7" 9781' 6168' Liner Perforation depth Measured depth 9435-9588 feet True Vertical depth 5880-5992 feet Tubing(size,grade,measured and true vertical depth) 3.5 L-80 9359'MD 5827'TVD Packers and SSSV(type,measured and true vertical depth) Packer Baker SAB Pkr 9299'MD 5876'TVD No SSSV Nipple CAMCO DS 501'MD 501'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): n/a Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: n/a n/a n/a n/a n/a Subsequent to operation: n/a n/a n/a n/a n/a 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory ❑ Development H Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil E Gas H WDSPL H Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ H WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: n/a Authorized Name: Kelly Lyons Contact Name: Kelly Lyons/Jan Byrne Authorized Title: Well Integrity Supervisor Contact Email: n1617@coj.com Authorized Signature: Date:3-6-18 Contact Phone: 659-7224 VTi- 3/14, 115 Form 10-404 Revised 4/2017 /'mac t;: (filqqee Submit Original Only t.) -i 3 ` V Iv,11 2'10 g S i ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 March 6, 2018 Commissioner Hollis French Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner French, Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. Development KRU well 2T-19 (PTD 195-026). The report is for a tubing patch that was set to repair a leak above the packer. Please call Jan Byrne or myself at 659-7224 if you have any questions. Sincerely, 4- Kelly Lyons Well Integrity Supervisor Attachments • • Date Event Summary 10/22/17 (SUB) MIT-OA PASS TO 1800 PSI /TIFL FAIL ( DUE TO PRESSURE INCREASE AND INFLOW Initial T/I/O = 240/1225/740. OA FL NS. IA FL 5851' (182' above St#3 OV @ 6033) Bled OA to 470 psi in 14 min at a reduced rate (gas). SI multiple times to allow gas to break out. Pressured up OA to 1800 psi with 0.75 bbl of diesel. Start T/I/O = 260/1060/1800 15 min T/I/O = 250/1125/1690 (-10/+65/-110) Repressured OA to 1800 psi with —1 gal of diesel. Start T/I/O = 255/1140/1800 15 min T/I/O = 260/1175/1745 (+5/+35/-55) 30 min T/I/O = 245/1210/1705 (-15/+35/-40) Repressured OA to 1800 psi with —1.2 gal of diesel. Start T/I/O = 255/1220/1800 15 min T/I/O = 250/1245/1760 (-5/+25/-40) 30 min T/I/O = 250/1250/1740 (0/+5/-20) 45 min T/I/O = 260/1245/1730 (+10/-5/-10) Pass Bled OA to 400 psi in 4 min (liquid). T/I/O = 260/1245/400 SI the WV and double blocked the AL line. Stacked out the T x IA in 60 min. T/I/O = SI 1125/1150/450. IA FL @ 5116' (735' inflow). Bled the AL line to 300 psi. Bled the IA to 450 psi in 60 min. IA FL @ 3678' (1438' inflow). T FL @ 5227'. SI for monitor: Start T/I/O = SI 1175/450/440 15 min T/I/O = SI 1175/500/440 (0/+50/0) IA FL @ 3312' (366' inflow) T FL @ Same Location 30 min T/I/O = SI 1175/550/440 (0/+50/0) IA FL @ 3018' (294' inflow) T FL @ 5206' (21' inflow) Final T/I/O = SI 1175/550/440 11/20/17 IDENTIFY APPARENT TBG LEAK WITH HOLEFINDER BETWEEN 6019' &6059' RKB. PULLED OV @ 6032' RKB (CHECK APPEARS GOOD) & REPLACED WITH NEW OV IN KIND. PULLED GLVs @ 4410' & 1969' RKB. SET NEW GLVs @ 4410' & 1969' RKB (GOOD P.T. ON TBG). PULLED TEST TOOL IN PATCH @ 7433' RKB. JOB COMPLETE. 11/23/17 (SUB) RE-TIFL POST SL (FAIL DUE TO PRESSURE INCREASE AND IA INFLOW) Initial T/I/O = 260/1175/570. IA FL @ 6377' (344' below St#3 OV @ 6033') SI the WV and double blocked the AL line. Stacked the T x IA in 40 min to T/I/O = SI 980/980/520. IA FL @ Same location Bled the AL line. Bled the IA to 410 psi in 60 min. IA FL @ 5324' (1053' inflow). T FL @ 3997' Start T/I/O = SI 925/410/490 15 min T/I/O = SI 950/420/490 (+25/+10/0). 30 min T/I/O = SI 950/430/490 (0/+10/0). IA FL @ 5015' (309' of inflow). T FL @ Same location. Final T/I/O = SI 950/430/490 • 12/30/17 SET 3" TTS TEST TOOL IN UPPER PACKER @ 7433' RKB. ATTEMPT MITT ( IA TRACKING )WITH HOLE FINDER OBTAIN 2500 PSI MITT ABOVE OV @ 5966' SLM. CMIT TBG x IA 2500 PSI ( PASS ) IN PROGRESS. PERFORM CMIT START= 2825/2605/610/150 15 MINS = 2810/2560/610/150 30 MINS = 2810/2545/610/150 PASS 01/01/18 PULLED OV @ 6033' RKB & REPLACED IN KIND. ATTEMPT MITT& IA TRACKING. PERFORM LDL & IDENTIFY POSSIBLE TBG LEAK©6610' RKB. ATTEMPT TO RELOG LEAK AND UNABLE TO ACTIVATE LEAK AGAIN. IN PROGRESS. 01/06/18 24-ARM CALIPER LOG: LOG REPEAT PASS OVER INTERVAL 7425' -7240', LOG MAIN PASS OVER INTERVAL 7425' TO SURFACE 03/04/18 SET LOWER 2.72" PIIP PACKER MID ELEMENT @ 6627' RKB. SET 3" TTS TEST TOOL IN LOWER PACKER; CMIT TBG x IA TO 2500 PSI ( PASS ) IN PROGRESS. BEGIN CMIT. INITIAL T/I/O/FL = 785/700/540/140 LRS PT TBG/IA TP 2500 PSI W/3.8 BBLS START = 2650/1600/570/140 15 MINS = 2600/2550/570/140 30 MINS = 2580/2525/570/140 45 MINS =2560/2510/570/140 RETEST W/ .1 BBLS START = 2660/2600/570/140 15 MINS =2650/2595/570/140 30 MINS = 2650/2595/570/140 PASS 03/05/18 SET UPPER 2.72" PIIP PATCH ASSEMBLY( OAL = 23' ) MID ELEMENT @ 6605' RKB. SET 3" TEST TOOL IN UPPER PACKER @ SAME. MIT TBG TO 2500 PSI ( PASS ) CMIT TBG x IA 2500 PSI ( PASS ) PULLED TEST TOOL. JOB COMPLETE. INITIAL T/I/O/FL = 760/700/550/140 LRS PT TBG TO 2500 PSI W/ .5 BBLS DSL. START= 2525/730/550/140 15 MINS = 2435/730/550/140 30 MINS = 2400/730/550/140 ( PASS ) RU TO IA. INITIAL T/I/O/FL =2350/730/550/140 HAVE TO TEST MULTIPLE TIMES TO GET PASSING TEST START= 2725/2610/590/140 15 MINS = 2725/2610/590/140 30 MINS = 2725/2610/590/140 PASS Executive A 22'TTS retrievable tubing patch was installed to cover a leak at 6610'. Integrity of the patch Summary was confirmed with MITT/CMIT pressure tests. • . i KUP PROD • 2T-19 ConocoPhiIIips Well Attributes Max Angle&MD TD Wellbore APIIUWI Field Name Wellbore Status II ncl(°I MD(ftKB) Act Btm(ftKB) Alaska,hi:. 501032021400 KUPARUK RIVER UNIT PROD 62.59 5,375.00 9,845.0 'on°°° Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ... SSSV:NIPPLE 25 1/28/2016 Last WO: 47.69 5/28/1995 2T-19,3/6/2018 10:15:19 AM Last Tag Vertical schematic(actual) Annotation Depth(MB) End Date Last Mod By Last Tag:RKB 9,574.0 4/19/2017 pproven HANGER:36.7 --11- Last Rev Reason Annotation I End Date 'Last Mod By Rev Reason:Patch installation 3/5/2018 famaj 11I ri .a. Casing Strings Casing Description00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 40.0 121.0 121.0 62.58 H-40 WELDED Casing Description 01)(in) ID(in) Top(kKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread as-AZCONDUCTOR;40.0-121.0 SURFACE 95/8 8.679 39.9 3,722.0 2,872.4 40.00 L-80 BTC Casing Description 'OD(in) ID(in) Top(ft613) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 38.5 9,821.4 6,167.5 26.00 L-80 BTC-mod NIPPLE;500.6 • Tubing Strings aTubing Description I String Ma...I ID(in) 'Top(ftKB) 'Set Depth(ft..f Set Depth(ND)(...I WI(Ib/ft) I Grade 'Top Connection TUBING 31/2 2.992 36.71 9,359.41 5,826.8 9.30 L-80 EUE-abm GAS LIFT;1,969.0 Completion Details Top(ND) Top Incl Nominal Top(ftKB) MB) ('1 Item Des Corn ID(in) 36.7 36.7 0.00 HANGER FMC GEN IV TUBING HANGER 3.500 500.6 500.5 0.85 NIPPLE CAMCO DS NIPPLE 2.812 SURFACE;39.9-3,722.0-. A. 9,289.6 5,779.6 48.27 NIPPLE CAMCO W-1 Selective Landing Nipple 2.812 9,297.7 5,785.0 48.08 SEAL ASSY BAKER KBH-22 Anchor Seal Assy 3.000 GAS LIFT;4,410.0-' ci 9,298.6 5,785.6 48.06 PACKER BAKER SAB PACKER 4.000 9,311.9 5,794.4 47.75 NIPPLE NIPPLE 4.000 GAS LIFT;6.032.6 ' ® 9,327.1 5,804.7 47.40 LOCATOR BAKER GBH-no seal 3.000 4 9,328.1 5,805.4 47.38 PACKER BAKER FB-1 4.000 PATCH;6,605.0 9,331.4 5,807.6 47.30 SBE BAKER PACKER`FAILED` 4.000 PATCH;6.627.0 9,340.7 5,814.0 47.09 SBE XO BAKERSBEXO 3.500 9,349.4 5,819.9 46.87 NIPPLE CAMCO D NIPPLE(Unuseeble for TBG P/T)NO GO 2.795 9,358.5 5,826.2 46.64 SOS BAKER SHEAR OUT SUB.ELMD TTL 0219350'during PERF REC 2.992 GAS LIFT;7,414.6-.-✓ on 06/03/95 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) PACKER;7,433.0 , Top IND) Top Incl • Top(ftKB) (ftKB) ("I Des Com Run Date ID lin) PATCH;7,435.0 6,605.0 4,298.5 59.57 PATCH 2.72"P2P#CPP35128,17.5'SPACER PIPE,SNAP 3/5/2018 1.625 PACKER;7,457.0- LATCH#CPAL35077.23'OAL,1.625"ID. .1. i' 6,627.0- 4,309.7 59.26 PATCH 2.72"P2P#CPP35155.4'OAL,1.625"ID 3/4/2018 1.625 7,433.0 4,717.9 60.02 PACKER WEATHERFORD 13DR ER UPPER PACKER 12/7/2009 1.750 GAS LIFT;8,541.1 7,435.0 4,718.9 59.89 PATCH PATCH-SPACER PIPE,SLIP STICK 8 SNAP LATCH 12/7/2009 1.750 ASSEMBLY 7,457.0 4,730.1 59.28 PACKER WEATHER 13CR ER LOWER PACKER 11/27/200 1.750 GAS LIFT;9.242.7 I. 9 9,653.0 6,040.3 41.38 FISH 20'PERF gun Lost in rathole;Guns appeared to not 6/3/1995 have fired;SEE WSR 6/3/95 Perforations&Slots NIPPLE;9,289.6 Shot Den Top(ND) atm(TVD) (shots/ft Top(ftKB) Btm(969) (ftKB) (kKB) Zone Date ) Type Com SEAL ASSY;9,297.7 9,435.0 9,455.0 5,879.6 5,893.9 C-4,UNIT B,2T 5/17/1998 6.0 APERF 60 deg Phasing;2 1/2"HC PACKER;9,298.6 '::: -19 9,500.0 9,515.0 5,926.5 5,937.5 A-3,2T-19 6/16/1995 2.0 RPERF Zero Deg.Phasing; NIPPLE;9.311.9 Orientated 90 deg.CCW 2 _ 1/8"Enerjet 9,500.0 9,542.0 5,926.5 5,957.4 A-4,A-3,2T-19 6/3/1995 6.0 IPERF 90 Deg.Phasing;(+/-)45 LOCATOR;9,327.1 deg from lowside;2 1/8" Enerjet PACKER;9,328.1 9,515.0 9,535.0 5,937.5 5,952.2 A-3,2T-19 6/13/1995 4.0 APERF Zero Deg.Phasing;Oriented SBE;9.331 4 .:r: (+/-)90 deg from lowside;2 1/8"Enerjet CI- 9,568.0 9,588.0 5,976.8 5,991.7 A-2,2T-19 2/5/2003 6.0 APERF 2.5"HSD 2506 PJ NMX,60 deg phase NIPPLE;9,349.4 Mandrel Inserts St ati SOS;9558.5al on N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) MKS) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com T) 1,969.0 1,895.9 MERLA 'TMPD 1 GAS LIFT GLV BK 0.188 1,271.0 11/20/2017 2 4,410.0- 3,225.7 MERLA TMPD 1 GAS LIFT GLV BK 0.188 1,256.0 11/20/2017 RPERF;9,435.0.9,455.0 -' 3 6,032.6 4,014.0 MERLA TMPD 1 GAS LIFT OV BK 0.250 0.0 11/20/2017 4 7,414.6 4,708.7 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 2/4/2007 5:00 RPERF;9500.0-9.515.0- 5 8,541.1 5,317.5 MERLA TMPD ' 1'GAS LIFT 'DMY BK 0.000 0.0 1/30/2007 !PEW 9,500.0-9,542.01 --f--. 6 9,242.8 5,748.7 MERLA TPDX 11/2'GAS LIFT 'DMY RM 0.000 0.0 1/30/2007 APERF;9515.0-9535.0 Notes:General&Safety _ End Date Annotation 7/17/2009 NOTE:LDL FOUND LEAK(7444'ELMD 12/8/2010 NOTE:View Schematic w/Alaska Schematics.° APERF;9,568.0-9,588.0- i-. FISH;9.653.0-.4 1 PRODUCTION;38.5-9,821.4 A • • V AP v I- 4 tr; 1 O X 6 O L C 6 ( in _i W (j 4- -0 (0 4 ' CD N z .1 O U N E > i -0 (a +, 0 N Q) '- m C4' a C o >, O ill r a O O• 2 ro O vN To c tt _cuo o Cr ma CO a) co co co co ?< C�'� c c c c co V) ca 1C1 �c R ca 7 t_ c c 0 Z . `' V• -0 R3 0 +- 41 E \ o 2 2 > -O Q) • O C i a N O N u 0 0 0 C L Q) 0 L ill J J J J J J IDA C ;r_- O Y': W W W W W W U `� In Q) L 1--. LL LL LL LL LL LL +, U U a) a a _0 > L Q1 �" ZZ ZZZ Z U O 0 i" Q W LL LL LL LL LL LL K -0 C > LC u _ L. C R '}"', Q) (0 C a) _c 0 Q E a) 0 v .) Co� Q coo ~ p ' ' > (6 a o 0 c u. Q a) a 0 a U �j� .•. �y LL LL y y LL I.L. i.c ' CI <_ a 0 0 a a O= Ce 0 v Ln U W •Q 2 5r \ v COaS v uVi'' 2 E CT) ( 4101 I f' ._.914, La P X CC Lx LY LY CC £ W W W W W W 3 ° z Y Y Y Y Y O _ ' > > > > > > aLLI Q Q Q Q Q Q " • LL a a a a a a a MDDDM C m o� 0 Y Y Y Y Y Y •LIULam ++ r co rn co X n — 00 U0,1 OA C K 0 0 0 0 0 0 N 0 It o o o cu a3 O Malt _ - t` a u_ n 0 O + V >- g } } d a a Lu 00000p C 0 N (6 FCW —� 4- < (0 O 0OOO (0 IX N a o Ln a t. i:4. EI !i1 O M N N M r O h. M M O O 0.701 0 U N N N N N N N ` _0 n T 01 M M a) T d v. R NNOONN •i 01 O O O O 3 O O O O O O 0 a) C C N N N rn a u, o Cl3 au Q▪ i I- I I I I I I I I I _ I _ Li '; • W Y p _...:..:, :. ct C C L al 3 a �O Z N O Q N p N 0/ O C o Q1 +' to Ot .., 00 m Z _ E ar 4 = E2 v) (Lot. ,, 6 — f- I' -� m E (o ` a C d Q O N J T N N Z N (0 0' t ' '-1 t r W C +-. (d cn O C J a c • as C O) ra Q � H a a s S . kq 5- 02--(0 WELL LOG TRANSMITTAL# To: Alaska Oil and Gas Conservation Comm. December 17, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 DATA LOGGED g /2,1/201(4 M. K.BENDER RE: Multi Finger Caliper(MFC): 2T-19 Run Date: 11/17/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2T-19 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20214-00 SCORED f `: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: MALLozek ..4,444teel, ConocoPhillips Alaska 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 Commissioner Dan Seamount: ~~ ~i O 1~ ,., ~ q A o a ~ ~~~ a ~1~ t rr z ~~ ~~~' 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 30t", 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 ~Q ~~ ~r own 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" Na 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 n/a 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 • • REcEIVED STATE OF ALASKA DEC 1 .1 2009 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIQM Oil & Gas Cons. Commission 1.Operations Performed: Abandon ❑ Repair Well 0 Plug Perforations ❑ Stimulate ❑ OthAnrhnrl • 11 Set Patch Alter Casing 1:1 Pull Tubing [3 Perforate Perforate N Pool ❑ Waiver 11 Time Extension Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter spended Well ❑ 2. Operator Name: 4. Well Class Before Work: Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ 195-026/ 3. Address: Stratigraphic ❑ Service ❑ API Number: P. O. Box 100360, Anchorage, Alaska 9951 C 50- 103 - 20214-00 7. Property Designation (Lease Number): Well Name and Number: ADL 25568 2T -19 9. Field /Pool(s) f Kuparuk River �Y1'l 10. Present Well ConcAtion Summary: Total Depth measured ` 9845' feet Plugs (measured) feet \ V 1 0 's true vertical 61Sr� feet Junk (measured) feet Effective Depth measured feet Packer (measured) feet true vertical feet (true vertical) feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 79 16" 121' 121' 1640 630 SURFACE 3,680' 9-5/8" 3,722' 2872' 5750 3090 PRODUCTION 9,779 7" 9,821' 616T 7240 5410 DF y I 20 Perforation depth: Measured depth: 9435 -9455, 9500 -9542, 9568 -9588 true vertical depth: 5880 - 5894, 5927 -5957, 5975 -5991 Tubing (size, grade, measured and true vertical depth) 3 -1/2 ", 9.3 ppf, L -80, 9359' MD, 582T TVD WFT 1.75" ID ER Patch 7434' -7460' Packers & SSSV (type, measured and true vertical depth) Packer = Baker "SAB" at 9299 MD, 5785 TVD SSSV = Cameo "DS" Nipple at 501' MD, 501' 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 I Water - Bbl Casing Pressure Tubina Pressure Prior to well operation Subsequent to operation — 13. Attachments . Well Class after work: Copies of Logs and Surveys run _ Exploratory ❑ Development Service ❑ Daily Report of Well Operations X Well Status after work: Oil Gas ❑ WDSPL ❑ GSTOR❑ WAG❑ GINJ ❑ 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: Contact Martin Walters / Brent Rogers Printed Name Martin Walters Title Problem Wells Supervisor Signature Phone 659 -7224 Date 12/13/2009 Form 10-404 Revised 7/2009 "�VVV /z /� Dy �v( Submit Original Only 0 2T -19 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/27/2009 SET WEATHERFORD LOWER 13 CR ER PACKER CENTER ELEMENT AT A DEPTH OF 7460'. SL TO SET UPPER ASSY. 12/7/2009 SET JJ TIE BACK RECEPTACLE, SPACER PIPE, SNAP LATCH ASS'Y @ 7460' RKB. TESTED TIE BACK ASS'Y 1500 PSI, GOOD. SET UPPER ER PACKER (7434' RKB), SPACER PIPE, AND JJ TIE BACK STINGER @ 7441' RKB. DRAW DOWN TEST ON IA, GOOD. COMPLETE. 12/1212009 Re -TIFL- passed; Initial T /I /0= 250/1200/500; Shut in WH and shot initial IA FL @ 5456ft. (577ft. above OV) Stacked out T with LG T /I /0= 1100/1100/400; Bled IA shot second IA FL@ same location. Final T /1 /0= 1120/370/300 Summary Set 1.75" ID Weatherford ER Patch from 7434' -7460' RKB. Conducted passing TIFL WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 2T-19 Run Date: 11/27/2009 December 1, 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-19 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20214-00 ~!~r~E~ J~I~ ~~ ~f ~~~C 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@halliburton. com ~. ~ ~, t , u t, ~~" r' ~ a ~., ~ E Date: ~,~~ E, fk ~g~~ i;4~? ~ ;°FIl~~i~rt ~$K~ Oi! ~ ~s~ fors. !~5 ~~~ ~ 9 p 3 ~ Signed: WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 21, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detection Log: 2T -19 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 -19 Digital Data in LAS format 1 CD Rom 50- 103 20214 -00 :.ANNE ti J 2 7 2009 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline Perforating C j Attn: Rafael Barreto /95 J 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 273 -3527 Fax: 907 273 -3535 rafael.barr- *O ib ,®n.G Date: NOV 0 5 2009 Signed: laska 0 Gas Con Gom, Gornni„sicr. AnchorNe ~ ~ ~,`_ , ~ ~ , ~ ---~__ ~~;, , .~, ~~ ~~~~~ ~ .ao~v~ ~iAC~vesaq~ Se~~ric~, ~~_ To: ~10GCC 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/ MTTj The technical data listed below is being submitted herewith. Please acknowledge receip~ by returning a signed copy of this transmittal letter to the following : BP Exploratian (Alaskaj, lnc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and i~ ;T ' r ;~ ~ ~ ~ ? ~ / ' /"`~ ProActive Diagnostic Services, (nc. O~CI d o~ Attn: Robert A. Richey 130 West International Airport Road Suite C ~,, ~,g~~a~.g.. , ~:_i;; .~ <? 7~~~ Anchorage, AK 99518 ' ~~J~"~° °'„ "°^~"`" Fax (907) 245-8952 1~ Caliper Report 21-JuE09 2T-19 2) Signed : Print Name: ,.. ln7 5~- 0~ 1 Report / EDE 50-1 d3-2021400 Date : _ _ PROACTIVE DIAGNOSTtC SERVICES, 1NC., 130 W. lNTERNATIONAL AIRPORT RD SUITE C, l~NCHORAGE, A6C 99518 PHOruE: (907~245-8959 Feuc: (907)245~8952 ~-PflAIL : ' bVEBSITE : ' ~ t'~3~~~~ ~'.:j ~e ... ~U:~J ~~~:~~ : ~~~ C:~Documen6 and Settings\OwnexlDesktop\T~ansmit_BP.doc~; ~v • • Memo~- Mul~i-~inger Caliper S Log Results ~ummary ~; Campany: ConocoPhillips Alaska, Inc. Wetf: 2T-19 Log Date: July 21, 2009 Field: Kuparuk Log No. : 10576 State: A(aska Run No.: 1 API No.: 50-103-20214-~0 Pipe1 Desc.: 3.5" 9.3 Ib. L-80 ABM-EUE Top Log Intvl1.: Surtace Pipe1 Use: Tubing Bot. ~og Intvl1.: 9,308 ~t. (MD) Inspection Type : Patch Candidacy /nspection CQMMENTS : This caliper data is tied into the W-1 Nipple @ 9,290' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing with respect to corrvsive and mechanical damage to determine patch viability after an LDL (07-16-09) indicated a leak at 7,~444'. With the exception of a 729~0 wall penetration recorded at 7,442', the caliper recordings indicate the 3.5" tubing is in good condition. No other significant wall penetrations, areas of cross-sectional wall loss, or I.D. restrictions are recorded throughout the tubing logged. The caliper recordings indicate slight buckling from ~3,90Q' to ~8,640'. A 3-D iog plot of the caliper recardings across the proposed patch interva! is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: Isolated pitting ( 72%) Jt. 236 @ 7,442 Ft. (MD) No other significant wall penetrations (> 189~0~ are recorded throughout the tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LC?S5: No significant areas of cross-sectional wall loss (> 6°~) are recorded throughout the tubing {ogged. MAXIMUM RECORDED ID RESTRIC710NS: Na significant I.D. restrictions are recorded throughoutthe tubing logged. ~ield Engineet: G. Etherton Analyst: C. Waldrop Witness: C. Fitzpatrick ProACtive Di~gnostic Ser~~ices, Inc. J P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281~ 565-1369 E-mail: PD.Sia~memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ~ ~ ~~ ~~ ~o ~ ~L~~~ ' • ~ .~~ PDS Multifinger Caliper 3D Log Plot , Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2T-19 Date : July 21, 2009 ' Description : Detail of Caliper Recordings Across Interval Where an LDL (07-16-09) Recorded a Leak o° so° ~so° 2~0° o° I ~~t; ^ ~~ ~~ ~oy~ ,ar 0° 90° 180° 270° 0° ' ' • ~ Correlation of Recorded Damage to Borehole Profile ~ Pipe 1 35 in (28.8' - 9304.9') Well: 2T-19 Field: Kuparuk Company: ConocoPhillips Alaska, Inc_ Country: USA Survey Date: )uly 21, 2009 ^ Approx. Tool DeviaUon ^ Approx. Borehole Profile 1 32 25 , 809 50 1590 GLM 1 ` 75 2380 100 3163 125 3942 GLM 2 15U _. - 4727 ^ ~ ~ ~ 175 5503 ;; ~ LL GLM 3 c Z 200 6290 r c ~ Q- ~ O ~ 225 7071 GLM 4 250 7859 GLM 5 2~5 8642 GLM 6 294.4 9305 0 SO 100 Darnage Prafile (% wall) / Tool Deviation (degrees) Bottom of Survey = 294.4 • • PDS Report Overview ~~, ~. Body Region Analysis Well: 2T-19 Survey Date: July 21, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 218527 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: C. Waldrop Tubing: Nom.OD Weight Grade & lrtiread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-80 ABM-EUE 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ~q, metal loss body 250 200 150 100 50 ~ 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of 'oints anal sed total = 302 pene. 0 232 69 0 1 0 loss 123 179 0 0 0 0 Damage Configuration ( body ) 10 0 isolate~l ~;onoral line ri~ hole ~ poss pitting corrosion mrrosion corrosion ible hole Number of 'oints dama ed total = 5 2 3 0 0 0 Damage Profile (°~ wall) ~ penetration body ~ rnetal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 GLM 6 Bottom of Survey = 294.4 Analysis Overview page 2 ~ PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 ABM-EUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ~LATION SHEEf 2T 19 Kuparuk ConocoPhillips Alaska, Inc. USA )u1y21, 2009 Joint No. Jt. Depth (Ft.) f'ern. ~1E,.c~~ Ilnti.) Pen. Body (Ins.) f'c~n. %, ~letal I~~s~ ~~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 29 ~~ 0.02 ~~ 1 2.92 PUP 1 32 (~ 0.03 1 ~~ 1 2.96 1.1 65 c~ 0.03 lU -1 2. 2 PUP 1.2 75 u 0.01 4 ~ 2.93 PUP 1.3 85 U 0.00 2 ~ 95 PUP 2 89 i~ 0.02 ~) ' 2.91 3 12 7 n 0.01 4 1 2.95 4 152 ~~ 0.04 I-3 1 2.95 5 184 ~~ 0.01 E~ 1 2.94 215 O 0.01 ~t 1 2.93 7 246 u 0.01 -~ 2.94 8 78 t~ 0.01 ~i 2.96 9 309 t~ 0.02 i I .93 10 340 ~~ 0.02 ~~ 2.91 11 372 ~~ 0.01 ~1 2.91 12 402 i ~ 0.01 4 2.96 13 433 u 0.02 ~1 1 2.95 14 464 U 0. 1 ~ _' 2.93 14.1 96 U 0 (1 ~ ~ 3.81 amco DS-Ni le 15 497 t1 0.01 S 1 .96 16 528 u 0 01 Z I 2.93 17 560 t~ 0.02 9 I 296 18 591 U 0.01 4 I 2.94 19 622 ~~ 0.03 1 1 I 2.94 0 653 i t 0.01 4 ' .95 21 684 i~ 0.01 4 ~ 2.94 22 716 ~~ 0.03 1 U I 2.94 23 747 i~ 0.02 ~) I 2.95 24 778 i~ 0.02 t, ' 2.95 25 809 ~~ 0.02 9 ? 2.96 6 841 (i 0.01 a 2.95 27 872 ~~ 0.01 ? I 2.94 28 904 ~ 1 0.01 5 1 2.96 29 935 t) Q01 5 < 2.96 30 96b ~) 0.02 ~l 1 2.95 31 997 U 0.01 i ' 2.96 32 1028 i~ 0.01 4 I 2.97 33 1060 i) 0.02 7 t ~ 2.97 34 1090 ~ ~ 0.03 1 I 2.96 35 1121 0 0.01 ~t I 2.95 36 1152 O 0.02 9 2.93 37 1183 i) 0.01 4 ~' 2.96 38 1215 c1 0.01 6 I .96 39 1246 U 0.01 4 1 2.96 40 1277 t~ 0.01 -1 1 2.94 41 1308 u 0.01 ~' 1 2.96 42 1340 i) 0.02 ~~ 2.96 43 1371 u 0.02 t9 2.94 44 1402 n 0.03 12 2.95 45 1434 ~~ 0.02 9 ' 2.94 ~Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TAB~ Pipe: 3.5 in 9.3 ppf L-80 ABM-EUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • -LATION SHEET 2T-19 Kuparuk ConocoPhillips Alaska, Inc. USA )uly 21, 2009 Joint No. JL Depth (Ft.) I'~~n. UF,sc~i (Ins.) Pen. Body (Ins.) f'c~n. °i~~ ~1c~i,~l I~x~ <, Min. I.D. (Ins.) Comments Damage Profile (% wall) 0 50 100 46 1465 (~ 0.02 t9 _' 2.95 47 1497 i~ 0.02 I 2.95 48 1528 ~) 0.02 ~) _' 2.95 49 1559 ~~ 0.01 -3 I 2.94 50 1590 ~ ~ 0.0 -~ ' 2.96 5 1622 t) 0.01 ~l I 2.96 52 65 ~> 0.0 ~~ 1 2.96 53 1684 (~ 0.02 ~ I 2.95 54 171 t~ 0. 1 4 I 2.96 5S 1747 c~ 0.02 ~) I .94 56 1778 l~ 0.01 5 I 2.94 57 1809 U 0.01 5 ~ 2.96 Lt De osits. 58 1841 (~ 0.01 _' 1 2.92 59 1872 i~ 0.02 '~ I 2.96 60 1904 ~! 0.02 '; ! 2.96 61 1935 U 0.02 tt 2.95 61.1 1967 ~> 0 ~~ ~~ N A GLM 1 Latch @ 3:30 62 1973 U 0. 7 ' 2.94 63 2005 ~~ 0.02 t3 1 2.96 64 2036 U 0.03 11 2 2.93 65 2067 i~ 0.03 I 1 I 2.96 66 2099 ~~ 0.02 ~~ ' 2.96 67 2130 ~~ 0.0 tl I 2.94 68 2161 ~ ~ 0.02 ~) 2.94 69 194 t~ 0. ~) ~~ 2.96 70 2225 l~ 0.03 11 I 2.95 71 2256 l~ 0.03 10 1 2.95 72 2288 ~~ 0.03 11 2 2.96 73 2319 i~ 0.01 4 2 2.96 74 2349 (~ 0.02 9 ~' 2.96 75 2380 l~ 0.02 t~ 1 2.96 76 2412 t~ 0.03 li~ ~' 2.96 77 2443 ~~ 0.04 1~1 _' 2.96 78 2475 l? 0.03 13 I 2.95 79 506 U 0.02 ~~ 2.94 80 2537 ~~ 0.03 13 2.94 81 2569 (~ 0.04 16 I 2.94 hallow rrosion. 82 2600 U 0.03 11 _' 2.93 83 2631 ~) 0.02 ~~ _' .96 84 2663 n 0.01 ~ 1 2.94 85 2694 c i 0.01 4 I 2.95 86 2725 ~~ 0.01 (~ 1 2.95 87 2756 ~~ OA2 ts 2.96 88 2788 ~1 0.02 tt I 2.95 9 2819 (a 0.02 ~) ~ 2.96 90 2850 c~ 0.02 7 ~ 2.95 91 881 u 0.02 9 ~~ 2.95 92 2913 ~~ 0.02 9 2 2.95 93 94 !? 0.02 7 1 2.95 94 2975 !'~ 0.03 12 1 2.95 ~Penetration Body Metal Loss Body Page 2 • PDS REPORTJOINTTABI. Pipe: 3.5 in 9.3 ppf L-80 ABM-EUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ~LATIQN SHEET 2T-19 Kuparuk ConocoPhillips Alaska, Inc USA July21, 2009 )oint No. )t. Depth (Ft.) I'~~n. 11~~sc~t (Irn.) Pen. Body (Ins.) f'~~n. `%> ~~lc~tal I oss ~~ Min. I.D. (Ins.) Comments Damage Pro(ilc ~~ (%wall) 0 50 1(~0 95 3006 ~~ 0.02 ~~ I 2.96 96 3037 c) 0.02 ~J _ 2.96 97 306 U 0.03 t i I 2.95 I I 98 3100 ~~ 0.03 1 U ,' 2.95 i I 99 313 U 0.03 12 -~ 2.9 100 3163 U 0.04 1 f3 ~~ 2.96 S allow corrosion. 101 3195 U 0.0 9 ~~ 2.9 102 3226 1) 0.04 15 ? 2.93 103 3256 0 0.01 ~ 2.9 Lt. De osits. 104 3287 U 0.02 ~~ 2.92 105 3318 ~? 0.01 4 ~ i .96 106 350 ~~ 0.02 9 1 .94 107 3381 ~~ 0.01 6 I 2.94 108 3413 t~ 0.01 6 I 2.95 109 3443 U 0.02 ~i ~._' 2.96 110 3475 O 0.03 It~ I 2.94 111 3505 U 0.01 > 2.94 112 3536 (1 0 01 (~ ~ 2.95 113 3568 t) 0.03 11 Z 2.95 114 3599 t? 0.04 16 5 .94 Sh Ilow corrosion. 115 3630 U 0. 1 4 ? 2. 5 116 3661 U 0.02 9 i~ 2.95 117 369 U 0.02 i 1 2.95 118 3724 i) 0.02 t3 1 2.96 119 755 ~~ 0.03 I 1 ,? 2.93 120 3786 ~~ 0.01 5 ~' 2.94 1 1 3817 ~) 0.03 I 2 1 2.95 122 3848 U 0.01 (, ~~ 2.94 123 3880 l1 0. 2 `) ? 2.9 51i ht bueklin . 124 3911 (~ 0.04 14 2.95 125 3942 l1 0.02 ~l E~ 2.95 126 3973 c) 0.03 13 ? 2.96 127 4005 ~> 0.0 ~) I 2.94 128 4036 ~~ 0.03 1 1 I 2.94 129 4067 ~) 0.01 h 2 2.95 Sli ht bucklin . 130 4098 ~? 0.02 ~~ I 2.93 131 41 0 t~ 0.03 11 2.94 132 4161 l) 0.03 1~' I 2.93 133 4192 U 0.02 ') -1 2. 3 134 4220 « 0.03 I~! 2.95 135 4 5 i~ 0.02 7 ? 2.96 Sli h bucMin . 136 4285 ~} 0.03 11 ~~ 2.95 137 4316 ~.~ 0.01 6 ~~ 2.93 138 4347 ~) 0.03 1? I 2.95 139 4378 U 0.01 5 ' 2.93 139.1 4409 (~ 0 (~ t) N A GLM 2 Latch C~9 6:00 140 4416 U 0.03 I I ~ 2.93 141 4446 U 0.02 ~) (, 2.93 14 4478 O 0.02 '~ ' .97 Sli h bucklin . 143 4508 ~~ 0.02 ~) I 2.94 ('cnetration Body Metal Loss Body Page 3 • PDS REPORT JOINT TABI. Pipe: 3.5 in 93 ppf L-80 ABM-EUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ~LATION SHEET 2T-19 Kuparuk ConocoPhillips ~1laska, Inc. USA )uly 21, 2009 Joint No. Jt. Depth (FL) N~n. UF~,E~t (Ins.) Pen. Body (Ins.) Nen. °4, ~Ic•i,~l I c,~~ Min. LD. (Ins.) Comments Damage Profile (°/a wall) 0 50 100 144 4540 ~ ~ 0.0 (, ~ 2.94 145 4571 (~ 0.04 14 2.96 146 460 (~ 0.01 (~ _ 2.96 Sli ht ucklin . , 147 4633 ~? 0.03 1'1 ' 2.95 ' ~ 148 4665 U 0.02 ' I .95 ~I 149 4696 ~~ 0.02 ~ I 2.94 ~ ~ ~ 150 4727 i~ 0.03 I I _' 2.93 Sli ht buckl'n . I 151 47 9 l~~ 0.01 h ~' 2 93 ~~ 152 4789 U 0.03 1 U _ 2.94 ~ 153 4821 U 0.03 I i~ 2.94 i, 154 4852 n 0.01 5 2.93 I ~ 155 4883 u 0.03 1 1 2.93 I~ ht bucklin 156 4914 U 0.02 ~) 1 2.92 57 4946 (~ 0.03 13 ~' .91 15t3 4974 t) 0.02 ti 2.93 159 5005 U 0.0 ~~ ~l 2.93 160 5037 i) 0.0 ~~ I 2.95 Sli ht bucklin . 161 5069 ~~ 0.03 I~I _' 2 93 162 5 98 U 0.01 (~ i~ 2.92 163 5130 U 0.03 11 2.93 164 5161 ~) 0.03 11 2.93 165 5192 l~ 0.04 15 2.91 51i ht bucklin . 166 52 2 t~ 0.03 1"~ _' 2.93 167 5253 U 0.02 ~) _' 2.93 68 5284 ~~ 0.0 1 l) ~ 2.9 169 5315 ~~ 0.02 ti I 2.93 170 347 U 0. 3 1O _' 2.94 Sli ht bucklin . 171 5378 !~ 0.02 7 I 2.95 172 5409 l~ 0.03 tu ~, 2.93 173 5441 O 0.03 I1 2.93 174 5472 U 0.02 9 ~' 2.94 175 5503 U 0.04 14 2 2.95 176 5535 l1 0.03 1? ~' .93 177 5566 U 0.01 (, 4 2.92 Sli ht bucklin . 178 5597 (1 0.03 I: S i 2.92 179 5628 !) 0.03 13 ~ 2.91 180 5660 U 0. 2 9 -l 2.93 l81 5691 t~ 0.02 ~1 ' 2.92 Sli ht bucklin . 182 5722 U 0.03 lU ~ 2.93 ~ 83 5754 U 0.03 12 i 2.93 184 5785 ~ 0.03 12 2.94 185 5816 cl 0.02 ~~ 2.93 186 5845 U 0.03 1 ~ 2.94 Sli ht bucklin . 187 5876 U 0.03 I I ~~ 2.94 18 5908 U .02 ~~ ~ ~ 2.94 189 5939 O 0.03 11 i~ 2.94 190 5970 t? 0.02 ~ ' 2.94 191 6001 (1 0.03 I3 ~~ ?.96 191.1 6033 U 0 ~~ i! N A GLM 3 Latch @ 1:30 192 6039 O 0.02 ~~ 2.93 Penetration Body Metal Loss Body Page 4 • PDS REPORT JOINT TABI.. Pipe: 3.5 in 9.3 ppf L-80 ABM-EUE Well: Body Wail: 0.254 in field: Upset Wall: 0.254 in Cornpany: Nominal LD.: 2.992 in Country: Survey Date: • iLATION SHEET 2T-19 Kuparuk ConocoPhillips Alaska, Inc USA )UIy 21, 2009 )oint No. Jt. Depth (ft.) N~•n. llE,tic~i (In>.:~ Pen. Body (Ins.) Nen. ",4, 'vtc~tal Ioss °%, Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 SO 100 19 071 ~! 0.03 13 2 2.92 Sli htb ckiin . 194 6102 ~ ~ 0.02 ~i ~> 2.9 195 6133 (~ 0.03 1 t ~, 2.93 196 6165 i~ 0.04 I 5 2.95 197 6196 U 0.03 I l~ 2.95 SI' ht bucMin . 198 622 7 (~ 0.02 ~~ `~ 2.94 199 6258 i~ 0.03 1~3 .94 Z00 6290 ~~ 0.03 10 ~ 2.93 201 6321 (~ 0.01 5 ~' . 2 202 6353 U 0.04 14 ~ 2.93 Sli ht buckl~n . 203 38 ~~ 0.03 1 Z 4 .93 04 6415 c~ 0.03 1 U ~ 2.92 205 6446 ~~ 0.03 13 ~; 2.93 2 6 ~,478 U 0.04 1 E> ; 2.91 Shallow ittin . 207 6509 U OA2 ~) -! 2.93 ZO 6540 ~~ 0. 1 5 _' 2.93 09 6572 U 0.0 9 l 2.92 210 6602 ~) 0.03 1 1 > 2.94 11 6634 c? 0.02 i .93 212 6665 U 0.01 5 2.93 Sli ht b cklin . 213 6696 U 0.01 5 ~ 2.92 214 6728 l) 0.04 1~ i~ 2.93 215 6759 ~) 0.02 9 ' 2.93 216 6790 ~~ 0.01 6 -1 2.93 17 821 t~ 0. 0 _' .93 li h b cklin . 218 6853 u 0.01 ~ ~~ 2.93 219 6884 i~ 0.0 ~) Z 2.91 220 6916 ~? 0.01 5 I 2.94 221 6947 ~ i 0.02 ~) I 2.92 222 6978 ~ 1 0.02 t3 2.94 Sli ht bucklin . 223 7010 u 0.02 ~~ 2.93 224 7039 i i 0.02 rt V 2.94 225 7071 u .01 - 2.93 226 7102 ~~ 0.02 - 2.92 227 7134 ~) 001 5 2.92 228 7165 U 0.02 ~ 2.94 9 7197 u 0.01 f; 2.9 230 7228 ~1 0.01 6 = 2.94 Sli ht bucklin . 231 7259 u 0.02 ~) ' 2.91 232 7290 c ~ 0.03 1~ _' 2.92 233 7322 U 0.03 13 I 2.93 234 7352 ~ ~ OA2 ,' ~ 2.93 235 7384 ~ ~ 0.02 ~) ' .93 235.1 7416 i ~ 0 ~) ~ i N A GLM 4 Latch @ 4:30 236 7421 U .18 ~ 1 -1 2.91 I olated ittin . 237 7453 u 0.02 ? I 2,93 238 74 4 c~ 0.01 ~ ..' 2.93 Sli ht bucklin . 239 7516 l) 0.01 4 < 2.92 240 7547 t~ 0.02 8 1 .93 241 7578 i~ 0.02 9 _' 2.94 Penetration Body Metal Loss Body Page 5 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 ABM-EUE Well: f3ody Wail: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: ~ ~LATION SHEET 2T19 Kuparuk CanocoPhillips Alaska, inc USA )uly 2i, 2009 Joint No. )t. Depth (Ft.) I'~~n. i1F,.~~t (Iro.) Pen. Body (Ins.) f'en. %> ~tc~~,il I~n~ ~~ Min. I.D. (Ins.) Comments Damage Profilc (%wall) 0 SO 100 242 7610 ~ ~ 0.0 'i . 3 243 7641 i i 0.01 i 2.9 244 7671 ~) 0.01 5 I 2.92 245 7703 ~~ 0.02 '~ I 2.94 246 7734 U 0.03 1~~ I 2.92 Sli ht buc lin . 47 7765 t) O.U2 £S I 2.93 248 7796 t~ 0.02 f9 2.95 249 7828 (~ 0.02 ~ 2.93 SO 7859 u 0.03 11 I 2.9 251 7890 U 0.02 Ef I 2.92 2 7921 tt 0.01 6 ' 2.93 253 7952 U 0.01 6 ' 2.93 Sli ht b cklin . 254 798 i? 0.02 ~) ~' 2.93 255 8013 l~ 0.02 ~) 1 .93 256 8044 u 0.02 ti 1 .93 257 8076 ct 0.01 ~ I 2.93 258 8107 l) 0.01 5 ' 2.93 259 8139 (1 0.01 E~ I .94 260 8170 t1 0.01 4 I .92 61 201 (~ .O1 i Z 2.93 Sli htbucklin . 262 8232 ~~ 0.01 (> 1 2.93 263 8264 ~~ 0.03 13 1 2.92 264 8295 ~~ 0.02 ~~ I 2.93 265 8327 ~~ 0.01 ~> _' 2.93 66 83 t~ . 1 h ! 2.9 Sli ht c li 267 8385 u 0.03 I~ 2.94 268 8416 ~~ 0.01 5 . 1 269 8449 ~~ 0.01 3 I 2.93 270 8480 ~i .02 ~) I 2.93 Sli ht bucklin . 271 8510 u 0.02 9 t 2.95 271.1 8541 ~~ 0 0 l1 N A GLM 5 at h~ 11:00 272 8549 ~~ 0.01 5 ' 2.93 2 73 8580 ~~ 0.02 ~ _' 2.91 274 8612 ~~ 0.02 ~) _' 2.93 Sli h buckli . 275 642 ~~ 0.02 ~~ I 2.93 276 8674 f 1 0.01 i I 2.93 277 8705 (1 0.02 ~i I 92 278 8736 t~ 0.02 I 2.9A 27 8768 c~ 0.04 I5 I 2.91 280 8799 ~) 0.02 ~~ ~~ 2.92 81 8830 ~ 1 0.03 1 l) ~~ 2.91 282 8861 ~) 0.02 t3 ~~ 2.93 283 8893 ~~ 0.01 (~ Z 2.93 284 8924 ~~ 0.02 !) 1 2.94 285 8956 t~ 0.02 t3 ~1 2.93 286 8987 t~ 0.02 ~~ I 2.94 28 9018 c~ 0.03 1 I 2.94 288 9049 U 0.02 ~) U 2.94 289 9081 ~) .Ot ~ 1 2.93 290 9112 ~~ 0.01 -1 1 2.93 ~ Penetration Body Metal Loss Body Page 6 ~ PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 ABM-EUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ~LATION SHEEf 2T-19 Kuparuk ConocoPhillips Alaska, Inc. USA July 2 t, 2009 Joint No. Jt. Depth (Ft.) I'~~n. t 1F,~~•I (In~.) Pen. Body (Ins.) I'c~n. °~, ~1c~t.il I c~ss ~~ Min. I.U. (Ins.) Comments Damage Profile (% wall) 0 50 100 291 9143 u 0.0 1U ! 2.9 292 9175 U 0. 2 9 ~' 2.93 293 9206 ~~ 0.01 i I 2.95 293.1 9239 ~~ 0.01 4 I .92 PUP 293.2 9242 !~ 0 ~~ i~ N A GLM 6 Latc ~ 10:30 2933 9253 i~ 0.01 _' I 2.92 PUP 294 9260 ~~ 0.01 ~ I .93 294.1 9290 t~ 0 (~ i'~ 3.81 Camco W-1 Selec6ve Ni le 294.2 9292 !~ 0.01 ~ ~~ 2.93 PUP 2943 9298 i~ 0 ~ 4.(l~ R;ikc~r SAB P.ack~~r 294.4 9305 0.01 - ~'.~) i__l _ -- ----------- ~ . ~'l l~.'_ __ --- ---- ---- Penetration Body ~ Metal Loss Body Page 7 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ PDS Report Cross Sections C..~~,~ _ ~'~ „ Well; 2T-19 Survey Date: July 21, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 218527 Company: ConocoPhillips Alaska, inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin : 3.5 ins 9.3 f L-80 ABM•EUE Anai st: C. Waldro Cross Section for Joint 236 at depth 7442.43 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 97 % Tool deviation = 59 ° Finger 6 Penetration = 0.183 ins Isolated pitting 0.18 ins = 72% Wall Penetration HIGH SIDE = UP r1 ~ r1 U Cross Sections page 1 ~ KUP 2T-19 ConocoPhilli ps ~ wep A rn~~ An ~ a iun ro ~~~' . . .. Wdlban eWNane W 501032021400 KUPARUK RIVER UNR PROD Md~ Qt1C ) 62.18 5.505.81 AQBOn ~ 9,845.0 ----.__... _-._ . ••• ... .. Gummat SSSV: NI PPLE H2 (VPm) 50 n 1/17Y1009 Last WO: ~e IB1TN 47 69 y ekaseDae 5128I1995 / -- ~-.. 1 :29 4 P7. - Nnotafon DepUi ~ ale . l.art y Last Tag~ SlM 9,556.0 7/8/2009 Rev Reason: LOL FOUND LEAK (.al 7444' Imosbor 7f 77/2009 ... _~. Casi Strin s CONDUCTOR. C~M~B ~~on ~q (~M w (~ s.t ~B) aet Nh m (~~ rn) annp w~ ro~ ~~ Md iz~ CONDUC TOR i 6 15.06 2 0.0 1 1.0 1 21.0 62.58 FI-00 SURFAC E 9 5 18 8.67 9 0.0 3,722.0 2, 8G3.6 40.00 L-80 waaie,soi PRODUC TION 7 6.15 1 0.0 9.821.0 6,1 459 26-OO L-80 Tubi Strin s Gns uFt lUbinD D esaf on ame M) nn~ i (lnl Top B) sN oe~m (~8) sn qn fl~g) 1 ~.eg w~ Pbsnq 4a0 e T M0 . i,~y TUBING 31 l2 2.99 2 0.0 9.359.0 5.8 052 9.30 L-80 ABM UE ~ Ofher I n Hole A ll J~we 1 : Tu Run 8 RetNavaDle Fish at c. SURfACE. 3,12I T ~ ~y~) (~8) T~ ~a (') esaiqbn m`nat M D6e D GAS L IF7 1 501.0 2.41 N IPPLE Canxo'D5 Nippte 5I2&Y995 2.812 a eio 1.969 1.895.6 36.38 UFT M RlAlTMPD/1fGLVlBK/ .156/12771 Cortment: S A 1 7/8/2009 2.920 4.410 3,216.1 57.04 G AS LI MERLA/TMPD/1 LVBKl. t88l13031 Comment: STA 2 7/8/2 2.920 6.033 4.004.6 6021 G ASUP"f MERLMMPD/1/OVBK/.2 5UCOmme nt: STA3 7/8f2009 2.920 cnsiiFr 6.033 7.415 4.698.8 59.98G ASt1FT AAER PD/1/ MY/BKI I/Canrt~ent STA4 2/4/2007 2.92(1 8,541 5.302.7 56.73G ASLIFT MERLIVTM 1IDMVBKI //Carrnent A5 1/3Q/1007 2.920 9.243 5.J2J.3 48.85G ASLIFT ME WTPD%/1.57DMV/R NU//Cortvre nt STA6 1/30/2007 2.920 c~ ~~~, 9, 5,759.1 48.43 N IPPLE Camco'W- ' SelecWe Nip pk 5i28/1995 2.812 ~ ai5 9,2 8 5, 64.3 12 A N HOR Baker KBH- 2 Andror Seal Assy. 28l1 5 .00 9.299 .764.9 4820 P ACKER Baker'SAB' PACKER 528/1995 4.000 GA^. LIR 9.312 5.773.5 47. 6 N IPPLE Camrn'D' Nipple NO GO 5128/1995 2.750 , e.sa+ 9.312 5,773. 47.86 P ~UG CA-2 PLUG /1212 0.000 9,327 5.783.4 47.46 P BR Baker GBH • no seal 5/281t99 3.000 GAS IiFT 9,J28 5,781.1 47M P ACK Baker'FB-i'PACKER 5/Z 1995 4.000 , s2a3 9.331 5,788.1 47.38 P ACKER Baker 7AC 'FAIL ' 9l1995 4.000 9,349 5,798.3 46.89 N IPPLE Cartico'D' Ky~ple (Unusea ble hu BG P!n NO GO 5/28/1995 2.750 9.359 5,805. 46.62 S OS Baker 5/28/1995 2.992 NIPPLE, 9,29U 9.360 5.805.9 46.60 T TL ELMD lTL ~ 9350 duing PERF REC on O6l0 5f28l1995 2.992 9.ft53 6,019.4 41.38 FI SN 20' PERF gun Lost in ratho fned: SEE WSR 6/3/95 le: Guns ~ peared to nm hav¢ &3I/995 ~n,~„oR. „ , Pa/ora tions 3 Slots e.zse PKKF.R.9.288 n ~~ 8011 Top(TW) ~ &m(iW) ~a Zoro OefC ant Dms (~~ Cq 1Y1Net 9.435 9.455 5.858.3 5,872.1 Cd. UNIT B. ZT-19 917l1998 6.0 APE Rf 60 deg Phassg; 2 12' HC NIPFLE. 831Y PLUG. 9,312 9.500 9.542 .90 .1 5.936.1 A4. A3. 2T-19 61311995 6.0 IPF RF 90 Deg. Phasing; ~OWSIf~B; 2 ~B° FJ (+l-) 45 deg llf~EL 9,500 9.516 ,905.1 5.916.1 -3. Zf-19 1611995 2.0 RPE RF Zero Deg. Phaseig: Orienuted 90 deg. CCVJ: 2 1!8" Enerjet aea. s 3zi 9.51 9. 35 .91 .1 . .9 -3. -19 1311995 4.0 APE RF Zero Deg. sir deg from bwside: g: Orienoed (~/') 90 2 118' Enerjet GACKER, 9 318 9.568 9.588 5,955.5 5.9 0.4 A-2, 2T-19 2/5/2003 6.0 APE RF 2.5' HSD 2506 PJ pham NMX. 60 deg Notias: ( ieneral 6 rte qmot ~on vo,cHeR.s,sai NOTE:LDL OUNDLEA K~174M' LMD NIPPLE. 9319 SOS.8359 TTL. 9,380 PFEFF. 9,a]S~B,a55 FGERF 9,500-8 515 IPENF, 8.500-9.5l2 P-ERF, 9.515,9 535 PPERF, 8,588-0 588 FISH, 9,653 PROWCTION, 9.87~ TD. 8,845 ~ Jul 21 09 10:55p PflS inc ~ 907 6~14 l ~ ~ ' { . ~, cas~t~ ~ Tuatr~G ~ ~.rNFa nEr~~ ~-t~'~s~iGt~.c~ma~ ARCtJ Alaska, lnc: p.2 WELL: 2T 13 KRU DA7'E: Sf28t$5 8u6skfEary at A NarrUc R1~trFlald Ccmpany 1 OF 1 P'ACES # ITEMS ~QMPI.ETE D6SCAIP~'tON C}F E(IlJIP14l~N7~ RLtM LENGTFi QEP7'H ~ ' ~ RKB tn Tubi Head/Ha r l.,odcdown Scre~vS - parker R' #245 36.75 FMC Gen 1V ~-ii2" Tutri H wl d6! in u. 3-ti12" EUE tanr~ thd . 3.22 36.75 1 JT i 3-1l2", 9.3~, L-8Q. ABM-EU~ T~tbin 31.37 39.97 ! S e Out Pu S 1 Q.t tY ! 10.1 D` / 4.05' 24.2~i 71.34 13 JTS ' 3-f/2", 9.3#. L-8t} A8M-EUE Tt~bin 404.99 96.59 ,Ni e GAMCO 3-t12" DS land{ iUi le, 4.5Q" OD. 2.856" Nb Go. 2.~'!2" (D 1.i S 54t3.58 4~ JTS 3-1/2". 9,3#, L-$0~ ~kBM-EUE Tt~bin ~'i 467.28 501.77 GLM ~6 MEFtI.A 3-i/2" X 7" TMF'~?. AV~ BK-~ Lafch> 5.82' OD, 2.~2` Id . 6.82 i 969,U3 78 JTS 3-i12", 9,~,L-E0, RSM-EUE 7ubi 2~434.rt 8 19~5.85 GLM~S M~RLA 3-1/2" X 1" TMPD [~V BK-5 Latch, 5.62" £1D. 29.2" (D $.83 4410.03 ~ 52 JTS 8-1+~` 9.3#, L-BO ABt~9-EU~ Tubin 1615_17 4~+1 ~_$fi GLM~"4 MERLA 3-1P2` X t" 3"MPQ DV B!C-5 Lat~ctt v.82° DD, 2.92" (D 6.82 &032.63 44 J7S 3-?r2°. 9.3# L.-Sil. ABM-EUE Tnl~in i375.18 6039.45 [~LIN ~+3 MER'~t 3-i12" X i" 71~+TPf?, DV~ BK-5 l.a~ch, 3.62" OQ. ~.9'2" iD 6.55 7414.65 36 JTS 3-112", 9.3#, !.-8!} ABA9-EUE 7ubitl 11 ~ 9.81 7421.18 ~ GL~ta ~2 tutERLA 3-11~" X 1~~ TMFD, DV. BK-5 ~atch, b.62" ~D. 2.82" ID 6.87 954.t.09 22 JTS 3-1f2" 9_3#> L-80, ASlt/!-EUE Tubin 688.7a 8547.9Q Pu Joint. 3-1l2" T~fn 6.1~ ~238.~5 GLM~i MIERLA 3-1/2" 7~ 1-t/Z' TPDX, DV, RA tatch, 5.96" (3p, 2.92" iD 8:$4 92d2.75 Pta Joini, 3-1l2" Tubin ~6.'Et! 9252,U9 1 JT 3-112", 9.3#, L-8D ABM-EUE Tubf 31.44 925$,7$ Ni le GAMCt} 3-112" W-1 Setective Laridin M!' , 4.~0" dD, 2_8f2" ID 1.98 9269_59 . Pu Joint, 8-1f2" Tubin &.12 9291.57 ~KER NCBH-22 Anchor Sea! Ass 4.~5~" 04, s" ID D.82 5287.69 ° PaClser BAKER SAB-3 Permanent Pa~lcer.5.887" Q~. 4" iC] 5.14 9298.6i Pu Joini, 3-1I2" Tvbi ' 8.10 93t13.75 Ni !e ChMCp 3-1I2" I~-Ni I@,'4.50" ~D. 2795° NO GO, 27Sfl" tD 1.t11 9311.85 Pu Jatnt, 5-112' Tubir 8_ia 9~1~_86 Pu Joint, 3-112" Tubin 6.09 9320.98 BAKER GBH t.4cats~r Seal Ass - Na Seals 12.67' Overatl - I..ac ±1' u 1.0 Q 9527.05 "°'•>,«" Perrrsanent PaCksr set on E-l.ine C~ 9320' E!M 51~~195 .•..•,°. ,,...... Packer BAKER ~B-1 Permanant Packer, 5.875~ 0~3, 4" 1d 3.32 9328.tJ5 Falfed BAKER Seat Bone Ejcterxs~an 84l4U 5.fl63" OD, 4" It? ~ 9.37 9381~.57 BAKER XC, SBE X 3•112" EUE, 5.~63" O~ o.so ~3ao.7a Pu Jt~in#, 3-tf~° Tubf 8.1Q 93A1.34 Nt ie C~fUt~lJ 3-1l2° b-N1 e, 4.5~ C?U, 2.795" No Go 2.754" !D 1.0~ 9349.d4 Pu Joint 3-1(2" Tubi ~ 8.10 9350.44 BAKER 3-i/2" ~ftea-' Out Sub Shear~d t?.90 9358.54~ Battam of Tubi 7aii ~~~> 9359.a4 Rema-~s' Str~ng Weighfs witf~ BloCks: 64K# Up, 82K~ D~-vvtz, 8K# Bl~cs. Rsin 294 join~5 af tubi n~l. ~Drifted tubiru~, QLhAs, & i~anqar vrith 2.86~` p~iastic rabbit iJsed Arc~tic Grade AP~ Nfoditied i~cs Lea d _ _ --- _ _ -_--- __ -- _ ihread compaurid on aiE connec~~ns. Tubing is nrtrt-qate~i. Naie: F8-i Packer alement leakadlf~iled. Remaved seals on LSA. 8oitr~m t?-IVinae IVC?T useab}e. KRU Producer 2T-19 (PTD 195~6) TxIA • Page 1 of 1 Regg, James B (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Saturday, June 27, 2009 8:18 AM To: Schwartz, Guy L(DOA); Regg, James B(DOA); Maunder, Thomas E(DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: KRU Producer 2T-19 (PTD 195-026) TxIA Attachments: 2T-19.pdf; 2T-19 TIO.pdf Jim, Tom, Guy, Kuparuk gaslifted producer 2T-19 (PTD 195-026) is suspected of having TxIA communication based upon a failed TIFL 6/26/09. A leaking gaslift valve is suspected so slickline will troubleshoot and repair if possible. The well will be repaired or SI by 7/24/09. It will also be add to the weekly SCP report. Attached are a wellbore schematic and 90 day TIO plot. . ~ ~ ;,~ .=d`~E.~9~'~ a' ~F ~ c_~t>~ «2T-19.pdf» «2T-19 TIO.pdf» Please let me know if you have any questions or require more detail MJ Loveland Weli Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 8/31 /2009 a a C'' ~ d o u~ V ~ wa~a~o~~ ~ 0 a ° a r : . . . . . : : : . . . . . . : : : . . . , . . : : : : :~ : .i . . ;~ : : .'ti . . ,; . . ;~ : : .i~ . . . ~ . . : ~ : : ~ : : ~ : : : : : i : : : . . : : : .t . . '~ : : p : . . . : : :~ : : ., . . .i . • ~ : : ~ C ~ ~ i . . . . : : . : : . . ; . . : : ~ : : ~ O : : : : : : ' . ~ : : , ,~ : : ~ ' ~ : : : : : i : : ' I : : r ~ : : : . . . : : . . ~ : : : ~ : : ' ~ ', r•+ O _ : : : • : : ~ : : ~ ' ~ : : : : : : d ~ p a : : : ~ : : O 1 : : : . . . :~~ : : . . ~ ~ I ~ •~ I ~ . . ~ . . ' . . .~ i . . ~~ ~ ~ . . . . • • , . . . . . ~I . ~ , i . ~ ~ ~ ' . . ; . ~.L ; . . ; : : , . . , . . . • • ; . ;''i : : , r . . , ~ . . . ~ . . ~ ~ ~ . . . . i . . . ~ ~ . . . . . . . . . ' . . ~ ~ ( I . • • • . . . • • . 1~tj • • , "' . . . ~' • • ~ ~ ~ ~ . • • . . . . i • • . . . T ~ ~~ ~`~ O O O ~ 0 O ~ O O O O O O O {~ ~ N r r I ISd KUP 2T 19 4+-~"< ~ Goncc~cct~~it~ps ~r~~!a~ ~~~~ ~ ~` _ = ~("L~~ ~-, ~~~~ ~~~a ` ~ a, ~. }. ~ ~ ~~ ~~ Incl (°) MD (RKB) Act B6n (ftKB) Wallbore API/UWI FIelO Nama Well Statua 501032021400 KUPARUK RIVER UNIT PROD 62.18 5,505.81 9,645.0 Comment H2S (ppm) D ate Annoqtlon End Date KB•Grtl (ft) Rig Release Dat ~~~ . g~ ~ ~ ~ SSSV: NIPPLE 100 7/1/2008 Last WO: 47.69 5/28/1995 _! ~ s8chematt~.Aqaffi Annotatlon De th ftK8 End Date A P ( ) nnotation Lasf Mod B End Date Y Last Tag: 9,582.0 8/31/2008 R ev Reason: add TTL comments ehelton SI20I2009 ~ '~~ '~~ ` ~ i i i„L i~ i1i ~iG u7 ' ~ r ~r ~ ~ ~ ~¢ a ~ - e ~ i i.:#2~: .~ ^_ ~ ` ,"~. : r~~ -~~ i I i f . Casing Descnption String 0... String ID ... T ~ ~ _:. Stnng . String Top Thrd~ op ((tKB) bet Depth (f... Set Depth (ND) .. Stnng Wl_ coNOUCroR, ° CONDUCTOR 16 15.062 0.0 121.0 121.0 62.58 H-40 At2t ~'~. ~~=~ Casing Description Sbing 0... String ID ... T op (kKB) Set Depth (t... S ef Depth (TVD) ... SMng Wt.. String ... String Top Thrd - ~~ SURFACE 9 5/8 8.679 0.0 3,722A 2,863.6 40.00 L-80 ~ Casing Deacription String 0... String ID ... T op (ftK8) Set Depth (f... Sel Depth (ND) ... String Wt... String ... String Top Thrtl NIPPLE,5o1 P RODUCTION 7 6.151 0.0 9,821.0 6,145.9 26.00 L-80 ' ~ {~. k~~~~- ~~ ~h~ '~~ ~~~~r ~ t~r.ii~ ~'~~~§"~- ~" ~ - ~ ~ Tubing Daccription St ing 0... SMng ID ... T Shing ._ String Top Thrd op (ftKB) Set Depth (t... Set Dapth (ND) . StrinB Wt._ ., TUBING 31/2 2.992 0.0 9,359.0 5,8052 9.30 L-80 ABM-EUE GFS LIFT, ° ~ y.. ~y~. _ ro~_ ` .i y ~ ' ~ -- ~ , - ~ .,-~t -., ~ -r- ' ~~ ~ d ~ '" ~ 1.888 y. lf ~ ~~$~ t~ ~!a'k .: ~1~~~.., 3 ~ ~-. ~ „F ~ -d.-' ' ~ . ~ ~.._~ ~ ~ Top Dapth ~ (ND) Top Incl SuRFACE Top (RKB) (ftKB) (°) Descriplion Comment Run Date ID L , oa,nz - 501 501.0 2.41 NIPPLE Camco'DS'Nipple 5/28/1995 2.8' " 1,969 1,895.6 36.38 GAS LIFT MERLAITMPD/1/GLVlBW.156/1261/ Comment: STA 1 2/4/2007 2.9; casuFT, 4 410 216 3 1 04 57 GASLIFT MERWTMPD/1/GW/BK/ 756/1254/Comment: STA2 2/4/2007 2.9; 4,610 , . , . . 6,033 4,004.fi 6021 GAS LIFT MERLAITMPD/1/OV/BK/.188!! Comment: STA 3 2/4/2007 2.9: - 7,415 4,698.8 59.98 GAS IIFT MERLNTMPD/1/DMY/BK/// CommenL STA 4 2l4/2007 2.8; GAS LIFT, - 6,033 B,S41 5,302.7 56.73 GAS LIFT MERLNTMPD(1/DMYIBWN Comment STA 5 1/30I2007 2.9: ` 9,243 5,727.3 48.85 GAS LIFT MERLNTPDX/1.5lDMY/RM/// Comment: STA 6 1/30/20W 2.9; 9,290 5,759.1 48.43 NIPPLE Camco 1N-1' Seledive Nipple 5/28/1995 2.8~ Z98 9 5J64.3 48.22 ANCHOR Beker KBH-22 Anchor Seal Assy. 5/26/1995 3A~ GAS LIFT, . ~~415 9,299 5,764.9 48.20 PACKER Baker'SAB' PACKER 5/28/1995 4.0~ - 9,312 5,773.5 47.86 NIPPLE Camw'D' Nipple NO GO 5/28/1995 2.7: GAS LIFT 9,327 5,783.4 47.46 PBR Baker GBH - no seal 5/28/1995 3.Oi , e,sai - 9,328 5,784.1 47.44 PACKER Baker'FB-1' PACKER 5@8/1995 4Ai ":)i 9.331 5,786.1 47.36 PACKER BakerPACKER'FAILED' 5/28/1995 4Ai ~~fi 9,349 5,798.3 46.89 NIPPLE Camco'O' Nipple (Unuseable kr TBG P/T) NO GO 5/28/1995 27: GASLIFT, 9,243 J,3SJ 5,805.2 46.62 SOS Baker 5/28I1995 2,9! 9,360 5,805.9 46.60 TTL ELMD TTL @ 9350' during PERF REC on O6/03/95 5/2811995 2.9! 9,653 6,019.4 41.38 FISH 20' PERF gun Lost in rathole; Guns appeared to not have 6/3/1995 fired; SEE WSR 6l3/95 NIPPLE, 8,290 _ ~$TEE#1'$ y~ ~~$.aF'~~~5 _ ~~i i ~ ~'r~ ~~ -~"~i ~ I ~ - ~ ~ za. ~. 1 r~~~ `-~''. '.~ " Shot Top (TV D) Btm (ND) Dens - O Top(/tKB~ Btm(ftK8) (RKB) (TtKB) Zane Date (°h~° Type Comment a, ANCH e.zae 9,435 9,455 5,858 .3 5,872.1 C-4, UNIT 8, 5/17/1998 6.0 APERF 60 deg Phasing; 2 1/2" HC '^ 2T-19 PACKER, 9,299 9,500 9,542 5,905 .1 5,936.1 A-4, A-3, 2T-19 6/3I1995 6.0 IPERF 90 Deg. Phasing; (+/-) 45 deg from i: lowside; 2 1/8" Enerjet 9,500 9,515 5,905 .1 5,916.1 A-3, 2T-19 6/16/1995 2.0 RPERF Zero Deg. Phasing; Orientated 90 deg. CCW; 2 1/8" Enarjet NIPPLE, 9,312 9,515 9,535 5,916 .1 5,930.9 A-3, 2T-19 6/13/1995 4.0 APERF Zero Deg. Phasing; Oriented (+/-) gi deg Nom lowside; 2 1I8" Eneryel 9,568 9,588 5,955 .5 5,970.4 A-2, 2T-19 2/5/2003 6.0 APERF~ 2.5" HSD 2506 PJ NMX, 60 deg PBR,8,327 Ph058 ~: .....:_. _ ~: . PACKER, 8,328 9,331 NIPPLE, 505, 9,359 TTL,9,360 APERF, 8,435-8,455 APERF, 9,568-H,588 FISH. 9.653 PRODUCTION, 0-9.821 TD, 9,845 09/15/08 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth • ~/ Well Job # ~~ ~.~~~~~~~ ~~~ t° ~ ~ao~ Log Description N0.4871 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 1C-172A 11978478 PRODUCTION PROFILE ~- 08/19/08 1 1 iC-172A 12080429 GLS/FBHP 08/19/08 1 1 3M-26 12096533 SBHP SURVEY 08/20/08 1 1 3N-02A 11996652 SBHP SURVEY 08/20/08 1 1 3M-22 11966276 SBHP SURVEY - 08/20/08 1 1 3C-17 11996657 SCMT ~ - / (n ~} /L/ 08/25/08 1 1 3C-15A 11996659 PERF/SBHP SURVEY ,a~~-Q'~~ ~~G3i~ 08/27/08 1 1 2U-O6 12080428 LDL -p - 08/29/08 1 1 2V-15 11996661 PRODUCTION PROFILE =p 08/29/08 1 1 2T-19 11996663 PRODUCTION PROFILE 08/31/08 1 1 2D-07 11975790 INJECTION PROFILE - (C{ Q 09/07/08 1 1 2H-09 11975788 PRODUCTION PROFILE ~ 09/05/08 1 1 iC-174 12096539 INJECTION PROFILE - ~- p 09/07/08 1 1 2H-12 12096540 PRODUCTION PROFILE ~ 09/09/08 1 1 30-01 11975792 LDL `~-O~ 09/09/08 1 1 3F-10 11975789 LDL ~ 09/06/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • /q f - f))Jo 03/30/06 lå...... NO. 3751 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth RECEIVED Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 "1 Z, '1.\ÆiíR ') {'¡ "o~r VI111 tII tI ¿ Uo Alaska Oil {~ Gas Cons. GommiS3í0/1 Anchorage Field: Kuparuk e Well Job# Log Description Date BL CD Color 1 8-06 11213713 PRODUCTION PROFILE W/DEFT (REDO) 02127/06 1 2T-19 12213723 PRODUCTION PROFILE W/DEFT 03/24/06 1 1 E-117 11213725 INJECTION PROFILE 03/26/06 1 1H-10 11213726 PRODUCTION PROFILE W/DEFT 03/27/06 1 3M-23 11213727 LDL 03/28/06 1 e Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ConoCOPhillips Mike Mooney Wells Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 March 11,2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 2T-19 (195-026) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforating operations on the Kuparuk well 2T-19. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, M. Mooney Wells Team Leader CPAI Drilling MM/skad RECEIVED ~AR 1 ~2003 ,~GANhlED NAR 1 3 2002 STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging_ Pedorate _XX Pull tubing _ Alter casing _ Repair well _ . Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ConocoPhillips Alaska, Inc. Development__XX RKB 41 feet 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 52' FNL, 4724' FEL, Sec. 12, T11N, R8E, UM (asp's 498945, 5969927) 2T-19 At top of productive interval 9. Permit number / approval number 1540' FNL, 634' FEL, Sec. 10, T11 N, R8E, UM 195-026/ At effective depth 10. APl number I 50-103-20214 At total depth 11. Field / Pool 1599' FNL, 894' FEL, Sec. 10, T11 N, R8E, UM (asp's 492215, 5968383) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 9845 feet Plugs (measured) true vertical 6164 feet Effective depth: measured 9582 feet Junk (measured) 20' of perf gun in rathole true vertical 5966 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 80' 16" 230 sx AS ~ 121' 121' SUR. CASING 3683' 9-5/8" 750 sx ASm, 570 sx C~ass G 3722' 2864' PROD. CASING 9784' 7" 260 sx C~ass G 9821' 6146' Perforation depth: measured 9435'- 9455', 9500'- 9542', 9568' - 9588' true vertical 5858' - 5873', 5905' - 5936', 5956' - 5971' 1 Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 9359' MD. ~0~&~~,~~, Packers & SSSV (type & measured depth) BAKER *FAILED* @ 9331' MD; BAKER 'FB-I' @ 9328' MD; BAKER 'SAB' @ 9299' MD; CAMCO 'DS' @ 501' 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 357 1326 297 - 347 Subsequent to operation 391 1362 306 333 15. Attachments 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. Questions? Call Mike Mooney 263-4574 Signed ..~ /~~ Title: Wells Team Leader Date Michael Mooned/ . Prepared b)/ Sharon AIIsup-Drake 263-4612 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Date Comment 2T-19 Event History 01/17/03 02/05/03 TAGGED FILL @ 9582' RKB> EST. 40' RATHOLE. DRIFTED TBG W/11'3" X 2.505" DUMMY GUN TO TD. [TAG] PERFORATE 9568-9588 FT MD IN 2 RUNS ( 10 FEET EACH ). TAGGED TD AT 9588.5 FT MD. AFTER SHUT IN WELL, WHP INCREASED TO 800 PSI PRIOR TO SHOOTING GUN #1. AFTER GUN #1, WHP INCREASED SLOWLY TO 1300 PSI. WHP HELD AT 1300 PSI AFTER GUN #2. BY RD, WHP = 1500 PSI. Page 1 of I 3/10/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdo~ 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 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: 53' FNL 556' FWL, Sec 12, -ri 1N, R8E, UM 2T-19 At top of productive interval: 9. Permit number/approval number: 1540' FNL, 634' FEL, Sec 10, T11N, R8E, UM 95-26 At effective depth: 10. APl number: 1588' FNL, 825' FEL, Sec 10, T11N, R8E, UM 50-103-20214-00 At total depth: 11. Field/Pool: 1605' FNL, 893' FEL, Sec 10, T11 N, R8E, UM Kuparuk River Field/Oil Pool 12. Present well condition summary Total Depth: measured 9845 feet Plugs (measured) None true vertical 6164 feet ; / ~, - , ~ .~ .,~ · Effective Deptt measured 9738 feet Junk (measured) 20 fl of pert gun in rafhole true vertical 6083 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 230 Sx AS I 121' 121' Surface 3683' 9-5/8" 750 Sx AS III & 3722' 2864' 570 Sx Class G Production 9784' 7" 260 Sx Class G 9821' ,6 ,,, Liner :'"'-~) 'i '1: :] : Perforation Depth , , , .~ iEt'?, ~:3~.tS ......... measured 9435'. 9455', 9500'. 9542 true vertical 5858' - 5873', 5905' - 5936 Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 9360' Packers and SSSV (type and measured depth) Pkrs: Baker SAB @ 9299', Baker FB-1 @ 9328' & Failed Baker @ 9331" SSSV: None, nipple @ 501~ 13. Stimulation or cement squeeze summary Perforate 'C' sands on 5/13/98. Intervals treated (measured) 9435' - 9455' Treatment description including volumes used and final pressure Perforated using 2-1/2" HC guns w/DP charges at 6 spt, final pressure = 1250 psi. 14. Represenlifive Daily Average Production or Injeclion Data OiI-Bbl ®as-Mcf Wafer-Bbl Casing Pressure ,tubing Pressure Prior to well operation 852 621 541 977 325 Subsequent to operation 1092 1084 613 977 328 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _ZX Oil ~X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. .Signed ~ Title: Wells Superintendent Date Form 10-404 R~v 06/15, SUBMIT IN DUPLICATE --. .~- .... ~ KUPARUK RIVER UNIT K1(2T-19(W4-6)) JOB SCOPE JOB NUMBER ., -19 PERFORATE, PERF SUPPORT 0508981915.3 DATE DAILY WORK UNIT NUMBER 05/13/98 ADD "C" SAND PERFS DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 (~ Yes O NoI (~ Yes O No SWS-JOHNSON SCHWE~IDE~AN FIELD AFC# CC# DAILY COST ACCUM COST ig~_~d/,, ~,..~. _ ESTIMATE KAWWRK 230DS28TL $10,639 $12,541 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial/Ou~Ann Final Outer Ann - 1000PSI 1250PSI 1100PSI 1100PSII [ //350 PSI 350 PSI DAILY SUMMARY HAD INITIAL PROBLEMS GETTING PERF GUN PAST 6455'. REMOVED 6'WT BAR. RERAN GUN. STOPPED AT 5175' I I RIGGED UP LRS AND PUMPED DOWN PERF GUN PERFORATED F/9435' - 9455' W/6 SPF/HC/DP/60 DEG PHASED. TIME LOG ENTRY 08:00 MIRU SWS (BRANTZ & CREW). TGSM TRIPPING HAZARDS, PERF GUN SAFETY. SHUT IN WELL, NOTIFIED PERSONNEL OF RADIO SILENCE. 09:00 SHUT DOWN SURFACE ELECT POWER. MU PERF GUN ASSEM (20', 2-1/2" HC, DP/WT/CCL) TL= 30'. PT BOPE TO 3000 PSI. 09:30 RIH GUN STOPPED AT 6455' ELM, MADE SEVERAL A'I-rEMPTS SE'I-I'ING DOWN SOLID. POH 10:30 AT SURFACE LAID DOWN LUBRICATOR, REMOVED VVT BAR MU LUBRICATOR PT TO 3000 PSI, RIH SAME GUN TL= 24'. STOPPED AT 5175' ELM RIGGED UP LRS AND PUMPED TOOL STAPPING AT 6455' ELM TOTAL 30 BBLS DID NOT GET FLUID TO SURFACE. 12:00 WAITED ON TRANSPORT FOR DIESEL. 14:00 PUMPED DOWN TUBING AT 1-1/2 BPM PUMPED TOTAL 120 BBLS CONTINUE RIH TO 9570' ELM TIE IN W/ 5/25/95 GR/CCL LOG PERFORATE 7" F/9435'TO - 9455' ELM W/2-1/2" HC/DP/6 SPF/60 DEG PHASING SAW GOOD SURFACE INDICATIONS. POH. 16:30 AT SURFACE LAID DOWN LUBRICATOR ALL SHOTS FIRED. RD EQUIP. 17:30 RETURNED WELL TO PRODUCTION. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $210.00 APC $509.00 $509.00 HALLIBURTON $0.00 $892.00 LITTLE RED $1,320.00 $2,120.00 SCHLUMBERGER $8,810.00 $8,810.00 TOTAL FIELD ESTIMATE $10,639.00 $12,541.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION coMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdo~ 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' RKE 3. Address: Exploratory__ 7. Unit or Property: P.O. Box 100360 Stratagrapic __ Anchora,(:je, AK 99510-0360 Service __ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 53' FNL, 556' FWL, Sec 12, T11N, R8E, UM 2T-19 At top of productive interval: 9. Permit number/approval number: 1540' FNL 634' FEL, Sec 10, T11N, R8E, UM 95-26 At effective depth: ~10. APl number: 1588' FNL, 825' FEL, Sec 10, T11N, R8E, UM 50-103-20214-00 At total depth: 11. Field/Pool: 1605' FNL, 893' FEL, Sec 10, T11 N, R8E, UM Kuparuk River Field/Oil Pool 12. Present well condition summary Total Depth'. true measured vertical 6164 9845 feet feet Plugs(measured) None !-'~) r? Effective Deptt measured 9738 feet Junk (measured) 20 ft of perf gun in rathole true vertical 6083 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 230 Sx AS I 121' 121' Surface 3683' 9-5/8" 750 Sx AS III & 3722' 2864' 570 Sx Class G Production 9784' 7" 260 Sx Class G 9821' 6146' Liner measured 9500' - 9542' true vertical 5905' - 5936' ' ' .~ ~ ,,,~ ~',. Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 9360' Packers and SSSV (type and measured depth) Pkrs: Baker SAB @ 9299', Baker FB-1 @ 9328' & Failed Baker @ 9331" SSSV: None, nipple @ 501~ 13. Stimulation or cement squeeze summary Fracture stimulate 'A' sands on 4/10/98. Intervals treated (measured) 9500' - 9542' Treatment description including volumes used and final pressure Pumped 133754 lbs of 20/40, 16/20 and 12/18 ceramic proppant into the formation, final pressure = 6000 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 599 486 300 960 337 Subsequent to operation 852 621 541 977 325 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 ~~ Title: Wells Superintendent Date Form 10-404 Cv 06/15/88 SUBMIT IN DUPLICATE~ ..,c. -' [(UPARUK RIVER UNIT j ,~ ~-~ K1(2T-19(W4-6)) ..-L JOB SCOPE JOB NUMBER 2T-19 FRAC, FRAC SUPPORT 0405980729.3 DATE DAILY WORK UNIT NUMBER 04/10/98 PUMP "A" SANDS REFRAC "DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 3 (~) Yes C) NoI (~) Yes C) No DS-GALLEGOS JOHNS FIELD AFC# CC# DAILY COST ACCUM COST Sig?e~//~ ESTIMATE KD2006 230DS28TL $112,100 $126,502 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 1100 PSI 1600 PSI 400 PSI 500 PSII 50 PSII 300 PSI DAILY SUMMARY PUMPED "A" SANDS REFRAC, SCREENED OUT WITH 133,754~ TO 12/18 AT PERFS. (DESIGN 255,871) LEFT 24,000# PROPPANT IN PIPE. TIME LOG ENTRY 07:00 MIRU DOWELL FRAC EQUIP., HOTOIL PUMP AND APC SUPPORT. 09:30 HELD JOB SITE SAFETY MEETING. 10:23 PRESSURE TEST TREATING LINE TO 9041 PSI. 11:26 PUMPING BREAK DOWN WITH 50# GEL, 30 BPM AND 7220 PSI TO 4774 PSI. PUMP I#PPA 20/40 AT 15 BPM AND 4189 PSI. PUMP FLUSH W/50 BBLS GEL , PUMP 2#PPA 16/20 AND FLUSH WITH 50BBLS GEL AND 118 BBLS SEAWATER. SHUTDOWN FOR ISIP 1694 PSI. 12:42 PUMP DATA FRAC WITH 100 BBLS 50# AND FLUSH WITH 98 BBLS SEAWATER. SHUTDOWN FOR ISIP 1662 PSI AND CLOSURE CALCULATION. 14:10 PUMP PAD WITH 330 BBLS 50# GEL, 5 TO 15 BPM AND 1593 PSI. 14:44 PUMP 2 PPA STAGE OF 20/40 15,439#., 15 BPM AND 4408 PSI. 14:57 PUMP 131,678# OF 12/18 AT 15 BPM, 6 PPA TO 12 PPA, AVG. 4670 PSI. MAX PRESSURE AT SCREEN OUT 6000 PSI. 15:46 SCREENED OUT AND SHUTDOWN. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $1,017.00 APC $7,800.00 $7,800.00 ARCO $500.00 $500.00 DOWE EL . $102,100.00 $102,100.00 HALLIBURTON $0.00 $8,549.00 LITTLE RED $1,700.00 $6,536.00 TOTAL FIELD ESTIMATE $112,100.00 $126,502.00 PERMIT DATA AOGCC Individual Well Page: 1 Geo. logi~.ca'l Mater'ials Inventor'y Date: 03/19/97 T DATA_PLUS RLI~ DATE_RECVD 9 5 -- 0 2 6 ............... CDR- 95-026 CDR FINAL 10-~07 Are DAILY WELL OPS R ]/6~'~'/~-~/ TO ~.;, ~¢,-~ f~ I ~ - ~ ~w~- ~,~.'. ~i ~. ) e'7I ~'~ dry ditch samples r'equ~red? yes Was Are Well the well cor'ed? yes r~(~!..alysis & description r'eceive~a:~ ~ s ~ n compl ~ ance .. I n~i t i a '1 COMMENTS tq 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMN,,,..SION WELL COMPLETION OR RI=COMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL ~ GAS ~ SUSPENDED ~ ABANDONED ~ SERVK;E [~n~ 2 Name of Operator 7 Permit Nu ! ARCO Alaska, Inc 95-26 /,~.~ 3Address 8 A PINumber P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20214 ~ . ......... '~-~ ....... -~,_ 9 Unitor Lease Name 4 Location of well at surfaco ~ ~'~.~?.~ ~r'~'~ 53' FNL, 556' FWL, Sec. 12, T11N, R8E, UM i',,/~,,~.~[~ ~i~ " Kuparuk River Unit At Top Producing Interval J[~/'/...~"~.,~'. ~ 10 Well Number 1540' FNL, 634' FEI_, Sec. 10, T11N, ReE, UM ~ ~!'.~.~:!~_? ~ i 2T-19 At Total Depth ! ~?~-'~' ..... ~i .~~ 11 Field and Pool 1605' FNL, 893' FEL, Sec. 10, T11N, R8E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Sedal No. RKB 41' Pad 81' ADL 25568 ALK 2666 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 116 No. of Completions Mar. 4, 1995 Mar. 12, 1995 6/3/95 (perf'd)I NA feet MSLI 1 17 Total Depth (MO+TVD) ,8PlugBackDepth(UD+TVD) 19 Direction, Survey 120 Depth where SSSV set 121 Thlckness of permafrost 9845' MD & 6164'TVD 9738' MD & 6083'TVD YES IX[ NO U] NA feetUDI 138O'ss APPROX 22 Type Electric or Other Logs Run GR/CDR 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5" H-40 Surf. 121' 24" 230 sx ASI 9.625" 40.0" L-80 Surf. 3722' 12.25" 750 sx ASIII Lead, 570 sx Class G crnt Tail 7" 26.0" L-80 Surf. 9821' 8.5" 260 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) 3-1/2", 9.3#, L-80 9360' 9328'(leaking), 9299 9500'-9535' MD 5905'- 5930'TVD 4 spf 9535'- 9542' MD 5930'-5936' TVD 6 spf 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9500 - 9542 12MLbs 20/40, 178 MLbs 12/18, 134 M Lbs 10/14 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 6/21/95 FLOWING Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 7/24/95 24 hrs TEST PERIOD i~ 985 1464 0 124{ 1487 FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press 343 1314 24-HOUR RATE I~ 985 1464 0 24.0° 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. AUG 3 0 1995 /~s~.~il & 6as Cons. ¢0mr~L~ . : ~h0ra[le ,' Form 10-407 Submit In duplicate Rev. 7-1-80 C(:X~ ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATiON TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 9433' 5857' Bottom Kuparuk C 9453' 5871' Top Kuparuk A 9482' 5893' Bottom Kuparuk A 9665' 6029' 31. LIST OF A'I-I'ACHMENTS 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: 06/16/95 Page: 1 ARCO Alaska Inc. DAILY DRILLING REPORT WELL:2T-19 RIG:PARKER 245 WI: 55% SECURITY:0 WELLID: AK8117 AFE: AK8117 TYPE:DEV AFE EST:$ 1350M/ 1760M AREA/CNTY:NORTH SLOPE STATE."AK API NUMBER:50-103-20214 · FIELD: KUPARUK RIVER SPUD: 03/04/95 START COMP: FINAL: 03/05/95 (1) TD: 2967'(2967) SUPV:RLM 03/06/95 (2) TD: 3737'(770) SUPV:RLM 03/07/95 (3) TD: 4244'(507) SUPV:RLM 03/08/95 (4) TD: 4850' (606) SUPV: JT 03/09/95 (5) TD: 6644' (1794) SUPV: JT MW: 10.0 PV/YP: 18/19 APIWL: 11.4 DRILLING Moved rig 15' from 2T-18 to 2T-19. Rig accepted; nippled up; mixed mud. Tested diverter system; made up and oriented BHA. Spud at 1430 hours 3/4. Directional drilled 12.25" hole to 2967'. DAILY $108,936 CUM:$108,936 ETD:SO EFC:$1,458,736 MW: 10.0 PV/YP: 29/32 APIWL: 10.8 CIRCULATE CASING ON BOTTOM Directional d~illed 12.25" hole from 2967' to 3737'; circulated. Wiped hole to HWDP; serviced top drive. RIH to 3737'; no fill. Circulated and conditioned mud for casing. POOH; laid down BHA for inspection. Rigged up to run casing; safety meeting; ran 3 joints 9.625" casing. Circulated 100 barrels with full returns. RIH with casing to 3722'; laid down CCP. Landed out on hanger and rigged up Dowell. DAILY:S154,630 CUM:$263,566 ETD:SO EFC:$1,613,366 MW: 9.0 PV/YP: 13/ 9 APIWL: 10.6 DRILLING Cement 9 5/8" casing. Nipple up 13 5/8", 5M BOPE. Test all BOP equipment to 300 low and 3000 psi. Make up BHA. Circulate and test casing to 2000 psi for 30 minutes. Drill new hole to 3747'. Perform FIT to 12.5 ppg EMW. Directional drill 8.5" hole from 3747' to 4101'. Hole packed off and stuck pipe; jar on stuck pipe at 4036'. Pipe came free. Directional drill 8.5" hole from 4101' to 4244'. DAILY $113,126 CUM:$376,692 ETD:SO EFC:$1,726,492 MW: 9.5 PV/YP: 17/11 APIWL: 7.8 DRILLING Directional drill 8.5" hole from 4244' to 4850'. Service rig and top drive. Trip to change out BHA. Wash and ream from 4112' to 4556'; 11' fill. DAILY:S82,389 CUM:$459,081 ETD:SO EFC:$1,808,881 MW: 9.3 PV/YP: 18/16 APIWL: 6.6 WORKING ON DRAW WORKS Drilled 8.5" hole from 4850' to 6644'. Lost 500 psi pump pressure. Found wash out in MWD tool. Tight hole from 4130' to 3600'; had to pump out inside of casing. Expedited MWD from Niakuk. Proceeded to change out wear pads on drum while waiting for MWD. Phase III conditions between Date: 06/16/95 Page: 2 ARCO Alaska Inc. DAILY DRILLING REPORT Kuparuk and Prudhoe 0700-0100 hrs. DAILY:S76,376 CUM:$535,457 ETD:SO EFC: $1,885,257 03/10/95 (6) TD: 7860' (1216) SUPV: JT MW: 9.3 PV/YP: 16/12 APIWL: 5.2 DRILLING Changed out wear pads on drawworks drum. Trip in the hole; ream from 3722' to 3910'. Drilled from 6644' to 7860'. DAILY:S71,949 CUM:$607,406 ETD:SO EFC:$1,957,206 03/11/95 (7) TD: 9125' (1265) SUPV: JT MW: 10.9 PV/YP: 18/12 APIWL: 5.4 TRIPPING Drilled f/7860 t/9125. Trip for slow penetration. DAILY:S144,194 CUM:$751,600 ETD:SO EFC:$2,101,400 03/12/95 (8) TD: 9845' (720) SUPV: JT MW: 10.9 PV/YP: 27/22 APIWL: 4.2 TRIPPING Continue RIH. Drilled f/9125' t/9845'. Short trip to casing shoe. DAILY:S81,230 CUM:$832,830 ETD:SO EFC:$2,182,630 03/13/95 (9) TD: 9845' ( 0) SUPV: JT MW: 10.9 PV/YP: 24/16 APIWL: 4.2 POOH W/FA#1 C&S Drilling line. Reset and test duomatic. RIH f/casing shoe. Bridge @ 9820'. Condition and circulate hole. Drop survey. Pump slug. Pooh. With 8 stds of HWDP out of hole, hung thread on pin, PU, slips unset and dropped remaining BHA in hole. PU FA#1 and R IH. Circ dp capacity. Check for flow. Engage fish. Tried to circ. Plugged. Pull fish free w/up wt 350K. Drop bar. POOH. DAILY:S78,095 CUM:$910,925 ETD:SO EFC:$2,260,725 03/14/95 (10) TD: 9845' ( 0) SUPV: JT MW: 10.9 PV/YP: 21/13 APIWL: 4.2 RU TO RUN CSG POOH w/FA#I. Full recovery. LD fish. RIH w/BHA #8. Tight hole @ 9250'. Ream to bottom. Circ high visc sweep and condition hole. POOH. Back ream f/9466 t/9310' Cont. POOH. LD BHA. DAILY:S81,472 CUM:$992,397 ETD:SO EFC:$2,342,197 03/15/95 (11) TD: 9845' ( .0) SUPV: RLM MW: 10.9 PV/YP: 20/10 APIWL: 4.4 REPLACE PACK OFF Rig up to run casing. Run 7" casing to shoe at 3722'. Run in with casing to 9821'. Circulate 747 bbls., full returns. Cement casing. CIP at 2305 hrs. 3/14/95. Unflange stack and pick up same. Set slips with 100K casing wt. DAILY: $214,569 CUM:$1,206,966 ETD:S0 EFC:$2,556,766 03/16/95 (12) MW: 10.9 PV/YP: 20/10 APIWL: 4.4 TD: 9845' ( 0) RIG RELEASED SUPV:RLM Install packoff and FMC tubing spool. Test seals to 3000 ~. ~ -~' .... ~-'~ psi. Installed fullbore 7" valve. Inject remaining mud. ~ · ~ ~ ~~ Freeze protected 7x9. 625 annulus. Rig released 1030hrs. 3/15/95. AUG ~0 ~99~ DAILY:S22,419 CUM:$1,229,385 ETD:SO EFC:$2,579,185 Gas Cons. (;ommission Date: 06/16/95 Page: 3 ARCO Alaska Inc. DAILY DRILLING REPORT REMEDIAL AND COMPLETION OPERATIONS WELL: WELLID: AK8117 AREA/CNTY: FIELD: SPUD: RIG:NORDIC WI: 0% SECURITY:0 AFE: AK8117* TYPE:DEV AFE EST:$ OM/ 0M STATE: API NUMBER: START COMP: FINAL: 05/26/95 (13) TD:. 9845' PB: 9738' SUPV: DEB CIRC. OUT DIE. CAP, RUN 3 MW: 0.0 SEAWATER Move rig from 2T-20 to 2T-19. Accept rig @ 1500 hrs. 5/25/95. Run 3-1/2" single completion assembly. DAILY: $49,857 CUM: $49,857 ETD:SO EFC:$49,857 05/27/95 (14) TD: 9845' PB: 9738' SUPV:DEB POH-STAND BACK 3-1/2" TUB MW: 0.0 SEAWATER Continue running 3-1/2" completion assembly. Set packer. Test tubing. Packer leaking. POH, stand back 3-1/2" completion. DAILY:S30,700 CUM:$80,557 ETD:SO EFC:$80,557 05/28/95 (15) TD: 9845' PB: 9738' SUPV:DEB RIG RELEASED MW: 8.6 DIESEL/SW Continue RIH with 3-1/2" completion assembly. Set packer. Test packoff and tree. Secure well. Release rig @ 0600 5/28/95. DAILY:S141,686 CUM:$222,243 ETD:SO EFC:$222,243 6/3/95 RU SWS. Held safety meeting. PT lub to 5000#; test OK. Rih w/ gun #1 2-1/8" enerjet w/ bh charges, 6 spf, 90 deg 'V' ph, oriented 45/-45 deg from the lowside to shoot 9521'-9542'; depth ref CDR dated Mar 6- Mar 12, 1995. In position at 9517' to shoot 9521'-9542'; pressure tubing to 4700# to shoot overbalanced. Guns appear to not have fired; the 4700# wellhead pressure did not drop off. Bleed down wellhead to 0#. POH.At surf w/tool string; guns lost in hole, wellhead pressure 0#. RIH w/gun #2 2-1/8" enerjet w/bh charges, 6 spf, 90 deg 'V' ph, oriented 45/-45 deg from the lowside to shoot 9500'-9521'.In position at 9496' to shoot 9500'-9521'; pressure tubing to 4700# to shoot overbalanced. Fired gun; pressure dropped 300# at firing. Observed pressure for 10 mins; pressure decreased to 3400#. Total pressure drop after firing was 1300#. Appears to be a tight zone. RIH to bottom and made log of jewelry; POH w/gun #2. WeLlhead pressure is 100#. Wellhead pressure has incr to 400#; decided to reshoot lower interval. I believe the first set of guns must have been damaged while RIH. The ability to pressure the tubing to 400# prior to shooting gun #2 is indication that first gun not fired properly. RiH w/gun #3 2-1/8" enerjet w/bh charges, 6 spf, 90 deg 'V' ph, oriented 45/-45 deg from the lowside to re-shoot 9521'-9542'. In position at 9517' to re-shoot 9521'-9542'; guns fired. POM. At surf w/tool string. Gun fired. RD SWS for night. 6/13/95 MIRU SWS. Held Safety meeting - importance of communication /radio silence. PT lub to 3000#. Test OK. RIH w/gun #1 2-1/8" enerJet w/bh charges, 2 spf, 0 deg ph, oriented 90 deg CCW from the lowside to shoot 9515'- 9535'. In position @ 9510' to shoot 9515'-9535', fired guns. POH. At surf w/gun #1, all shots fired. PT lub to 3000#, test OK. RIH w/gun #2 2-1/8" enerjet w bh charges, 2 spf, 0 deg ph, oriented 90 deg CW from the lowside to shoot 9515'- 9535'. In position @ 9510' to shoot 9515'-9535'; fired guns. POH. At surf w/gun #2, all shots fired. KDMO. 6/16/95 MIRU. Held safety mtg. (perf. safety procedures.) Standby for rig move. Rig move delayed. Press. tested lubricator to 2000 psig. Picked up gun #1 (2-1/8" enerjet with bh charges, 2 spf, 0 degree phase, orientated 90 degrees CCW.) RIH. Tied into short jts. Made 21' correction. Set CCL at 9496' RKB to perf from 9500' to 9515'. Fired gun. POH. OOH. All shots fired. Picked up gun #2 (2-1/8" enerjet with bh charges, 2 spf, 0 degree phase, orientated 90 degrees CW.) RIH. Tied into flag at 9400' RKB. Made 20' correction. Set CCL at 9496' RKB to perf. from 9500' to 9515' Fired gun. POH. OOH. All shots fired. RD. End of WellSummary for Well:AK8117 PAG£ HOo 1 A~ ~ A)81t7 API W~LL =~ 50-103-20214-00 JO3 # *w*~*~o~*~o SURVEY PROGRAM ~oq*~***** CO~PAP¥ ARCO ACASkA WiLC H~M£ 27-19 COCqTIOq I XUPARUX LO£A~ICN 2 ALASKA MAGN~I:C ~£CLIHATION 28,51 ~RID CCHVSRO~HC~ AHGL£ 0,00 DAT£: 12-MAR-95 t~LC HEAO LOCATIOH: LAT(H/-S) 0,00 AZ!-~UTH ?~O~ ROTARY TA)CE TO TARC£T IS ~EP(£/-~) 0,00 TIE IH P][NT(TIP) : MEASURE~ ~£PTH 121,00 ?RU~ VERE D£PTH 121,00 INCL]~ATICN Q,O0 AiIMVTF 0,00 LATITCD£(¥/-S) 0,00 RECEIVED 1.~ ~5 JUL 07 oo ' A.~k~ Oil & 6as Cons, C~mmi~sion FA~£ SURVEY CALCULATIONS ~*~.~****~*** CIRCULAR ARC H£THO~****~*~ 2T-l? M£~SURED INT£RVAL VERTICAL ~EPTH ~EPTH ft ft ft 121,00 0,0 12!,00 374,33 ~3,3~- 374,~°~ 650,78 276,4 650.7~ 73~.06 87.3 737,99 827.70 89,6 827,62 ?~R~ET STATIOH AZIMUTH LATITUDE SE:TION INCLH, N/-S f: deg deg ft ~,00 0,00 0,00 0,00 -0,74 0,37 52,08 0,50 -4,79 1,50 51,78 3,28 -6,37 0.97 35,47 4,58 -5,91 1,41 279.88 5,39 D3FA~TER£ DISPLAC£HEN? at AZIMUTH f: ft dee 0,00 0,00 0,00 ~,~4 0,~1 52,08 4,t8 5,31 51,8~ 5,50 7,16 50,19 4,~5 7,25 41,9~ lOOft 0.00. 0.15 0,41 0,72 2,27 92!,15 1012,63 1194,75 1258,12 93,5 920,9~ 91,5 I012,05 90,0 1101,35 92,1 1192,19 93,4 1283,57 -~,36 4,29 260,64 5,02 7.05 6,27 255,98 ~,25 !~,4~ 8,33 256,61 0,56 33,49 I0,44 257,09 -2,85 ~2,63 I3,22 258,55 -6,86 ~,27 5,03 3,04 3,20 -7,95 8,59 292,27 2.21 -19,¢~ 19,07 271,67 2,29 -~3.6~ 33.80 265,16 2.29 -52,40 52,~5 262,54 3,00 1280,97 1474,59 1568,72 1668,65 1756,73 92,9 I373.37 95,6 1464,3C 92,1 1549,96 94,? 1635,89 93,1 1717,88 7~,18 16,17 258,50 -11,55 !85,68 19,78 258,79 -!7,35 13~.58 23,4! 257,65 -24,30 179,88 26,85 257,74 -32,89 223,~2 29,63 257,51 -42,33 -75,~8 76,36 261,30 3,17 -104,41 105,84 260,56 3,78 -t~7,59 139,72 259,98 3,95 · 17~,~7 180,00 259,47 3,62 -219,98 224,02 259,11 2,99 1851,73 1943,81 2037,21 2129,54 222~,70 95,0 I799,!5 92,1 1875,35 93,4 1949,85 92,3 2020.34 94,2 2088,51 273,10 32,74 257,37 -53,0~ ~24,76 35,54 258,74 -63,71 381,08 38,64 256.56 -75,79 44~,69 41,80 257,22 -89,30 535,61 45,41 259,34 -102,45 -267,99 273,19 258,81 3,27 -318,54 324,85 258,69 3,16 · ~73,55 381,16 25S,53 3,61 -~!,61 440,75 258,31 3,45 -495.19 505,68 258,31 4,13 2316,30 2407,79 2502,51 2597,47 2691,09 92,6 2151,47 91,5 2209,73 94,7 2265,63 95,0 2316.84 93,6 2363,25 573,47 48,91 258,30 -115,63 645,00 51,98 257,00 -130,73 723,44 55,66 258,40 -146,99 890,39 59,07 257,90 -163,41 881,~7 61,49 258,98 -179,69 -5~!,78 573,56 258,37 3,86 -83~,(8 644,08 25~,29 3,53 -7¢5,37 720,52 258,23 4,06 -783,82 800,48 258,22 3,62 -8~3,27 881,77 258,24 2,77 287$,67 3067,41 3252,80 3439,7~ 364~,71 188,6 2454,76 187,7 2548,75 185,4 2639,41 187,0 2728,69 209,9 2529,57 1046,48 . 60,45 258,86 -211,37 120~,08 59,47 256,03 -246,67 1370,67 61,99 258,57 -281,75 1534,~3 ~0,97 257,82 -314,94 I719,03 61,59 257,44 -354,38 ']C25,~7 1046,64 25S,35 -1!~3,69 1209,12 258,23 'JS41,52 1370,79 25~,14 '~ ~ 1535,0~ 258,16 -]~82,24 1719,I7 255,10 0.55 1,40 1,90 0,74 0,33 382!,99 39I&,25 4141,82 421~,73 447!,37 172,3 2912,92 94,3 2959,18 225,6 3073,96 72,9 3112,8C 256,6 3249,54 1869,80 60,55 257,83 -386,67 i95],92 60,66 257,24 -404,39 2145,¢7 58,I6 256,42 -448,61 22~7,78 57,46 257,72 -462,42 2424,80 5~,17 261.02 -502,44 -I~29,52 1869,94 258,07 -1~0~,71 I952,06 25S,04 -!0~8,77 2146,13. 257,93 -2!58,~1 2207,87 257,91 -!372,34 2424,9~ 258,04 0,64 0,56 1.15 1,80 1,12 4661,4._. 4942,85 5221,94 5505,82 5707,23 190,1 3344,8C 281,4 3477,90 279,1 3610,79 283,9 3745,0~ 281~4 3881,65 25S~,85 61,67 261,88 -526,87 2835,I0 61,86 261,19 -563,37 S08],41 '61,33 256,26 -611,32 3231,45 62,18 256,62 -669,95 2577,45 59,75 256,66 -726,79 -253~,¢0 2589,17 25~,26 -!780,10 2836,6? 258,54 -3¢2:),e4 3082,07 258,56 -32~3,94 3331,98 258,40 -3503,2! 3577,91 255,28 1,88 0,23 1,56 0,32 0,86 SURVEY CALCULATIONS *w*~*~******* CIRCULAR ARC M~ASURED !NtERVAC VERTICAL DEPTH DE?TH ft ft ft 606E,29 279,1 4021,16 624~,88 282,6 4160,44 663C,40 281.5 4301,43 69!3,23 282,8 4446,82 7I~2,05 278,8 4587,52 TA!~E? STATION AZIMUTH LATITUDE SECTION INCLN, N/-S ft deq deq ft ~819,!2 60,26 256.88 -7B2,09 ~6S,C0 60.6B 257,61 -B36,37 433S,57 59,23 254,44 -895,16 ~55~.72 5~,91 253,41 -962,31 47~0,63 60,34 253.05 -I031,72 D~P~R?UR£ DISPLAC£M~NT at E/-~ 'ft ft ~ .... -,~, 3817,~0 '3778,~9 4065,35 -:2:4,e2 430~,~3 -4~47,94 4550,85 -~7),24 4790,66 AZIMUTH 258,18 25B,13 255,01 257,79 257,56 de~/ lOOft 0,20 0,27 1,10. 0,33 0,53 7474,84 775~,4~ 8039.53 ~321,13 282,8 4728,76 281.0 5027,39 281,6 5182,45 278,7 53S5,0~ 5¢35,28 59,88 255,14 -1098,93 5276,91 57,11 254,17 -1162,90 55!~,91 57,22 257,33 -1221,03 ~749,28 56,74 256,44 -1274,66 5~8~,45 56,67 256,61 -1328,99 -4914,00 5035,33 257,39 -5147,18 5276.92 251,27 -5376,01 5512,93 257.20 -~EOS,~3 5749,31 257,19 -5~3,01 5982,47 257,16 0,66 1,02 0,95 0,28 0,11 ~69~,45 8787,02 ~87~o26 8972,~0 93,6 5386.7I 92,6 5439,$~ 92,2 5494,7I 93,2 5552.40 46,5 5581,77 60~0~52 56,34 255,67 -1347,69 6137,~ ~q 54,48 256,v8, -1365,91 (211,67 52,51 257.73 -1382,16 6284.g0 51,02 257,67 -1397,76 E320,75 49,95 257,7? -1405,37 -SgO),~l 6060,56 257,15 -59~3,6~ 61~7,5~ 257,I4 -6C5~,~9 6211,72 257,14 -~[27,54 62~4,94 257,15 -6162,58 6320,7? 257,15 2,30 2,23 1,59 2,32 ?067,08 916~,43 9254,47 934E,21 9441,46 48.I 56!3,02 ??,4 5677,3~ 88,0 5734,94 91,7 5796,50 95,3 5863,0t ~257,49 49,64 257,51 -1413,23 d433,15 49,62 256,~5 -1430.03 649?,79 48,73 255,45 -1445,98 ~5~?,75 46,96 255,12 -1463,25 6E3~,87 44,46 255,02 -!4B0,81 -5[~8,:7 6357,53 257,16 -6272,27 6433,23 257.16 -5326,?~ 6497,84 257,15 -6402,74 6567,81 257,13 -5:~8,61 6635,94 257,1! 0,78 0.50 1,57 1,95 2,62 ?542,42 ?763,99 9845,00 101,0 5936,52 221,6 6102,78 PROJECTED 81,0 6164,22 &,~ no 42,07 256,16 '1498,05 6~51,45 40,68 256,34 -1532,87 TO T~ 6~04,24 40,68 256,34 -I545,34 -6535,~1 6705,10 257,09 -5677,~7 6851,54 257,07 -677, lfi 6904,34 257,07 2,49 0,63 0,03 ARCO Alaska, Inc. Date' May 4, 1995 Transmittal #. 9235 RETURN ~~"-'~-'--~-----~- ~--- Attn: Brian Hebert ._ ARCO Alaska, Inc. Kuparuk Operations File Clerk' "--- ATO-1119 B T:":-_O. BOx 100360 Anchorage, AK 9951 0-0360 Transmitted below are the following open hole items. receipt and return one signed copy of this transmittal. ~' ,-,~'- ~'~ ? 2%20 CDR Final Print 3/18-23/95 ~.3 - l¢ (,.o 1Y-18 CNTG Depth Corrected 9/9/93 2T-19 CDR Final Print 3/6-1 2/95 DISTRIBUTION_: Please acknnwledge Ref# 50-123-20215 Ref#93423 MAY 9 1995 Alaska Oil & Gas Cons. Commission Anchorage Mr. Vernon E Pringle, Jr. (Geology) DeGIoyer and MacNaughton One Energy Square Dallas, TX 75206 Sharon AIIsup-Drake DS Development ATO- 1205 Clifton Pose,/ Geology ATO 1251 Erickson/Zuspan NSK Central Files NSK 69 Larry Grant (+Sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Sandy L~mke ATO 1336 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9438 Company: 5/2/95 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-19 95105 CDR 031295 I I 1 2T-20 95113 CDR 032395 I I 1 1Y-18 93423 REDO CNT-G 090993 I I 1 · , ::~Pi"EASE NOTE: ' MA'f "~-"18':REPROCESSED TO INCLUDE AVERAGE: ~,laaka 0il & Gas Cons. Commission .,. Anchorage SIGNED: ~_ DATE: MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: FROM: David Joh,~, Chairman J Blair Wondzell, P. i. Supervisor Dou'" Amos ~ t-'e~ro~eum Inspector DATE: FILE NO: SUBJECT: March 6, 1995 abxhcfcd.doc BOPE Test Parker 245 Arco KRU 2T-19 Kuparuk Rv. Field PTD No. 95-026 Monday~ March 6~ 1995: I was called out at 12:00 noon to witness the BOPE test at Arco's KRU 2T-19 well on Parker Rig 245. When I arrived on location the crew was still in the process of nippling up the BOPE stack. While waiting for the commencement of the test I updated the Arco and Parker representatives computers with copies of the new AOGCC BOPE test form. The test commenced at 3:30 PM and was concluded at 6:00 PM. As the attached AOGCC BOPE Test Report indicates, there were no failures and the rig was in compliance with the additional requirements of the BOPE Test Report Form, i.e. PTD was on location; Standing Order was posted; Hazardous drilling area's posted. SUMMARY: I witnessed BOPE test at Arco KP, U 2T-19 well on Parker Rig 245. 24 Valves, No Failures, 3.0 Test Hours Attachments: ABXHCFCD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Parker Drilling Rig No. Operator: Arco Alaska Inc. Well Name: KRU 2T-19 Casing Size: 9 518" Set @ 3,722 Test: Initial X Weekly Other 245 PTD # Rep.: Rig Rep.: Location: Sec. 95-026 DATE: 316195 Rig Ph.# 659-7670 Bobby Morrison Granville Rizek 12 'I'. 11N R. 8E Meridian Umiat Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location Yes Standing Order Posted Yes BOP STACK: Quan. Annular Preventer 1 Pipe Rams 2 Pipe Rams 1 Blind Rams 1 Choke Ln. Valves 1 HCR Valves 1 Kill Line Valves 2 Check Valve N/A Well Sign OK Drl. Rig OK Hazard Sec. Yes Test Pressure P/F 300/3,000 P 300/3,000 P 300/3,000 P 300/3,000 P 300/3,000 P 300/3,000 P 300/3,000 P N/A N/A FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Quan. Pressure P/F 1 300/3,000 P 1 300/3,000 P 1 300/3,000 P 1 3OO/3,O0O P CHOKE MANIFOLD: No. Valves 16 No. Flanges Manual Chokes 2 Hydraulic Chokes 1 Test Pressure P/F 300/3,000 P 38 300/3,000 P P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure 3,000 I P Pressure After Closure 1,800 I P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure 0 minutes 36 sec. Trip Tank OK OK System Pressure Attained 2 minutes 57 sec. Pit Level Indicators OK OK Blind Switch Covers: Master: Yes Remote: Yes Flow Indicator OK OK Nitgn. Btl's: 6 (~ 2150 (Avge.) Meth Gas Detector OK OK Psig. H2S Gas Detector OK OK Number of Failures: 0 ,Test Hrs.: 3.0 Hours. Number of valves tested 24 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at: 279-1433 REMARKS: Good Test! ! Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c -Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Doug Amos F1-021 L (Rev. 12/94) ABXHCFCD.XLS ALASKA OIL ~ND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVEi~NOI~ 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 1, ~995 Michael Zanghi Drill Site Devlop. Supv. ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2T-19 ARCO Alaska, Inc. Permit No: 95-26 Sur. Loc. 53'FNL, 556'FWL, Sec. 12, TllN, R8E, UM Btmhole Loc. 1566'FNL, 914'FEL, Sec. 10, TllN, 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. Sincerely, Russell A. Douglass Commissioner 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 N_A..SKA ALASKA OIL AND GAS CONSERVATION COMMI:SSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [] lb Type of Well Exploratory [] Stratigraphic Test [] Development Oil X Re-Entry [--] Deepen ['"J Service E] Development Gas r-] Single Zone X Multiple Zone E] 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, Anchoracje, AK 99510-0360 ADL 25568, ALK 2666 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 2O AAC 25.O25) 53' FNL, 556' FWL, Sec. 12, TllN, RSE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1508' FNL, 656' FEL, Sec. 10, T11N, R8E, UM 2T-19 #U-630610 , At total depth 9. Approximate spud date Amount 1566' FNL, 914' FEL, sec. 10, T11N, RSE, UM 3/1/95 $200,000 1 2. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2T-1 8 9886' MD 914'~ TD feet 14.7' ~ 400' MD feet 2560 6208' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2O AAC 25.035(e)(2)) Kickoff depth 800' feet Maximum hole angle 60.4° Maximumsudace 1707 psig At total depth (TVD) 3100 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement , Hole Casing Weight Grade Couplinc~ Length MD TVD MD TVD linclude sta~,e datat 24" 16" 62.5# H-40 Weld 80' ~1' 41' 121' 121' +200 CF 12.25" 9.625" 40.0# L-80 BTC 3631' 41' 41' 3672' 2884' 680 Sx Arcticset III & HF-ERW 570 Sx Class G , 8.5" 7" 26.0# L-80 BTCMOE 9845' ~1' 41' 9886' 6208' 260SxClassG HF-ERW Top 500' above Kuparuk 1 9. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True VerticaJ depth Structural R E C E IV E D Intermediate ProductionF E 8 2 3 19 9,5 Liner Perforation depth: measured /~,!~$~. 0il & (~aS Cons. Commission true vertical Anch0r~., 20. Attachments Filing fee X Property plat [] BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [] Refraction analysis r'~ Seabed report [-~ 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge / / Signed . Title Drill Site Develop. Supv. Date ~ '~ Commission Use Only Perm(:~,.~m~~c::~ I'-~Plnumber I Approva,~at,~_~._/ ,~,,..~,~- J see cover letter for ~ 150-/'"('~, ~' --' -~- ~ ~--,/'~7/ ~ other requirements Conditions of approval Samples required r-] Yes ~] No Mud logrequired [~ Yes ~[] No Hydrogen sulfide measures ~] Yes [~ No Directional survey required ~] Yes [--] No Required working pressure for BOPE ['-1 2M ~ 3M [] 5M E] 1OM r-] 15M Other: ORIGINAL SIGNED BY RUSSELL A. DOUGLASS by order of Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triolicate . . , 10. 11. 12. 13. 14. 15. 16. 17. 18. GENERAL DRILUNG PROCEDURE KUPARUK RIVER FIELD 2T-19 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (3,672')according to directional plan. Run and cement 9-5/8" casing. Install and test mOPE. 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 (9,886') 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 & full opening valve for cased hole logging. Secure well and release rig. Run cased hole cement evaluation. ND full opening valve and NU master valve and cap. Move in and rig up Nordic #1. Install and test mOPE. Pressure test 7" casing to 3500 psi. Perforate and run completion assembly. Set and pressure test packer. ND mOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVED FEB 2 ,'5 i99,5 Oil & Gas Cons. Commission Anch0r-~ · DRILLING FLUID PROGRAM Well 2T-19 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 15-40 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 10.6 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 surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a sudace pressure of 1,707 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 2T-19 is 2T-18. As designed, the minimum distance between the two wells would be 14.7'@ 400' 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 the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by Arctic pack upon completion of fluid pumping. Risks in the 2T-19 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 10.6 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 FEB 2,~ 1995 0il & 6as Cons. Commission Anchorr ,iCreoted by : jones For: D PETRASH !Dote plotted : 7-Feb-95 !Plot Reference is 19 Version #.3. iCoordinates are in feet reference slot #19. iTrue Vertical Depths are reference Estimated RKB.t i --- Baker Hughes INTEQ --- I I V 350 m 0 7200 6800 6400 ARCO ALASKA, ][110. Structure : Pad 2T Field : Kuparuk River Unit Well : 19 Location : North Slope, Alaska <-- West 6000 5600 5200 4800 4400 4000 3600 3200 2800 2400 2000 1600 1200 800 II II II II II II II II II II II II II I I Scale 1 : 200.00 400 0 400 I I I I I 350 1050 _ 1400_ _ 1750' _ 210DI 2450t 2800t 3150J 3500_ _ 3850_ 4200 _ 4550_ 4900_ _ 5250_ - 5600_ _ 5950_ TO LOCATION: I 1566' FNL, 914' FEL SEC. 10, T11 N, RSE ES'II~All~ RKB EkEI/A~]0N: 125' TARGET LOCATION: 1508' FNL, 656' FEL SEC. 10. T11N. RSE TARGET 'i'VD=5895 TMD=9475 DEP-6653 SOUTH 1455 WEST 6492 KOP TVD=800 TMD=800 DEP=O 6.00 12.00 BUILD 3 18.00 B/ PERMAFROST TVD=150$ TMD=1520 DEP=134 2,koo T/ UGNU SNDS TVD=1548 TMD=1569 OEP=lSD 30.00 '~ 42.00 48.00 T/ W SAK SNDS TV0=2257 TMD=2457 DEP=675 5¢.00 60.00 EOC WD=2461 TM0=2815 DEP=968 B/W SAK SNDS TVD=2675 TMD=5244 0EP=13¢1 9 5/8" CSG PTTVD=2884 TMD=5672 DEP=1713 K--lO TVD--3034 TMD-3976 DEP-197B K-5 WD=4533 TMO=7014 DEP=462! ESTIMATED SURFACE LOCATION: 53' FNL, 556' FWL SEC. 12, T11N, R8E S 77.37 DEG W 6653' (TO TARGET) RECEIV[D FEE~ 2 5 1995 ~:~ka Oil & Gas Cons. Corr]mjssio~ Anch0r~ ... MAXIMUM ANGLE 60.44 DEG TARGET ANGLE 6~ooi 40 DEG 6650 550 0 350 700 1050 1400 1 21 O0 24 2800 3150 3500 3850 4200 Scale 1 : 175.00 Verticol Section on Z57,37 ozimuth with reference 0,00 N, 0.00 E from slot #19 BEGIN ANGLE DROP '[%/0-5243 TMD-8455 DEP-5872 60.00 66.00 DROP 2 D£G / 100' 50.00 46.00 TARGET - T/ ZONE C (EOD) TVD=5893 TMD=9475 DEP=6653__ T/ ZONE A '[VD=5958 T~D=9533 T/A3 SNOS TV0=5956 TMD=9557 DEP=6706 ,,% B/ KUP SNDS TVD=6055 TMD=9686 DEP=6789 TD / ?" CSG PT TVD=6308 TMD=9886 DEP=Ogt8 i i i i i i i i i i i i i i i 4.550 4900 5250 5600 5950 6300 6650 7000 40O o B 8 4OO 0 - I _1200 I V _180O _20~ ARCO ALASKA, Inc. Structure : Pad 2T Well: 18 / 19 Field : Kuporuk River Unit Location : Nor'th Slope, Alaska West Scale 1- lO.OO ~ 560 340 520 ~ 280 260 240 220 200 180 160 140 120 1 oo 80 60 40 20 0 20 40 60 80 100 I. I I I I I I I I I I I I I I I I I I I I I I I t I I I I I 1 I I I I I I I I I ! I I I I I I I '~3700 ~ 90O 1000 RECEIVED FEB 2. 5 1995 0il & Gas Cons. Commission Anchorr. 120 " .o loo 8 20 1 oo 120 V 160 180 2O0 220 24O _ 260 300 Casing Design/Cement Calculations 16-Feb-95 Surface Csg MD: Surface Csg TVD: Production Csg MD: Production Csg TVD: Top of West Sak, TMD: Top of Kuparuk, TMD: Top of Target, C Sands, TVD: Estimated Pressu re: Surface Casing Choice: Production Csg Choice: Production Casing Frac. Pressure 3,672 ft 2,884 ft 9,886 ft 6,208 ft 2,457 ft 9,475 ft 5,893 ft 3100 psi ** See Page 4 For Casing Choices 3,500 psi Maximum anticipated surface pressure Estimated BH pressure at top of target zone -I-VD surface shoe {(13.5'0.052)-0.11}*TVDshoe Estimated Pressure= Top of Target, TVD = Overbalance, psi= Anticipated Mud Weight =[ 2,884 ft 1,707 psiI 3,100.0 ppg 5,893 ft 150 psi 10.6 ppg~ Surface lead: Top West Sak, TMD = 2,457 ft Design lead bottom 500 ft above the Top of West Sak = 1,957 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 663 cf Excess factor = 100% Cement volume required = 1,325 cf Yield for Permafrost Cmt = 1.94 Cement volume required =1 680 sxJ Surface tail- TMD shoe = 3,672 ft (surface TD ~ 500' above West Sak) * (Annulus area) = 537 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4257 cf/If Cmt required in casing = 34 cf Total cmt = 571 cf Excess factor = 15% Cement volume required = 657 cf Yield for Class G cmt = 1.15 Cement volume required =[ 570 sxJ RECEIVED FEB 2 ,'3 t995 Casing Design / Cement Calculations 16-Feb-95 Production tail: TMD = 9,886 ft Top of Target, TM D = 9,475 ft Want TOC 500' above top of target = 8,975 ft 5" casing tail top (100' above C sand) =1 9,886 ft 5" Annulus area (9" Hole) = 0.3054 7" Annulus area (9" Hole) = 0.1745 (5" Casing Top-TOC)*7" Annulus area + (5" to TD)* 5" Annulus area = 159 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.2148 Cmt required in casing = 17 cf Total cmt = 176 cf Excess factor = 75% Cement volume required = 308 cf Yield for Class G cmt = 1.19 Cement volume required =1 260 sxI TENSION - Minimum Design Factors are: T(pb)=l.5 and T(js)=l.8 Surface (Pipe Body): Casing Rated For: Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =[ Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ Production (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/R) = Dead Wt in Air = Buoyancy = Tension (Pipe Body)= Design Factor =1 Production (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ 916000 lb 3,672 ft 40.00 Ib/ft 146880.0 lb 23170.4 lb 123709.6 lb 979OOO lb 3,672 ft 40.00 Ib/ft 146880.0 lb 23170.4 lb 123709.6 lb 7.9] 604000 lb 9,886 ft 26.00 Ib/ft 257036.0 lb 41114.9 lb 215921.1 lb 667000 lb 9,886 ft 26.00 Ib/ft 257036.0 lb 41114.9 lb 215921.1 lb Casing Design / Cement Calculations BURST - Minimlcm Design Factor = 1.1 Surface Casing: Burst = Maximum surface pressure Casing Rated For: Max Shut-in Pres = Design Factor =[ Production Csg: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres (3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor COLLAPSE - Minimljm Design F~ctor = I.Q Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' 'I'VD with 9.0 # Mud 2. Ext. Pres=Mud Wt*0.052*TVD-(2000'TVD of 9# Mud) Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ Production Csg 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =L 16-Feb-95 5750 psi 1707.3 psi 3.4J 7240 psi 6924 psi 2873 psi 4051 psi 1.81 3090 psi 0.552 Ib/ft 655 psi 4.7] 5410 psi 0.552 Ib/ft 3424 psi 1.6J RECEIVEr) Anchor[ - Casing Design / Cement Calculations 16-Feb-95 Surface Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength I 9.625 8.681 47 L-80 13.5724 sq. in. 1161000 lb 1086000 lb 2 9.625 8.835 40 L-80 11.4538 sq. in. 979000 lb 916000 lb 3 9.625 8.921 36 J-55 10.2545 sq. in. 639000 lb 564000 lb 4 10.750 9.950 45.5 J-55 13.0062 sq. in. 931000 lb 715000 lb Collapse Burnt 4750 psi 6870 psi 3090 psi 5750 psi 2020 psi 3520 psi 2090 psi 3580 psi Production Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength I 7.000 6.276 26 L-80 7.5491 sq. in. 667000 lb 604000 lb I 5.000 4.276 18 L-80 5.2746 sq. in. 376000 lb 422000 lb 2 7.000 6.276 26 J-55 7.5491 sq. in. 490000 lb 415000 lb Collapse Burnt 5410 psi 7240 psi 10490 psi 10140 psi 4320 psi 4980 psi ..UPARUK RIVER UN[ 20" DIVERTER SCHEMATIC 6 I4 3 2 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. . MAINTENANCE & 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) 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. 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. REC£1VED DKP 11/9/94 I , 6 5 13 5/8" 5000BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER lIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 10. 11. 12. 13, 14. BOP STACK TEST I 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 UNE 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. ~INUE TESTING ALL VALVES, lINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM 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 TESTTO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOM~ PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILUNG SUPERVISOR. 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 SPOOLW/ 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 RECEIVED 3 ~,,~[~. Oil & GaS CONS. Cornmissio~ Anchor[ WELL PERMIT CHECKLIST FIELD POOL ?O COMPANY /- / WELL NAME GEOL AREA UNIT# PROGRAM: exp [] dev~ redrll [] serv [] ON/OFF SHORE O/~ ADMINISTRATION 1. Permit fee attached ................... 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary. 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ....... ENGINEERING APPR 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. wellbore separation proposed ......... 22. Adequate diverter required, is it adequate .......... 23. If 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to ~~) psig. Y~ 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of E2S gas probable ............. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... 32. Seismic analysis 9f shallow gas zones .......... Y./ 33. Seabed condition survey (if off-shore) ........ 34. Contact name/phone for weekly progress reports . · . /. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: zlz Comments/Instructions: HOW/Jo - A:%'=ORMS%cheklist rev 03/94 c) Z 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. Gas ns. * ALAMKA COMPUTING CENTER * ****************************** *mmememmmemmmmmmmmmmmmmmeeemm, *------- ~CHLUMBERGER ****************************** C[]~PANY NA~E : ~RCO ALASKA, WELL NAME : 2T-19 FIELD NA~E : KUPARUK RIVER UNIT RC)ROUGH : NORTH SLOPE STATE ~ ALASKA API NUMBER : 50-103-20214-00 ~EFERENCE NO : 95105 IS Tame Verification Listing chlumberger AlasKa ComputinQ Center 21-APR-!995 15:43 SFRVICE NA~E : FOIT D~T~ : 95/04/21 OPlGIN : FLIC RFE[, WA~E ~ g5105 CONTINUATIOM PREVIOUS RE~L COM~fNT : ARCO ALASKA INC,, KUPARU~ 2~-lg , AP! #50-103-20~14-00 **** TAPE HEADER **** SERVICE NAME : EDiT D~TF : g5/04/21 ORIGIN : FLIC T~P~ NAME : g5105 CONtINUaTION # : l P~EV'IOUS TAPE ~ COMMENT : ~RCO ALASKA INC,, KUPARUK 2T-19 , APl #50-103-20214-00 TAP~ ~EADER KUP~RUK RI~ER UNIT MWD/MAD bOGS W~bI, NA~E: API NUMBER: OPERATOR: LOG~!NG COMPANY: TAPE CREATION DATE: JOB DATA jOB DATA 2T-19 50t. 032021.400 2J-APR-95 BIT RUN 1 BIT ~UN 2 BIT RUN 3 95105 95105 95105 NICObS/STANOUR N'ICOI,$/$TAMOUR N!COL$/$TA~OUR MORRiSON TRANTHAM TRANTHAM BIT RUN 4 BIT RUN 5 95105 95105 NICObS/STA~OUR NICOL$/STA~OUR TRANTHA~ TRANTHAM SURFACE LOCATION SECTION: TOWNSN!P: RANGE: FNL: FSL: FEb: FWL~ ELEVATION(FT FROS KELLY BUSMING: DERRICK FLOOR: GROUND bEVEL: 12 lin 53 556 12200 80~50 PAGE: I$ Tape Verlficat~on Listin0 chlumberger AlasKa Computt~ Center 21.-~PR-1995 15:43 WFLL CaSInG RECORD 1ST STRING 2ND STRING ~RD STgING PRODUCTION STRING qPEg MOLE CASING DRILLERS BIT SIZE (IN) SIZE (1N) DEPTH (FT) 9'. 625 3792,0 8,500 Drilled iDterval 3673' to 9845', Well drilled 6-~AR through ~2'MAR, ~995, No deptb-shlftimG perfor~i,~ as Der Dave sharer of ARCO, K,B'': TOPDRIVE. LOG ~EASURED FROM DRILI~ FLOOR, $ $ PAGEt **** FILM ~EADER **** FILE NA~E : EDIT ,00! SERVICE : FLIC VERSION : 00lC01 DAT~ : 95/04/21 MAX REC SIZE : 1024 FIL~ TYPE : LO LAST FILE : FILE HEADER F/hE NU~BER: EDITED ~ERGED MWD ~epth s:~ifted and clipped curves: all bit runs ~erged. D~PTH INCR ~ : 5 E ~EN'T O, 000 FIL~ SOl, MARY LDWG TOOL CODE START DEPTH STOP DEPTH ~WD 3737 9845,0 CURVE SMIFT DAT~ (~iEASU~EO DEPTM) ----------M(~UiVALENT O~SMIFTMD OEPTM-.-----~-- ~ASELIME DEPTH MERGED DATA SOURCE LDWG TOOL CODE $ BIT RUM NO ,ERGE TOP MERGE BASE ~ 3737,0 4246,0 2 4246,0 4556,0 3 4556,0 6644~0 4 6644.0 9~.25,0 5 9~.25,0 9845,0 IS Tape Verification Listing chlumberoer AlasKa Computtno Center 21-~PR-19g5 15:43 PAGE: RE;4ARK$: f~o depth-shifting this well, This file contains the very enhanced ORO resistivity ~itb ~' average reprocessec at GeoOuest 21-APR-95, $ LIS FORMAT DATA DATA FOR:4AT SPEC!~'ICATIO~: RECORD SET TYPE - 64EL *~ TYPE REPR E VAL, E I 66 0 2 66 0 4 66 5 66 6 73 7 65 8 68 0,5 1~ 66 ' 12 68 13 66 0 14 65 15 66 68 16 66 0 66 0 ** SET TYPE - CHAN ** N S~RV U T SERVICE API API API FILE N MB NUMB REPR ESS ~R ID ORDE # LOG TYPE CLASS MOD NUMB SAMP ~EM CODE (MEX) ........ ........................ .........-..........,............ ..... DEPT FT 619185 00 000 00 0 ! ~ 4 68 00 0000 GR ~WD GAPI 619185 O0 000 O0 0 I I ! 4 68 0000000000 ROP NWD FPHR 619185 O0 000 O0 0 1 ~ ! 4 68 0000000000 F~T MWD HR 619185 O0 000 O0 0 1 1 ~ 4 68 0000000000 RA ~WD OH~ 619185 O0 000 O0 0 I ! ~ 4 68 0000000000 RD ~ND OHHM 619185 O0 000 O0 0 1 I ! 4 68 0000000000 DER MWD OH~M 619185 O0 000 O0 0 I I I 4 68 0000000000 V~A MWD Og~ 619185 O0 000 O0 0 I I 1 4 68 0000000000 VDP ~WD OH~ 619185 O0 000 O0 0 I ! 1 4 68 0000000000 ** DaT.a ** IS Tape Veri. ficatJon Llsttnq chlumberger AlasKa Computing Center 21-APR-1995 15:43 PAGE: DEPT. 9845.000 GR.MWD RA,MWD -9q9.250 Pp. MwD VRP,~W~ -999.250 -999.250 ROP.MWD 73,490 -999.250 DER.~WD -999,250 DFPT. ]672,500 GR,MWD 44.703 ROP.MWD -999.~50 R~.~WD -999.250 ~P.MWD -999°250 DER°~WD -999°250 VRP.~W~ -999.250 FET.N~D VRA.HWD FET,~WD VRA,MWD '999,250 '999.250 -999,250 -999,250 ** E~D OF DATA ** **** FILE TRAIt, ER FILF NA~E : EDIT .001 SERVICE : FbIC V~RSION : O01CO1 DATE : ~5/04121 MAX R~C SIZE : 1024 FILE TYPE : LO LAST FI!,E : **** FILE HEADER **** FILE NA~E : EDIT .002 SERVICE : FLIC V~RSION : O0~CO1 DATF : 95/04/~1 MAX AEC SIZE : 10~4 FIL~ TYPE : LO LAST FILE : FILF }~EADER FILM NUMBER 2 R~W MWD Curves and log header data for each bit run in separate files, BIT RUN NUMBER: 1 DFPTH INCREMENT: 0,5000 # FILF SUMMARY VENDOR TOOb CODE START DEPTH 367 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION; DOWNHOLE SOFTWARE VERSION: DATA TYPE (ME~,ORY or REAL-TIME): STOP DEPTH 4245,0 07-MAR-95 FAST2,5/LOGOS20.4 V40C IS Tape Verification Listinq chlumberger AlasKa Comp,.!ttnO Center 21-APR-1995 15:43 PAGE: TI) DRILLER (FT): TOP LOG INTERVAL ROb>TOM LOG iNTERVAL {FT): PIT ROTATING SPEED [~O[.E INCLINATION (DEG) MINIMI)~ ANGLE~ MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE .... . ............... ..... CDR GAM~A RA Y/RESISTIVITY CDR GAM~A RAY/RESISTIVITY $ ROREHObE AND CASING DATA OPEN HOLE BIT SIZE (IN)~ DRILLERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: DENSITY (LB/G): VISCOSITY MUD PM: CHLORIDES (PPM): FLU'ID bOSS RESISTIVITY (OH~M) AT TEMPERATURE (DEGF): ~UD AT MEASURED TEMPERATURE (MT): ~UD AT MAX CIRCULATION~ TEmPEraTURE : ~tJD FILTPATE AT (~T): ~UD CAKE AT (NT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EW~ FREQUENCY 4245.0 3672.0 4245.0 TOOL NUMBER RGS02 RGSO35 8 5oo LSND 0 2,490 2.!30 ~EMARKS: RUNII DRILLED iNTERVAL 3737':' - 4246' RUNI: BIT TO GR: 75.53 FT' TO RES, 65,!! FT, DOWNHOLE SOFTWARE V4.0 $ LIS FORMAT DATA 66.0 66.0 IS Ta~e Verification chlumberger Alaska Computin~ Cemter 21-APR-1995 15:43 PAGE: ** DATA FORMAT SPECIFICATIO~ PECORD ** ** SET TYPE TYPE REPR CODE VALUE i 66 0 2 66 0 4 66 5 66 6 7] 7 65 11 66 16 12 68 13 66 0 14 65 FI 15 66 6B i6 66 0 66 ** SET TYPE - CHAN ** NA F SERV N SERVICE AP API AP API FIL~ NU B NUMB S ZE EPR PR ESS ID ORDER # bOG TYPE CLASS ~OD NUmB SA~P ELEM CODE (HEX) DEPT MT 619185 0 000 O0 0 2 1 i 4 68 0000000000 GR LW1 G~PI 619185 O0 OOo O0 0 2 1 I 4 68 0000000000 ROPF LW1 F/HR 619185 O0 000 O0 0 2 1 1 4 68 0000000000 TAB bWl H~ 619185 O0 000 O0 0 ~ 1 I 4 68 0000000000 ATR LWl OH~ 619185 O0 000 O0 0 2 1 I 4 68 0000000000 PSR LW1 OH~ 619185 O0 000 O0 0 2 t I 4 68 0000000000 DER LW1 OHM~ 619185 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** .4245,500 OR,LTl ~999.250 ROPE'bWI 99.444 TAB.[.W! -999.~50 999.250 PSR.,LWI 999,250 DER:,DW1 -999,~50 ** END OF DATA ** IS Tape Verification ListJno chlumberger AlasKa ComPutind Center 2~-~P~-1995 15:~3 PAGE~ **** FILM TRAI[,E~ **** F~LF NA~E : EDIT ,002 SERVICE : FbIC VERSION : OO1C01 DATE : 95/04/21 ~X REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILM HEADER F~LF NA~E t EDIT .003 SERVICE : ?LIE VERSION : 00!C01 DATE : q5/04/~1 ~AX REC SIZE : FILE TYPE ~ LO LAST FILE FILE NU~ BER 3 Curves and log header data for each bit run in separate files, BIT RUN NUMBER: 2 DEPTH INC~EMENT: 0.5000 ~:ILE SUMMARY VENDOR TOOL CODE START DEPTM 4t ,0 $ LOG HEADER DATA DATE LOGGED: SOFTWARe: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION~ DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): ~OTTO~ LOG iNTERVAL (FT):. BiT ROTATING SPEED HOLE INCLINATION (DEG) MINIMUM ANGLE: ~AXI~U~ ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR GA RAY/RESISTIVITY CDR GA~A R~Y/RESISTiVITY $ STOP DEPTH 4556,0 07-MAR-95 FAST~,5/LOGOS20,4 V4,0C MEMORY 4556.0 4136,0 4556.0 . RGS035 IS Tape Verification blstina chlum-.erqerb AlasKa Computing Center 2!-~PR-!995 1.5:43 PAGE: BOPEHOLE AND CASING DATA OPEN HOLE BIT SIZE (ItJ): DRILLERS CASING DEPTH PUPEHO[,E CONDITIONS ~UD TYPE: DENSITY VISCOSITY MUD CHLORIDES F[,UID L~SS RESISTIVITY (OH~) aT T~PERATUR~; (DEGF): ~UD AT ~EASURED TEMPERATURE ~OO AT MAX CIRCULATION6 TEmPerATUrE : gbD FILTRATE AT ~UD CAKE AT ~{E[IT~O~ TOOL ~ATRIX: ~AT~IX DENSITY: HOLE COPRECTION (IN); TOO[, STANDOFF (IN): FWR FREQUENCY PESARKS: RUN2: DRILLED INTERVAL 4246' - 4556' RUN2: BIT TO GR~ 42~08 DOWN[{OLE SOFTWAPE $ LIS FORMAT DATA 8 5O LSND 9.40 41.0 2.490 2.130 FT. TD RES. 52.50 66.0 66.0 ** ~ATA FORe'AT SPECIFICATI~ON RECORD ** ** SET TYPE - 64E~ ** TYPE REPR CODE VALUE i 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0'5 9 65 FT 11 66 36 12 68 13 66 0 14 65 PT IS Tare Verification !.,istin~ chlUl't!berger Alaska Comput~.mO Center 21-APR-1995 15:43 PAGE: mmmmmmmmmmm~#mmm~.mmmmmmmmmmmm TYPE REPR C ('il) E VAht!E t 5 66 68 16 66 1 0 66 ** SET T~PE - CMA~ ** NaMF S RV UNIT SE PI API API F bE NUMB ~B $IZ~: R..R PROCESS ID ORDER ~ LOG TYPE CLASS ~OD NUmB SA~P ELEM CODE (HEX) DEpT FT 6 9 8 O0 0 00 0 1 I 4 68 0 00000000 GR bW2 GAPI 619105 O0 000 00 0 3 1 1 4 68 0000000000 ROPE I,,~2 F/HR 619185 O0 000 O0 0 3 I 1 4 68 0000000000 T~B I~W~ HR 619185 O0 000 O0 0 3 1 1 4 68 0000000000 ATR LW2 0~ 619185 00 000 00 0 3 1 I 4 68 0000000000 PSR LW2 OHM~ 619185 00 000 O0 0 3 1 1 4 68 0000000000 DER LW2 O~M~ 619185 O0 000 O0 0 ~ 1 I 4 68 0000000000 ** DAT~ ** DEPT 4556.000 GR, bW2 ~ IR ~ LW2 -999 . 250 PSR . LW 2 D~PT 4136.000 OR h~2 ATp:L~ -999.250 PSR:LW2 END OF DATA ** 250 ROPE.hW2 99:~50 DER.bW2 17.8 5 ROPE,~W2 999.2750 DER.L~'2 -99g .250 -999,250 -999,250 **** FILE TRAILER **** F!bF NA~E : EDIT .003 SERVICE ~ FLIC ERSION : 00~C01 ATE : 95/04/21 ~AX RFC SIZE : FILE TYPE : LO LAST FILE **** FILE MEADER **** FILM NAME : EDIT ,004 SERVICE ~ FLIC V~R$ION : 00~C01 DAT~ : ~5/04/~ ~AX RFC SIZE : 1024 FILE TYPE ~ LO ,IS TaPe Verification I,istlna ;chlumberger AlasKa Computing Center 21-APR-1995 15:43 FILE HEADER FILE NIIMB~R 4 RAW ~WD Curves and log ~eader data for each bit run in separate files, BIT RUN r{UMBER: 3 DEPTH INCREMENT: 0.5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH ;~'''''' ............ 4448~ .... 50G HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFT~ARE VERSION= DOWNHOLE $OFT~ARE VERSION: DATA TYPE (MEMORY or RKAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTO~ bOG INTERVAL ~IT ROTATING SPEED ~OLE INCLINATION [DEG) MINIMU~ ANGLE~ ~AXIMUM ANGLE: STOP DEPTH TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR GAMMA Rh /RESISTIVITY CDR GA~A RAY/RESISTIVITY $ BO~EHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): MORE80LE CONDITIONS MUD TYPE: MUD DgN$ITY (LB/G): MUD VISCOSITY ~UD MUD CHLORIDES (PP~)~ FLUID bOSS RESISTIVITY (OR,M) AT TEMPERATURE (DEGF): ~UD AT MEASURED TEMPERATURE (MT): ,AT ~A× CIRCULATIO~ G TEMPE ATURE : R FILTRATE ~T (MT): CAKE AT ~EI)TRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTIO~ (IN): 08-MAR-95 FAST2.5/LOGOS20.4 V4,0C MEMORY 6644.0 4448.0 6644.0 TOOL NUMBER ~GS022 ~GS035 8.500 3722'0 LSND 9 5O 4~.0 2,490 2,130 66,0 66,0 PAGE: 10 IS Tape Yerification Listing ChlUmber~r Alaska Computing Center 21"APR-1. 995 15:43 PAGE: 11 TOOL REMARKS: RUM3: DRILLED IMTERVAL 455b' - 6644' R[!N3: BlT TO GR: 75.80 FT. TO R~S 65.38 FT. DOW~4~OLE SUFTWARE ¥4.0 LIS FORe'AT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE R~P~ CODE ~ALUE 1 66 0 2 66 0 3 7] 4 66 5 66 6 73 7 65 8 68 0 5 9 65 1] 66 12 68 13 66 0 14 65 15 66 68 16 66 0 66 ** SET TYPE - C~AN ** ... ......... ............... ...-;....... ........... .......................... ~ S~RV u~ s~n~c~ API ~ A~I P~ F~ NU~ NU~ S~ZE R~P~ ~ROC~SS ID ORDE. ~ hOG TYPE CL155 ~OO ~UMB ShgP ~LEM CODE {HE ] DEPT FT 619185 O0 000 O0 0 4 1 1 4 68 00o00o0000 GR [,w3 GAP! 619185 O0 000 O0 0 4 I I 4 68 0000000000 ROp~ LW] F/HR 619185 O0 000 O0 0 4 1 I 4 68 0000000000 TAB L~3 MR 619185 O0 000 O0 0 4 I 1 4 68 0000000000 ATR LW~ OHMM 61~185 O0 000 O0 0 4 1 I 4 68 0000000000 PSR LW3 0~ 619185 O0 000 O0 0 4 1 1 4 68 0000000000 D~R b~3 OHMM 619185 O0 000 O0 0 4 I I 4 68 0000000000 mmmmm~mmMmmmm#mmmmm~mm~mmm~mmmmmmmmmmmmmmmmmmmm~mm~mmmm~mmmmmmmmmmmmmmNmmmmmmmmmmmmmmm!· IS Tame Verificat~.on L.istinq chlumberoer Alaska Com!'.)utin~ Center 21-APR-lgg5 15:43 PAGEs 1¸2 DEPT. 6644.000 GR.bW3 ATP.LW3 -999.250 PSR.bw] DEPT. 4448.'J00 GR.bW] ATP.LW~ -999.250 PSR.LW] END O~ DATA -999.250 ROPE.LW3 -999.250 DER.LW3 97.136 ~OPE.LW3 -999.250 DER.LW] 151.729 -999.250 -999.~50 -999,~50 TAB.LW3 TA~.L'W3 -999,250 -999.250 FILF ~A~E : EDIT ,004 SERVICE : FDIC VERSION : 001C01 DATE : MAX R~C SIZE : 1024 FILF TYPE LaST FILE : **** FILM HEADER **** FILE NA~E : EDIT ,005 $~RVICE : FLIC VERSION : 001C01 DATF : 95/04/~1 ~X EEC SIZE : 1024 FIL~ TYPE : LO LAST FII~E : FILE HEADER FILE NUMBER 5 RA~ MWD Curves and log header data for each bit. run in se~.arate files, BIT RUN NUMBER: 4 DEPTH INC~EMENT: 0,5000 .# FILM SUMMARY VENDOR TOOL CODE START DEPTH CDR 6555,0 #. LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL CFT): STOP DMPTH 9125,0 II-MAR-95 FAST2.5/L(]GO$20.4 V4,0C ~EMORY 9125,0 6555,0 IS Tame Verification Listir, Q cblumber~er ~lasKa Comput!no Center 21-A~R-1995 15:~3 PAGE: ~OTTOh LOG INTERVAI, (FT): BIT ROTATING SPEED ~ULE INCLINATION (DEL) ~INIMUM ANGLE: TOOL STRING (T~P TO BOTTOH) VENDOR TOOL COQE TOOL TYPE ..... ......... .... ....... CDR GAMMA RAY/RESISTiVITY CDR GA~A RAY/RESISTIVITY S ~OREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH BOREHOLE CONQITIONS ~UD TYPE: DENSITY (LB/G): VISCOSITY (S): PM: MUD C~bORIDES (PP~): FLUID bOSS iMUD ,AT MAX ,CIRCULATIONG TE PE'AT:RE : ~UD FILTRATE AT (MT): uUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL, STANDOFF (IN): FWR FREQUE~CY ~125.0 TOOb NUMBER ~G8022 ~GS035 8 500 LSND 0 2,490 2,130 ~EMARKS{ RUN4: DRILLED INTERVAL 6644' - 9125' RUN4: BIT TO UR: 75.80 FT.' TO RES. 65.38 DOWNHOLE SOFTWARE V4,0 ' $ LiS FORMAT DATA 66.0 66.0 IS Tape VertflcatJ. on Listlnq chlumherQer AlasKa ComputtnQ Cent:er 21-APR-!995 15:43 PAGE: 14 ** .AFA FOR~AP! SPMCIPICATI(ON ~EC(]PD ** SET q:¥PE - 64EB ** .... . ...... .... .. ..... - .... 'PYPE R CODE V LUE 1 66 0 2 66 0 3 73 4 6~ 1 5 66 6 73 7 65 ~ 65 1~. 66 3b 12 68 i3 66 0 14 65 FT 15 66 68 16 66 0 66 ** SET TYPE - CHAN NA~ S~RV UNI E~IC~ AP1 API AP1 I . ILE N B NUmB SIZE EPR pROCESS ID ORDER ~ LOG TYPE CLASS MOD NUMB SA~P ELEM CODE (HEX) D~PT FT 619185 O0 000 O0 0 5 1 1 4 68 0000000000 G~ LW4 GAPI 619185 O0 000 O0 0 5 1 I 4 68 0000000000 ~OPE Lw4 F/HR 619185 O0 o00 O0 0 5 1 I 4 68 0000000000 TAB Lw4 H~ 619185 O0 000 O0 0 5 I 1 4 68 0000000000 ATR LW4 OHM~ 619185 O0 O00 O0 0 5 I .1 4 68 0000000000 PSR LW4 OHMM 619185 O0 000 O0 0 5 1 I 4 68 0000000000 DER LW4 OHM~ 619185 O0 000 O0 0 5 I 1 4 68 0000000000 DaTa DEPT. 9!~5.000 GR.LW~ ~TP.[W4 -999,250 PSR,LW4 DEPT, 6554.500 G'R.bW4 AT~.!~W4 -999,~50 PSR'LW4 -999 ~.50 ROPE.I~W4 103,050 ROPE,LW4 -999,250 DER,SW4 816 TAB,LW4 ' 999.:250 TAB,LW4 1999 '~50 -999,250 ,, '999,2150 END 0? DATA IS Tare verifY, carl. oD I, ist~nq Cbl~mberq~r AlasKa Computlna Center 21-AFR-~g95 15:43 PAGE: 15 **** FILE TRAILER **** FILE NA~E : EDIT .005 SERVICE : FLIC VERSION : O0~CO1 DATE : 95/04/21 MAX REC STZ~ FTLF TYPE : LO L~S? FILE **** FILE ~EaDER **** FILE NA~E : FOIT .006 SERVICE ~ FbIC VFRSI~M : OO1CO1 DATF : 95/04/31 MAX ~EC SIZE ~ 10~4 FILF TYPE : LO LAST FI!,E : FILE HEADER FILE ~UMBER 6 RAW MWD Curves and log header data for each bit run in separate files, BIT RUN NUMBER: 5 DEPTH I~CREMENT: 0,5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH CDR 9037,0 ,L...G ~EADER DATA DATE hOGGED: SOFTWARE: SURFACE SOFTWARE VERSION~ DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-T]~E): TD DRILLER TOP LOG INTERVAL (FI): ~OTTOM bOG INTERVAL PIT ROTATING SPEED MOLE INCLINATION (PEG) .... ~AXIMUM ANGLE: STOP DEPTH 9845,0 TOOL STRING (TOP TO BOTTOm1) VENDO~ TOOL CODE TOOL TYPE CDR GA~N'A RAY. RESISTiViTY CDR G~.M~A R~.Y/RMSISTIVITY 12-MAR-95 FAST~.5/bOGO$20,4 V4,0C MEMORY 9845 0 9037:0 9845,0 IS ?ar, e Verification Llst],ng CblUmberger AlasKa Computing Center PAGE: 16 BOREHOLE AND CASIiqG DATA OPEN HOLE BIT; SIZE (IN): D~ILLERS C~S]~tG DEPTH (PT}: 8 5O FOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): !0 90 MUD VISCOSITY (S): 4~.0 ~UD PH: ~UD CHLORIDES (~PM)~ FLUID LOSS RESISTIVITY (OHMS) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): ~,490 ~UD AT M~X CIRCULATIONG TEMP~RATUR~ ~UD FILTRATE AT ~UD CAKE AT (~T)~ ~KUTRO~ TOOL ~ATRIX: ~ATRIX DENSITY: HOLE CORRECTION TOOL STANDOFF (IN)~ ~W~ FREQUENCY (HZ): ~EMARKS: RUNS: DRILLED INTERVAL 91~5' - 9845' RUNS: ~IT TO GR: 5~,54 FT TO RES, 43,1~ FT, HOLE DEVIATION .~T ~D: 4o,9 DEG QOWNHOSE SOFTWARE V4.0 $ LIS FORMAT DATA 66,0 66,0 DATA FORMAT SPECIFICATION RECORD TYPE REPR CODE V~LUE i 66 0 2 66 0 3 73 28 4 66 ~ 5 66 6 73 7 65 9 68 0,5 9 65 FT l~ 66 36 12 68 13 66 0 IS Tape V~ri~Icat'.lon ListJnc CblUmberq~r AlasKa ComputlnO Center 21-APR-1995 1,5143 PAGE: 17 14 65 FI 15 66 68 16 66 1, u 66 ** SET TYPE - CHAM ** "' ..... '""'"'"'""'"" ............ .......... ,'""'"',,,'""'"'",,'"'" NAMF SERV [IN~T S~¥ICE API API API A FILE NUM NUMB S REPR PR ESS ID ORDER ~ LOG TYPE CLASS MOD ~' _. .... UMB SAMP ELEM CODE ([{EX) DFP? FT 619185 O0 000 O0 0 6 1 I 4 68 0000000000 GR LW5 GAPI 619185 O0 000 O0 0 6 1 I 4 68 0000000000 ROPF LW5 F/HR 619185 O0 000 O0 0 6 1 1 4 68 0000000000 T~B LW5 HR 619185 O0 000 O0 0 6 1 1 4 68 0000000000 ATR LW5 O~M~ 619185 O0 000 O0 0 6 l 1 4 68 0000000000 PSR bW5 OHM~ 619185 O0 000 O0 0 6 1 I 4 68 0000000000 D~R [,W5 OMMM 619185 O0 000 O0 0 6 1 I 4 68 0000000000 mmm#mmmmmmmmmmmmm-m~-mmmmmmmmmmmmmmm~mmmmmmmmmm-mmmmmmm#mmm#m-#mmmmmmmmmm-~mmmmm~m#~mm , * D ~ T A * * DEPT 9845,000 GR.LW5 -999.250 ROPE.LW5 7~.490 TAB.L~5 AT~:LW5 -999,250 pSR,LW5 -999,250 DER.I~W5 ~,999,~50 DF. pT 9036.500 GR,LW5 216,645 ROPE,LWL' -999,250 TAB.LW5 AT~ ~LW5 -999'250 PSR,LW5 -999,250 DER,LW5 -999'250 ** END OF DATA ** '999,250 '999,250 **** FILE TRAILER **** FI5~ MA~E : EDIT .006 SERVICE : FblC VERSION : 001C01 DATE : 95/04/~! MAX REC SIZE : 102~ FIL~ TYPE : LO L~ST FILE : IS Tare Yer1~.catlon Listin~ chlumberger AlasKa Comput~n~ Center 21-APR-~995 15:4~ PAGE: **** TAPE TRAIl. ER **** SERVICE DaTE : q5/04/Pl O~I~IN : TAPE NA~E : 95105 CONTInUaTION P~EVIOUS TAPE : COM~EMT : ARCO ALASKA INC., KUPAROK ~T-19 ,API #50-~03-~0~14-00 **** REB:L TRAILER **** SERVICE NAMM : EDIT DATF : 95/04/~1 O~I~lN : FLIC REEL NAME : 95105 CONTINUATION # : P~EVIOU$ ~EEL ~ COMMENT : ARCO ALASK~ INC., KUPARUK 2T-19 ,API ~50-10]-20~14-00
