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Home My WebLink About195-176Originated: Delivered to:9-Oct-25HalliburtonAlaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun333 West 7th Avenue, Suite 1006900 Arctic Blvd.Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 2P-422A 50-103-20400-01 910312860 Kuparuk River Multi Finger Caliper Field & Processed 23-Sep-25 0 12 2P-422A 50-103-20400-01 910313140 Kuparuk River Multi Finger Caliper Field & Processed 28-Sep-25 0 13 2X-12A 50-029-21189-01 910262801 Kuparuk River Leak Detect Log Field- Final 26-Aug-25 0 14 3G-07A 50-103-20127-01 910313294 Kuparuk RiverLeak Detect LogField- Final 14-Sep-25 0 15 3K-20 50-029-23019-00 910312855 Kuparuk River Multi Finger Caliper Field & Processed 26-Sep-25 0 16 3K-32 50-029-22763-00 910292590 Kuparuk River Multi Finger Caliper Field & Processed 31-Aug-25 0 17 3Q-07 50-029-21682-00 910313132 Kuparuk River Tubing Cut Record Field- Final 28-Sep-25 0 18 3Q-09 50-029-21674-00 910313102 Kuparuk River Plug Setting Record Field- Final 13-Sep-25 0 19 3T-617 50-103-20918-00 910346072 Kuparuk River Radial Bond Record Field & Processed 25-Sep-25 0 110 1B-10 50-029-20656-00 910325714 Kuparuk RiverLeak Detect Log with IntelliScopeField & Processed 16-Sep-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T40970202-067195-176190-085201-088197-076186-194186-186225-053181-135T40974T40974T40975T40976T40977T40978T40979T40980T409812X-12A50-029-21189-01910262801Kuparuk RiverLeak Detect LogField- Final26-Aug-2501Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.10.09 13:02:18 -08'00' Originated: Delivered to:26-Aug-25HalliburtonAlaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun333 West 7th Avenue, Suite 1006900 Arctic Blvd.Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1L-09 50-029-22025-00 910180917 Kuparuk River Plug Setting Record Field- Final 15-Jul-25 0 12 1R-33 50-029-22529-00 910219407 Kuparuk River Leak Detect Log Field- Final 19-Aug-25 0 13 1R-33 50-029-22529-00 910218799 Kuparuk River Multi Finger Caliper Field & Processed 5-Aug-25 0 14 1Y-06A 50-029-20958-01 910277376 Kuparuk RiverLeak Detect Log with IntelliScopeField & Processed 23-Aug-25 0 15 1Y-06A 50-029-20958-01 910180481 Kuparuk River Leak Detect Log Field- Final 22-Jul-25 0 16 1Y-06A 50-029-20958-01 910180481 Kuparuk River Plug Setting Record Field- Final 22-Jul-25 0 17 2B-02 50-029-21154-00 910151022 Kuparuk River Packer Setting Record Field- Final 3-Jul-25 0 18 2G-17 50-029-23134-00 910157884 Kuparuk River Leak Detect Log Field- Final 14-Aug-25 0 19 2K-23 50-103-20125-00 910180916 Kuparuk River Plug Setting Record Field- Final 12-Jul-25 0 110 2X-12A 50-029-21189-01 910262801 Kuparuk River Plug Setting Record Field- Final 24-Aug-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:190-034194-156197-134184-122202-243190-014195-176T40827T40828T40828T40829T40829T40829T40830T40831T40832T408338/27/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.08.27 12:51:45 -08'00'2X-12A50-029-21189-01 910262801Kuparuk RiverPlug Setting RecordField- Final24-Aug-2501190 014195-176 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: 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 8681'feet None feet true vertical 6311' feet None feet Effective Depth measured 8313'feet 5403' feet true vertical 6129' feet 4790' feet Perforation depth Measured depth: True Vertical depth: Tubing (size, grade, measured and true vertical depth) 3-1/2" J-55 5405' MD 4791' TVD Packers and SSSV (type, measured and true vertical depth) 5403' MD 498' MD 4790' TVD 498' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: 3090' 3005' Burst Collapse Production Liner 7285' 3308' Casing 5656' 4-1/2" 7317' 5371' 8679' 3055' 115'Conductor Surface Intermediate 16" 9-5/8" 79' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 195-176 50-029-21189-01-00 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: ADL0025642 Kuparuk River Field/ Kuparuk River Oil Pool KRU 2X-12A 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) 10 Gas-Mcf MD 1350 Size 115' 3472 135051 9 1513466 140 N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 59 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Seal Assembly SSSV: Camco TRDP-4E SFTY VLV (locked out) Katherine O'Connor katherine.oconnor@conocophillips.com 263-3718Senior Well Intervention Engineer New Perfs: 8243-8257' Existing Perfs: 7717-7852', 7909-7940', 8278-8318' New Perfs: 6090-6097' Existing Perfs: 5836-5899', 5926-5941', 6108-6128' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 10:35 am, Jun 05, 2024 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: 2024.06.05 07:29:42-08'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor RBDMS JSB 060624 DSR-6/7/24 DTTMSTART JOBTYP SUMMARYOPS 4/21/2024 ACQUIRE DATA DRIFT & TAG 2.75" D NIPPLE @ 5375' RKB FOR C/F, DRIFT FOR E LINE W 20' X 2.70" DUMMY DRIFT TO TD & 8315' RKB, NO WEIGHT SWINGS OR ANOMALIES. READY FOR ELINE. 5/6/2024 ACQUIRE DATA PERFORATE INTERVAL: 8243' - 8257' WITH 2-3/8", 5 SPF GEODYNAMIC RAZOR PERF GUNS. JOB COMPLETE, WILL RETURN WHEN STIM-TUBE IS AVAILABLE 6/2/2024 ACQUIRE DATA PERFORATE STIM-TUBE OVER INTERVAL: 8247' - 8253' JOB COMPLETE 2X-12A Perforations Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,313.0 2X-12A 5/19/2023 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Add Perfs 2X-12A 5/6/2024 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: TBG RKB PARKER 245 RIG/PROD CSG RKB NABORS 26E RIG 10/8/2012 osborl NOTE: WELL SIDETRACKED TO 'A'11/25/1995 osborl 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 36.0 115.0 115.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 35.1 3,090.1 3,004.9 36.00 J-55 BTC PRODUCTION 7 6.28 32.0 7,317.2 5,656.1 26.00 L-80 BTC WINDOW 'A' 7 6.00 5,524.0 5,534.0 4,889.2 26.00 L-80 LINER A 4 1/2 3.96 5,370.7 8,679.0 6,306.8 12.60 L-80 NSCT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 36.7 Set Depth … 5,405.5 Set Depth … 4,791.4 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8RDMOD 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 0.04 HANGER 7.062 CAMERON GEN 4 TUBING HANGER 3.500 498.2 498.2 0.17 SAFETY VLV 5.250 CAMCO TRDP-4E SAFETY VALVE (LOCKED OUT 3/23/01) 2.812 2,841.3 2,796.0 29.43 GAS LIFT 6.018 CAMCO MMM 2.920 4,524.6 4,106.7 39.28 GAS LIFT 6.018 CAMCO MMM 2.920 5,329.4 4,731.9 38.56 GAS LIFT 6.018 CAMCO MMM 2.920 5,375.1 4,767.6 38.48 NIPPLE 4.437 CAMCO D 2.75" LANDING NIPPLE NO GO 2.75" 2.750 5,382.3 4,773.2 38.47 LOCATOR 5.125 GBH-22 LOCATOR 3.000 5,403.4 4,789.8 38.43 SEAL ASSY 4.000 SEAL ASSEMBLY 3.000 5,405.2 4,791.1 38.43 MULE SHOE 3.812 MULE SHOE 3.000 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) 2,841.3 2,796.0 29.43 1 GAS LIFT GLV RK 1 1/2 1,240.0 4/18/2018 0.188 4,524.6 4,106.7 39.28 2 GAS LIFT GLV RK 1 1/2 1,224.0 4/18/2018 0.188 5,329.4 4,731.9 38.56 3 GAS LIFT OV RK 1 1/2 0.0 4/18/2018 0.250 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,717.0 7,747.0 5,836.1 5,850.1 C-4, 2X-12A 3/29/1996 4.0 APERF 7,747.0 7,777.0 5,850.1 5,864.2 C-4, 2X-12A 3/31/1997 4.0 APERF 7,777.0 7,785.0 5,864.2 5,867.9 C-4, 2X-12A 3/29/1997 4.0 APERF 7,850.0 7,852.0 5,898.4 5,899.3 C-3, 2X-12A 3/29/1996 4.0 APERF 7,909.0 7,940.0 5,926.2 5,940.9 C-1, 2X-12A 2/6/2006 6.0 RPERF 2.5" HSD PJ, 60 ph 7,924.0 7,926.0 5,933.3 5,934.3 C-1, 2X-12A 3/29/1996 4.0 APERF 8,243.0 8,257.0 6,090.3 6,097.3 A-4, 2X-12A 5/6/2024 5.0 APERF GEODYNAMIC RAZOR 8,278.0 8,298.0 6,107.9 6,117.9 A-3, 2X-12A 12/30/1995 6.0 IPERF 8,298.0 8,318.0 6,117.9 6,127.9 A-3, 2X-12A 12/30/1995 4.0 IPERF 2X-12A, 5/21/2024 4:52:33 PM Vertical schematic (actual) LINER A; 5,370.7-8,679.0 IPERF; 8,298.0-8,318.0 IPERF; 8,278.0-8,298.0 APERF; 8,243.0-8,257.0 APERF; 7,924.0-7,926.0 RPERF; 7,909.0-7,940.0 APERF; 7,850.0-7,852.0 APERF; 7,777.0-7,785.0 APERF; 7,747.0-7,777.0 APERF; 7,717.0-7,747.0 PRODUCTION; 32.0-7,317.2 WINDOW 'A'; 5,524.0-5,534.0 GAS LIFT; 5,329.4 GAS LIFT; 4,524.6 SURFACE; 35.1-3,090.1 GAS LIFT; 2,841.3 SAFETY VLV; 498.2 CONDUCTOR; 36.0-115.0 KUP PROD KB-Grd (ft) 46.08 RR Date 11/22/198 4 Other Elev… 2X-12A ... TD Act Btm (ftKB) 8,681.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292118901 Wellbore Status PROD Max Angle & MD Incl (°) 67.59 MD (ftKB) 5,906.96 WELLNAME WELLBORE2X-12A Annotation Last WO: End Date 11/27/1995 H2S (ppm) 225 Date 1/22/2014 Comment SSSV: LOCKED OUT ORIGINATED TRANSMITTAL DATE: 6/25/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 4877 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 4877 2X-12A 500292118901 Production Profile (PPROF) 0-Jan-1900 RECIPIENTS ConocoPhillips Alaska, Inc. DIGITAL FILES PRINTS CD'S 1 0 0 0 USPS 0 0 0 0 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 195-176 T39044 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.26 08:49:45 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com 0 195-176 T38925 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.13 08:28:45 -08'00' Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. i q~L/¢~¢ File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED Logs of various kinds [] Other COMMENTS: Scanned~ TO RE-SCAN Dianna Vincent Nathan Lowell Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ ~ (/ ~; ~ , / ,. I F ~~ ~~~~~~~~ NO. 5005 Schlumberger -DCS • 2525 Gambell Street, Suite 400 ~• ~; ~~ - Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 `~` i'"'"~'*~~ ~~~~~f u' `'' ~n~ ~, Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk 12/17/08 Well Job # Log Description Date BL Color CD 1 ~~~ • 2X-10 11978476 PRODUCTION PROFILE / - / 08/17/08 1 1 2V-09 12100460 PRODUCTION PROFILE (p 11/16/08 1 1 1Y-O6A 12100461 PRODUCTION PROFILE 11/17/08 1 1 2X-12A 12100464 PRODUCTION PROFILE 9 ~ 11/21/08 1 1 2U-08 12096574 PRODUCTION PROFILE 11/28/08 1 1 3K-108 12100466 USIT 11/23/08 1 1 3K-30 12097433 LDL _ / _ ~" 11/28!08 1 1 30-01 12097434 LDL ~Q ~ 11/29/08 1 1 1E-04 12097436 LDL T 11/30/08 1 1 3A-04 12097432 INJECTION PROFILE t - 11/27/08 1 1 iH-16 12096581 PRODUCTION PROFILE ~ 12/05/08 1 1 3A-06 12114994 BAKER LOWER STRADDLE PACKER 11/26/08 1 1 2U-14 12096578 INJECTION PROFILE C - 1 12/02/08 1 1 1 G-06 12096580 INJECTION PROFILE 12/04/08 1 1 2V-10 12096582 PRODUCTION PROFILE 12/06!08 1 1 3F-01 12086694 PRODUCTION PROFILE 12/07/08 1 1 2W-14 12086695 INJECTION PROFILE .~ 12/08/08 1 1 iJ-102 12086701 INJECTION PROFILE - 12/14/08 1 1 i D-07 12114999 USIT _ i 12/15/08 1 1 3C-02 12114997 INJECTION PROFILE -' ) 3 12/13/08 1 1 2T-18 12086703 INJECTION PROFILE „_, ~ = 12/17/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. RECEiVED 09/11/06 ('CD, .j '7nn~ .)LI ! (, ~'_'JU Scblumbel'gel' NO. 3955 ,~Oil & Gas Cons. CommisSion Anchorage Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ¡ c)J-/?h Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1 4. '2.ÛGß SCANNED SEP Field: Kuparuk Well CD Log Description Date BL Color Job # 2M-35 11213795 LDL 08/16/06 1 1Y-24A 11213786 SBHP 07/25/06 1 2X-12A 11249946 PROD PROFILE W/DEFT 08/25/06 1 1 D-06 11249948 INJECTION PROFILE 08/26/06 1 1A-10 11216318 INJECTION PROFILE 08/28/06 1 1J-184 11249951 PRODUCTION PROFILE 08/29/06 1 1 J-127 11249953 PRODUCTION PROFILE 08/31/06 1 1J-170 11249954 PRODUCTION PROFILE 09/01/06 1 1G-04 11216321 INJECTION PROFILE 08/31/06 1 1 D-12 11216322 PRODUCTION PROFILE 09/01/06 1 2F-06 11216320 FLOWING BHP SURVEY 08/30/06 1 , Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . e Conoc6Phillips e Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 March 16, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 (:; Subject: Report of Sundry Well Operations for 2X-12A (APD # 195-176) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforation operation on the Kuparuk well 2X-12A. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, 4) MottX0!~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION e e RECEIVED MAR 2 8 2006 Ai"..I,... na 0. f". f'. ... 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other ~horag~ Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Ope rat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 195-176/ - 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21189-01 , 7. KB Elevation (ft): . 9. Well Name and Number: RKB 41', Pad 117' 2X-12A , 8. Property Designation: 10. Field/Pool(s): ADL 25642: ALK 2573 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8681' feet true vertical 6311' feet Plugs (measured) Effective Depth measured 8314' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SURFACE 3049' 9-5/8" 3090' 3005' PRODUCTION 5481' 7" 5522' 4883' LINER 3308' 4-1/2" 8679' 6310' Perforation depth: Measured depth: 7717'-7785',7850'-7852',7909'-7940',8278'-8318' true vertical depth: 5839'-5871',5901'-5902',5929'-5944',6111'-6131' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 5405' MD. Packers & SSSV (type & measured depth) pkr= BAKER ZXP @ 5371' SSSV= 498' 12. Stimulation or cement squeeze summary: Intervals treated (measured) refer to attachment Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation 178 1908 3393 -- 186 Subsequent to operation 4 779 5202 -- 196 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAG 0 GINJD WINJD WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name ø100~; Title Wells Group Team Lead 3/ '/ . Signature Phone Date. -:20 00 À PreDared bv Sharon AI/suo-Drake 263-4612 , l ~ ÁÞ s - y¡;~ REPORT OF SUNDRY WELL OPERATIONS ion Form 10-404 Revised 04/2004 ORIGINAL ,;r¡~7(}Å f2- Submit o!~...na~~;/IY &0,.., '7\~\ ~7';', f"'v Dttmstart 2/6/2006 e e 2X-12A Well Events Summary Summary PERF 2.5 HSD 2506 PJ FROM 7909' - 7940' (31 feet) 6 SPF @ 60 DEG PHASE. Tubing (0-5405, OD:3.500, ID:2.992) Perf (7717-7747) Perf (7747-7777) Perf (7777-7785) Perf (7850-7852) Perf (7924-7926) Perf (8278-8298) Perf (8298-8318) c J",." , f~, '~ P!iµbing Size 3.500 I?erforations Summar Interval ~~: TVD L_. __io.l1~ : Status _7}17 -7747 i _!5_839 - 5853 C-~ += 7747 - 7777 5853 - 5867 C-4 -7in - 77855867 - 5871 C~4--- -7850 - 7852 590T~ 5902 C_3----r--- -7924 - 7926 ' -593i~ 5938 C:1--;-- ~~~~: ~~~tl ~g~: ~~~~ I :~:J£E ~as Lift MandrelsNalves StfMD'TVD I Man E-iityp~ V Mfr' _~_+_,,_,,_~_~_+_ 'Mfr 1 ' 2841 ~ 2'795 : CAMCO : --MM~j'- CAMCÖ 2i4525 4107 CAMCO:- MMM : CAMCO -TT~_53g9 4732 cÄMcbt MMM .... -CÄry,ÇO (¡:the_q~s, ea'!!!p,.,J~tc.) - JEWELR'y_ º-epttl-+_I~P Tvpe ! 498 : 491 5371-i476 5375 ' .-- 5384 5391 il ) i Ù;;:),;:)V 'CAMCO TRDP-4E (LOCKED out 3/23/01) ;r--PKR - BAKER ZXP , _ _ _8 NIP CAMCO D NIPPLE ffi~5- - HGR BAKER HMC PBR BAKER PBR _35- . i-8fi_ . , :3:000 --- :-2.750 3.500 '---992 l___~ ~ GLV OV OV Descri V o~rLatch 1.5 , -- 1.5-----' 1.5 0.188 0.250 0.250 V Type Ft 30 30 8 2 2 20 20 SPF ¡Date ~ 3/29h9 4 3/31/19 4 3/29/19 __4 13/29/19 4 . 3/29/19 6 ; 12/30ïi 4 i 12ï30ii Port ! Tvpe 96 1 APERF 9} 1 APERF 97 ; APERF 96'APERF 96 i APERF 9951 IPERF §J951 IPERF- ..... TRO Date ConocoPhiUips Ala. a Inc. e KRU 2(-12A - ~OD ~16/1! Rev Reason: PULL PLUG, TAG - FILL . ._,u··_ Last U date: 1/212006 ;81 m ; -------i-___ . n_ :deg I 7 --_.-.~. Bottom TVD ~WL Thread _-0- ---- 115 I 115 ' 62.50 Welded ::-:ig~~ ~¡~~~ : ~~:~g. --"-.-- BTC -.......--- -~j¡-~79 , 631_c±::illÞ BTC-mod 1 NSCT -----;--Ifit ~~~il ' 9:30- Schlumberger RFCEIVED NO. 3638 Schlumberger -DCS ,JA~J 0 9 2006 2525 Gambell Street, Suite 400 Com pany: Anchorage, AK 99503-2838 A TTN: Beth ~iask2 Cil & Gas ConS. Commission Anchcrage Field: Well Job# Log Description Date BL 20-02 N/A SHUT IN BOTTOM PRESSURE 12/03/05 1 1A-07 N/A INJECTION PROFILE 12/06/05 1 1 H-21 11166748 PROD PROFILE W/DEFT 12/26/05 1 2X-12A /tlS-/7/ø 11166749 PROD PROFILE W/DEFT 12/27/05 1 2U-08 11166750 PROD PROFILE WIDEFT 12/28/05 1 2X-13 11144057 GLS 12/25/05 1 2V -11 11166736 PROD PROFILE WIDEFT 12/16/05 1 30-09 11166737 LDL 12/17/05 1 3S-21 11166738 INJECTION PROFILE 12/18/05 1 3F-17 11144054 PROD PROFILE W/DEFT 12/22/05 1 2X-15 11144058 PROD PROFILE WIDEFT 12/26/05 1 30-09 11144055 LDL 12/23/05 1 2V -01 11144056 INJECTION PROFILE 12/24/05 1 - < - k\ I>~ ~ 2.GOo C-ANNED jAr\! QJ J,. ... S . .t~U ~.. ,,--= <., SIGNED~dOÜOOifJ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. DATE: 12/30/05 Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk Color -- CD ..--- " ') ) AT,A.SIiA. OIL AND GAS CONSERVATION COMMISSION / October 25,2004 q;;-fl ~ @~ ~ ~-e .~ ~ fii\ l fii\ @~« ~ ~ - JL, - 1: ~ f W .=J10j èiJ~~W FRANK H. MURKOWSKI, GOVERNOR 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Mike Wheatall Operations Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 l\nchorage,A}( 99510-0360 Dear Mr. Wheatall: The Alaska Oil and Gas Conservation Commission ("Commission") performed an inspection of your well safety valve system (SVS) at~~~"~l<.j\River"Ønit2X:.("K.RU 2X") pad on October .15, 2004. Attached is a copy of the Inspection Report. Regulation at 20 AAC 25.265 requires all wells to be equipped with a Commission approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a . subsurface safety valve must be maintained in working order and is subject to perfonnance testing as part of the SVS. An SVS cornponent failure rate of 12.5 percent was identified during the above-noted inspection. Commission policy, as outlined in a letter dated November 14, 1995, states that the testing frequency will be increased when a failure rate exceeds 10 percent. The AOGCC-AOGA Safety Valve System Task Force report issued June 13, 2003, supported retention of the 10% failure threshold. Also noted during the Commission's inspection were unsupported flow piping and. pilots on KRU 2X pad, specifically Wells 2X-03 and 2X-09. These were not included in the failure rate calculation but clearly are deficiencies in the SVS that must be corrected. Effective October 15, 2004, and until an acceptableJevel of perfonnance is achieved, the safety valve systems associated with wells located on KRU 2X must be tested every 90 days. When testing is sched ed, you must notify the Commission Field Inspector at 907-659-2714 to provi~ (?,rtu. 0 witness ilie SVS tes~mCerelY, Ø~/ 0 ~ I .!Ji. Norman Daniel T. Seamount, Jr. . ;; ;Þ- Chainnan Commissioner Attach. copy by email: Bob Fleckenstein; AOGCC Inspectors N a c:::> ~, Safety Valve & Well Pressures Test Report Reviewed By: P.I. Suprv..::rße.. 'Dzslù+ Comm Pad: KRU_2X Insp Dt 10/15/200 Inspected by Jeff Jones Interval 90 Days InspNo svsJJ041019163228 Field Name KUP ARUK RIVER Operator CONOCOPHILLIPS ALASKA INC Operator Rep Bob Noble 1""'.".'..<',:,,f;ii:r,:,'.:f'N:/jV7t~~¡'...:.<_f,;:;.~_:":.'~.:>,:-.,;/ :'... /j .¡..n;:;';.::' .'. ...';.. ...'X'; try;~;(.::,>.:'.'%.',¡......... ,-c. .;.-_:;~~.-~~.,_._~.._,:~..._., :.'-,--~,.:'-:(,"'-.'~~';'. Related Insp: Reason ISO-Day Src: Inspector Well Permit Separ Set UP Test Test Test Number Number PSI PSI Trip Code Code Code 2X~03 1831090 I 2700 I, 2000 1900 I P I P I 2X-08 1831140 2700 2000 1750 P P 2X~09 1841620 98 70 50 P P 2X-I0 1841630 98 70 60 P P 2X-ll 1841640 98 70 65 P 4 2X-12A 1951760 98 70 65 P P 2X-13 1841740 98 70 44 3 P 2X-14 1841750 98 70 75 P P 2X-15 1841760 98 70 55 P 7 2X-16 1841720 98 70 52 P P 2X-17 1951710 98 70 50 P P 2X-18 1951600 98 70 55 P P Comments The SSV on well2X-l1 failed the pressure test & will require repair. The pilot on well 2X-13 tripped low & was cycled & passed a re-test. Both the wing and pit valves leaked on we1l2X-15 and the SSV could not be tested. I inspected 12 well houses. .L_.__.- Date SI Oil,WAG,GINJ, Tubing GAS,CYCLE, SI PSI YeslNo YeslNo W AGIN Flow piping & pilot not supported properly; loose & wobbly. W AGIN I-OIL Flow piping & pilot not supported properly; loose & wobbly. ~ I-OIL I-OIL 750 900 175 No Yes IA x OA communication I-OIL wing valve leaks. I-OIL I-OIL I-OIL wing & pit valves leak. I-OIL I-OIL I-OIL Performance Wells Components Failures Failure Rate 12 24 3 12.5% Monday, October 25, 2004 ~ MEMORANDUM State of Alaska TO: THRU: FROM: Alaska Oil and Gas Conservation Commission Julie Heusser, CommissiOner Tom Maunder, P. I. SuperviSor Chuck Scheve; Petroleum Inspector DATE: SUBJECT: January 25, 2001 Safety Valve Tests Kuparuk River Unit 2X Pad Thursday, January 25, 2001' I traveled to the Kuparuk River Field-and witnessed the 90-day retest of the safety valve systems on 2X Pad. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 12 wells and 24 components with one failure observed. The Surface Safety Valve on Well 2X-14 had a slow leak when pressure tested. This valve was serviced and I witnessed a successful retest on 1-26-01. Earnie Barndt conducted the testing today he demonstrated good test procedure and was a pleasure to work with . All the wellhoUses entered at this location were clean and all related equipment appeared to be in good condition. Summary: Field. I witnessed the 90,day SVS testing at 2X Pad in the Kuparuk River KRU 2X Pad, t2 wells, 24 components, 15 wellh°use inspections ' 1 failure 4.1% failure rate Attachment: sVs KRu 2X Pad 1-25-01 CS X unclassified Confidential (Unclassified if doc. Removed) SVS KRU 2X Pad 1-25-01 CS.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Operator Rep: Earnie Bamdt AOGCC Rep: .... Chuck Scheve Submitted By:- (?hu'ck SCh~ve Date: Field/Unit/Pad: Kupanak / KRU / 2X Pad Separator psi: LPS_ 99. HPS 1/25/01 i ii i i i ii . i . I i i i~ ii Well Pemit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number ,, psi PSI Trip Co, de Code Code Passed GAs o.r, CYCLE 2X-01 1830840 2X-02 '1831030 375.0 2000 1800 P 'P WAG , , , 2X-03 1831090 2X-04 1831180 3750 2000 2000 P P WAG 2X-05 1831070 2X-06 1831100 2X-07 1831130 37~0 2000 2000 p p ...... w/~G 2X-08 1831140 2X-09 1841620 99 60i 60 P P OIL , 2X-10 1841630 5X-11' ..184'1646, 99 ,60 : '.'50 ',P, P .... ' 0IL 2X-12A 1951760 99 60 55 P P OIL 2X-13 ' "1~17~0 ' 99 60 55 P P ' ' OIL '~2X-14 'i8'41750 99 60 55 P 4 " 1/26/01 ~)IL 2X-15 1841760 99 60 55 P P OIL 2X-16 "1841720 - 99 ~3'{) 55 P ' "P OiL 2X-17 "1951710 99 60 60'" 1~ P .... OIL 'SX- 18 19'51600 99 go 60 p p ' ' oiL 2x-19 - 1951750 Wells: _ 12 Components: , . 2..4 Failures: . 1 Failure Rate: 4.17% 1"190 Day Remarks: Surface Safety on well 2X-14 ha~.d .very slow leak when pres .su. re. tested, valve to be serviced and retested' by. operator. RJF 1/16/01 Page 1 of 1 SVS KRU 2X Pad 1-25-01 CS.xls THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03 2001 PL M A T E E IA L U N D W E R T H IS M ARK E R C:LOICI~fl~ILM.DO C 95-. 'i 76 ~~ T 95 ..... i76 ARC 5 ~.. 95 'i 78 ARC 9 5 .... I 7 6 ,/ /- i;: I. I i'..! I:::: E C V D i:., 0 'l ,,/26/' 96 2/3 0:2/27 / ,.. Ar"e d r' y Was "i:he weii cor'ed? J'l (il STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate X Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1230' FSL, 598' FEL, Sec. 4, T11N, R9E, UM At top of productive interval 413' FNL, 2070' FEL, Sec. 4, T12N, R9E, UM At effective depth 145' FSL, 2463' FEL, Sec. 33, T12N, R9E, UM At total depth 217' FSL, 2508' FEL, Sec. 33, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 8681 6311 6. Datum elevation (DF or KB) RKB 41 7. Unit or Property name Kuparuk River Unit 8. Well number 2X- 12A 9. Permit number/approval number 95-176 10. APl number 5o-029-21189-01 11. Field/Pool feet feet feet Plugs (measured) Kuparuk River Field/Oil Pool None Effective depth: measured 8 5 8 2 true vertical 6261 feet feet Junk (measured) None Casing Structural Conductor Surface intermediate Production Liner Perforation depth: Length Size 80' 16" 3060' 9-5/8" 5495' 33O7' measured 7717'-7785', true vertical 5840'-5871 ', Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 5405' Packers and SSSV (type and measured depth) Cemented Measured depth True vertical depth 260 Sx CS II 121 ' 700SXCS III& 3090' 550 Sx CS II 7" 515 Sx Class G & 250 Sx CS I 5522' 4882' 4.5" 84 BBLs Class G 8 6 7 9' 6 31 0' 121' 3004' 7850'-7852', 7924'-7926', 8278'-8318' 5902'-5904', 5937'-5939', 6111'-6131' 0RI$1NAL Pkr: Baker ZXP @ 5371'; SSSV: Camco TRDP @ 498' 13. Stimulation or cement squeeze summary Perforate "C" sands on 3/29/97 & 3/31/97. Intervals treated (measured) ii li\] I 'i 1997 771 7'-7785', 7850'-7852', 7924'-7926' Treatment description including volumes used and final pressure psi Alaska. 0it & Gas Cons. 60ml~~su' Perforated using 2-1/8" HSD guns w/ DP charges, 4 SPF, fp = 850 . 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 390 210 2876 1255 168 Subsequent to operation 451 227 3703 1258 170 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. ! hereby certify that the foregoing is true and correct to the best of my knowledge. i , / Signed ~//'~~ ~~~ Title Wells Supedntendent Form ,7/,~-40~4 /R~v (0~¢'~1-'5~8 '- / Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT '' WELL SERVICE REPORT K1(X-12A(W4-6)) WELL JOB SCOPE JOB NUMBER 2X-12A PERFORATE, PERF SUPPORT 0303972120.5 DATE DAILY WORK UNIT NUMBER 03/31/97 PERFORATE "C" SANDS F/7747- 7777' ELM DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 3 (~) Yes O NoI (~ Yes O No SWS-WALSH B,J_~ACK.._~ FIELD AFC~ CC_~ DALLY COST ACCUM COST ~ig.r~d~ - ~ ESTIMATE KAWWRK 230DS28XL $ 33,0 9 0 $66,885 .-~z_,,,--- Initial Tb.q Press Final Tb_q Press Initial Inner Ann Final Inner Ann I Initial Outer An'ni I Final Outer Ann 850PSI 850PSI 1300PSI 1300PSIIIOPSI 0PSI DAILY SUMMARY PERFORATED "C" SANDS F/7747 - 7777' ELM W/2.5" HSD DP @ 4 SPF & 180 DEG PHASED (UNSURE OF ORIENTATION DUE TO USEI I OF ROLLER SYSTEMS. TIME LOG ENTRY 07:30 09:30 15:45 16:30 19:45 21:30 00:00 02:30 MIRU SWS (WALSH & CREW) & APC PUMP CREW. TGSM - WEATHER / JOB OVERVIEW. MU GA#1 (ROLLERS/2.5" HSD/ROLLERS/CCL) TL - 23'. PT BOPE TO 3000 PSI. RIH TO 5600' ELM. BEGIN PUMPING UP TO 5 BPM DIESEL. RAN OUT OF DIESEL, STANDBY. CONT'D RIH TO 8150' ELM (DIFFICULT & PUMPED 645 BBLS DIESEL). TIED IN & SHOT F/7767- 7777' ELM. NO INDICATION @ SURFACE. POOH. CON, GUNS DID NOT FIRE. BLASTING CAP DID NOT FIRE BUT SHOWS CURRENT THROUGH CAP (GUNS OK). MU GA~¢2 (ROLLERS/2.5" HSD/ROLLERS/CCL/WT) TL-27'. PT & RIH PUMPING 5 BPM DIESEL F/5650 TO 8150' ELM (PUMPED 82 BBLS DIESEL, MUCH EASIER GE'i-I'ING DOWN). TIED IN & PERFORATED F/7767 - 7777' ELM W/2.5" HSD DP @ 4 SPF & 180 DEG PHASED. SAW SURFACE INDICATION. POOH W/GA#2. ALL SHOTS FIRED. MU GA#3 (SAME AS GA#2). RIH W/GA#3 PUMPING 5 BPM DIESEL F/5650 TO 8150' ELM (PUMPED 84 BBLS DIESEL). TIE IN & PERFORATE F/ 7757 - 7767' ELM W/SAME GUNS / SHOTS / FTC AS BEFORE. POOH W/GA#3. ALL SHOTS FIRED. MU GA#4. (SAME AS BEFORE). RIH W/GA#4 PUMPING 5 BPM DIESEL F/5650 TO 8150' ELM (PUMPED 85 BBLS DIESEL). TIE IN & PERFORATE F/ 7747 - 7757' ELM W/SAME GUNS / SHOTS /ETC AS BEFORE. 04:00 POOH W/GA#4. RD SWS & APC. IN PROGRESS OF RD @ REPORT TIME. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $375.00 APC $6,000.00 $7,950.00 ARCO $4,500.00 $7,300.00 HALLIBURTON $0.00 $1,481.00 LR-rLE RED $0.00 $8,100.00 ,= SCHLUMBERGER $22,590.00 $41,680.00 TOTAL FIELD ESTIMATE $33,090.00 $66,886.00 ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(X-12A(W4-6)) WELL JOB SCOPE JOB NUMBER 2X-12A PERFORATE, PERF SUPPORT 0303972120.5 DATE DAILY WORK UNIT NUMBER 03/29/97 IN PROCESS OF PERFORATING "C" SANDS UNIT #1 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 (~Yes L"~No' (~)Yes (~No S WS-WALSH 'e~~nal0 FIELD AFC.,ff CC# DALLY COST ACCUM COST ESTIMATE KAWWRK 230DS28XL $1 7,475 $33,795 Initial Tb.q Press Final Tbq Press Initial Inner Ann Final Inner Ann I Initial Out uter Ann 1 000 PSI 1 000 PSI 1 300 PSI 1 300 PSII 0 PSII 0 PSI DAILY SUMMARY MADE 1 OF 4 PERF RUNS. PERFORATED F/7777-7785' ELM W/2.5" HSD DP @ 4 SPF PHASED 180 DEG. UNABLE TO ORIENT DUE TO USE OF PETROLINE ROLLERS. SDFN DUE TO PUMP BREAKDOWN. TIME LOG ENTRY 08:30 MIRU SWS (WALSH & CREW) & LRS. MU GA#l, GR NOT WORKING. WO NEW GR. MU GA#1 (2.5" HSD/WT/CCL/GR) TL-27'. TGSM - SPILLS. PT BOPE TO 3000 PSI. 12:30 RIH TO 5750' ELM. BEGIN PUMPING F/3-5 BPM DIESEL. COULD NOT WORK PAST 5750' ELM. 14:15 16:30 19:45 POOH F/PETROLINE ROLLERS. WO SWIVEL F/ROLLERS. NEW GR NOT WORKING. MU GA#2 (ROLLER/2.5" HSD/ROLLER/CCL) TL-23'; PT. RIH W/GA#2 TO 8100' ELM PUMPING UP TO 5 BPM DIESEL (DIFFICULT GE'I-FING DOWN). TIE IN TO 12/16/95 SWS PERF RECORD & 12/16/95 SWS CBL. PERFORATE F/7777 - 7785' ELM W/2.5" HSD DP @ 4 SPF & 180 DEG PHASED (UNSURE OF ORIENTATION DUE TO USE OF ROLLERS). PUMPED 371 BBLS OF DIESEL TO THIS POINT. POOH F/NEXT GUN RUN. OOH W/GUNS, ALL SHOTS FIRED. HOT OIL UNIT PUMP DOWN W/NOTHING AVAILABLE UNTIL AM. SDFN. RD SWS & LRS. 22:30 OFF LOCATION UNTIL AM. LEAVE WELL SHUT IN & NOTIFY PRODUCTION. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $375.00 APC $1,200.00 $1,950.00 ARCO $1,500.00 $2,800.00 HALLIBURTON $0.00 $1,481.00 LITTLE RED $4,500.00 $8,100.00 SCHLUMBERGER $10,275.00 $19,090.00 TOTAL FIELD ESTIMATE $1 7,475.00 $33,796.00 ARCO Alaska, Inc. KUPARUK RIVER UNIT '' WELL SERVICE REPORT ~ K1(X-12A(W4-6)) WELL JOB SCOPE JOB NUMBER 2X-12A PERFORATE, PERF SUPPORT 0303972120.5 DATE DAILY WORK UNIT NUMBER 03/28/97 ATTEMPT TO PERFORATE "C" SANDS UNIT #1 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 O Yes k'~ NoI O Yes (~) No SWS-WALSH ~ FIELD AFC~ CC~ DAILY COST ACCUM COST ESTIMATE KAWWRK 230DS28XL $1 3,065 $16,320 Initial Tb_q Press Final Tb.q Press Initial Inner Ann Final Inner Ann I Initial Outer Ar~r~ '1 Final Outer Ann 750 PSI 850 PSI 1 100 PSI 1 300 PSII 0 PSI! 0 PSI DAILY SUMMARY ATTEMPTED TO PERFORATE "C" SANDS F/7747- 7785' ELM W/2-1/8" EJ DP. UNABLE TO GET PAST 7750' ELM W/20' OR 10' GUNS WHILE PUMPING UP TO 5 BPM DIESEL. WILL ATTEMPT DIFFERENT GUNS. HAD 5 GAL DIESEL SPILL RD SWS LUBRICATOR TIME LOG ENTRY 08:30 11'15 14:00 MIRU SWS (WALSH & CREW) & LRS. WELL SHUT IN ON ARRIVAL W/FLOW LINE & TBG FP. MU GA#1 (2-1/8" EJ/CCL/GR/WT) TL-36'. TGSM - JOB OVERVIEW & PUMPING SAFETY. PT BOPE TO 3000 PSI (FOUND LEAKING O-RING ON LUBRICATOR & REPAIRED). RIH W/GA#1 TO 5650' ELM. BEGIN PUMPING F/1 - 2.0 BPM DIESEL. UNABLE TO MAKE PROGRESS. SD & RU LRS HARDLINE. PULL UP TO 5550 PUMPING F/1 - 4 BPM DIESEL. ABLE TO RIH TO 5750' ELM. WORK BUT UNABLE TO GET FURTHER. POOH TO SHORTEN GA. 17:00 18:45 SHUT DOWN FOR NIGHT & NOTIFY PRODUCTION. OOH. MU SHORTENED GA#2 (2-1/8" EJ/CCL/GR/WT) TL -26'. PT BOPE & RIH TO 5750' ELM WHILE PUMPING UP TO 5 BPM DIESEL. COULD NOT WORK PAST 5750' ELM. POOH. WILL MU & A'FFEMPT 2.5". HSD DP GUNS IN AM (SUCCESSFULLY RAN 2.5" HOLLOW CASE CARRIERS ON 12/29/95). RD SWS & LRS. HAD 5 GAL SPILL OF DIESEL F/SWS LUBRICATOR. MADE NOTIFICATIONS & CLEANED UP. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $375.00 APC $750.00 $750.00 ARCO $1,300.00 $1,300.00 HALLIBURTON $0.00 $1,481.00 LITTLE RED $2,200.00 $3,600.00 SCHLUMBERGER $8,815.00 $8,815.00 TOTAL FIELD ESTIMATE $1 3,065.00 $1 6,321.00 0/3/96 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10437 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk 1Q-2A c~ ~'-_ I~H CBT 960806 I 1 =. 1 Y- 1 3 °o ~ - (5 t %- INJECTION PROFILE 9 6 0 8 2 0 I 1 ........ 1Y-25 ~.,~ - O'~°1 PRODUCTION PROFILE W/DEFT 960821 I 1 2X. r12A c~ .%.._ !--i~2 GAS ELF]'. SURVEY 960810 I 1 2 X- 17 c~ ~-- - I ~ t PRODUCTION PROFILE 9 6 0 81 0 1 1 3A-18 °/f~ - ~'75 USIT 960907 I 1 3A-18 '4/ CBT 960907 I 1 3G-25X ~(~ - [;~(~ CBT 960809 I I SIGNED' (~~ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. p,E.CE'IVEE) OCT 0 DATE: .......... ~,.,.-,.' ARCO Alaska, Inc. Date' January 31, 1996 Transmittal #' 9328 RETURN TO' ARCO Alaska, Inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATO-1119 B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open/cased hole items. Please acknowledge receipt and return one signed copy of this transmittal. ~'2---0¢:~ 1 H-08 ~3 -o'-72,.1Y_24 c¢ ~"'(-o¢? 3R-26 q-)-'-"'f 7~ 2X-12A ~ ~"- ~,,,r-~.3 A-04 Dual Burst TDT-D Dual Burst TDT-D ARC's ARC's Dual Burst TDT-D 02/05/95 01/07/95 12/15/95 11/25/95' 01/09/96 50-029-20763-00 50-029-22371-00 51 72-8866 5797-8640 50-029-21433-00 Acknowledged' Date: DISTRIBUTION' · Mr. Vernon E. Pringle Jr. DeGloyler and MacNaughton One Energy Square Dallas, TX 75206 Erickson/Zuspan NSK Central Files NSK 69 Sharon AIIsup-Drake DS Development ATO - 1205 Larry Grant AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Clifton Posey Geology ATO - 1251 ,~}as~a 0ii & Gas Co~s. Corr~mission A,~orage ~ka, Inc. ost Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 30, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2X-12A (Permit No. 95-176) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the recent operations on KRU 2X- 12A. If there are any questions, please call 265-6206. Sincerely, M. Zanghi~]-~ Supervisor Kuparuk Drill Site Development MZ/skad STATE OF ALASKA ' ALAS~,., OIL AND GAS CONSERVATION COMMIL_..ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL [~] GAS [---] SUSPENDED r'~ ABANDONED [~] SERVICE [~] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 95-176 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-21189-01 4 Location of well at surface 9 Unit or Lease Name . -~ .... .~ ~.:_.. :~-j'~;-j .. 1230' FSL, 598' FEL, Sec. 4, T11N, R9E, UM ~;' ~:.?...~-.i~i '~ :.:::' ~ ;~ j.~,,£:., .~-;.:;~;~ , KUPARUK RIVER UNIT At Top Producing Interval ~ 10 Well Number 2X-1 2A ~i' i~'"'~' ~'~'11 Field and Poo, At Total Depth 217' FSL, 2508' FEL, Sec. 33, T12N, RgE, UM:- .... ~ ~ KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) .... J 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 41' Pad Elev. 77'J ADL 25642 ALK 2573 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 116 No. of Completions 11/20/1995 sidetrack 24-Nov-95 16-Dec~95 (perf'd)I NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set 21 Thickness of permafrost 8681' MD & 6311' TVD 8582' MD & 6261' TVD YES [~ NOE~J 498' feetMD 1500' APPROX ;? Ty'pe Electric or Other Logs Run GR/CCL/SLT-J, CAMERA SURVEY 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE ~ GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5# H-40 Surf 121' 24" 260 sx CS II 9-5/8" 36.0# J-55 Surf 3090' 12-1/4" 700 sx CS Ill, 550 sx CS II 7" 26.0# L-80 Surf 5522' 8-1/2" 515 sx Class G & 250 sx CS I KICKOFF SIDETRACK @ 5527' 4.5"'1 12.6" I L-80 5370' 8679' 6-1/8" 234 sx Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 5405' 5371' & 5391' 8278'- 8318' MD 2 spf 6111' - 6131' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8278'-8318' 177,000# proppant in perfs, 28,524# in pipe (2029 slurry; 25,000# 20/40, 180,524# 12/1 27 PRODUCTION TEST Date First Production JMethod of Operation (Flowing, gas lift, etc.) 1/10/96J FLOWING Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 1/20/96 24 TEST PERIOD I~ 169 81 97 176 482 Flew Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press 150 ## 24-HOUR RATE I~ 169 81 97 ,~24o - 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. · ; .-.- ~ ~"~ ,~' ,~- ;.,. ,./...',: ~....:.....,.; Form 10-.407 Submit in duplicate Rev. 7-1-80 CONTII\IJEDON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS NAME Include inter~al tested, pressure data, all fluids recovered and gravily, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7712' 5835' Bottom Kuparuk C 7944' 5945' Top Kuparuk A 8216' 6078' Bottom Kuparuk A 8471' 6204' 31. LIST OF A'I-FACHMENTS Directional Survey, Daily Well Operations 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 Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Subni'~:t~l~._,?W.'_.~t~'~f~'-~:i~ ii.i.ii,~' jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date- 1/15/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 1 WELL:2X-12A RIG'PARKER 245 WELL ID: AK8357 AFC: AK8357 TYPE: STATE:ALASKA AREA/CNTY' NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD: START COMP: BLOCK' FINAL' WI: 55% SECURITY:0 AFC EST/UL:$ OM/ OM API NUMBER: 50-029-21189-01 11/20/95 (1) TD. 5516' (5516) SUPV: DCL DAILY' 11/21/95 ( 2) TD' 5600' ( 84) SUPV'DCL DAILY' 11/22/95 (3) TD: 6895' (1295) SUPV'RLM DAILY: 11/23/95 (4) TD: 8173' (1278) SUPV:RLM DAILY' 11/24/95 (5) TD: 8289' (116) SUPV'RLM DAILY' 11/25/95 ( 6) TD: 8680' (391) SUPV:RLM DAILY' 11/26/95 ( 7) TD: 8680' ( 0) SUPV'RLM DAILY' MW: 9.9 PV/YP: 0/ 9 APIWL: 7.4 RIH W/ BHA #1 Move rig and spot over 2X-12. Test BOPE. Safety meeting. PU 99 jts DP. RIH w/ BHA #1. $405,176 CUM: $405,176 ETD: $0 EFC: $405,176 MW: 9.9 DRILLING Drilling from 5516' to 5600' $99,547 CUM: $504,723 ETD: PV/YP: 0/32 APIWL: 7.8 $0 EFC: $504,723 MW: 9.6 PV/YP: 0/11 APIWL: 6.4 DRILLING DRILL TO 5650'. CBU. POOH; PICKUP BHA #3. RIH & ORIENT. DRILL THRU WINDOW 5650' TO 5797'; MWD FAILED. POOH; CHANGEOUT MWD. RIH DRILL 5797' TO 6895'. $87,609 CUM: $592,332 ETD: $0 EFC: $592,332 MW: 11.6 PV/YP: 0/20 APIWL: 5.2 DRILLING DRILL FROM 6895' TO 7768'; INCREASE MW TO 11.6 PPG. LOSING MUD IN KUPARUK. ADD MORE LCM. REAL TIME LOGGING AND SURVEY TOOL FAILED DUE TO ADDITIONAL LCM. LOSSES STABILIZED. DRILL FROM 7768' TO 8173'. $102,480 CUM: $694,812 ETD: $0 EFC: $694,812 MW: 11.6 PV/YP: 0/23 APIWL: 4.8 CIRCULATE BOTTOMS UP DRILL FROM 8173' TO 8223' SHORT TRIP. DRILL FROM 8223' TO 8289' TRIP OUT TO CHANGE BHA AND BIT. $88,318 CUM: $783,130 ETD: $0 EFC: $783,130 MW: 11.6 PV/YP: 0/14 APIWL: 4.6 POOH DRILL FROM 8289' TO 8680' TD. SHORT TRIP. TRIP OUT TO RUN LINER. $81,065 CUM: $864,195 ETD: $0 EFC: $864,195 MW: 11.6 PV/YP: 0/18 APIWL: 4.2 LAY DOWN DRILL PIPE TRIP TO RUN LINER. RUN 4 1/2" LINER WITH HANGER AND LINER-TOP PACKER ON 3 1/2" DRILL PIPE. CEMENT 4 1/2" LINER, CIP AT 0015 HRS 11/26/95. PLUGS BUMPED, SET HANGER AND PACKER, FLOATS HELD. RELEASE FROM LINER HANGER AND REVERSE OUT. PRESSURE TEST LINER PACKER TO 3500 PSI. LAY DOWN CEMENTING HEAD AND DRILL PIPE. $151,138 CUM: $1,015,333 ETD: $0 EFC: $1,015,333 Date' 1/15/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 2 11/27/95 (8) TD: 8680' ( 0) SUPV:RLM DAILY' MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 EQUALIZE DIESEL LAY DOWN DRILL PIPE AND BHA FOR RIG MOVE. RIG UP AND RUN 3 1/2" SINGLE COMPLETION. SWAP TO SEAWATER AND SPACE OUT COMPLETION. FREEZE PROTECT TUBING AND ANNULUS. $99,763 CUM: $1,115,096 ETD: $0 EFC: $1,115,096 11/28/95 (9) TD' 8680'( 0) SUPV'RLM DAILY' MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED CONNECT CONTROL LINE TO HANGER AND TEST TO 6500 PSI. LAND TUBING AND RUN IN LOCKDOWN SCREWS. TEST TUBING AND ANNULUS TO 2500 FOR 15 MIN. LAY DOWN LANDING JT. RIG DOWN TBG. TOOLS. REMOVE DOORS ON BLIND RAM CAVITY. CHANGE LOWER PIPE RAMS TO 4" NIPPLE DO~ BOP STACK. NIPPLE UP TREE. TEST SEALS TO 5000 PSI, TREE TO 250/5000 PSI. INSTALL BPV. RELEASE RIG. $90,615 CUM: $1,205,711 ETD: $0 EFC: $1,205,711 End of WellSummary for Well:AK8357 DALLY SUMMARY RAN CEMENT BOND LOG AND PERFORATED A SANDS F/8278'-8318'. TIME 07:00 08:00 09:30 11:30 14:00 15:00 16:16 17:40 20'10 21:20 23:00 00:30 02:20 LOG ENTRY MIRU SWS RIH W/CCL , GR AND SLTJ. TOOLS NOT WORKING DOWN HOLE AT 6700' , PUH. TOOLS AT SURFACE , TO TROUBLE SHOOT PROBLEM. REPAIRED PROBLEM AND RIH WITH CCL, GR AND SLTJ. TIE IN WITH MWD LOG DATED 11-95 , TAG 8550' , LOG UP TO TOP OF CEMENT 6750' , CEMENT BOND LOOKS GOOD. PUH. RIH W/2-1/8" ENERJET B.H. PERF GUN 20', 2 SPF AND CCL & GR. GUN IS CCW FROM HIGH SIDE. TIE IN TO GAMMA RAY , CCL HAS WEAK SIGNAL DUE TO NSCT FLUSH JOINT ON LINER. TIE-IN WITH TOP SHOT AT 8298' , BTM AT 8318'. SHOOTGUN POOH . SHOT AT400 WHP , NO CHANGE. POOH. ALL SHOTS FIRED. RIH W/2-1/8" ENERJET B.H. PERF GUN 20', 2 SPF AND CCL. GUN IS CW F/HIGH SIDE. UNABLE TO PASS 5700'. POOH TO ADD WEIGHT. RIH W/2-1/8" ENERJET B.H. PERF GUN 20', 2 SPF, CCL & ADDITIONAL WB. GUN IS CW F/HIGH SIDE. TIED IN W/ CCL. PERFORATED F/8298'-8318'. WHP = 0 PSI, DID NOT CHANGE AFTER PERFORATING. POOH. ALL SHOTS FIRED. RIH W/2-1/8" ENERJET B.H. PERF GUN 20', 2 SPF, CCL & ADDITIONAL WB. GUN IS CW F/HIGH SIDE. TIED IN W/ CCL. PERFORATED F/8278'-8298'. WHP = O PSI, DID NOT CHANGE AFTER PERFORATING. POOH. ALL SHOTS FIRED. RIH W/2-1/8' ENERJET B.H. PERF GUN 20', 2 SPF, CCL & ADDITIONAL WB. GUN IS CCW F/HIGH SIDE. TIED IN W/ CCL. PERFORATED F/8278'-8298'. WHP = 0 PSI, DID NOT CHANGE AFTER PERFORATING. POOH. ALL SHOTS FIRED. RDMO SWS. ,RCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2X-12A(W4-6)) WELL JOB SCOPE JOB NUMBER 2X-12A FRAC, FRAC SUPPORT 1215951224.1 UNIT NUMBER DATE 12/30/95 DALLY WORK RE-PERFORATE 'A' SAND ~Tbg PreSs ,FinalTbg Press I Initial Inner Ann I 1700 PSII 1700 PSI 0 PSI DAILY SUMMARY RE-PERFORATE 'A' SAND INTERVAL 8278'-8318' USING 2-1/2" TITANS W/BH CHARGES @ 2 JSPF, ORIENTED 90 DEC CW F/ LOWSIDE & 0 BEG PH. TIME LOG ENTRY 10:15 MIRU SWS/LIL' RED. HELD SAFETY MTG. 12:00 PT LUB TO 3000#; TEST OK. RIH W/GUN #1 - 2 WGT. BARS, CCL, 2-1/2' TITAN GUN W/2 SPF, BH CHARGES, ORIENTED 90 DEC CW F/LOWSIDE, 0 DEC PH TO SHOOT 8308'-8318' 12:30 ON BO'iq-OM TO TIE-IN TO PERF RECORD DATED 12/16/95 12:45 GUN#1 FIRED; POH. 13:30 AT SURF W/GUN#l; ALL SHOTS FIRED. 14:20 PT LUB TO 3000#; TEST OK. RIH W/GUN #2- 2 WGT. BARS, CCL, 2-1/2' TITAN GUN W/2 SPF, BH CHARGES, ORIENTED 90 DEC CW F/LOWSIDE, 0 DEC PH TO SHOOT 8298'-8308' 14:50 ON DO'l-TOM TO TIE-IN TO PERF RECORD DATED 12/16/95 15:00 GUN#2 FIRED; POH. 15:30 AT SURF W/GUN#2; ALL SHOTS FIRED. 16:15 PT LUB TO 3000#; TEST OK. RIH W/GUN #3- 2 WGT. BARS, CCL, 2-1/2' TITAN GUN W/2 SPF, BH CHARGES, ORIENTED 90 BEG OW F/LOWSlDE, 0 DEC PH TO SHOOT 8288'-8298' 17:00 GUN#3 FIRED; POH. 17:30 AT SURF W/GUN#3; ALL SHOTS FIRED. 18:00 PT LUB TO 3000#; TEST OK. RIH W/GUN #4- 2 WGT. BARS, CCL, 2-1/2' TITAN GUN W/2 SPF, BH CHARGES, ORIENTED 90 BEG CW F/LOWSlDE, 0 DEC PH TO SHOOT 8278'-8288' 18:30 GUN#4 FIRED; POH. 19:15 AT SURF W/GUN#4; ALL SHOTS FIRED. Final Inner Ann I 0 PSI I Initial Outer Ann I 0 PSI I Final Outer Ann 0 PSI 20:30 RDFN. P~GE NO, ! AFC ~ AK8357 API WELL , 50-029-21189-01 COMPAHY ARCO ALASKAt INC, WELL HAME 2X-12A LOCATIOH 1 KUPARUK LOCATION 2 ALAS[A MAGNETIC DECLINATION 27,87 GRID CONVERGENCE ANGLE 0,00 DATE: 25-NOV-95 WELL NUMBER 0 WELL HEAD LOCATION: LAT(N/-S) 0,00 D£P(E/-W) 0,00 AZIMUTH FROM ROTARY TABLE TO TARGET IS 335,93 TIE IH POINT(TIP) MEASURED DEPTH 5521,00 TRUE VERY DEPTH 4882,27 INCLINATION 37,77 AZIMUTH 346,41 LATITUDE(N/-S) 1903,34 DEPARTURE(E/-W) -402,09 MEASURED IHTERVAL YERTIgAL DEPTH DEPTH ft ft ft 5521,00 0,0 4882,27 5554,32 33,3 4907.62 5604,60 50,3 4941,89 5695,32 90,7 4990,36 5906,97 211,7 5076,97 6184,33 6462,71 6747.51 7017,10 7390.19 277,4 5183.69 278,4 5294,11 284,8 5411.89 269,6 5527,96 373,1 5691.66 7665,35 7763,32 7851,36 8038,53 8211,Q9 275,2 5815.66 98,0 5861,31 88,0 5902,57 187,2 5992,02 172,6 6077,66 8225.66 8317,68 8502,03 8569,00 14,6 6085,02 92,0 6131,31 184,4 6221,10 67,0 6254,11 PROJECTED SURVEY: 8681,00 112,0 6311.37 ******~****** AHADRILL ************** SURV£f CALCULATIONS ************* CIRCULAR ARC METHOD******** TARGET STATION AZIMUTH LATITUDE SECTIOH INCLN, ft deg de§ ft 0,00 37,77 346,41 1903,34 21,01 43,14 351,84 1924,56 57,34 51.23 335,32 1959,57 133,56 64,09 328,69 2026,90 325.27 67,59 329,54 2192,61 579,71 67,15 329,62 2413,37 833,07 66,12 327,32 2631,19 1089,55 65,02 327,62 2849,80 1329,93 63.98 326,40 3053,89 1660,53 63,97 326,35 3333,06 1902,02 62,46 324,46 3535,26 1987,03 62.00 324,80 3605,94 2063,32 62,10 324.70 3669,45 2224,63 60,80 324,90 3803,~0 2371,04 59,70 322,50 3924,53 2383,30 59,60 324,00 3934,61 2461,25 60,00 325,00 3999,35 2619,43 61,70 325,40 4131,56 2676,93 59,25 327,87 4180,21 2772,23 59.25 327,87 4261,72 .-. _ 2X- 12A ~ DEPARTURE DISPLACEMEHT at AZIMUTH DLS £/-W de§/ ft ft deg lOOft -402,09 1945,35 348,07 0,00 -406.11 1966,94 348,08 19,26 -416,79 2003.41 347,99 28,89 -452,94 2076.89 347,40 15,45 -552,03 2261.04 345.87 1,69 -681,66 2507,79 344,23 0,16 -815,27 2754.60 342.78 0,84 -954,71 3005,46 341.48 0,40 -1087,18 3241,64 340.40 0,56 -1272.83 3567,82 339,10 0,0I -1412,26 3806,91 338,22 0,82 -1462,44 3891,22 337,92 0,56 -1507.33 3966,98 337.67 0,15 -1602,10 4127,42 337,16 0,70 -1690,77 4273,25 336,69 1,37 -1698,29 4285,48 336.65 8,91 -1744,47 4363,26 336,43 1,04 -1836,35 4521,28 336,04 0,94 -1868,40 4578,76 335,92 4,87 -1919,60 4674.09 335,75 0,00 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 AT'TN: Sherrie NO. 10004 Company: 1/24/96 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open/Cased Hole) US Well Job ff Log Description Date BL RF Sepia DIR MWD Tape ~,. 1H-08 ,?2--r.)'::'.~ --95064 '~UAL BURSTTDT-P (BORAX) 950205 1 I '", .... "' ~ Y:24__ ~.:~,,~-' ?)','~2 95036 DUAL BURS,'r TDT-P (BORAX) 950107,, I I .... .31:1-26 .:/~'-"-. t~' '? 95406 ARC5 951 21 5 I I 1 2X-12A ~'~"T ["/{~ 95382 ARC5 951 1 25 I I I ~- ..... 3A-04 ?';'- 2 ~ '? 95(!:38 OUAL. B__uRs'r'TI~T-P BoRAx 9501 09 I .. I I 6 _ , . . . . SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ARCO Alaska, inc. Date: January_ 15, 1996 Transmittal #: 9318 RETURN TO: ARCO Alaska, Inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATOol 119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. ._/"',;'~ ¢ 2x-18 CBL ~-)" ~l,,/2X-12A CBL , V I%,/ 2X-19 CBL ~._,,~ '~ ./2Z-12A CBL ~'~ Receipt -- Acknowledge: DISTRIBUTION: 12/05/95 1 2/16/95 1 2/04/95 12/12/95 Date: · Sharon AIIsup-Drake DS Development ATO-12O5 ~.Gmm (+sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Erickson/Zuspan NSK Central Files NSK-box 69 TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION November 13, 1995 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Michael Zanghi, Drill Site Develop. Supv. ARCO Alaska Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River 2X-12A ARCO Alaska, Inc. Permit No 95-176 Surf Loc 1230'FSL, 598'FEL, Sec. 4, T11N, R9E, UM Btmhole Loc 318'FSL, 2582'FEL, Sec. 33, T12N, R9E,UM Dear Mr Zanghi: Enclosed is the approved application for permit to re-drill the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-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) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to ddlling a new hole. Notice may be given by contacting the Commission's petroleum field inspector on the North Slope pager at 659-3607. dlf/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl "---" STATE OF ~ ' AL _,KA OIL AND GAS CONSERVATION COMMI.. ON PERMIT TO DRILL 20 AAC 25.005 ,1~. TypeofWork Drill [-'] Redrill Xllb TypeofWell Exploratory [--] StratigraphicTest r-] Development Oil X Re-Entry [] Deepen []I Service [] Development Gas [] Single Zone X Multiple Zone 2, Name of Operator 5. Datum Elevation (DF or KB) 1 0, Field and Pool ARCO Alaska, Inc. RKB 41', Pad 77' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25642, ALK 2573 4. Location of well at surface 7. Unit or pcoperty Name 1 1, Type Bond (see 20 AAO 25,O25) 1230' FSL, 598' FEL, Sec. 4, TllN, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 167' FSL, 2482' FEL, Sec. 33, T12N, R9E, UM 2X-12A #U-630610 At total depth 9. Approximate spud date Amount 318' FSL, 2582' FEL, Sec. 33, T12N, R9E, UM 1 1/17/95 $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 2X-01 8810' MD 167'@ TD feet 1836' @ 5563' MD feet 2560 6341' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 5563' feet Maximum hole angle 6 5° Maxirnum~rface 3052 psig At total depth (TVD) 3 700 psig 18. Casing program Setting Depth size Specifications Top Bottom Quanti~ of cement Hole Casing Weight Grade Coupling Lenc, lth MD TVD MD TVD ' linclude stac~e dataI 6.125" 4.5" 12.6# L-80 NSCT 3447' 5363' 4762' 8810' 6341' 420 Sx ClassG Top 1000' above Kuparuk 1 9. To be completed for Redrill, Re-entry, and Deepen Operations. ~ . ~. ., ... Present well condition summary Total depth: measured 3 0 9 0 feet Plugs (measured) !"~ ~iV c.~ -. .,~-~ ~, .. ;~, : ) !.'; ;:.: :.) true vertical 3004 feet Effective depth: measured 7236 feet Junk (measured) i true vertical 6285 feet Casing Length Size Cemented Measured depth True Vertical depth Structural 70' 1 6" 260 sx CSII 1 00' 1 00' Conductor Surface 3060' 9-5/8" 700 sx CSIII & 550 sx CSII 3090' 3004' Intermediate Production 7287' 7" 515 sx Class G & 250 sx CSI 731 7' 6352' Liner Perforation depth: measured 6732-6812', 6822-6854', 7037-7048', 7060-7112' true vertical 5864-5931', 5939-5966', 6118-6127', 6137-6186' 20. Attachments Filing fee X Property plat F'] BOPSketch X Diverter Sketch [--] Drilling program X Drilling fluid program X Time vs depth plot E] Refraction analysis E] Seabed report E] 20 AAC 25.050 requirements X 21. I hereby c/~rtJfy that the!foregoing is true and correct to the best of my knowledge Signed (~,[~/,~ ~,~ Title Drill Site Develop. Supv. Date '/~'('"""~'/~ Commission Use Only PerrJzit Number ,,/'/ I APl number I Approval dat i See cover letter for /'%"',o¢"'--////~'' 5 0- c3 ~ ~'--- ~ /"/2 ~ ,~_... 4:3' / e//_..../.~ .. ,~,~- other requirements Co d,t,on of a prov. Sam esre. u red I--i Yes No Mud logrequ red l-1 Yes No Hydrogen sulfide measures ~ Yes r"] No Directional sur~,ey required ~ Yes g] No uired work,ng pressure for BOPE [3 2M [3 ffi 5M E] [3 Other: Signed By Approved by '" Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate GENERAL DRIllING PROCEDURE KUPARUK RIVER FIELD 2X-12A SIDETRACK Pre-Parker Operations: Nordic Rig #1 will P&A the original Kuparuk location, mill a window in the 7" casing, and set a kickoff plug as described in the Sundry approved on 10/20/95, No. 95-182. 1. Move in and rig up Parker #245. Install and test BOPE to 5000 psi. RIH to cement plug and establish sidetrack from original well. Estimated kickoff point is _+5,563'. Perform leak off test to 12.5 ppg EMW in new open hole. Drill 6-1/8" hole to total depth (8,810') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 4-1/2" liner on drillpipe, with 5" polished seal bore. Set liner hanger and liner-top packer with 200' of liner lap from the kickoff point. Release from liner. Note: Due to the long length of the liner, the cementing program is not designed to reach the liner lap but to extend 1000' above the top of the Kuparuk. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Pressure test casing and liner-top packer to 3500 psi. Run completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus. ND BOPE and install production tree. Note: As a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. Shut in and secure well. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. . . , , , . . . 10. 11. 12. Oil & Gas Cons, Commission AncRorage DRILLING FLUID PROGRAM Well 2X-12A Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casin~l 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 +10% Drill out to weiCht up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% 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' Weight up to TD 11.6 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% ?,lOV 05 i99-5 Oil & Gas Cons. Commission Anchorage 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 leak-off at the kick-off point of 14.5 ppg EMW and a gas gradient of 0.11 psi/ft. At the anticipated 3700 psi of reservoir pressure, formation breakdown would not occur before a surface pressure of 3,052 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 5000 psi. The nearest existing well to the 2X-12A sidetrack is 2X-01. As designed, the minimum distance between the two wells would be 1,836' @ 5,563' MD. Annular Pumping Activities: Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2X-12A surface/production casing annulus has been Arctic packed. Drilling Area Risks- The main risk in the 2X-12A drilling area is high pressures in the Kuparuk formation. Lost circulation above the Kuparuk is not thought to be a problem. The formations suspected to be the cause of lost circulation above the Kuparuk will be behind pipe due to the deep kickoff point. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 11.6 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7" kickoff point will be tested to an equivalent mud weight of 12.5 ppg upon establishing the sidetrack. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. ,CO ALASKA, Inc. Structure : Pad 2X Well : 12A Field : Kuparuk River Unit Location : North Slope, Alaska < West Scale 1 : 100.00 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 iCreoted by ; jones For: D PETRASH iOote plotted : 26-Oct-95 i iPIot Reference is 12A Version #6. iCoordinotes ore in feet reference slot j~12A, True Verticol Depths ere reference RKB (Perker ~245), N 24.07 DEG W 4619' (TO TARGET) ***PLANE OF PROPOSAL*** d 4600_ o _ .. 480O_ __e 5000_ 5400_ 56OO_ -- 5800_ _ [ 6000_ I v - 6200_ 6600_ KOP - SIDETRACK PT TVD=4916 TMD=5563 DEP=1927 47.58 12 BEG / 100' DLS .25 EOC TVD=5079 TMD=5825 DEP=2127 AVERAGE ANGLE 65 DEG TD LOCATION: TD -- 5 1/2 Coslng P[.,/,~.~ N .318' FSL, 2582' FEL \ TARGET - B/ Kup Sands ~ ~) SEC...~3, T12N, Rg.~~.~ ~.~p A Unit SEC. 35. T12N, Rg~ ~ TARGET ~ T~V'MDD==6¢6~6 Top D Unit X~To x~opC Unit DEP=4619 ~ NwOE~T~H ~47 x% K--1 Marker \ a~uska 0ii & Gas Cons, Comm~ssion ,Anchorage KOP - SIDETRACK PT TVD=4915.54 TMD=5563.02 DEP=1927.0,3 $7.5 DEG 346.64 AZ NORTH 1928.29 WEST 408.06 K0P - Sidetrack Pt B/ HRZ TVD=5648 TMD=7172 DEP=5532 K-1 TqD=5796 TMD=7522 DEP=3645 D UNIT TVD=5879 TMD=7718 DEP=3821 T/ C UNIT TVD=5882 TMD=7725 DEP=3827 T/ B UNIT TVD=5992 TMD=T986 DEP=4060 T/ A UNIT TVD=6129 TMD=8310 DEP=4350 TARGET - B/ KUP SNDS TVD=6956 TMD=8610 DEP=4619__ TD -~ t/2" ~G PT TVD=6341 TMD=88t0 DEP=4798 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 Scale 1 · 100.00 Vertical Section on 335.93 azimuth with reference 0.00 N, 0.00 E from slot #12A 4600 _ _4400 _ _4200 _ _4000 _ _5800 _ _3600 _ _5400 L5200 - _5000 - _2800 -- _2600 _ _2400 _ _2200 - _2000 800 6 5 4 3 13 5/8" 5000 PS, 6OP 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. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TESTALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 5000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOWAND 5000 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 BO'FI'OM RAMS TO 250 PSI AND 5000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5(X)O PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 5000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" -5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR i2'42PM ARCO AI.ASKA iNC No. 4592 STATE OF ALASKA ALASKA OIL AND GAS CGN~I::RVATION CQMMI~ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon X_ Suspend _ Operation Shutdown_ Re-enter suspended well Alter easing _ Repair well_ Plugging _~_ Time extension _ Stimulate Change approved program _ Pull tubing _ Variance _ Perforate _ Other X Plugback for Redrlll 2. Name of Operator ARCO_A_!aska._ 3. Address P., ,O. Box 100360, Anchorage, AK 99510 4. Location of'Bell ~i ;~urlace 1230' FSL, 598' FEL, Sec. 4, TllN, RgE, UM At top of productive interval 1461' FNL, 1176' FEL, Sec 4, T11N, ROE, At etfective depth 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) P. 3/3 feet RKB 1_1 _2'.___ P ecl Elev. 77_' 7. Unit or Property name Kuparuk River Unit @. Well number 2X-12 9. Permit number 84-165 10. APl number 1185' FNL, 1222' FEL, Sec. 4, T11N, RgE, UM At total depth 1127' FNL, 1232' FEL, .S..ec. _4., T11_N_, RgE, UM 12. Present well condition summary Total Depth: measured Eflect[ve depth: 7343' (approx) true ver~ieal 6374' measured 7236' feet Junk (measured) (approx) true vertical 6285' feet None Casing Length Size Cemenmd Structural 7 0' 1 6" 260 SX CS II Conductor Surface .... 3060' 9.5/8' 700 sx C$111 & '3o9o' Intermediate 550 sx CS il Production 7287' 7' 515 SX Class G Liner 250 sx CS I Perforation depth: measured ! lear Plugs (measured) feet 50.02g-2118~ 11, Field/Pool Kupursk River Field/ Kuparuk River Oil Pool gi~sl_~ k/il & Gas Cons. Commissio. n ........ ~ ~ch0ragq Measured dep~ 'True ve~i~ depth 100' 100' 7317' 6270' 13. 6732'-6812', 6822'-6854' MD 7037'-7046', 7060'-71t2' MD true vertical 5864'-5932', 5940'-5967', Tubing (size, grade, snd meaeured depth) 3-1/2', J-55, @ 6923' MD PaCkers ~nd SSSV (tTpe and measured depth) Baker FB-1_@_6893', BAKER FHL @ .6..562', ~ Baker FVL ~ lgO1' Attachments 12 spf 120 degree phasing 4 spt 120 degree 0basing 6119'-6128', 6138'-6182' TVD Description summary ol proposal OCT 1/ i995 ~as~ 0~i,& Gas Cons. ~ch0~a~ Detaile~l operation program ~ BOP sketch_ 14. Estimamd date for commencing opera'on I;1~.' $~atus of well cla, s~ificatJon as: . October 30. 1~_ ~ OII ~ Gas ~ $uspendad_ 16. 1[ proposal was verb~ly approved Name of spprover D~te approved Service , , 7. I hereby ~'~' that ~he/Toregoing is true an~ ~orla~ to the best ot my knowledge. ' ' .... ~ ( ,' ~ i - F~MMI~[ONusEONLY .... Plug integrity ~ ~~Lo~d~ar~ __[ ~ ~ I ~- - / Mechanical Integrity Te ~ eT Approved b7 the order ol the Commission ate Fo~ 10-403 Rev 06/15/88 .... ~~-~' ~ ~uB~iT IN ~RI~LICATE ARCO ALASKA iNC No, 4592 P. i/3 KRU 2X.12 SUNDRY OBJECTIVE to P & A WELL FOR SIDETRACK OPERATIONS (reference attached plugback schematic) PRE-RIG WORK: 1. RU slickliae unit, RIH and shut in C Sand. Pull plug from 'D' nipple in tubing tail and open A Sand. RU coiled tubing uniu RIH and clean out fill to 50' below A Sand gerfs. Place a balan~/~ ~ 2. cement plug from 50' below the A Sand to the tubing tail (+/-115' above top A Sand 3. RU slicklin¢ unit. R1H and dummy off all GLMs, leave deepest GLM open. Pull dummy,x, valves from all C Sand mandrels leaving open pockets. , WORKOVER RIG W0_RK; ~!; !(~)o ~ 1. MIRU Nordic Rig. Lay hard-line ,o m;¢. Pull BPV and VR plug. _~la$!,a :0.,1: 'B~; ~;e Goa, mis'cio.n 2. Loadpitsw/killwcightmud(expectedkillwt=10.$ppg), Circulalewentokill~veigh~ mud. Ensure wen is dead~ ~ / 3. NDtre¢. NU and test B OPE. L / 4. Screw in landing joint~ POOH laying down all robing and jewelry. ~/ 5 RUE line unit. RIH with cemem retainer and set at 5706' MD RKB (200'~o~low mp of proposed section in 7" casing). PU DP and RIH to cement retainer. Pump cement squeeze below retainer into C Sand peffs filling 7" casing to top of bottom packer. Unsting from retainer and spot 3 bbl cen~nt on top of ~tainct'. Cixculatc well to milling fluid. POOH standing back DP. 7. RIH w/section mill Spot an 18 ppg balanced mud pill from PBTD to the base of proposed section. Cut a 50' section in ~e 7" casing from 5506' - 5556'. POOH w/mill, RIH w/open ended DP. Wash down through section and circulate any metal shavings from well. Mix and pump balanced cement kick-off plug f/100' below base of section to 200' above top of section. POOH LD drill pipe stopping at 1800' TVD to freeze protect well. 9_ Install tubing hanger with BPV. ND BOPE. NU and test uee. RDMO Nordic Rig. Post-It'" brand fax transmittal memo 7671 *l-~!,ag'e,, ..~ I WSI 10/16/95 OCT 1 / 1995 Alas~.0il & Gas Cons. Commission ~chorag~ ARCO ALASF~A i~C ~o, 4592 P. 2/3 2X-12 Proposed Plu" ack APl #: 50-029-21189 RKB = 112' GL = 77' 9-5/8' 36#, J-55 set @ 3090' MO ; Gas Cons, Corr~missi~_r~ ~choraga ~ Cement Kick-off plug 5306' - 5656' MD: 17.0 ppg 7" Casing section milled 5506'- 5556' MD OC'f ][ ~995 Oil & Gas Cons, 'Anchorage 18,0 ppg Mud from 5656'- 5706' MD: 17.0 ppg 7" Baker 'K,I' Cement Retainer@ 5706' MD with cement squeezed below retainer down ~ bottom packer. 3-1/2" X 7" Bake~ 'FHL' Retrievable produclion packer w/PBR bbl @ 6565' MI:). Abandoned C Sand Perfs Top perforatian @6732' MD Bottom perforation @ 6854' MD Abandoned A Sand Perfs 7% 26#, J-55 3-1/2" x 7" Baker 'FB.I' Permanent packer @ 6895' MI). A Sand Perfs isolated by oemem plug from tubing tail at 6923' to +/-7165' MD. Top perforation @7037' MD Bottom perforation @ 7112' MD Top of till at +/-7165' MD. PBTD =7236' MD TO = 7343' MD WSI 10/16/95 WELL PERMIT CHECKLIST ~DMINI STRATION 1. 2. 3. 4. 5. 6. 10. 11. 12. 13. Permit fee attached .................. Lease number appropriate ............... Unique well name and nu/nber .............. Well located in a defined pool ............ Well located proper distance from drlg ~nlt boundary. Well located proper distance from other wells ..... Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ........ Operator only affected party ............. Operator has approprla~e bond in force ........ Permit can be issued without conservation order... Permit can be issued without administrative approval. Can permit be approved before 15-day wait ...... ENGINEERING N N '. Y N WELL NAME GEOL AREA UNIT# PROGI~%M: exp [] dev [] redr serv [] ,., I? ^_},,. 14. Conductor string provided ................ 15. Surface casing protects all known USDWs'. ........ 16. CMT vol adequate to circulate on conductor & surf osg. 17. CM~ vol adequate to tie-in long string to surf csg . . 18. CMTwill 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.~ 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate ......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to .~~ psig.~ 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... 29. 'Is presence of H2S gas probable . . .. ...... ,. · GEOLOGY Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis 9f shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ ~ N - 34. Contact name/phone for weekly progress repo.-ts .... /. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISS ION: Comments/Instructions: 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, informati;3n of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ALASKA COMPUTING CENTER · SCHLUMBERGER · COMPANY NAME : ARCO ALASKA, INC. WELL NAME : 2X-12A FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-~29-21~$9-0~ REFERENCE NO : 95582 ..S Tape Verification Listing Schlumberger Alaska Computing Center 19-JAN-1996 16:43 **=, REEL HEADER =~*~ SERVICE NAME : EDIT DATE : 96/0~/19 ORIGIN : FLIC REEL NAME : 95382 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA IN¢., KUPARUK 2X-12A, API #50-029-2i189-0~ **** TAPE HEADER **=* SERVICE NAME : EDIT DATE : 96/01/19 ORIGIN : FLIC TAPE NAME : 95382 CONTINUATION # : ~ PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., KUPARUK 2X-~2A, API ~50-029-2~189-01 TAPE HEADER KUPARUK RIVER MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA 2X-~2A 50~292~890~ ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 19-JAN-96 BIT RUN 1 BIT RUN 2 BIT RUN 3 ENGINEER WITNESS SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD KADRMAS KADRMAS KADRMAS MORRISON MORRISON MORRISON 4 liN 9E [230 598 77.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 9.625 3090.0 7.000 5552.0 PAGE: .=$ Tape Verification Listing Schlumberger Alaska Computing Center 19-JAN-1996 16:43 PRODUCTION STRING REMARKS: Well drilled 21-NOV through 25-NOV-g5 with ARC5 only. All data was collected in three bit runs. No MAD data was collected. $ $ PAGE: · ,,, FILE HEADER FILE NAME : EDIT SERVICE : FLIC VERSION : 001C01 DATE : 96/01/19 MAX REC SIZE : le24 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH MWD 5620.5 8680.5 $ BASELINE CURVE FOR SHIFTS: GE CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH. BASELINE DEPTH MWD 88888.0 88887.0 8460.0 8459.0 8447.5 8446.0 8431.5 8429.5 8331.0 8329.5 8309.0 8307.0 8278.0 8275.5 8269.0 8266.0 8230.5 8229.0 8167.5 8165.0 8057.5 8055.0 8016.0 8013.5 7912.5 7910.5 7900.0 7898.0 7891.0 7888.0 7839.0 7842.0 7816.0 7819.0 7798.5 7801.5 7790,0 7794.0 _~S Tape Ver|~ication Listing Schlumberger Alaska Computing Center 19-JAN-1996 16:43 7715.0 7716.5 7696.0 7692.5 7689.0 7687.0 7681.5 7680.5 7673.5 7671.0 7665.0 7662.0 7618.9 7615.5 7546.9 7544.9 7454.9 7452.9 7417.9 7415.9 7564.9 7369.5 7287.5 7283.9 7267.5 7265.9 7254.5 7251.9 7205.9 7291.5 7143.5 7149.0 7135.9 7131.5 7125.5 7122.5 7116.9 7113.9 7199.9 7096.5 7992.5 7989.0 7959.5 7957.0 7935.9 7931.5 7~93.5 6999.5 6918.5 6914.5 6859.0 6855.5 6726.5 6723.5 6647.9 6644.0 6614.5 6611.9 109.9 96.5 $ MERGED DATA SOURCE LDWG TOOL CODE BIT RUN NO. MERGE TOP MERGE BASE MWD 1 5620.$ 5797.0 MWD 2 5797.0 8289.0 MWD 3 8289.0 8680.5 $ REMARKS: The depth adjustments shown above reflect the MWD GR to the CBT GR logged by SWS, All other MWD curves were carried with the GR. No ticks or ROP are shown due to data incompatibility. $ LIS FORMAT DATA PAGE: _~S Tape Verification Listing Schlumberger Alaska Computing Center 19-JAN-1996 16:43 PAGE: DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 32 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 00 008 80 0 I 1 I 4 68 0000000000 FET DWI) HR 08 000 00 0 I 1 1 4 68 0000000000 GR MWD GAPI ~0 ~0~ 00 0 1 1 1 4 68 0000000000 RPXX MWD OHMM 00 e00 00 0 1 1 1 4 68 0000~0~000 RPX MWD OHMM 0~ 000 00 0 I 1 1 4 68 00~0000000 RPS MWD OHMM 00 000 00 0 I 1 ! 4 68 000000~000 RPM MWD OHMM 00 000 ~0 0 1 1 1 4 68 0000000000 RPD MWD OHMM ~0 000 00 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 8679.500 FET.MWD 1.653 GR.MWD 90.225 RPXX.MWD RPX.MWD 3.633 RPS.MWD 3.811 RPM.MWD 4.040 RPD.MWD DEPT. 8000.000 FET.MWD 0.933 GR.MWD 66.301 RPXX.MWD RPX.MWD 6.446 RPS,MWD 6.597 RPM.MWD 6.737 RPD.MWD DEPT. 7000.000 FET.MWD 0.144 GR.MWD 127.641 RPXX.MWD RPX.MWD 4.676 RPS.MWD 4.984 RPM.MWD 5.434 RPD.MWD DEPT. 6000.000 FET.MWD 0.197 GR.MWD 113.517 RPXX.MWD RPX.MWD 3.935 RPS.MWD 3.968 RPM.MWD 3.998 RPD.MWD 3.480 4.289 6.264 6.874 4.512 5.902 3.856 4.063 _~$ Tape Verification Listing Schlumberger Alaska Computing Center 19-JAN-1996 16:43 PAGE: DEPT. 5617.000 FET.MWD RPX.MWD 3.388 RPS.MWD 4.5~9 GR.MWD 3.472 RPM.MWD 112.287 RPXX.MWD 3.563 RPD.MWD 3,308 3.652 ** END OF DATA ***~ FILE TRAILER **~* FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 96/01/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : *~** FILE HEADER FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : MAX REC SIZE : ~024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 562e.5 $ 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): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) 5797.0 25-NOV-95 4.0B 4.0B IDEAL MEMORY 868~.0 5620.0 8640.0 _iS Tape Verification L|st|ng Schlumberger Alaska Computing Center 19-JAN-1996 16:43 MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER ARC5 RESISTIVITY SLIMi TELEMETRY $ ARC5 475 SLIM1A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: ******BIT RUN 1 & 2****** GR TO BIT: 37.8~,RES TO BIT: 33.8~ RUN ! DRILLED 5650~ TO 5797~ RUN 2 DRILLED 5797~ TO 8289~ ******BIT RUN 3****** GR TO BIT: 47.8~,RES TO BIT: 43.8~ RUN 3 DRILLED 8289~ TO 8681~ 5522.0 LIGNO-GEL il.6e 2.600 2.35~ 7S .0 75.0 USED IDEAL 4:0B.321.11.O3,SPM 4.~BOS,DH 4.0B09 BIT RUN DATA STRIPPED FROM MERGED FIELD FILE $ LIS FORMAT DATA PAGE: .iS Tape Verification Listing Schlumberger Alaska Computing Center 19-JAN-1996 16:43 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB =* TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 32 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 32 12 68 13 66 14 65 FT 15 66 68 16 66 0 66 PAGE: SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 00 000 00 0 2 1 1 4 68 0000090000 FET LW1 HR 99 999 99 9 2 1 1 4 68 9999999999 GR LW1 GAPI 99 999 99 9 2 1 1 4 68 9999999999 RPXX LW1 OHMM 99 999 99 9 2 1 1 4 68 9999999999 RPX LW1 OHMM 99 999 99 9 2 1 1 4 68 9999999999 RPS LWl OHMM 99 999 99 9 2 1 1 4 68 9999999999 / RPD LW1 OHMM 99 999 99 9 2 1 1 4 68 9999999999 ,~, ** DATA DEPT. 5797.99~ FET.LWl 9.139 GR.LWl RPX.LW1 3.690 RPS.LW1 3.763 RPM.LW1 DEPT. 5629.500 FET.LWl 4.519 GR.LW1 RPX.LW1 3.388 RPS.LW1 3.472 RPM.LW1 91.408 RPXX.LW1 3.833 RPD.LWl 112.287 RPXX.LW1 3.563 RPD.LWl 3.600 3.995 3.308 3.652 ** END OF DATA ** _iS Tape Veri~icat|on Listing Schlumberger Alaska Computing Center · ~.~ FILE TRAILER FILE NAME : EDIT SERVICE : FLIC VERSION : 991C91 DATE : 96/91/19 MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : 19-JAN-igg6 i6:43 PAGE: **** FILE HEADER FILE NAME : EDIT SERVICE : FLIC VERSION : DATE : 96/91/~9 MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW MWD Curves and log header data ~or each b|t run in separate files. BlT RUN NUMBER: 1 DEPTH INCREMENT: 9.5999 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD $ LOG HEADER DATA 5797.9 8289.9 DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 25-NOV-95 4.9B 4.9B IDEAL MEMORY 8681.9 5629.0 8649.9 TOOL NUMBER ARC5 RESISTIVITY SLIM1 TELEMETRY $ ARC5 475 SLIM1A LiS Tape Verification Listing Schlumberger Alaska Computing Center 19-JAN-1996 16:43 PAGE: BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): 5522.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): LIGNO-GEL 11.60 50.0 2.600 2.350 75; .0 75 .o NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: ******BIT RUN 1 & 2****** GR TO BIT: 37.$~RES TO BIT: $g.8~ RUN ~ DRILLED 5650' TO 5797' RUN 2 DRILLED ~797~ TO $289' ******BIT RUN 3****** GR TO BIT: 47.8.1~RES TO BIT: 45.8~ RUN 3 DRILLED 8289~ TO 8681~ USED IDEAL 4.0B.$2[.II.O3~SPM 4.0BOS~DH 4.0B09 BIT RUN DATA STRIPPED FROM MERGED FIELD FILE LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE · 1 66 2 66 3 73 4 66 5 66 6 73 7 65 0 0 32 1 LIS Tape Verifica%ion Li$%ing Schlumberger Alaska Computing Cen~er [9-JAN-1996 16:43 PAGE: 10 TYPE REPR CODE VALUE 8 68 0.5 9 65 FT 12 68 13 66 0 [4 65 FT [5 66 68 0 66 SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 0~ 000 ~0 0 3 1 1 4 68 00~0~00~0 FET LW2 HR 00 000 00 0 3 1 1 4 68 00000000~0 GR LW2 GAPI 0~ 000 00 0 3 1 1 4 68 00~000~0~0 RPXX LW2 OHMM 00 000 00 0 3 1 1 4 68 0000000090 RPX LW2 OHMM 99 999 99 9 3 1 ~ 4 68 ~900909~99 RPS LW2 OHMM 09 999 00 9 3 1 I 4 68 9909899099 RPM LW2 OHMM 09 909 90 9 3 ~ 1 4 68 0999099999 RPD LW2 OHMM 09 999 09 9 3 1 I 4 68 9999999999 ** DATA ** DEPT. 8289.099 FET.LW2 2.398 GR.LW2 26.285 RPXX.LW2 RPX.LW2 ~28.677 RPS.LW2 169.345 RPM.LW2 173.136 RPD.LW2 DEPT. 8eee.~e9 FET.LW2 9.917 GR.LW2 68.743 RPXX.LW2 RPX.LW2 6.472 RPS.LW2 6.552 RPM.LW2 6.664 RPD.LW2 DEPT. 78~e.~9~ FET.LW2 9.239 GR.LW2 177.936 RPXX.LW2 RPX.LW2 4.119 RPS.LW2 4.228 RPM.LW2 4.392 RPD.LW2 DEPT. 6890.~98 FET.LW2 9.208 GR.LW2 116.935 RPXX.LW2 RPX.LW2 4.~47 RPS.LW2 4.~95 RPM.LW2 4.173 RPD.LW2 DEPT. 5797.000 FET.LW2 9.139 GR.LW2 91.408 RPXX.LW2 RPX.LW2 3.690 RPS.LW2 3.763 RPM.LW2 3.833 RPD.LW2 87.574 179.116 6.339 6.850 4.078 4.510 3.975 4.296 3.6~9 3.905 ** END OF DATA LIS Tape Verificat|on L|sting Schlumberger Alaska Computing Center **** FILE TRAILER FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001C01 DATE : 96/01/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 19-JAN-1996 16:43 PAGE: **** FILE HEADER **** FILE NAME : EDIT .&&4 SERVICE : FLIC VERSION : 001C01 DATE : 96/91/19 MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: 9.5999 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD $ LOG HEADER DATA 8289.9 8689.5 DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 25-NOV-95 4.9B 4.9B IDEAL MEMORY 8681.9 5629.9 8649.9 TOOL NUMBER ARC5 RESISTIVITY SLIM1 TELEMETRY $ ARC5 475 SLIM1A LIS Tape Verification Listing Schlumberger Alaska Computing Center 3.9-JAN-1996 16:43 PAGE: 3.2 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): 5522.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): LIGNO-GEL 50.0 2.600 2.350 75.0 75.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: ******BIT RUN 1 & 2****** GR TO BIT: 37.$1~,RES TO BIT: 33.@~ RUN 1 DRILLED 5650~ TO 5797~ RUN 2 DRILLED 5797~ TO 8289~ ******BIT RUN 3****** GR TO BIT: 47.$1~,RES TO BIT: 43.$~ RUN 3 DRILLED 8289~ TO 8681~ USED IDEAL 4.~B.321.1~.O3,SPM 4.0BO8,DH 4.0B09 BIT RUN DATA STRIPPED FROM MERGED FIELD FILE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 2 66 3 73 4 66 5 66 6 73 7 65 0 0 32 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JAN-1996 1.6:43 PAGE: 1.3 TYPE REPR CODE VALUE 8 68 0.5 9 65 FT 1.1 66 32 12 68 13 66 0 1.4 65 FT 15 66 68 0 66 SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT FET LW3 HR GR LW3 GAPI RPXX LW3 OHMM RPX LW3 OHMM RPS LW3 OHMM RPM LW3 OHMM RPD LW3 OHMM 00 000 00 0 4 1 I 4 00 ~00 00 0 4 1 I 4 00 00~ 00 0 4 1 1 4 00 00~ 00 ~ 4 1 I 4 00 ~00 00 ~ 4 1 1 4 ~0 000 ~0 0 4 1 1 4 00 ~00 ~0 ~ 4 1 1 4 00 ~00 ~0 ~ 4 1 1 4 ** DATA ** DEPT. 8680.500 RPX.LW3 3.633 DEPT. 8289.000 RPX.LW3 128.677 ** END OF DATA ** FET.LW3 1.653 GR.LW3 RPS.LW3 3.811 RPM.LW3 FET.LW3 2.308 GR.LW3 RPS.LW3 160.345 RPM.LW3 90.225 RPXX.LW3 4.040 RPD.LW3 26.285 RPXX.LW3 173.136 RPD.LW3 3.480 4.289 87.574 179.116 **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : 001C01 DATE : 96/01/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JAN-3.996 3.6:43 PAGE: 3.4 · ~** TAPE TRAILER .-~, SERVICE NAME : EDIT DATE : 96/03./~9 ORIGIN : FLIC TAPE NAME : 95382 CONTINUATION # : ~ PREVIOUS TAPE : COMMENT : ARCO ALASKA INC.~ KUPARUK 2X-i2A~ API #50-029-23~89-03. *~*~ REEL TRAILER SERVICE NAME : EDIT DATE : 96/0~/19 ORIGIN : FLIC REEL NAME : 95382 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC.~ KUPARUK 2X-~2A~ API