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193-006
Originated: Delivered to:10-Apr-25 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 1 1A-24 50-029-22984-00 909933118 Kuparuk River Leak Detect Log with ACX Field & Processed 24-Mar-25 0 1 2 1E-04 50-029-20478-00 909915381 Kuparuk River Multi Finger Caliper Field & Processed 24-Mar-25 0 1 3 1E-04 50-029-20478-00 909915381 Kuparuk River Plug Setting Record Field- Final 25-Mar-25 0 1 4 1E-04 50-029-20478-00 909915381 Kuparuk River SBHP Record Field- Final 24-Mar-25 0 1 5 1E-11 50-029-20787-00 909938097 Kuparuk River Leak Detect Log with ACX Field & Processed 9-Mar-25 0 1 6 1E-11 50-029-20787-00 909953630 Kuparuk River Multi Finger Caliper Field & Processed 29-Mar-25 0 1 7 1E-11 50-029-20787-00 909953630 Kuparuk River Plug Setting Record Field- Final 29-Mar-25 0 1 8 1E-11 50-029-20787-00 909953630 Kuparuk River SBHP Record Field- Final 27-Mar-25 0 1 9 1H-01 50-029-22330-00 909916110 Kuparuk River Packer Setting Record Field- Final 9-Mar-25 0 1 10 1Y-27 50-029-22379-00 909915690 Kuparuk River Leak Detect Log Field- Final 22-Mar-25 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 200-181 182-057 182--051 193-006 193-088 T40306 T40307 T40307 T40307T40308 T40308 T40308 T40308 T40309 T40310 4/10/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.10 14:24:17 -08'00' 91H-01 50-029-22330-00 909916110 Kuparuk River Packer Setting Record Field- Final 9-Mar-25 0 1 193-006 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: Tubing Patch 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 7880'feet None feet true vertical 6850' feet 7166', 7800'feet Effective Depth measured 7880'feet 7070', 7086', 7120', 7166', 7529' feet true vertical 6850'feet 6152', 6166', 6195', 6234', 6546' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 7552' MD 6566' TVD Packers and SSSV (type, measured and true vertical depth) 7070' MD 7086' MD 7121' MD 7166' MD 7529' MD N/A 6152' TVD 6166' TVD 6195' TVD 6234' TVD 6546' 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: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 144 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: P2P Patch Packer Packer: P2P Patch Packer Packer: P2P Patch Packer Packer: Baker FHL Packer Packer: Baker FB-1 Packer SSSV: None Shelby Sumrall Shelby.Sumrall@conocophillips.com (907) 265-6678Staff Well Integrity Engineer None None 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) 169 Gas-Mcf MD 1369 Size 121' 2634 137471 203 2882535 325 measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 193-006 50-029-22330-00-00 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: ADL0025639 Kuparuk River Field/ Kuparuk River Oil Pool KRU 1H-01 Plugs Junk measured Length Production Liner 7820' Casing 6832'7859' 4766' 121'Conductor Surface Intermediate 16" 9-5/8" 79' 4808' 4244' Burst Collapse 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 8:15 am, Apr 08, 2025 Digitally signed by Shelby Sumrall DN: OU=Alaska, O=Conocophillips, CN=Shelby Sumrall, E=Shelby.Sumrall@conocophillips.com Reason: I am the author of this document Location: Anchorage Alaska Date: 2025.04.07 15:51:48-08'00' Foxit PDF Editor Version: 13.1.6 Shelby Sumrall RBDMS JSB 041025 DSR-4/11/25JJL 5/8/25 DTTMSTART JOBTYP SUMMARYOPS 3/9/2025 ACQUIRE DATA DRIFT TBG w/ 2.72" x 30' PATCH DRIFT TO 7200' RKB. SET 2.72" P2P LOWER PATCH PACKER MID-ELEMENT @ 7123' RKB (SN: CPP35324 OAL= 4.01'). OBTAIN PASSING CMIT-TxIA TO 2500 PSI. SET 2.72" P2P, SPACER PIPE & ANCHOR LATCH PATCH ASSEMBLY (OAL= 34.88' SN: CPP35326). TOP OF UPPER PACKER @ 7086' RKB (MID-ELEMENT 7089' RKB). JOB IN PROGRESS. 3/10/2025 ACQUIRE DATA SET 3.5" TTS TEST TOOL IN UPPER PATCH. ABLE TO PRESSURE TBG TO 2500 PSI BUT PRESSURE DROPS OFF SLOWLY AND IA BEGINS TO CLIMB. SET STUBBY HOLE FINDER ON TOP OF TTS TEST TOOL AND GET PASSING MIT-T TO 2500 PSI, INDICATING HOLE IN TBG BETWEEN UPPER PACKER AND HOLE FINDER (6' FROM UPPER PACKER TO HOLE FINDER ELEMENT). PULL DUMMY VALVE f/ STA # 3 @ 5159' RKB. SET NEW 1" x 1/4" OV ON BK LATCH @ SAME. PULLED TTS TEST TOOL. SET 2.72" P2P UPR PKR MID-ELEMENT AT 7072.69' RKB w/ SPACER PIPE & ANCHOR LATCH (OAL= 16.27' SN: CPP35118). JOB IN PROGRESS. 3/11/2025 ACQUIRE DATA SET TTS TEST TOOL IN UPPER PKR @ 7068' RKB. ACHIEVED PASSING MITT & CMIT T x IA TO 2500 PSI. JOB COMPLETE. 1H-01 Tubing Patch Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 7,664.0 1H-01 3/8/2025 bworthi1 Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Patch and OV 1H-01 3/10/2025 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: Station # 4 & 5 valves difficult to pull. Latch damage? fergusp NOTE: Mandrel @ 7099 - Apparent junk on latch @ 7099 RKB or latch missing 4/16/01. 9/22/2010 ninam NOTE: View Schematic w/ Alaska Schematic9.0 9/22/2010 ninam 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 42.0 121.0 121.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 41.5 4,807.9 4,244.4 36.00 J-55 BTC PRODUCTION 7 6.28 39.3 7,859.0 6,831.7 26.00 K-55 BTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 38.0 Set Depth … 7,552.0 Set Depth … 6,566.5 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 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) 38.0 38.0 0.28 HANGER 8.000 FMC GEN IV HANGER 3.500 473.5 473.3 3.49 NIPPLE 4.562 CAMCO DS NIPPLE 2.875 2,860.0 2,593.6 32.82 GAS LIFT 5.390 CAMCO KBMM 2.920 4,386.5 3,885.0 31.05 GAS LIFT 5.390 CAMCO KBMM 2.920 5,159.1 4,544.4 33.36 GAS LIFT 5.390 CAMCO KBMM 2.920 5,837.7 5,111.4 33.71 GAS LIFT 5.390 CAMCO KBMM 2.920 6,485.0 5,651.7 32.52 GAS LIFT 5.390 CAMCO KBMM 2.920 7,098.8 6,176.3 30.97 GAS LIFT 5.968 CAMCO MMG 2.920 7,152.3 6,222.1 30.72 PBR 5.000 BAKER PBR w/ 5.875 GUIDE 3.000 7,165.9 6,233.9 30.68 PACKER 5.937 BAKER FHL PACKER 2.937 7,211.9 6,273.5 30.60 PRODUCTION 5.968 CAMCO MMG 2.920 7,288.0 6,339.0 30.55 BLAST RINGS 4.500 BLAST RINGS (6) 2.992 7,516.1 6,535.5 30.55 SLEEVE-O 4.000 BAKER 3.5" CMU SLIDING SLEEVE w/ CAMCO DS PROFILE - OPEN 6/14/2009 2.813 7,526.0 6,544.1 30.54 NIPPLE 4.500 BAKER NO GO NIPPLE 4.187 7,527.8 6,545.7 30.53 SEAL ASSY 4.000 BAKER SEAL ASSEMBLY - STUNG IN 6' 3.000 7,528.8 6,546.5 30.53 PACKER 5.872 BAKER 3.5" x 5.872" FB-1 PACKER 2.992 7,532.2 6,549.4 30.53 MILLOUT 5.000 BAKER MILL OUT EXTENSION 4.000 7,544.1 6,559.7 30.53 NIPPLE 4.250 OTIS XN 3.5" NIPPLE, 2.813 x 2.75 NO GO 2.750 7,551.5 6,566.0 30.54 WLEG 4.500 BAKER 3.5" WIRELINE ENTRY GUIDE 3.000 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) 7,070.2 6,151.8 31.10 PACKER - PATCH - UPR 3-1/2" UPR P2P PATCH PKR MID-ELEMENT AT 7070' RKB W/ SPACER PIPE AND ANCHOR LATCH, OAL 16.27' TTS P2P CPP3 5118/ CPAL 35168 3/10/2025 1.625 7,074.3 6,155.3 31.09 SPACER PIPE 2-1/16" P-110 SPACER PIPE 3/10/2025 1.580 7,086.5 6,165.7 31.04 PACKER - PATCH - UPR 3-1/2" UPR P2P PATCH PKR MID-ELEMENT AT 7089' RKB W/ SPACER PIPE AND ANCHOR LATCH, OAL 34.04' TTS P2P CPP3 5326/ CPAL 35196 3/9/2025 1.625 7,090.6 6,169.2 31.02 SPACER PIPE 2-1/16" P-110 SPACER PIPE 3/9/2025 1.580 7,092.0 6,170.4 31.01 LEAK - TUBING TBG Leak found with E-line 7/14/2014 2.992 7,110.0 6,185.8 30.91 LEAK LEAK IDENTIFIED VIA LDL AT 7110' RKB 2/28/2025 2.992 7,120.6 6,194.9 30.86 PACKER - PATCH - LWR 3-1/2" LWR P2P PATCH PKR MID-ELEMENT AT 7123' RKB, OAL 4.01' TTS P2P CPP3 5324 3/9/2025 1.625 7,166.0 6,234.0 30.68 FISH GR PIN RETAINER RING LOST IN HOLE 9/6/2002 0.000 7,800.0 6,780.6 30.04 FISH DROPPED BK LATCH 7/10/2009 0.000 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) 2,860.0 2,593.6 32.82 1 GAS LIFT GLV BK 1 1,208.0 2/14/2010 0.125 4,386.5 3,885.0 31.05 2 GAS LIFT GLV BK-5 1 1,279.0 2/14/2010 0.188 5,159.1 4,544.4 33.36 3 GAS LIFT OV BK 1 3/10/2025 0.250 5,837.7 5,111.4 33.71 4 GAS LIFT DMY BK-5 1 0.0 2/27/2001 0.000 6,485.0 5,651.7 32.52 5 GAS LIFT DMY BK 1 0.0 4/20/2008 0.000 1H-01, 4/7/2025 1:02:33 PM Vertical schematic (actual) PRODUCTION; 39.3-7,859.0 FISH; 7,800.0 APERF; 7,672.0-7,684.0 A-SAND FRAC; 7,648.0 APERF; 7,648.0-7,684.0 RPERF; 7,648.0-7,672.0 PACKER; 7,528.8 APERF; 7,438.0-7,466.0 CEMENT SQUEEZE; 7,300.0 ftKB IPERF; 7,304.0-7,394.0 PRODUCTION; 7,211.9 PACKER; 7,165.9 FISH; 7,166.0 PACKER - PATCH - LWR; 7,120.6 LEAK; 7,110.0 SPACER PIPE; 7,090.6 GAS LIFT; 7,098.8 LEAK - TUBING; 7,092.0 PACKER - PATCH - UPR; 7,086.5 SPACER PIPE; 7,074.3 CEMENT SQUEEZE; 6,916.0 ftKB PACKER - PATCH - UPR; 7,070.2 C-SAND FRAC; 6,970.0 GAS LIFT; 6,485.0 GAS LIFT; 5,837.7 GAS LIFT; 5,159.1 SURFACE; 41.5-4,807.9 GAS LIFT; 4,386.6 GAS LIFT; 2,860.0 NIPPLE; 473.5 CONDUCTOR; 42.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/30/1993 Other Elev… 1H-01 ... TD Act Btm (ftKB) 7,880.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292233000 Wellbore Status PROD Max Angle & MD Incl (°) 34.29 MD (ftKB) 6,000.00 WELLNAME WELLBORE1H-01 Annotation Last WO: End Date 2/27/2001 H2S (ppm) 12 Date 1/25/2019 Comment SSSV: NIPPLE 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) 7,098.8 6,176.3 30.97 6 GAS LIFT DMY RKP 1 1/2 0.0 2/27/2001 Latch Broke off? 0.000 7,211.9 6,273.5 30.60 7 PROD DMY RK 1 1/2 0.0 3/12/2001 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,304.0 7,394.0 6,352.7 6,430.4 C-4, C-3, 1H-01 6/6/1993 4.0 IPERF 7,438.0 7,466.0 6,468.3 6,492.4 C-1, UNIT B, 1H- 01 8/30/1997 4.0 APERF 7,648.0 7,684.0 6,649.2 6,680.2 A-4, 1H-01 8/30/1997 4.0 APERF 7,648.0 7,672.0 6,649.2 6,669.8 A-4, 1H-01 9/3/2006 6.0 RPERF 2.5" PJ 2506 - Pure 7,672.0 7,684.0 6,669.8 6,680.2 A-4, 1H-01 8/30/1997 6.0 APERF Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 7,648.0 7,684.0 1 A-SAND FRAC 4/14/2001 0.0 0.00 0.00 6,970.0 7,124.0 1 C-SAND FRAC 10/26/2006 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,300.0 7,466.0 6,349.3 6,492.4 CEMENT SQUEEZE Cement (82 bbls Glass G w/ Aggregate); Cleaned Out Cement down to 7494' 6,916.0 7,230.0 6,019.8 6,289.0 CEMENT SQUEEZE C-sands squeezed with 12 BBLS of 15.8 PPG LARC with API FL of 72 ML. FCT= .88(inch). MAX achieved squeeze pressure = 2,350 PSI with wellbore full of sea water. 7" casing flushed to hard tag at 7,246.7' CTMD. 1H-01, 4/7/2025 1:02:34 PM Vertical schematic (actual) PRODUCTION; 39.3-7,859.0 FISH; 7,800.0 APERF; 7,672.0-7,684.0 A-SAND FRAC; 7,648.0 APERF; 7,648.0-7,684.0 RPERF; 7,648.0-7,672.0 PACKER; 7,528.8 APERF; 7,438.0-7,466.0 CEMENT SQUEEZE; 7,300.0 ftKB IPERF; 7,304.0-7,394.0 PRODUCTION; 7,211.9 PACKER; 7,165.9 FISH; 7,166.0 PACKER - PATCH - LWR; 7,120.6 LEAK; 7,110.0 SPACER PIPE; 7,090.6 GAS LIFT; 7,098.8 LEAK - TUBING; 7,092.0 PACKER - PATCH - UPR; 7,086.5 SPACER PIPE; 7,074.3 CEMENT SQUEEZE; 6,916.0 ftKB PACKER - PATCH - UPR; 7,070.2 C-SAND FRAC; 6,970.0 GAS LIFT; 6,485.0 GAS LIFT; 5,837.7 GAS LIFT; 5,159.1 SURFACE; 41.5-4,807.9 GAS LIFT; 4,386.6 GAS LIFT; 2,860.0 NIPPLE; 473.5 CONDUCTOR; 42.0-121.0 KUP PROD 1H-01 ... WELLNAME WELLBORE1H-01 ORIGINATED TRANSMITTAL DATE: 3/4/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk River PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 3520 1H-01 50029223300000 Leak Detection Log 28-Feb-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 193-006 T40183 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.03.05 10:29:16 -09'00' 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 AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Originated: Delivered to:19-Feb-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 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 1A-20 50-029-22112-00 909816966 Kuparuk River Leak Detect Log Field- Final 23-Jan-25 0 12 1A-20 50-029-22112-00 909816966 Kuparuk River Multi Finger Caliper Field & Processed 22-Jan-25 0 13 1A-20 50-029-22112-00 909816966 Kuparuk River Plug Setting Record Field- Final 22-Jan-25 0 14 1D-38 50-029-22961-00 909594223 Kuparuk River Multi Finger Caliper Field & Processed 16-Jan-25 0 15 1E-17 50-029-20793-00 909817737 Kuparuk River Plug Setting Record Field- Final 4-Feb-25 0 16 1E-22 50-029-20884-00 909817740 Kuparuk River Multi Finger Caliper Field & Processed 2-Feb-25 0 17 1E-22 50-029-20884-00 909817740 Kuparuk River Plug Setting Record Field- Final 3-Feb-25 0 18 1H-01 50-029-22330-00 909817089 Kuparuk River Multi Finger Caliper Field & Processed 7-Feb-25 0 19 1H-01 50-029-22330-00 909817089 Kuparuk River Plug Setting Record Field- Final 7-Feb-25 0 110 1H-110 50-029-23601-00 909817451 Kuparuk River Plug Setting Record Field- Final 24-Jan-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:T40111T40111T40111T40112T40113T40114T40114T40115T40115T40116190-162200-077182-116182-214193-006218-0312/20/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.02.20 11:39:57 -09'00'1H-0150-029-22330-00 909817089Kuparuk RiverMulti Finger CaliperField & Processed7-Feb-250191H-0150-029-22330-00 909817089Kuparuk RiverPlug Setting RecordField- Final7-Feb-2501T40115T40115193-006 Originated: Delivered to:9ͲOctͲ24Halliburton Alaska Oil and Gas Conservation Comm.Wireline & PerforatingAttn.:Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska99501Anchorage, Alaska 99518Office: 907Ͳ275Ͳ2605FRS_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#11AͲ08 50Ͳ029Ͳ20313Ͳ00 909572342 Kuparuk River Leak Detect Log with ACXField & Processed 13ͲSepͲ24 0 121BͲ20 50Ͳ029Ͳ23164Ͳ00 909462416 Kuparuk River Multi Finger CaliperField & Processed 15ͲAugͲ24 0 131CͲ24 50Ͳ029Ͳ23063Ͳ00 n/a Kuparuk River Leak Detect Log FieldͲFinal 25ͲAugͲ24 0 141CͲ24 50Ͳ029Ͳ23063Ͳ00 n/a Kuparuk River Multi Finger CaliperField & Processed 25ͲAugͲ24 0 151CͲ24 50Ͳ029Ͳ23063Ͳ00 ALSL764Ͳ002 Kuparuk River Packer Setting Record FieldͲFinal 15ͲSepͲ24 0 161DͲ32 50Ͳ029Ͳ22982Ͳ00 909582494 Kuparuk River Multi Finger CaliperField & Processed 6ͲSepͲ24 0 171EͲ29 50Ͳ029Ͳ20828Ͳ00 909524908 Kuparuk River Leak Detect Log FieldͲFinal 8ͲSepͲ24 0 181EͲ29 50Ͳ029Ͳ20828Ͳ00 909524908 Kuparuk River Packer Setting Record FieldͲFinal 7ͲSepͲ24 0 191HͲ01 50Ͳ029Ͳ22330Ͳ00 909524903 Kuparuk River Multi Finger CaliperField & Processed 29ͲAugͲ24 0 110 1HͲ01 50Ͳ029Ͳ22330Ͳ00 909593144 Kuparuk River Plug Setting Record FieldͲFinal 23ͲSepͲ24 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:T39678T39679T39680T39680T39680T39681T39682T39682T39683T39683178-040203-115201-248200-173182-154193-00610/21/2024Gavin GluyasDigitally signed by Gavin Gluyas Date: 2024.10.21 10:33:37 -08'00'1HͲ0150Ͳ029Ͳ22330Ͳ00909524903KuparukRiverMultiFingerCaliperField&Processed29ͲAugͲ2401101HͲ0150Ͳ029Ͳ22330Ͳ00909593144KuparukRiverPlugSettingRecordFieldͲFinal23ͲSepͲ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igitally signed by Roger Mouser DN: O=Conocophillips, CN=Roger Mouser, E=N1927@conocophilllips.com Reason: I am the author of this document Location: your signing location here Date: 2021.09.11 16:46:15-08'00' Foxit PDF Editor Version: 11.0.0 Roger Mouser By Meredith Guhl at 8:20 am, Sep 13, 2021 RBDMS HEW 9/13/2021 DSR-9/13/21VTL 01/24/2022 Digitally signed by Roger Mouser DN: O=Conocophillips, CN=Roger Mouser, E=N1927@conocophilllips.com Reason: I am the author of this document Location: your signing location here Date: 2021.09.11 16:45:09-08'00' Foxit PDF Editor Version: 11.0.0 Roger Mouser !"##$% !&'(!$)*+ ,++-%$ %(!' .%$ . (& %(!". !/0 10 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 7880' Casing Collapse Conductor Surface Production Packers and SSSV Type:PKR:Packers and SSSV MD (ft) and TVD (ft):PKR: 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date:7/4/2021 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Well Integrity Field Supervisor Roger Mouser / Roger Winter n1927@conocophillips.com 7116' MD 6191' TVD / 7166' MD 6234' TVD / 7529' MD 6547' TVDWeatherford Lower (patch) / Baker FHL / Baker FB-1 7552' 4808' 7820 121'121' 7859 79'16" 9 5/8" 7" 4766'4244' 6832 PRESENT WELL CONDITION SUMMARY Length TVD BurstMD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025639 193-006 P.O. Box 100630, Anchorage, Alaska 99508 5002922330-0000 ConocoPhillips Alaska, Inc. Kuparuk River Unit 1H-01 Kuparuk River / Kuparuk River Oil COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): 6353' - 6680' Perforation Depth TVD (ft):Tubing Size: 7304' - 7684' Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 659-7506 Weatherford Upper ER (patch) 7086' MD 6165' TVD / Size Authorized Signature: 7/20/2021 3 1/2" Perforation Depth MD (ft): L-80 6850' m n P s 66 t y t _ c Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 7:51 am, Jul 06, 2021 321-336 Digitally signed by Roger Winter DN: CN=Roger Winter, E=n1927@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2021.07.04 13:38:28-08'00' Foxit PhantomPDF Version: 10.1.3 Roger Winter SFD X ext conductor Photo document pre and post extension VTL 7/14/21 SFD 7/6/2021 X 10-404 DSR-7/6/21 50-029-22330-00-00 SFD 7/6/2021 JLC 7/14/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.14 12:42:55 -08'00' RBDMS HEW 7/14/2021 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 04 July 2021 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KUP 1H-01 (PTD 193-006) to extend conductor. Summary: Conductor has subsided or well has grown 11” or more so we would like to add conductor to cover the surface casing. Please contact Roger Winter or Roger Mouser at 659-7506 if you have any questions. Sincerely, Roger Winter Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Digitally signed by Roger Winter DN: CN=Roger Winter, E=n1927@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2021.07.04 13:38:08-08'00' Foxit PhantomPDF Version: 10.1.3 Roger Winter Conductor has subsided or well has grown 11” or more Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 42.0 Set Depth (ftKB) 121.0 Set Depth (TVD) … 121.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 41.5 Set Depth (ftKB) 4,807.9 Set Depth (TVD) … 4,244.4 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 39.3 Set Depth (ftKB) 7,859.0 Set Depth (TVD) … 6,831.7 Wt/Len (l… 26.00 Grade K-55 Top Thread BTC-MOD Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 38.0 Set Depth (ft… 7,552.0 Set Depth (TVD) (… 6,566.5 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 38.0 38.0 0.28 HANGER FMC GEN IV HANGER 3.500 473.5 473.3 3.49 NIPPLE CAMCO DS NIPPLE 2.875 7,152.3 6,222.1 30.72 PBR BAKER PBR w/ 5.875 GUIDE 3.000 7,165.9 6,233.9 30.68 PACKER BAKER FHL PACKER 2.937 7,288.0 6,339.0 30.55 BLAST RINGS BLAST RINGS (6) 2.992 7,516.1 6,535.5 30.55 SLEEVE-O BAKER 3.5" CMU SLIDING SLEEVE w/ CAMCO DS PROFILE - OPEN 6/14/2009 2.813 7,526.0 6,544.1 30.54 NIPPLE BAKER NO GO NIPPLE 4.187 7,527.8 6,545.7 30.53 SEAL ASSY BAKER SEAL ASSEMBLY - STUNG IN 6' 3.000 7,528.8 6,546.5 30.53 PACKER BAKER 3.5" x 5.872" FB-1 PACKER 2.992 7,532.2 6,549.4 30.53 MILLOUT BAKER MILL OUT EXTENSION 4.000 7,544.1 6,559.7 30.53 NIPPLE OTIS XN 3.5" NIPPLE, 2.813 x 2.75 NO GO 2.750 7,551.5 6,566.0 30.54 WLEG BAKER 3.5" WIRELINE ENTRY GUIDE 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 7,086.0 6,165.3 31.04 PACKER WEATHERFORD UPPER ER PACKER 10/3/2009 1.750 7,087.0 6,166.1 31.04 PATCH PATCH = SNAP LATCH ASSY, SPACER PIPE 10/3/2009 1.750 7,115.8 6,190.8 30.88 PACKER WEATHERFORD LOWERER PACKER (2.74" RUNNING OD), TOP OF JJ TIE BACK RECEPTACLE @ 7095 9/29/2009 1.750 7,166.0 6,234.0 30.68 FISH FISH GR PIN RETAINER RING LOST IN HOLE 9/6/2002 9/6/2002 0.000 7,800.0 6,780.6 30.04 FISH DROPPED BK LATCH 7/10/2009 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,304.0 7,394.0 6,352.7 6,430.4 C-4, C-3, 1H-01 6/6/1993 4.0 IPERF 7,438.0 7,466.0 6,468.3 6,492.4 C-1, UNIT B, 1H -01 8/30/1997 4.0 APERF 7,648.0 7,684.0 6,649.2 6,680.2 A-4, 1H-01 8/30/1997 4.0 APERF 7,648.0 7,672.0 6,649.2 6,669.8 A-4, 1H-01 9/3/2006 6.0 RPERF 2.5" PJ 2506 - Pure 7,672.0 7,684.0 6,669.8 6,680.2 A-4, 1H-01 8/30/1997 6.0 APERF Frac Summary Start Date 4/14/2001 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 4/14/2001 Top Depth (ftKB) 7,648.0 Btm (ftKB) 7,684.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Start Date 10/26/2006 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 10/26/2006 Top Depth (ftKB) 6,970.0 Btm (ftKB) 7,124.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Start Date Com 7,300.0 7,466.0 6,349.3 6,492.4 CMT SQZ 8/30/1997 6,916.0 7,230.0 6,019.8 6,289.0 CMT SQZ 10/14/200 6 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,860.0 2,593.6 CAMCO KBMM 1 GAS LIFT GLV BK 0.125 1,208.0 2/14/2010 2 4,386.5 3,885.0 CAMCO KBMM 1 GAS LIFT GLV BK-5 0.188 1,279.0 2/14/2010 3 5,159.1 4,544.4 CAMCO KBMM 1 GAS LIFT OV BK-5 0.250 0.0 2/14/2010 4 5,837.7 5,111.4 CAMCO KBMM 1 GAS LIFT DMY BK-5 0.000 0.0 2/27/2001 5 6,485.0 5,651.7 CAMCO KBMM 1 GAS LIFT DMY BK 0.000 0.0 4/20/2008 6 7,098.8 6,176.3 CAMCO MMG 1 1/2 GAS LIFT DMY RKP 0.000 0.0 2/27/2001 7 7,211.9 6,273.5 CAMCO MMG 1 1/2 PROD DMY RK 0.000 0.0 3/12/2001 Notes: General & Safety End Date Annotation 9/22/2010 NOTE: View Schematic w/ Alaska Schematic9.0 9/22/2010 NOTE: Mandrel @ 7099 - Apparent junk on latch @ 7099 RKB or latch missing 4/16/01. Comment SSSV: NIPPLE 1H-01, 7/2/2018 11:38:07 AM Vertical schematic (actual) PRODUCTION; 39.3-7,859.0 FISH; 7,800.0 APERF; 7,672.0-7,684.0 A-SAND FRAC; 7,648.0 APERF; 7,648.0-7,684.0 RPERF; 7,648.0-7,672.0 WLEG; 7,551.5 NIPPLE; 7,544.1 MILLOUT; 7,532.2 PACKER; 7,528.8 SEAL ASSY; 7,527.8 NIPPLE; 7,526.0 SLEEVE-O; 7,516.1 APERF; 7,438.0-7,466.0 CEMENT SQUEEZE; 7,300.0 ftKB IPERF; 7,304.0-7,394.0 PRODUCTION; 7,211.9 PACKER; 7,165.9 FISH; 7,166.0 PBR; 7,152.3 PACKER; 7,115.7 GAS LIFT; 7,098.8 PATCH; 7,087.0 PACKER; 7,086.0 CEMENT SQUEEZE; 6,916.0 ftKB C-SAND FRAC; 6,970.0 GAS LIFT; 6,485.0 GAS LIFT; 5,837.7 GAS LIFT; 5,159.1 SURFACE; 41.5-4,807.9 GAS LIFT; 4,386.6 GAS LIFT; 2,860.0 NIPPLE; 473.5 CONDUCTOR; 42.0-121.0 HANGER; 38.0 Last Tag Annotation Last Tag: SLM End Date 6/26/2018 Depth (ftKB) 7,650.0 Last Mod By Jhansen8 Last Rev Reason Annotation Rev Reason: WELL REVIEW End Date 6/5/2012 Last Mod By osborl KUP PROD KB-Grd (ft) Rig Release Date 1/30/1993 Annotation Last WO: End Date 2/27/2001 1H-01 H2S (ppm) Date... TD Act Btm (ftKB) 7,880.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292233000 Wellbore Status PROD Max Angle & MD Incl (°) 34.29 MD (ftKB) 6,000.00 Wellbore Status PROD WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 5, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 1H -01 Run Date: 9/29/2009 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 1H-01 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 22330 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline Perforating 19 to Attn: Rafael Barret() U� 6900 Arctic Blvd. l 159L/4 Anchorage, Alaska 99518 Office: 907 273 -3527 Fax: 907 273 -3535 rafael.b aneto @halliburton: com Date: NOV ?Rif Signed: w ~ . • . ~~~~~ ~! ~~ STATE OF ALASKA ~ OCT ~ ~ ~QO~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATION~~~S~~Q~~&GasCons.Commission 1. Operations Performed: Abandon ^ Repair Well ^~ Plug Perforations ~ Stimulate ~ Other Se Patch Alter Casing ^ P~II Tubing ^ Perforate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, It1C. Develapment 0 Ex~bra#ory ^ 193-006 / 3. Address: Stratigraphic ^ Service ^ 6. API Numbef: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22330-00 7. KB Elev t~n (ft): 9. Wefl Name and Number: RKB 96' `~ 1 H-01 8. Property Designation: 10. Fieid;Pool{s): ADL0025639 ``~. ~ Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measure~~ 7880' feet ~ 6850' feet Plugs (measured) true vertical Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SURFACE 4712' 9-5/8" 4808' 4245' 3520 2020 PRODUCTION 7763' 7" 7859' 6832' 4980 4330 Perforation depth: Measured depth: 7304-7394, 7438-7466, 7648-7672, 7672-7684 true vertical depth: 6353-6430, 6468-6492, 6649-6670, 6670-6680 • Tubing (size, grede, and measured depth) 3-1/2", L-80, 7552' Weathertord 1.75" ID Patch from 7086' - 7118 Packers & SSSV (type & measured depth) Baker "FHL" packer at 7166' SSSV= NIPPLE SSSV= 473' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Not AppCcab/e Treatment descriptions including volumes used and final pressure: 13. Representative DailyAverage Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation PIA NA NA NA NA Subsequent to operation NA NA NA - MA NA 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ^~ Gas ^ WAG ~ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. sundry Number or wA if C.o. Exempt: Cor~act Brent Rogers/Martin Walters Printed Name Martin Walters Titie Problem Wells Supervisor Signature 1 Phone: . 659_~~~4 Date 10/10/2009 ~ ~~~2~Q~~~ ~ ~ /~. f 6 Martin Walters 659-7224 ~ / - ~ •~- I O' ~ O Form 10-404 Revised 04/2006 `~ Submi Orig~al Only , . _ _ . , ~ • • ~ 1 H-01 DESCRIPTION OF WORK COMPLETED • SUMMARY Date Event Summary 9/29/2009 COMPLETED SETTING WEATHERFORD ER PATCH PACKER. CCL OFFSET = 9.9', SET ER PATCH PAGKER MID ELEMENT 7118' 10/3/2009 CMIT TBG X IA AGAINST LOWER ER PACKER @ 7116' RKB TO 2200 PSI ( PASSED ). SET LOWER SECTION OF STADDLE PATCH ( JJ TIE BACK RECEPTICLE, SPACER PIPE, AND SNAP LATCH ASSEMBLY --22' 2" OAL & MAX OD @ 2.740 W/ MIN. ID OF 1.75 ) W/ TOP OF JJ TIE BACK @ 7095' RKB. RAN TEST TOOL AND COMBO TESTED TBG X `IA TO 2500 PSI AGAINST JJ TIE BACK ( PASSED ). SET UPPER SECTION OF STRADDLE PATCH ( ER PACKER, SPACER PIPE, AND JJ TIE BACK STINGER--9' 8" OAL W/ MAX OD 'i(c~ 2.74 W/ MIN. ID OF 1.75 ) W/ TOP OF ER PACKER @ 7086' RKB. IN PROGRESS. 10/4/2009 MIT TBG. TO 2500 PSI PASSED . MITIA TO 2500 PSI PASSED . 5ummary SET WEATHERFORD ER PATCH FROM 7086'-7118'. PERFORMED PASSING MITT AND .~ MITIA TO 2500 PSI. ~ WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detection Log: 1 H-O l Run Date: 7/14/2009 September 4, 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 1 H-Ol Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22330-00 ~ i~ ~~}~ :` __..;~ ~~.~i ~.~:~ _ .- 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 ~.~ ~ ~~ ~ ~D~ Date: - - ~~~~ ~ , ,,. ~ ~' ~ ?~J' ! ~r ~`~_ Signed: ':, j~ ~ ~ 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: 1H-O1 Run Date: 8/20/2009 August 27, 2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention o£ Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1H-O1 Digital Data in LAS format, Digital Log Image file 50-029-22330-00 1 CD Rom 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@hal~l~ib _ n , ~- ~ -,; ~~ ~~~; , ~~ Date: SEP 0 1 700~ ~~~sk~. ~ii ~ f~~s Cons. ~crramis~ic~~U ,4ncM~r~4~ kP1~i 3 ,.. ~ , ~ « . , R+.r-ar x ~... t-~ ~ ~ ~,~ : u~ ~ ~~3 - aa~ ~~~~4a Signed: • 'd ~' _ _._~..:_~ v`.~~~' .Y ~'~ }'^:t~~ca~er~ ~iaq~a~s~c ~~~e~~s, 7~c. RE : Cased Hole/Open Hoie/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) 1'a: A.OGCC ~hristine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907j 859-5102 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal (etter to the following : • ~ ~~ ~ , , ~ ~ .. 4 r ~ ~ , 8 ~~ ~ BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 ~~U ~~s0~ ~ and ~~. ~ i 9 3- c~o~ t~~/v t ProActive Diagnostic Services, {nc. ~`~ Attn: Robert A. Richey 130 West International Airport Raad , _ ~,u,. Suite C ~,~s~~~'~i',~~:r ~~iJ;r :~ _ ~~v~ Anchorage, AK 99518 Fax (907) 245-8952 1 J Caliper Report 2) Caliper report ~ Signed : ~ Print Name: 26-Ju1-09 1 L-12 1 Repart / EDE 50-029-22033-00 23-Juf-09 1 H-01 1 Report / EDE 50-029-2233t]-00 Date : - PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SURE C, ANCHORAGE, AK 99518 PHONE: (9~7~245-893i Fax: (9071245-88952 E-MAIL : ~. ~_:,:_ ~ . . e _~:_'_ ~~~~ NVEBSITE: ~ :~ ~~, . .:_. .: ~ ~ •~..d-i C.\Docutnen6 and Settings\Owne[tDesktop\Transmi[_BP docx • ~ Memory MuftirFinger Caliper ~ Log Resu~s Summary Compahy: ConocoPhillipsAlaska,lna Weli: 1H-01 Log Date: July 23, 2009 Field: Kuparuk Log No. : 6766 State: Aiaska Run Mo.: 1 API No.: 50-029-22330-00 Pipe1 Desc.: 3.5" 9.31b. L.-80 EUE-$RD Top Log Intvl1.: Surface Pipe1 Use: Tubing Bot. Log Irttvl1.: ?,202 Ft. (MD) lnspection Type : Corrosive & Mechanical Damage lnsp~ection COMM~NTS : Thfs calfper data is tied into the top of GtM 6@ 7,099' (Driller's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage. The caliper recordings indicate the 3.5" tubing logged is in good condition, with the exception of a Z6% wall penefiratian recorded at an isolated pit in joint 183 (5,810'). Other recorded damage appears as shallow corrosion. No other signific;~nt wall penetrations, areas of cross-sectionaf wall loss, or I.D. restrictions are recorded throughout the tubing logged. MAXIMUM RECORDED WALL PENETRATIONS: Isolated pitting ( 26%) Jt. 183 ~ 5,810 Ft. (MD) Na other significarrt wall penetrations (> 19%) are recorded throughout the tubing logged. MAXIMUM RECbRDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss ~> 7%) are recorded throughout the tubing logged. MAXIMURA RECORDED ID RESTRICT10NS: No significant I.D. restrictions are recorded throughout the tubing Itygged. Field Engineer: N. Kesseru Analyst: C. Waldrop Witness: C. Fifipatrick ProActive Diagnostic Services, Inc. / P.O. Box 1369, Staffard, TX 77497 Phone: {281) or {888) 565-9G85 Fax: (281) 565-1369 E-mail: PD5tCimemorylog.com Prudhoe Bay Field Office Phone: (90?} 659-2307 Fax: (907) 659-2314 u ~ ~ (,~t'v ~ OC~ ~ / ~ ~( ~ l • • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (9.9' - 7175.8') Well: 1 H-01 Field: Kuparuk Cornpany: ConocoPhillips Alaska, Inc. Country: USA Survey Date: July 23, 2009 ~ Approx. lool I~e vialion ~ A E>E~r~~~. R<>reho le Pr~~til c~ 1 1U ~ 788 ~ 1S68 2353 GLM 1 3157 ~ ~ ~ c 3943 t .. n.. v GLM 2 0 4749 GLM 3 5552 GLM 4 6358 GLM 5 GLM 6 224 7176 0 5 0 1 00 Dam age Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 224 25 50 75 100 a`, ~ E Z 125 c ' o 150 . #.. ~ =1 175',;' ~ ; 200 ~ • • PDS Report Overview 1 s. Body Region Analysis Well: 1 H-01 Survey Date: July 23, 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. Waldro Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-80 EUE-8RD 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body tir,~,s; metal loss body 250 2~~ 150 100 50 ~ 0 to 1 to 10 to 20 to 40 to over 1% 10% 20°/ ~10% 85% 85% Number of ~oints anal sed total = 240 pene. 0 138 101 1 0 0 loss 16 224 0 0 0 0 Damage Configuration ( body ) 10 0 isola~ed general line nr~ hole/poss pitting mrros~on corrosion cormaon ible hole Number of ~oints dama ed total ~ 17 8 9 0 0 0 Damage Profile (% wall) ~ penetration body .,E_~.- metal (oss body 0 50 100 1 GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 GLM 6 Bottom of Survey = 224 Analysis Overview page 2 ~ PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf L-t30 FUE-8RD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • iLATION SHEET 1H-01 Kuparuk ConocoPhil~ips Alaska, Inc. USA Jufy 23, 2b09 Joint No. Jt. Depth (Ft.) I'~~n. I 1F~sc~i (In,.) Pen. Body (Ins.) I'c~n. `~4> V1~~t~~l I uss 'ii~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 1 10 ~ l OA3 1 1 ~1 2.96 1.1 40 ~~ 0.02 7 ~' 2.97 PUP 1.2 45 ~~ 0.01 b Z 2. 1 PUP 1.3 55 ~~ 0.01 6 2 2.95 P P 2 6 i~ 0.01 ~, ' 2.96 96 (~ 0.03 I ~~ 2.94 4 127 (~ 0.02 ~) -1 2.97 5 159 U 0.02 8 ' 2.96 6 190 l~ 0.02 ~~ ~' 2.9 7 222 U 0.03 12 ~' .96 8 254 !~ 0.01 5 ' 2.96 9 285 u 0.02 t3 _' 2.96 10 316 ~ ~ 0.01 > 2.96 11 348 ~ ~ 0.02 ~ ~ 2.95 12 379 ~! OA2 2.97 13 411 t 1 0.01 t, ~ 2.96 13.1 442 u 0 U ~ ~ 2.88 Camco S-Ni le 14 u 00 5 ' 2.96 15 476 (~ 0.02 9 ~' 2.96 16 507 O 0.03 11 4 2.96 17 538 [~ 0. 1 6 ~ .94 18 569 (? 0.02 7 s 2.94 19 601 t~ 0.03 13 5 2.94 20 632 U 0.03 11 ~ 2.94 2 63 ~~ 0. ~ -1 2. 3 22 695 ~~ 0.02 ~~ E~ 2.94 23 726 u 0.02 7 2.93 24 756 (~ 0.03 1 3 0 2.94 25 788 U 0.03 1:_> i 2.94 26 819 U 0.02 ~) 2 2.94 27 850 U 0.02 ') 4 2.94 28 882 U 0.02 ~~ 3 2.95 29 913 U 0.0 I; 2.94 30 945 ~ 1 0.03 1 ~~ 2.94 31 976 U 0. 3 1~ -i 2.94 32 1007 t) 0.03 1~ 2.94 33 1039 U 0.03 11 _' 2.94 34 1069 U 0.02 ~) -1 2.94 35 1100 ~? 0.03 l i -1 2.94 36 1132 u 0.02 ~) ' 2.94 37 1162 ~~ 0.03 1"t _' 2.94 38 1193 t) 0.03 1 I 2.95 9 1225 ~~ 0.02 £s ~ 2.95 40 1256 U 0.03 1~t 2.95 41 1286 ~~ 0.03 1' 2.94 42 1316 i~ 0.03 ~12 (~ 2.94 43 1348 U OA ~) ' .94 44 1379 (1 0.04 15 5 2.94 Shallow itti 45 1411 l~ 0.02 7 .95 46 1442 U 0.02 ~~ -~ 2.94 ~Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINTTABI. Pipe: 3.5 in 9.3 ppf L-80 EUE-8RD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ~LATION SHEET 1H-01 Kuparuk ConocoPhillips Alaska, Inc. USA July 23, 2009 Joint No. Jt. Depth (Ft.) I'~~n. U~~sc~t (In~.) Pen. Body (Ins.) I'c~n. °/o ~Ic~tal I oss °~~~> Min. (.D. (Ins.) Comments Damage Profilc~ (%wall) 0 50 100 47 1473 (1 0.02 ~) ? 2.94 48 1505 (1 0.02 ~) -1 2.94 49 1536 t~ 0.04 1~ ~ 2.94 Sha low ittin . Lt. De osits. SO 1568 i~ 0.02 9 5 2.94 51 1599 ~~ 0.02 9 -t 2.95 52 1631 ~~ 0.03 I 1 - 2.95 53 1662 U 0.0 12 -t 2.93 54 1693 ~~ 0.03 10 ? 2.96 55 1725 i~ 0.02 7 ~ 2.96 56 1757 (~ 0.02 7 ' 2.96 57 1788 ~) 0.02 - ~~ 2.96 58 1819 ~ t 0.02 ~> > .96 59 1851 t~ .02 8 2.96 60 1882 ~~ 0. 1 ~ 2.96 61 1913 ~~ 0.02 <i _' 2.96 62 194 (~ 0.02 ~~ 2.96 63 1976 U 0.01 5 ~~ 2.94 64 2008 U 0.03 13 ; .96 65 2040 ~1 0.03 10 =~ 2.96 66 2070 (~ 0.03 13 ? 2. 7 67 2101 ~1 0.03 13 > .96 68 2133 n 0.02 t3 ; 2.95 69 2165 U 0.02 9 ? 2.94 70 2196 ~> 0.02 8 ~ 2.96 71 2 ~ 1 0. I 1 ; .9 72 2258 ~~ 0.02 ~) ~ 2.96 73 2290 O 0.02 9 I 2.96 74 2322 U 0.02 ~3 Z 2.96 75 2353 U 0.02 ~i Z 2.96 76 2384 u 0.01 6 ~i 2.96 77 241 i~ 0.01 5 2.96 78 2448 U 0.01 , 2.96 79 2478 ~~ 0.01 4 ' 2.95 80 2509 U 0.01 5 I 2.96 81 2 541 l 1 0.02 7 _' 2 91 82 2573 t~ 0.03 10 ~ 2.96 83 2603 c~ 0.02 7 ~' 2.94 84 2634 ~~ 0.01 6 1 2.95 85 266 u 0.02 i ' 2.95 86 2697 ~~ 0.01 5 2.96 87 2729 u 0.02 ~) I . 5 88 2760 l) 0.01 2 I 2.96 89 2792 i~ 0.03 12 a 2.95 89.1 2824 ~~ 0.02 f~ ' 2.94 PUP 89.2 2829 u 0 U i~ N A GLM 1 Latch @ 9:30 89.3 2836 t~ 0.03 1I ' 2.93 PUP 40 2842 U 0.02 ~~ ? 2.96 91 2873 ~~ 0.03 ~10 ~' 2.96 92 905 ~~ 0. 5 19 5 2.96 I olated ittin . 93 2936 0.03 11 2,96 Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 EUE-8RD Welf: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal LD.: 2.992 in Country: Survey Date: ~ ~LATION SHEET 1H-01 Kuparuk ConocoPhillips Alaska, Inc. USA ~uly 23, 2009 Joint No. )t Depth (Ft} Pc~n. II~,~F~i (li».~ Pen. gody (Ins.) Pc~n. `%, ,~1~•i.~l I~~~~ „ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 94 2~368 u 0.03 1~~ 2.96 95 3000 ~? 0.02 ts 2.96 96 3031 ~ ~ 0.02 ~) 2.96 97 306 t~ 0.03 1 1 ~_' 2.95 9 3094 ~) 0.03 11 ~ 2.96 99 3125 t~ .03 1U ? 2.95 10 157 ~~ 0.02 ~~ 2.96 101 3189 t~ 0.02 ~) s 2.96 102 3220 U 0.02 9 s 2.95 103 3252 U 0.03 11 ~' 2.95 104 3284 ~~ 0.03 1 1 ~ 2.95 105 3315 ~~ 0.03 12 ~> 2.97 106 3347 U 0.0 I3 2.96 1 7 3378 u 0.01 5 2.96 108 3410 ~~ 0.03 1 s -1 .95 109 3441 t~ 0.01 6 <' 2.95 110 3473 t~ 0.03 12 _' 2.96 111 3504 ~ ) 0.02 ~) -a 2.96 112 3535 ~~ 0.01 ~~ _' .96 113 3566 U 0.03 1 t) ~ 2.96 114 3598 t~ 0.02 % 2.95 115 3629 t) 0.02 `~ .96 116 3659 c1 0.02 ~) 2.96 117 3691 (~ 0.01 4 ' 2.96 118 37 2 ~~ 0.01 2 I 2.93 119 3754 (~ 0.02 ~) ~~ 2.96 120 3785 t) 0.01 6 2 2.96 121 3817 l~ 0.02 9 ~' 2.96 122 3849 (~ 0.02 9 ? 2.95 123 3880 c? 0.03 1, 2.94 124 3912 c~ 0.04 I 4 ~ 2.96 125 3943 ~~ 0.02 ~~ 2.95 12 3975 i~ 0.01 i> ' 2.96 127 4006 !~ 0.02 ~) ' 2.95 128 4038 U 0.02 ~i 2.93 129 4070 t) 0.03 ll) 2.95 130 4101 t) 0.03 I1 •~ .9 131 4133 U 0.02 9 ~' 2.95 132 4164 U 0.02 9 2.97 133 4195 U 0.02 ~> ; 2.96 134 4228 u 0.03 11 2.95 135 4259 U O.D2 ~) ' 2.96 136 4290 ~) 0.03 I.! 2.96 137 4321 U 0.02 ~) > 2.94 138 4353 U 0.03 12 ~4 2. 6 138.1 4385 (1 0.01 5 I 2.91 PUP 138.2 4391 U 0 U ll N A GLM 2 Latch 3:30 1383 4397 ~l 0.03 13 Z 2.92 PUP 139 4404 U 0.03 IO ! 2.96 140 443 5 ~~ 0.03 IO I 2.96 Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINT TABI, Nipe: 3.5 in 9.3 ppf L-80 EUE-8KD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.U.: 2.992 in Country: Survey Date: • ~LATION SHEET 1H-01 Kuparuk ConocoPhillips Alaska, Inc. USA July 23, 2009 Joint No. Jt. Depth (Ft.) I'c~n. I)E~Sr~t (In~.) Pen. Body (Ins.) I'c~n. °/, Mc,t.~l Ic~ss °~~~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 141 44b 7 ~~ 0.02 ~7 ? 2.95 142 4498 ~~ 0.03 11 5 2.94 143 4530 i~ 0.03 11 .95 144 4560 ~~ 0.03 1~? _' 2.94 145 4592 ~~ 0.03 I 1 .95 146 4624 ~~ 0.03 1; 2.96 147 4656 ~ ~ 0.01 !, _' 2.96 148 4686 ~~ 0.03 I 3 ~' 2.96 149 4719 ~~ 0.03 I I ' 2.95 150 4749 U 0.04 14 ' .96 Shallow ittin . 151 4782 U 0.03 13 4 2.9 152 4812 ~~ 0.03 1 i ! 2.94 153 4843 ~~ .03 1 1 <' 2.95 154 4875 ~~ 0.04 1 ~ 5 2.96 Corrosion. 155 4906 u 0.03 1 s 1 2.96 156 4936 ~~ 0.03 13 ~ 2.96 157 4966 ~~ 0.03 1 i ' 2.94 158 49 8 ~ 1 0.03 I 3 t 2.95 159 502 9 u 0.03 12 5 2.96 1 0 5061 u 0.03 13 2.96 161 509 t~ 0.03 1~~ 2.96 16 5124 ~? 0.03 11 I 296 162.1 5156 i~ 0.03 1 1 ' 2.91 PUP 162.2 5162 ~~ 0 (~ ~? N A GLM 3 Latch @ 1130 1623 5168 l1 0. 4 15 ~ 2.96 PUP Sh Ilow o r sion. 163 5174 ll 0.03 13 - 2.94 164 5205 t~ 0.03 1~ -1 2.96 165 5236 t~ 0,04 17 2.95 Isolated itti . 166 5268 ~~ 0.03 1;i -1 2.96 167 5299 ~ 1 0.04 14 ~ 2.95 Shallow corrosion. 168 5331 U 0.03 1 U 4 2.93 169 5362 ~) 0.04 14 S 2.95 Shallow corrosion. 170 394 (~ 0.03 11 ~3 2.96 171 5425 (~ 0.04 1''i ; 2.96 Shallowc,orrosion. 72 5457 li 0.04 14 -1 2.96 5hallow corrosion. 173 54E39 ~~ 0.04 I 4 -1 2.95 Shallow c.orrosion. 17~} 5520 t~ 0.03 13 ~~ 2.95 175 5552 ~~ 0.03 13 _' 2.96 176 5583 ~~ 0.03 1 3 ~ 2.92 177 5614 ~~ 0.04 17 ~l 2.94 Isolated ittin . 178 5646 ~ ~ 0.03 12 ! .93 179 5678 ~? 0.03 11 _' 2.93 180 5709 (~ 0.04 1 i ~~ 2.93 Isolated ittin . 181 5741 t ~ 0.04 I~3 -} 2.95 Shallow corrosion. 18 5772 ~? 0.04 1 5 < 2.93 Shallow co rosi n. 183 5804 ~~ 0.07 _'~~ 2.96 Isolated ittin . 183.1 5835 U 0 02 ~~ ~ 2.95 PUP 183.2 5841 U 0 l) U N A GLM 4 Latch ~ 11:3 18 .3 5847 U 0.03 1l 1 .92 PUP 184 5854 c~ 0.03 1:; ~ 2.96 ~ Penetration Body Metal Loss Body Page 4 ~ PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 EUE-SRD Well: i3ody Wail: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • i LATI O N S H EET 1H-01 Kuparuk ConocoPhillips Alaska, Inc. USA July 23, 2009 Joint No. JL Depth (Ft.) I'c~n. ~ lE~,c~~ (In..) Pen. Body (Ins.) I'c~n. % ~te~f,~l I~~~~ ~ Min. I.D. (Ins.) Comments Damage Profile (% walQ 0 50 100 185 5886 (~ 0.03 11 _' 2.97 186 5917 ~l 0.03 11 _' 2.96 187 5948 ( ~ 0.03 13 ~' .96 18 5980 t) 0.03 1 1 3 2.95 189 6012 t~ 0.02 9 ' 2.95 190 6043 U 0.03 Il) 2.96 191 6074 c~ 0.0 lt) 2.95 1 2 6107 U 0.02 f1 _' 2.95 193 6138 i 1 0.02 I 2.94 194 6169 u 0.02 ~) ~ 2.95 195 6201 U 0.0 7 ~' 2.96 196 6232 u 0.03 11 ~~ 2.95 197 6263 (~ 0.02 t3 Z 2.94 198 62 6 ~~ 0.0 i 1 2.96 199 632 7 i~ 0.02 6 ' 2.95 200 6358 !) 0.03 1 I 5 2.93 201 6390 ~~ 0.02 ~~ 1 2.94 202 6420 U 0.02 ~) ~_' 2.96 20 452 U 0.0 5 I 2.94 203.1 6486 U 0.02 ~ ' 2.89 PUP 203.2 489 u 0 U U N A GLM 5 Latch ~ 1030 2033 6496 U 0.02 ~3 ? 2.97 PUP 204 6502 U 0.0 12 5 2.93 205 6533 U 0.03 1t1 _' 2.93 206 6564 ~~ 0.04 14 292 207 6595 U 0.02 ~~ ' 2.93 20 662 i~ 0.03 1( ) ' 2.92 209 6657 t1 0.03 1; 2.92 210 6688 U 0.02 tS i 2.92 211 6718 ~) OA2 i5 2.92 212 749 ( t 0.0 t~ ~ I 2.9 213 6781 ~ ~ 0.04 I~1 -~ 2.91 214 68 3 tt 0.02 ~~ I 2.93 215 6843 t~ 0.02 ~) 5 2.92 216 6875 t1 0.02 t3 ~ .92 217 6906 ~~ 0.02 £3 2.93 218 6937 ~~ 0.03 1~~ ~1 .94 219 6968 U 0.02 ~i 2.93 220 6999 U 0.02 9 2.91 221 7030 ~~ 0.03 1:~ i 2.92 22 7061 U 0.03 11 ~ 2.91 222.1 7093 U 0.01 t> _' 2.94 PUP 2 2.2 7099 l~ 0 t) U N A CLM 6 Latch ~ 7:00 222.3 7108 l~ 0.03 1 Z ~' 2.93 PUP 223 7114 l~ 0.02 ti ~' .94 223.1 7146 ~~ 0.03 IU -1 2.93 PUP 223.2 7152 i~ 0 i~ U 3.00 Baker PBR W 5.875 Guide 223.3 7154 i ~ 0 t~ t~ N A Seal Assemb) 2 3.4 7165 ~~ 0 U ~~ .94 Bak r'FH ' Packer 224 7176 i~ 0.03 I I 2.93 ~ Penetration Body Metal Loss Body Page 5 ~ ~ i ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~U ~~ PDS Report Cross Sections Well: 1 H-01 Survey Date: )uly 23, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 218527 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA ~\'o. of Fingers: 14 Tubin : 3.5 ins 9.3 f L-80 EUE•8RD Anal st: C. Waldro Cross Section for Joint 183 at depth 5810.31 ft Tool speed = 43 Nominai ID = Z.992 Nominal OD = 3.500 Remaining wall atea = 98 °~ Tool deviation = 38 ° Finger S Penetration = 0.066 ins Isolated pitting 0.07 ins = 26% Wall Penetration HiGH SIDE = UP ~ I • Cross Sections page 1 X~a KUP ~ 1 H-01 ~OI'IOCO~l1~~Ip 5 ' 1~-ell Attributes An le 8 MD TD :~~ .. , wNw«e ~+n a e wenscaus mdP1 Iroca) 500292233000 KUPARUKRIVERUNIT PROD 3429 6.000.00 nc~ tm ~ 7.859.0 ~--~-~ Cormiail SSSV~ NIPPLE N(ppny 170 7l2/2007 A~on Las[ WO: BMOate Craryt) 2l272001 Nease 1/30l1993 ~_ ~ e~- ..- . ~ ae Amotylon Lss[ Y Dah o last Tag: SlM 7.676A 6l92009 Rev Resson: Set Plug. GLV C/O, dropped FISH knosbor 7/1312009 Casin Str s ~+e ~ 1~+1 p~) rop ~ mKSt ~+a 1~1 I~W ~e~ ros~q ~ a.a eutie *on ~ CONDUCTO t 6 16.060 0.0 127.0 121.0 62.50 Hd0 VJEIDED coNr~x~ov i: i SURPACE 9 . 0-0 4,808.0 4,244.5 36.00 J BTC-MOD PRODUCTION 7 6.151 0.0 7,959.0 6.831J 26.OD K-55 BTC-MOD Tubin Stri NIPPLE.413 ndnq oesaipaon led IMl rop (mce) ~[ MK~I ~ f~ ro~q aaae sm~y rap nra ~ TUBING 3 1 2.9 0.0 7.552.0 6,566.5 9.30 L-80 EUE-8rd Otlier I n Hole A ll Jewe l : Tubin Run 3 Relrisvab F~Sh etc. cas uFr. TaP I~sl rop (T~W ~~ Top MM 19 camme't Ru~ Date b 1~1 ? es° 473 4 28 3.49 N I PLE CAMCO "DS" NI LE Zl27/2001 2.875 2,860 2.593.5 32.82 G AS LIFT CAMCCYKBMM-2/1lDMV/8K!// Canvnent STA 1 7/i1/20D9 2.920 ~^s ~~T. s.aes 4,386 3.884.5 31.04 G AS IJ CAAACCYKBMM-?!tlDMY/&(3/ff CanrneM: STA 2 7/11I2W9 2.920 5,15 4,544.4 33.42G ASLIFT CAAACO/KBMM-2/t VBKbl2SlCammentSTA3 4Y102008 2.920 5.837 5,110. 33.71 C y1S LIFT CAMCO/KBMM-2/1lDMYBK3!// Camment STA4 2I27Y200 2.920 SURFACE. a.we 6.4SA 5.660. 32.64 G AS LIFT CAAACQ'KBMM-2/tIDMYBK/// Cmwnent: STA 5 42N2008 2.920 c~ ~i~. s ise - 7.099 6.176.4 30.97 G AS LI CAMCOIMNMd1.5lD IRKPII/ CortMr~ent: APPARENT JUNK ON LATCH ~ 7099' RKB OR LATCH MISSING 4/16/01 5TA6 21272001 2.92b , 7.152 6,221.9 .~ BAKE PB w/5.875 Caide 7/272001 3.000 7,766 6234.0 30.68 ACKER BAKER'FHL' AC 2/272001 2.938 60.5 UFT 7.166 6,234.0 30.68 F ISH FISH GR PIN RETAINER ING LOST IN HOLE 9/612002 9MJ2002 . s.e3r 7212 .273. 30.60 P RODUCTION CAMCO/MMG71.6/DMVlRK/!/ Canrtienl: STA 7 3/12I2001 2.9 0 7,516 6,535. 30.53 P LUG 7/11/2 0.000 7,516 6,535.5 30.53 S LEEVE-0 BAKER 3.5"'CMU' SLIDING SIEEVE Wl 'DS PROFILE - OPEN 6/14/2009 2/27f2001 2.813 cns uFr. 7,526 6,544.1 30.53 N IPPLE BAKER NO GO NIPPLE 2l27/2 1 4.189 6°B4 7,5 8 6,545.8 30.53 S BAKER Seal Assemdy 7J2 I2001 3.0 0 7,5 ,546.7 30.53P ACKE BAK 3.5"X5.872"FB-1'PACKER 2I27I2001 2.992 7,544 6,55 .6 30.53 N IPPLE OTIS'XN' 3.5° NIPPLE,2.813 x 2J5 NO GO 4/27/2001 2.750 asiwo runc, s aro 7.552 6,566.5 30.54 G UID BAK R 3.5° WLEG 2f27/2001 3.000 . 7,gpp 6.780.6 30.04 FI SH DROPPEDBKIA CH 7/t012009 0.000 eAS ~~~ , ose Pertora Uons 8 Sbts T Bhn iop (TVq P~BI 9bn (TW) PV~I Zo11e Da[e ~ a~s M~-• f.anNqtllt 7.304 7.394 6,352J 6.430.4 G.G3.1H-01 &6/1993 4.O IPERF 7,438 7,466 6,488.3 6.492.4 C 1 4, UNR B, H-01 Wt997 4.0 APER p~. ~ ;s, 7,648 ~, 64 6,6492 8,6802 i G7, UNIT B, H-01 &30/1987 4.0 APERF PncKea r inn ~,648 ,672 6,649.2 fi,689.8 A 4. 1H-01 9fd2006 6.0 ERF 2.5` PJ 2606 - Pure Fis".'.'a'' 7.672 7.6 4 6,669.8 6.6802 A ~4, 1H-01 &3NY997 6.0 A RF Stimuls Hons ~ Tr~ ts moouCnora uii MnTop oePW fl~al liYCBOn ~P~ p~l TopOep~ I~W 1~1 ~q~ 1~1 P~1 Da~ eonmml cEmeNr soue~c. s.s~s ia~RF. ~~_~ 39,~ npEaF, ~ asa i ass 6.970.0 7.124.0 8,066.0 6,197.9C SANDFRAC t01262006 PUMPCSANDFRAC.WlYF150kGEL708472q 16l20 CARBO PROP. PUMPED TOTAL OF 112% OF DESIGN. EXTEND 10 PPA STAGE TO 117 BBIS FROM 60. FLILSH W/10 BBLS WF-20 AND 59 DIESEL. FLUSHED TO COMPLETION, FINAL PUMPING PRESSURE 4556 PSI, ISIP- 2593 PSI (2260 PSI EST. BOTTOM HOIE PRESSURE). ~~M soueEZE, 7,648.0 7,684.0 6,649.2 6.680.2 A -SAND FRAC 4/14J2007 'A' SAND FRAC - Leh half of tree save/ rubber in tree 1,300 ~t @~Z6~ s~EevEV. ~sis T Tua~ 17w1 Blm (KK81 ~~ Rwl (~0) n StatD3e CmYnerR PLUG. ].518 s,sis.o ~,z3o.o s,ois.a s.xas.o c ~m srn,e~e iaianaos 7.300.0 7.466.0 6,%9.3 6.492.4 C ertie~t Squeeze &3W7997 NIPP~E, 15~6 SEAL. ].5~8 PACKER, ) 529 NI P ] /6 P 5 LE, GUIDE, 7 557 RPERF, 7,608-1671 PPERF, T.618-],884 h5P1JD FRAC, ] fiM18 PPERF, ] 812-7 881 FISH, /,800 PROWCTION. 1,tl19 TD. 1.859 ' 1H-O1 (PTD 1930060) Report o~ailed TIFL • Page 1 of 1 Regg, James B (DOA) . _ _ __ From: NSK Problem Well Supv [n1617@conocophillips.com] I Sent: Tuesday, June 16, 2009 4:18 PM ~~~ ~ ~~(a~ To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy (DOA sponsored) Cc: NSK Problem Well Supv Subject: 1 H-01 (PTD 1930060) Report of failed TIFL Attachments: 1 H-01 90 day TIO plot.jpg; 1 H-01 schematic.pdf Tom, Jim Kuparuk gas lifted producer 1 H-01 (PTD 1930060) failed a diagnostic TIFL on 06/15/09. The well was SI at the time of testing. The TIO prior to the test was 1050/1050/300. A leaking GLV is suspected. Slickline will troubleshoot the leak and repair if possible. Attached is a schematic and a 90 day TIO plot. Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 «1 H-01 90 day TIO plot.jpg» «1 H-01 schematic.pdf» 6/17/2009 KRU 1H-O1 PTD 193-006 6/16/2009 TIO Pressures 1400 1200 1000 800 N a 600 400 200 0 TIIlO Plot -1 H-01 ~ i ~ ~ ...............................*1...4................................................j.................f... .. '•11....~...............................y 01-Apr-09 01-May-09 Date 01-Jun-09 200 150 a E as 100 d Y O •~ V 50 0 KUP ~ 1H-01 ~~" --- _ - CC~cit~coF'ht~~j~3s ~ Welt Attributes ~ Max Angle & MD_ TD Welltmre APW WI Field Nama Well Statue Incl (°) MD (RK8) Act Btm (TRCB) ', ~ 500292233000 KUPARUK RIVER UNIT PROD 34.29 6,000.00 7,859.0 Commem H23 (ppm) Date Annotation End Date KB-Grtl (R) RIg Release Day r ~ .: _ _ I ,, SSSV: NIPPLE 170 7/2/2007 Last WO: 2/27/2001 1130/1993 - -- - I Annotation Depth (RKB) End Date Annotation Last Mod By End Date o •.'_.i Tag: SLM 7,676.0 6/92009 Rev Reason: PULL PLUG/GAUGES, OPEN Imosbor 6/15/2009 --- Caxin Strings - ~ _ _ ' Strln9 OD String ID Set Depth Sec Depth (ND) String Wt String I Casing Deaaipaon Pn) ON Top (ttKB) (RK8) (RKB) Qas/(t) Orade 3tring Top Thr it CONDUCTOR 16 15.060 0.0 121.0 121.0 62.50 H-40 WELDED CONDUCTOR, F ~ SURFACE 95/8 8.765 0.0 4,808.0 4,244.5 36.00 J-55 BTC-MOD 1z1 PRODUCTION 7 6.151 0.0 7,859.0 6,831.7 26.00 K-55 BTC-MOD NIPPLE, GAS LIFT, 2,860 GAS LIFT, 4.386 SURFACE, 4,808 GAS LIFT, 5,159 GAS LIFT, 5,837 ( s GAS LIFT, c"* 6,464 1 ~~ I C-SAND FRAC, ~ ~~ 6,970 ~. _ ~ E f GAS LIFT, F` 7,099 1~~ 1 ~~ PBR, 7,152 PACKER, 7,166 _r FISH, 7,166 -~].r W~ -~ PRODUCTION, ~:~~" - 7,212 I~~ CEMENT ~ I~ SQUEEZE, .2 6,916 5 IPERF, 7.304.7.394 ~ 1 APERF, 7,438-7,466E 1 CEMENT SQUEEZE, 7,300 C SLEEVE-0, ~,:~.;i~a 7,516 i NIPPLE, 7,526 22 SEAL, 7,528 I { PACKER, 7,529 1 ./ S NIPPLE. 7,544 L~~ GUIDE, 7.552 RPERF, „11111 7,848-7,672 APERF, 7.648-7.684 ~ ':~ A-SAND FRAC, 7,648 APERF, 7,672-7,fi84 - PRODUCTION, - 7,859 TD. 7,859 Tubin Strings -_ _ _ - __ String OD Str ng ID Set Depth ~ Set D pth (ND) Sllring Wt String Tubing De rlptlon '~. Iln) (-n) Top (RKB) (ft KB) ~ IkK61 Fs/kl Grade Str ng Top Thrd~ TUBING ~i 31/2'~ 2.992 0.0 7 5520. 1 -~_ _9.30 L 80 EUE-8rd Other_I_n Hole Ail Jewel :Tubing Run 8 Retrievable~Fish, etc.) Top Depth (ND) Top Incl Too rRKB) (RKB) I (^) Description Comment Run Date ID (in) 4 16 010 STA gCH @ 7099' RKB OR LATCH MISSING -OPEN 6/142009 ,Perforations & Slots Top (ND) Btm To (RKB) etm (ttKB) (RKB) (6 7,304 7,394 6,352.7 6, 7,438 7,466 6,468.3 6.. 7,648 7,684 6,6492 6. Stimulations & Treatments X Dens (ah... Beaem Min Top Max Btm Top Depth Depth Depth Depth (ND) (ND) (RKB( (RK8) (RKB) (RKB) Type Data Comment 6,970.0 7,124.0 6,066.0 6,197.9 C-SAND FRAC 10262006 PUMP C-SAND FRAC.W/YF150# GEL 108472# 16/20 CARGO PROP, PUMPED TOTAL OF 112% OF DESIGN, EXTEND 10 PPA STAGE TO 117 BBLS FROM 60. FLUSH W/10 BBLS WF-20 AND 59 DIESEL. FLUSHED TO COMPLETION, FINAL PUMPING PRESSURE 4556 PSI, ISIP= 2593 PSI (2260 PSI EST. BOTTOM HOLE PRESSURE). 7,648.0 7.684.0 6,649.2 6.680.2 A-SAND FRAC 4/142001 'A' SAND FRAC -Left halt of Vee saver rubber in Vee Cement Squeezes _ Top Depth (ND) _ Btm Depth (TVD) Teo fftl(B1 Btm fRKB1 (RKB) (RKB) Deseriotfon Start Data Commem ~~ ~~~~ NO. 4707 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # `~t..:~~~~~~~ .~~~ ~~ ~ 208 i~F i i „,fiV Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Log Description Date BL Color CD 05/ 15/08 C] 1 F-12 11996623 PRODUCTION PROFILE --~ / / ~ 05/01/08 1 1 3J-11 11996624 PRODUCTION PROFILE - CAL( 05/02/08 1 1 3K-102 11963094 MEM PROD PROFILE ap"~ - ~' 05/09/08 1 1 1J-152 11996632 GLS ( C 05/09/08 1 1 1 E-166 11994665 GLS / 05/11/08 1 1 1E-168 11994665 GLS 05/10/08 1 1 111-01 11996626 PRODUCTION PROFILE W/FSI / (o / 05/10/08 1 1 2X-15 11996634 PRODUCTION PROFILE W/FSI - ~ 05/12/08 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. • . Conoc6Phillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 29, 2006 ~. Tom Maunder Alaska Oil & Gas Commission 333 West 7th. Avenue, Suite 100 Anchorage, AK 99501 ôCANNED JAN 1 6 2007 Dear Nlr. Maunder: oo~ \~~.. 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 by surface casing annulus. The voids were fIrst filled with cement to a level of approximately 1.0 foot. The remaining volume of annular void respectively was coated with a corrosion inhibiter, RG2401 that was 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 top-fill operation was completed on December 16, 2006 and the sealant top was completed on December 27,2006 for IH-Pad and December 28, 2006 for ID-Pad. Schlumberger Well Services mixed 15.7 ppg Expando cement in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The 2401 sealant was pumped in a similar manner. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or MJ. Loveland at 907-659-7043, if you have any questions. Sincerely, ~-/cD~ Jerry Dethlefs ConocoPhillips Problem \-Vells Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 12/29/2006 Initial Top Cement Final Top Sealant Well Name PTD# of Cement Volume of Cement Cement Volume Sealant Feet Barrels Feet Oate Gallons Oate 1 H-01 193-006 12" na 12" na 7.4 12/27/2006 1 H-02 193-008 21'4" 2.9 14'6" 12/16/2006 na na 1 H-1 0 193-030 4' na 4' na 29 12/27/2006 1 H-11 193-036 Surface na Surface na 1 12/28/2006 1 H-12 193-044 4'8" 0.6 8" 12/16/2006 4.98 12/27/2006 1 H-13 193-049 6' 0.8 4' 12/16/2006 29 12/27/2006 1 H-14 193-052 35' 4.7 12" 12/16/2006 7.4 12/27/2006 1 H-18 193-020 14'4" 2.7 12" 12/16/2006 7.4 12/27/2006 1 H-21 193-046 4" na 4" na 2.4 12/27/2006 1 H-401 198-101 45' 4.4 18" 12/16/2006 20.1 12/27/2006 10-109 197-235 10'9" 2.1 12" 12/16/2006 10.8 12/28/2006 1 0-11 0 200-039 8'6" 1.4 10" 12/16/2006 9 12/28/2006 10-111 198-166 17'7" 3.4 25" 12/16/2006 21 12/28/2006 1 0-120 197-221 13'6" 2.9 18" 12/16/2006 16 12/28/2006 10-121 197-181 13' 2.2 20" 12/16/2006 16.2 12/28/2006 1 0-132 198-121 10' 8" 2.0 14" 12/16/2006 11 12/28/2006 1 0-133 197-206 6' 1.0 6" 12/16/2006 4.6 12/28/2006 10-136 200-046 10' 2" 2.0 10" 12/16/2006 6.4 12/28/2006 10-137 200-047 11 ' 2.00 24" 12/16/2006 13.2 12/28/2006 1 0-138 200-048 11' 7" 2.3 4'6" 12/16/2006 29.7 12/28/2006 1 0-139 200-049 11' 2" 2.2 18" 12/16/2006 9.9 12/28/2006 1 0-140 200-136 29'9" 3.4 12" 12/16/2006 na na . . Howard Gober Wells Group Engineer Drilling & Wells Cono~illips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4220 September 11 , 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 RECEIVED SEP 1 5 LOUO Alaska Oil & Gas Cons. Commission Anchorage Subject: Report of Sundry Well Operations for 1 H-01 (APD # 193-006) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforation operation on the Kuparuk well 1 H-01. If you have any questions regarding this matter, please contact me at 263-4220. Sincerely, ~ t"p ÄIUil.í£::- U~f'&JIt'~1(¡O"n S'E' PJ €'J. 0 20Jnt::, 61 ~l . ,'-v H. Gober Wells Group Engineer CPAI Drilling and Wells HG/skad . RECE'\IED ALASKA OIL AND GAS CONSERVATION COMMISSION ~ REPORT OF SUNDRY WELL OPERATIONS STATE OF ALASKA .' SEP 1 8 ¡ûli6 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 k &~h~r, . ('[;)' ."r¡m;$SÎon Alter Casing 0 0 Alas a i. Ii <;11 U8f¡ "\).,, ¡".~" ..<I Pull Tubing Perforate New Pool 0 Waiver 0 Time ExteAweno,~e Change Approved Program 0 Operat. ShutdownD Perforate 0 . Re-enter Suspended Well 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 193-006 1 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22330-00 . 7. KB Elevation (ft): 9. Well Name and Number: RKB 96' 1 H-01 8. Property Designatjon: 10. Field/Pool(s): ADL 25639, ALK 464 Kuparuk River Field 1 Kuparuk Oil Pool , 11. Present Well Condition Summary: Total Depth measured 7880' feet true vertical 6850' . feet Plugs (measured) Effective Depth measured 7689' feet Junk (measured) 7166' true vertical 6685' feet Casing Length Size MD rvD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SURFACE 4712' 9-5/8" 4808' 4245' PRODUCTION 7763' 7" 7859' 6832' Perforation depth: Measured depth: 7304'-7394', 7438'-7466', 7648'-7684' true vertical depth: 6353'-6430',6468'-6492',6649'-6680' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 7552' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'FHL' PKR; BAKER 3.5" X 5.872" 'FB-1' pkr= 7166'; 7529' Cameo 'OS' nipple @ 473' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable 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 55 421 224 -- 204 Subsequent to operation 82 415 129 -- 193 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 GlNJ 0 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 Howard Gober @ 263-4220 Printed Name Howard Gober Title Wells Group Engineer '1 ~ . Signature ~ Phone Date IS¡~" PrenarPrl hv Sh"rD All ak'" 263-4612 ~I Þ 'I. ZO·O(.. Form 10-404 Revised 04/2004 RBDMS 8FL SEP 2 8 2006 ;;>C,.. SUbmit~~~ 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc, 3. Address: p, O. Box 100360, Anchora e, Alaska 99510 7. KB Elevation (ft): RKB 96' ~~o .(}7 9' f .' ~Q( Measured depth: 7304'-7394'~~~\7 6',7648'-7684' true vertical depth: 6353'-6430', ~6 -6492',6649'-6680' 8. Property Designation: ADL 25639; ALK 464 11. Present Well Condition Summary: Total Depth measured true vertical Effective Depth measured true vertical Casing Structural CONDUCTOR SURFACE PRODUCTION Length 80' 4712' 7763' Perforation depth: Tubing (size, grade, and measured depth) t< t:'l'; t:: I V t:: u . . SEP 1 5 2006 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons. REPORT OF SUNDRY WELL OPERATIONS ission Repair Well 0 Pull Tubing 0 Operat. ShutdownD Stimulate 0 Waiver 0 Plug Perforations 0 Perforate New Pool 0 Perforate 0. 4. Current Well Status: Development 0 Stratigraphic 0 Other Re-enter Suspended 5. Pe it to Drill Number: 193-006 1 . API Number: 50-029-22330-00 . Exploratory 0 o Service 1 H-01 . 10. FieldlP (s): Kuparuk iver Field 1 Kuparuk Oil Pool . 7880' feet 6850' feet 7689' feet 6685' feet Size 16" Junk (measured) 7166' Collapse rvD Burst 121' 4245' 6832' 9-5/8" 7" Packers & SSSV (type & measured depth) pkr= BA R 'FHL' PKR; BAKER 3.5" X 5.872" 'FB-1' pkr= 7166'; 7529' Cam 'DS' nipple @ 473' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable es used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 55 421 224 204 Subsequent to operatio 82 415 129 193 14. Attachments 15. Well Class after proposed work: Copies of Logs a Exploratory 0 Development 0" Service 0 16. Well Status after proposed work: Oi10. Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 rtify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Howard Gober @ 263-4220 Howard Gober Sign / /' Title Phone Wells Group Engineer Date Pre Sharon AlIsu -Drak 263-4612 Form 10-404 Revised 04/2004 0 RIG I N A L ~ 'fdr. ~ Submit Original Only . ConocoPhillips Alaska, Inc. . KRU "H-01 1 H-01 API: 500292233000 Well Type: PROD Angle (â) TS: 30 deg (â) 7303 TUBING SSSV Type: NIPPLE Orig 1/30/1993 Angle @ TD: 30 deg @ 7880 (0-7552, OD:3.500, Completion: ID:2.992) Annular Fluid: Last W/O: 2/27/2001 Rev Reason: TAG FILL, CLOSE SLEEVE Reference Ref Log Date: Last Update: 7/8/2006 Loa: Last Tag: 7689 TD: 7880 ftKB Last Tag 6/29/2006 Max Hole 34 deg @ 6000 Date: AnQle: Casino Strino - All Strinas Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16,000 0 121 121 62,50 H-40 WELDED SURFACE 9.625 0 4808 4245 36,00 J-55 BTC-MOD PRODUCTION 7.000 0 7859 6832 26,00 K-55 BTC-MOD Tubina Strlna - TUBING Size Top I Bottom I TVD I Wt I Grade I Thread 3.500 0 I 7552 I 6566 I 9.30 I L-80 I EUE-8rd Perforations SUmmarv Interval TVD Zone Status Ft SPF Date Tvpe Comment 7304 - 7394 6353 - 6430 C-4,C-3 90 0 B/30/1997 7438 - 7466 6468 - 6492 C-1,UNIT 28 0 B/30/1997 B 7648 - 7684 6649 - 6680 A-4 36 4 B/30/1997 IPERF Stimulations & Treatments Interval Date Tvpe Comment 7300 - 7466 8/30/1997 CEMENT Cement (82 bbls Glass G w/ Aggregate); Cleaned SQUEEZE Out Cement down to 7494' 7648 - 7684 4/14/2001 FRAC 'A' SAN D FRAC - Left half of tree saver rubber in tree Gas Lift MandrelsNalves St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt 1 2860 2594 Cameo KBMM-2 GLV 1.0 BK 0,125 1241 8/6/2002 2 4386 3884 Cameo KBMM-2 DMY 1.0 BK-5 0.000 0 /27/2001 3 5159 4544 Cameo KBMM-2 GLV 1.0 BK-5 0.156 1270 8/6/2002 4 5837 5111 Camco KBMM-2 DMY 1.0 BK-5 0.000 0 /27/2001 5 6484 5651 Camco KBMM-2 OV 1.0 BK 0.188 0 8/6/2002 6 7099 6176 Camco MMG DMY 1.5 RKP 0.000 0 /27/2001 (1 ) Perf 1. Apparent junk on latch @ 7099' RKB or latch missing 4116/01 (7304-7394) Production MandrelsNalves St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv CEMENT Mfr Run Cmnt SQUEEZE 7 7212 6274 CAMCO MMG CAMCO DMY 1.5 RK 0.000 0 /12/2001 (7300-7466) Other (I luos eoui D., etc,) - COMPLETION Depth TVD Tvpe DescriDtion ID 473 473 NIP CAMCO "DS" nipple 3.5" x 2.875" 2.875 7152 6222 PBR BAKER PBR w/5 .875 Guide 3.000 7166 6234 PKR BAKER 'FHL' PACKER 2.938 7516 6535 SLEEVE-C BAKER 3.5" 'CMU' SLIDING SLEEVE W/CAMCO 'DS' PROFILE - 2.813 CLOSED 6/29/2006 7526 6544 NIP BAKER NO GO NIPPLE 4.188 7528 6546 SEAL BAKER Seal Assembly 3.000 7529 6547 PKR BAKER 3.5" X 5.872" 'FB-1' PACKER 2.992 7544 6560 NIP OTIS 'XN' 3.5" NIPPLE,2.813 x 2.75 NO GO 2.750 7552 6566 GUIDE BAKER 3.5" WLEG 3.000 PKR Fish - FISH (7529-7530, DeDth I Description I Comment OD:5.872) 7166 I FISH I GR PIN RETAINER RING LOST IN HOLE 9/6/2002 FRAC 4= ~ (7648-7684) ~ ~ . 1 H-01 Well Events Summary . DATE Summaryops 8/10/06 DRIFT TUBING WITH 18' X 2.65". TAG @ 7695' RKB, EST. 11' OF RATHOLE. 9/3/06 PERFORATIONS: 2 1/2" PJ2506 / PURE PERFO. PERFS: 7648 - 7660 FT, 7660 - 7672 FT. GUN STRING STICKING IN TUBING TAIL AROUND D-NIPPLE. LRS ON LOCATION TO AID IN FREEING UP GUNS TO RIH. WORK GUNS THROUGH ON FIRST RUN. 9/5/06 FISH E-LlNE TOOLSTRING (PERF GUNS) FROM 7490' SLM. RDMO, JOB - COMPLETE. ') ConocriP'hillips ) Mike Mooney Wells Group Team Leader Drilling & Wells Iq3-l91J~ P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 October 22,2004 RECEIVED OCT 2 6 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Alaska Oil & Gas Cons. Commission Subject: Report of Sundry Well Operations for 1 H-01 (APD # 193-006) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Kuparuk well 1 H-01. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, /l4~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad SCANNEtJ NOV 0 3 2004 Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 96' 1. Operations Performed: ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION E EIVE REPORT OF SUNDRY WELL OPERATIONS OCT 2 6 2004 Stimulate 0 Other ~ ., Waiver 0 Aias~J'A~~rQ~O . COmmiSSiOn AnCímra, Re-enter Suspended Well 5. Permit to Drill Number: 193-006 1 6. API Number: 50-029-22330-00 RepairWell 0 Pull Tubing 0 Operat. ShutdownD Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development - 0 Stratigraphic 0 Exploratory 0 Service 0 9. Well Name and Number: 1 H-01 8. Property Designation: ADL 25639, ALK 464 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION Perforation depth: 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool measured 7880' feet true vertical 6850' feet measured 7715' feet true vertical 6707' feet Length Size MD 80' 16" 121' 4712' 9-5/8" 4808' 7763' 7" 7859' Plugs (measured) Junk (measured) 7166' TVD Burst Collapse 121' 4245' 6832' Measured depth: 7304'-7394',7438'-7466',7648'-7684' true vertical depth: 6353'-6430',6468'-6492',6649'-6680' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 7552' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'FHL' PACKER; BAKER 3.5" X 5.872" 'FB-1' PACKER pkr= 7166'; 7529' Cameo 'OS' nipple @ 473' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 7642'-7690' 13. Treatment descriptions including volumes used and final pressure: SEE ATTACHED SUMMARY Oil-Bbl SI 130 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Tubinq Pressure Casinq Pressure Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations_X 52 210 15. Well Class after proposed work: Exploratory 0 Development 0 Service D 16. Well Status after proposed work: oil0 Gas 0 WAGD GINJD WINJ D 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: Form 10-404 Revised 04/2004 Contact Printed Name Signature 188 WDSPLD Mike Mooney @ 263-4574 ~i}e ~oney ifl/(~ Title Phone Kuparuk Wells T earn Leader,,,, I.. '.!- Date /9'z 2/(/1 pr¡:rv Sharon ðCtTJr2 2~-4!nol Submit Original Only OR\G\NAL ~ ConocoPhillips AI:Ska,~ . 1H-01 API: 500292233000 SSSV Type: NIPPLE Annular Fluid: Reference Log: Last Tag: 7715 Last Tag Date: 8/15/2004 Casing String - All Strings Description CONDUCTOR SURFACE PRODUCTION Tubing String - TUBING Size I Top 3.500 0 Perforations Summary Interval TVD 7304 - 7394 6353 - 6430 7438 - 7466 6468 - 6492 TUBING (0-7552, OD:3.500, ID:2.992) Perf (7304-7394) CEMENT SQUEEZE (7300-7466) PKR (7529-7530, OD:5.872) FRAC (7648-7684) J I III I"" J .J I~ . ~.fr:: :J L. 1111 J I 1111 ~ I I ~ 1 IÌ f: ~ ";~ . . =: : - KRU 1 H-01 Well Type: Orig Completion: Last W/O: Ref LOÇJ Date: TO: Max Hole Angle: PROD 1/30/1993 2/27/2001 Angle ~ TS: 30 deg ~ 7303 Angle ~ TD: 30 deg ~ 7880 Rev Reason: TAG FILL Last Update: 8/21/2004 7880 ftKB 34 deÇJ @ 6000 Size 16.000 9.625 7.000 Top 0 0 0 Bottom 121 4808 7859 TVD 121 4245 6832 Wt 62.50 36.00 26.00 Grade Thread H-40 WELDED J-55 BTC-MOD K-55 BTC-MOD Bottom 7552 I Grade I L-80 Thread EUE-8rd TVD 6566 Wt 9.30 Zone C-4,C-3 C-1,UNIT B Status Ft SPF Date 90 0 8/30/1997 28 0 8/30/1997 Type Comment 7648 - 7684 6649 - 6680 Stimulations & Treatments Interval Date Type Comment 7300 - 7466 8/30/1997 CEMENT SQUEEZE Cement (82 bbls Glass G w/ Aggregate); Cleaned Out Cement down to 7494' 'A' SAND FRAC - Left half of tree saver rubber in tree A-4 36 4 8/30/1997 IPERF 7648 - 7684 4/14/2001 FRAC Gas Lift MandrelsNalves St MD TVD Man Man Type V Mfr V Type V OD Mfr 1 2860 2594 Cameo KBMM-2 GLV 1.0 2 4386 3884 Cameo KBMM-2 DMY 1.0 3 5159 4544 Cameo KBMM-2 GLV 1.0 4 5837 5111 Cameo KBMM-2 DMY 1.0 5 6484 5651 Cameo KBMM-2 OV 1.0 6 7099 6176 Cameo MMG DMY 1.5 1. Apparent junk on latch ~ 7099' RKB or latch missing 4/16/01 Production MandrelsNalves St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Mfr 7 7212 6274 CAMCO MMG Other (plugs, equip., etc.) - JEWELRY Depth TVD Type 473 473 NIP 7152 6222 PBR 7166 6234 PKR 7516 6535 SLEEVE-C Latch Port TRO Date Run BK 0.125 1241 8/6/2002 BK-5 0.000 0 2/27/2001 BK-5 0.156 1270 8/6/2002 BK-5 0.000 0 2/27/2001 BK 0.188 0 8/6/2002 RKP 0.000 0 2/27/2001 Vlv Cmnt (1 ) CAMCO Date Run 0 3/12/2001 Vlv Cmnt DMY 1.5 RK 0.000 7526 6544 7528 6546 7529 6547 7544 6560 7552 6566 Fish;<FISH Depth I 7166 FISH Description CAMCO "DS" nipple 3.5" x 2.875" BAKER PBR w/5.875 Guide BAKER'FHL'PACKER BAKER 3.5" 'CMU' SLIDING SLEEVE W/CAMCO 'DS' PROFILE - CLOSED 4/29/2004 BAKER NO GO NIPPLE BAKER Seal Assembly BAKER 3.5" X 5.872" 'FB-1' PACKER OTIS 'XN' 3.5" NIPPLE,2.813 x 2.75 NO GO BAKER 3.5" WLEG 4.188 3.000 2.992 2.750 3.000 ID 2.875 3.000 2.938 2.813 NIP SEAL PKR NIP GUIDE Description I Comment GR PIN RETAINER RING LOST IN HOLE 9/6/2002 ') 1 H-01 Well Events Summary ') Date Summary 08/15/04 RAN GR/CCL FOR DEPTH DETERMINATION -- RAN PST TOOL AND STIMULATED THE A--4 SAND PERFS DOING STATION STOPS(MIN TIME 26 MIN) EVERY 6' FROM 76421 - 7690'. ConocoPhillips Alaska P.O. BOX 1.00360 ANCHORAGE, ALASKA 99510-0360 August 31, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a short list of wells fro:m the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled wi.th cement to the top of the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. The top-fill ope:ration was completed on August 24, 2003. Dowell-Schlumberger batch-'mixed Arctic Set I cement to 15.7 ppg in a blender for each well. The cement was pumped from the bottom of the void to the top of the conductor on each well via high pressure hose. The attached, spreadsheet presents the well name, top of cement depth prior to filling, and the number of sacks used on each conductor. Please call Nina Woods or me at 907-659-7224, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Pro'blem Well Supervisor Attachment ,sOANNE SEP 0 8 ; 003 ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-off Kuparuk Field WELLS PTD# TOC VOLUME TYPE SACKS ft BBLS Cement · '1 H-01 1930060 18.0 3.74 Prod 22.6 1 H-21 1930460 21.0 3.66 Prod 22.1 2K-08 1890830 6.0 1.8 Prod 10.9 3M-09 1870290 46.0 8.32 Prod 50.2 3M-10 1870350 52.0 10.1 Inj 61.0 3Q-03 1911260 14.5 3.44 Prod 20.8 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ X RKB 96 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk Unit 4. LocatiOn of well at surface 8. Well number 734' FNL, 1147' FEL, Sec. 33, T12N, R10E, UM (asp's 549200, 5979966) 1H-01 At top of productive interval 9. Permit number / approval number 1764' FSL, 768' FWL, Sec. 34, T12N, R10E, UM 193-006/ At effective depth 10. APl number 50-029-22330 At total depth 11. Field / Pool 3772' FNL, 4337' FEL, Sec. 34, T12N, R10E, UM (asp's 551315, 5976942) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 7880 feet Plugs (measured) true vertical 6850 feet Effective depth: measured 7518 feet Junk (measured) true vertical 6537 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 80' 16" 200 sx Permafrost C 80' 121' SURFACE 4712' 9-5/8" 975 sx PFE, 425 sx Class G 4808' 4245' PRODUCTION 7763' 7" 265 sx Class G 7859' 6832' Perforation depth: measured 7304' - 7394', 7438' - 7466', 7648' - 7684' true vertical 6353' - 6430', 6468' - 6492', 6649' - 6680' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 7552' MD. Packers & SSSV (type & measured depth) BAKER 'FHL' PACKER @ 7166' MD; BAKER 3.5" X 5.872" 'FB-I' PACKER @ 7529' MD; CAMCO "DS" NIPPLE 3.5'I X 2.875" @ 473' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) 7304' - 7394', 7438' - 7466' Treatment description including volumes used and final pressure see attachment 14. Representative Daily Average Production or I niection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 214 423 1965 - 188 Subsequent to operation 159 207 1440 188 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ X Gas __ Suspended _ Service _Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mike Mooney263-4574 Signed .~ /~/~f/~.~ Title: Wells Team Leader Date ~'/~¢'~(....---~ Michael Mooney Prepared b~/ Sharon AIIsup-Drake 263-4612 SCANNED OCT O,'Z[ 200Z , , ?80 S 8£/. S£P/i 2002 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Date Comment 1H-01 Event History 08/03/02 08/04/02 08/05/02 08/06/02 DISPL TBG W/23 BBL DSL, CLOSED CMU SLV, PRESSURE TESTED TBG 1500 PSI TEST GOOD, PULLED OV F/6484' RKB, OV WAS PLUGED OFF, LEFT POCKET OPEN, PULLED GLV'S F/5159' & 2890' RKB, REPLACE W/DV'S, IN PROGRESS [PT TBG-CSG] DISPL CSG W/171 BBLS VIA TBG W/56 BBLS, SET 1" DV @ 6484' RKB, PRESSURE TEST TBG 2500 PSI GOOD TEST, OPENED CMU SLV, PERFORMED INJECTION TEST 1.5 BPM, TBG PSI @ 1200 PSI TOTAL PUMP AWAY 10 BBLS, COMPLETE [PT TBG-CSG] PUMP 200 BBLS OF 10% HCL/3% ACETIC ACID WITH 70% QUALITY N2 FOAM AND WAX BEADS FOR DIVERTER. OVERDISPLACE ACID TREATMENT WITH 560 BBLS OF FILTERED PRODUCED WATER. PRIOR TO PUMPING ACID TREATMENT, THE TUBING WAS PICKLED WITH 15 BBLS OF 10% HCL/3% ACETIC ACID/10% XYLENE DAD. INSTALLED NEW GLV'S & OV @ 2860' 5159' 6484' RKB COMPLETE [GLV] SCANNED OCT 04 Page I of I 8/29/2002 Ph'-LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 April 30, 2001 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 RECEIVED r,4AY 0 'i 2001 Alaska Oil & Gas Cons. Commission Anchorage Subject: Report of Sundry Well Operations 1H-01 (93-06) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the KRU well 1H-01. A fracture treatment was performed on this well. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Staff Engineer Phillips Drilling MM/skad ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RI::PORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown_ Stimulate X Plugging _ Perforate_ Pull tubing Alter casing Repair well Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): Phillips Alaska, Inc. Development X RKB 96 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: 732' FNL, 1151' FEL, Sec. 33, T12N, R10E, UN 1H-01 At top of productive interval: 9. Permit number/approval number: 1764' FSL, 768' FWL, Sec. 34, T12N, R10E, UN 93-06/300-318 At effective depth: 10. APl number: 50-029-22330-00 At total depth: 11. Field/Pool: 1510' FSL, 944' FWL, Sec. 34, T12N, R10E, UN Kuparuk River Field / Kuparuk River Pool 12. Present well condition summary Total Depth: measured 7880' Plugs (measured) true vertical 6850' Effective Deptt measured 7764' Junk (measured) true vertical 6749' Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 200 sx Permafrost C 121' 121' Surface 4767' 9.625" 975 sx PFE & 425 sx Class G 4808' 4245' Production 7819' 7" 265 sx Class G 7859' 6832' Liner Perforation Depth measured 7304'-7394', 7438'-7466', 7648'-7684 RECEIVED true vertical 6353'-6430', 6468'-6492', 6649'-6680 ' 200! Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 7552' Alaska Oil & Gas C0;-,s. {;0mmissi0n Anchorage Packers and SSSV (type and measured depth) Baker 'FHL' packer @ 7166' and Baker 'FB-I' packer @ 7528'. No SS,~ ! 3. Stimulation or cement squeeze summary Intervals treated (measured] see attached summary Intervals treated (measured) 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 169 737 74 222 Subsequent to operation 298 330 541 173 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 !hzot t~e fa, re, going is true and correct to the best of my knowledge. Signed~z,.~.~--- _~,,J~ ~,,~.~ ,~/,,o~--_~ Title'. Staff Engineer Date Mike Mooney Form 10-404 Rev 06/15/88 Prepared by Sharon AIIsup-Drake SUBMIT IN DUPLICATE 4/14/01: 1H-O1 Description of Completion Summary PUMP 200 BBLS 20# GEL BREAKDOWN STAGE - PERFS BROKE BACK AT 7000 PSI AND 25 BPM - PRESSURE DROPPED TO 4730 PSI AT 30.1 BPM - PUMP 150 BBL SCOUR STAGE WITH 1950 LBS 16/20 CARBOLITE AT I PPA IN 50# XL GEL- PUMP 150 BBL 50# XL GEL DATA FRAC - INC PAD TO 400 BBLS - PUMP FRAC - HAD NWBSO WITH 7.4 PPA 12/18 CARBOLITE ON PERFS - LEFT 19200 LBS PROPPANT IN WELLBORE - PLACED 29850 LBS 16/20 CARBOLITE AND 81340 LBS 12/18 BEHIND PIPE ******NOTE: LEFT 1/2 OF A TREE SAVER RUBBER IN THE TREE****** [Frac-Refrac] PH'-LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. Trantham Phone (907) 265-6434 Fax: (907) 265-6224 March 16, 2001 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 1H-01 (93-06 / 300-318) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on KRU well 1H-01. If there are any questions, please contact me at 265-6434 or Pat Reilly at 265-6048. Sincerely, J. Trantham Drilling Engineering Supervisor Phillips Drilling JT/skad RECEtVr.:u MAR 1 9 ZOO1 Alaska Oil & Gas Cons. Commission STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS !. Operations performed: Operation Shutdown _ Stimulatew Plugging _ Perforate _ Pull tubing __X Alter casing _ Repair well _X Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): Phillips Alaska, Inc. Development X, RKB 96 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: 732' FNL, 1151' FEL, Sec. 33, T12N, R10E, UN 1H-01 At top of productive interval: 9. Permit number/approval number: 1764' FSL, 768' FWL, Sec. 34, T12N, R10E, UN 93-06 / 300-318 At effective depth: 10. APl number: 50-029-22330-00 At total depth: 11. Field/Pool: 1510' FSL, 944' FWL, Sec. 34, T12N, R10E, UN Kuparuk River Field / Kuparuk River Pool 12. Present well condition summary Total Depth: measured 7880' Plugs (measured) true vertical 6850' Effective Depfl measured 7764' Junk (measured) true vertical 6749' Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 200 sx Permafrost C 121' 121' Surface 4767' 9.625" 975 sx PF E & 425 sx Class G 4808' 4245' Production 7819' 7" 265 sx Class G 7859' 6832' Liner - Perforation Depth measured 7304'-7394', 7438'-7466', 7648'-7684 true vertical 6353'-6430', 6468'-6492', 6649'-668G Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 7552' Packers and SSSV (type and measured depth) Baker 'FHL' packer @ 7166' and Baker 'FB-I' packer @ 7528', No SSi 13. Stimulation or cement squeeze summary Intervals treated (measured~ N/A Intervals treated (measured) 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A Subsequent to operation 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. Questions? Call Pat Reilly 265-6048 \ Signed . J(~¢~,.~.% ~/?~,~r'~:x~-'L Title: Drilling Engineering Supervisor Date i~:~ (~¢,z~ i'~,~2o ~, ~ James Trantham Form 10-404 Rev 06/15/88 ORIGINAL REOE~VEDperedbysher°nA,sup-Droke MAR 1 9 2001 SUBMIT IN DUPLI~ Rpt Date Begin Time End Time 02/16/01 12:00 AM 19:00 20:00 02/16/01 12:00 AM 20:00 00:00 02/17/01 12:00 AM 00:00 04:00 02/17/01 12:00 AM 04:00 11:00 02/17/01 12:00 AM 11:00 14:00 02/17/01 12:00 AM 14:00 19:00 02/17/01 12:00 AM 19:00 21:00 02/17/01 12:00AM 21:00 00:00 02/18/01 12:00 AM 00:00 02:00 02/18/01 12:00 AM 02:00 05:00 02/18/01 12:00 AM 05:00 06:00 02/18/01 12:00 AM 06:00 10:00 02/18/01 12:00 AM 10:00 11:30 02/18/01 12:00 AM 11:30 18:30 02/18/01 12:00 AM 18:30 21:30 02/18/01 12:00 AM 21:30 00:00 02/19/01 12:00 AM 00:00 07:00 02/19/01 12:00 AM 07:00 15:30 02/19/01 12:00 AM 15:30 16:00 02/19/01 12:00 AM 16:00 18:00 02/19/01 12:00 AM 18:00 00:00 02/20/01 12:00 AM 00:00 05:00 02/20/01 12:00 AM 05:00 06:30 02/20/01 12:00 AM 06:30 07:30 02/20/01 12:00 AM 07:30 11:30 02/20/01 12:00 AM 11:30 13:00 02/20/01 12:00 AM 13:00 14:30 02/20/01 12:00 AM 14:30 19:30 02/20/01 12:00 AM 19:30 20:30 02/20/01 12:00 AM 20:30 00:00 ORIGINAL Comments Move rig to 1H-01-spot & level same. (rig accept @ 20:00 2/16/2001 Rig up hawco wireline while attempting to pull BPV. Pull vr plug-rig up hardline to well 1H-16-Berm cellar & spot cuttings tank. Run hawco wi & tag sand top @ 7224'-Attempt to pull valve from mandrel @ 7152'-no success-attempt second run-3rd run pull valve @ 6791 '. (1" valve) Rig down hawco wi. PJSM-N/D tree cap flane-nipple up 2" 1502 flange-lines & manifold-Test lines-install drip dikes-install block valve. PJSM-circ hot seawater down tbg.-out annulus thru choke to 1H- 16 flow line-Heat & pump 75 bbls. hot diesel down annulus to clean tbg.& pump back up annulus, pressure (280 tbg. 500 annulus) Circ. 9.7 mud around & kill well-monitor well-well dead. Install BPV-n/d tree & n/u bope. N/U bope. Test bope 250-4000# ok. Rig up floor to lay down tbg.-pull test plug & bpv. M/U landing jt.-bolds-pick up to 135K-tbg. would not pull-work pipe while waiting on sws for free point & chemical cut. PJSM-rig up for hooking up sws-change to long bails for safety valve-pump in sub & packoff. Prep for e line. Work pipe-attempt to pull tbg. while waiting on sws. (load-rack- drift & tally tbg. while working pipe. Rig up sws-PJSM-hang sheave in derrick-set slips w/90k. Running free point tool on wire line. Running free point. PJSM-running chemical cutter-'0' ring failure on 1st run-cut @ 6818' wlm-poh & rig down sws. Pull hanger to floor & rig up to circ. CBU while rigging up to lay down tbg. POH laying down tbg. & control line. Continue to POOH L/D 4 1/2" & 3 1/2" Tbg w/Jewelry. Recovered 143 jts of 4" 11# J-55 DSS-HTC btg& 76 jts of 3 1/2" 9.3# J-55 EUE 8rd tbg. 21.1' Cut off of 3 1/2" tbg. 1 4-1/2" SSSV 6 3-1/2" X 1" KBUG GLM's I 3-1/2" X 1 1/2" MMG GLM. Recovered 16 SS Run test plug. Test lower pipe rams to 250-4000 psi. Pull test plug Set wear ring. Load and strap tools M/U and RIH w/Fishing BHA #1 RIH on 3 1/2" DP Tag up @ 6813' Up weight 115k Down Weight 95k. Work over fish @ 6813'. Jar fish slowly up hole for 55' before coming free. Jar w/75K over string weight. Circulate bottoms up 60 spm @ 490 psi. POOH Monitor well after 20 stds Continue to POOH L/D Acc jars. L/D overshot. R/U to L/D fish. L/D 10.78' 3-1/2" cut off 11 jts of 3-1/2" 9.3# J-55 EUE 8rd tbg 1 3-1/2"X1-1/2" MMG GLM 1 Seal Assy 394.13' M/U BHA #2 packer mill RIH. R~CE~VED Alaska Oil & Gas Cons. Cornmmslon An~.hnrmn~ 02/21/01 12:00 AM 00:00 01:30 02/21/01 12:00 AM 01:30 02:30 02/21/01 12:00 AM 02:30 07:00 02/21/01 12:00 AM 07:00 08:00 02/21/01 12:00 AM 08:00 12:00 02/21/01 12:00 AM 12:00 13:30 02/21/01 12:00 AM 13:30 17:30 02/21/01 12:00 AM 17:30 18:00 02/21/01 12:00 AM 18:00 22:00 02/21/01 12:00 AM 22:00 00:00 02/22/01 12:00 AM 00:00 01:30 02/22/01 12:00 AM 01:30 05:00 02/22/01 12:00 AM 05:00 06:00 02/22/01 12:00 AM 06:00 07:00 02/22/01 12:00 AM 07:00 13:00 02/22/01 12:00 AM 13:00 16:00 02/22/01 12:00 AM 16:00 17:30 02/22/01 12:00 AM 17:30 00:00 02/23/01 12:00AM 00:00 07:30 02/23/01 12:00 AM 07:30 08:30 02/23/01 12:00 AM 08:30 10:00 02/23/01 12:00 AM 10:00 12:30 02/23/01 12:00 AM 12:30 16:30 02/23/01 12:00 AM 16:30 20:30 ORIGINAL Continue RIH w/BHA #2 Pkr mill to 7100' on 3 1/2" DP Slip and cut drilling line. Check crown o matic O.K. Tag up on packer @ 7186' Nordic depth. Up wt 120-125k Dn wt 90-100k W/pumps on up wt 125k Dn wt 100k Rt wt 112k 60 RPM 3500-4000 fi/lb torque 570 psi @ 60 spm. Mill 2.5' before packer moved down hole total of 13' Top of fish @ 7199' Nordic depth Circulate bottoms up 90 spm @ 970 psi. Lite gas cut mud on bottoms up. Test csg pressure increasing 100 psi for every 2 pump strokes till pressure reached 1300 psi were it was taking 3 strokes 100 psi. Continue pumping till pressure @ 1450 psi. Shut down Pump Dry job & Blow down top drive. POOH W/BHA #2 pulled 10 std hole took 2 bbl's continue pooh @ 20 std hole took 2 bbls running behind by 6 bbl's. Monitor well pipe pulling dry and well stable. Pulled 10 more std took 2 bbl's behind 9 bbls well stable Circulate bottoms up. Gas cut mud @ surface w/1500 strokes. Lite gas cut mud. Did not have to close well in. No water cut mud. At bottoms up mud smoothed out looked good. POOH w/5 stds took I bbl. Pumped out 5 stds took 4.2 bbl's Continue to pump out. Service top drive. Clean up floor area. Continue to pump out to HWDP L/D mill and junk baskets. Recovered 3 control line bands & mill junk. M/U Spear on BHA #3 RIH on 3 1/2" DP. Continue RIH w/BHA #3 Spear 4.010". Tag fish @ 7265' tail @ 7300' Nordic depth. Work into packer assy w/Spear. Pull up to 7160'. Circulate bottoms up. Lite gas cut mud circulate two bottoms up. Pump dry job Blow down top drive. POOH Pulled 10 stds. Not taking fluid right. Service rig Pump OOH L/D Junk Pkr assy. Well 5 bbl's short on fill. Well trying to flow. Mud creeping down flow line. P/U 6" RR Bit with 7" scraper spaced out to cover packer run. R IH to 7258' Circulate out gas cut mud & Injection water. Tad fill @ 7275'. Clean out sand at a controlled 50 fph. Fluid loss 7-8 bph. 900 psi @ 85 spm. Up wt 110k Dw Wt 100k Rt wt 125k Rotary 60 rpm. At 7513' @ Midnight. Continue to clean out sand F/7513' to 7764' PBTD Pick off bottom and circulate hole clean. Monitor well for 15 min O.K. No flow. Pull 10 stds to 6807' Gained 3 bbl's. Shut well in Monitor while wighting up mud f/9.6 to 9.9 ppg. Shut in pressure after 2 hrs 20 psi. Circulate 9.9 ppg mud around. POOH stand back 3 1/2" DP. L/D 12 4-3/4" dc's Jars & scraper. P/U 7" Baker Retreive-o-matic test packer RIH on 3 1/2" DP to RECEIVED Alaska Oil & 5;~s Cons. Corrlmlssior, Anchorage 02/23/01 12:00 AM 20:30 21:30 02/23/01 12:00 AM 21:30 00:00 02/24/01 12:00 AM 00:00 01:30 02/24/01 12:00 AM 01:30 05:00 02/24/01 12:00 AM 05:00 06:00 02/24/01 12:00 AM 06:00 10:00 02/24/01 12:00 AM 10:00 12:00 02/24/01 12:00 AM 12:00 15:30 02/24/01 12:00 AM 15:30 17:30 02/24/01 12:00 AM 17:30 18:00 02/24/01 12:00 AM 18:00 00:00 02/25/01 12:00 AM 00:00 01:30 02/25/01 12:00 AM 01:30 06:30 02/25/01 12:00 AM 06:30 12:00 02/25/01 12:00 AM 12:00 13:30 02/25/01 12:00 AM 13:30 14:00 02/25/01 12:00 AM 14:00 16:00 02/25/01 12:00 AM 16:00 19:00 02/25/01 12:00 AM 19:00 22:00 02/25/01 12:00 AM 22:00 00:00 02/26/01 12:00AM 00:00 03:00 02/26/01 12:00AM 03:00 03:30 02/26/01 12:00 AM 03:30 06:00 02/26/01 12:00 AM 06:00 13:30 02/26/01 12:00 AM 13:30 14:30 02/26/01 12:00 AM 14:30 16:30 02/26/01 12:00 AM 16:30 19:00 02/26/01 12:00AM 19:00 21:00 02/26/01 12:00 AM 21:00 22:00 ORI61NAL Test 7" casing to 3500 psi for 30 min. Lost 50 psi. Pump dry job. Blow down top drive. POOH Continue to POOH w/7" Baker Retrieve-o matic test packer. L/D 12 jts 3 1/2" HWDP & Pkr. RIH w/3 1/2" mule shoe on 3 1/2" DP to 7200'. Set Baker 7" storm packer 50' below rotary table. Stand back running tool.Test to 1000 psi. Drain stack. Pull mouse hole. PJSM Bleed pressue off 9 5/8" X 7" Annulus. N/D BOPE @ tbg flange. Slip and cut drilling line while bleeding pressue. 20 psi on annulus. Change FMC 9 5/8" X 7" Pack off. Test to 2400 psi. N/U BOPE Set test plug and test broken flanges to 4000 psi. Pull test plug. Set wear ring. Pull strom pkr. Pump sweep ahead of 9.9 ppg Brine @ 7000' and displace 9.9 ppg mud. Fill pits w/92 bbls Brine for completion. Monitor well for 30 min. Well Dead. POOH L/D 3.5" DP caculated hole fill 38 bbls Actual fill 39 bbls. R/d floor R/U Schlumberger wireline unit. While started creep shut in pressure build up 20 psi after 30 min. R/U to run 3 1/2" 9.3# L-80 EUE 8rd tbg RIH w/3 1/2" mule shoe on 3 1/2" tbg to 7226'. Gained 13 bbls while tripping in hole. R/U circulating lines. Shut in well and monitor well while waiting on mud. @ 0700 hrs 40 psi 0900 hrs 50 psi 1000 hrs 60 psi. Load 350 bbl's of 9.9 ppg mud. Weight up to 10.3 ppg. Displace 9.9 ppg clear brine w/10.3 ppg mud. Monitor well 30 min O.K. Pull 10 stands Monitor well Circulate bottoms up condition mud.to 10.3 ppg blanced Pumped dry job. Blow down top drive. POOH stand back 75 stands and L/D 6 jts. Well took 8 bbls over displacement. R/U Schlumberger wireline unit. Run Gauge ring w/junk basket to 7660' Junk basket was clean. M/U Baker 7" 'FB-1 packer and tail pipe assy. RIH hole wireline. Continue running 7" Baker 'FB-I' Pkr w/Tail pipe assy. Set top of @ 7528' (WLM) and tail @ 7552'. POOH R/D wireline unit. Pull wear ring & r/u to run 3.5" completion string w/Blast rings & jewelry. RIH w/Blast rings & Packers. Continue running 3.5" 9.3# L-80 EUE 8rd tbg w/GLM's to surface. Total 227 jt's R/U and circulate to veraify stabed into 'FB-I' Pkr @ 7528' WLM. Bleed off pressue. Drop ball rod w/1 5/16" ball. Pressure up to 2600 psi & hold for 30 min lost 60 psi. Bleed off presuure. Shear Pbr w/115K. Space out install tbg hanger land tbg RILDS. Set BPV. N/D 11" BOPE N/U 4 1/16" 5M Production tree on 7 1/16" 5M X 4 1/16" 5M Adapter. Pull BPV and set test plug. Test pack off to 5000 psi. Test tree to 250-5000 p~l~.~. ~ i,t / plug. !~ \Lk.~, L i VL MAR I 9 2001 ,'\nchorage 02/26/01 12:00 AM 22:00 02/26/01 12:00 AM 23:00 02/27/01 12:00 AM 00:00 02/27/01 12:00 AM 02:00 02/27/01 12:00 AM 03:30 02/27/01 12:00 AM 05:00 23:00 00:00 02:00 03:30 05:00 07:30 R/U circulating lines. Test 7" x 3.5" Annulus to 2500 psi for 15 min Pressure up to 3150 psi shear out DCR valve, Displace 10.3 ppg mud w/Seawater through GLM @ 7212' Pumping down annulus taking returns f/tbg. Displace well to seawater @ 4 bpm. Freeze protect well w/90 bbls. diesel. 'U' tube same (330 psi on tbg. & annulus) Rig down circ lines-set bpv-secure well & cellar. Move rig off well-remove rig equipment-wood-matts & liner- clean up location. (rig released @ 07:30) RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Other _ Change approved program _ Pull tubing _X Variance _ Pedorate _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development_X RKB 96 feet 3. Address Exploratory _ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk River Unit 4. Location of well at surface 8. Well number 732' FNL, 1151' FEL, Sec. 33, T12N, R10E, UM 1H-01 At top of productive interval 9. Permit number / approval number 1764' FSL, 768' FWL, Sec. 34, T12N, R10E, UM 93-06 At effective depth 10. APl number 50-029-22330-00 At total depth 11. Field / Pool 1510' FSL, 944' FWL, Sec. 34, T12N, R10E, UM Kuparuk River Field/Kuparuk River Pool 12. Present well condition summary Total depth: measured 7880 feet Plugs (measured) true vertical 6850 feet Effective depth: measured 7774 feet Junk (measured) true vertical ' 6758 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 80' 16" 200 sx Permafrost C 121' 121' Surface 9.625" 975 sx PF E & 425 sx Class G 4808' 4245' Production 7" 265,sx Class G 7859' 6832' Liner Perforation depth: measured 7304'-7394', 7438'-7466', 7648'-7684' RECEIVED D£C ? 7 2000 true vertical 6353'-6430', 6468'-6492', 6649'-6680' · Alaska Oil & Gas Cons. Commissbn Tubing (size; grade, and measured depth 4" / 3.5", J-55, @ 4381' & 7236' . Anchorage Packers & SSSV (type & measured depth) Baker 'FB-I' perm packer @ 7200', Camco TRDP-4A-RO SSSV @ 1799' 13. Attachments i Description summary of proposal X Detailed operations program_ BOP sketch__ Schematic__X I Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic __ . 14. Estimated date for commencing operation 15. Status of well classification as: January 9, 2001 16. If proposal was verbally approved Oil __X Gas __ Suspended __ Name of approver Date approved Service __ 17. I hereby certify that the foregoing is.true and correct to the best of my knowledge. Questions? Call Pat Reilly 265-6048 Signed /.¢/)~ ~./',,h//c,c,,~,~'z-~ 7~/'7....~,,,¢¢"/¢-~ Title: Drilling Engineering Supervisor Date James Trantham Prepared by Sharon AIIsup-Drake FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no. Plug integrity_ BOP Test ~ Location clearance__I ,~C_.~-- Mechanical Integrity Test ~ Subsequent form required 10- ~ ¢ ORIGINAL SIGi',,E~_)"::'"1"7/ !_ Approved by_order of the.__C_~mmission .............. ~__?a¥!Or Se~mOLlrri: Commissioner Date ~) ~/ Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE PRE-RIG WORK: KRU 1H-01 GENERAL WORKOVER PROCEDURE 1. RU Slick Line Unit. RIH and tag bottom. Dummy off all GLM's. 2. RU CTU and RIH and set sand plug across A sand perfs 3. RU Slick Line, RIH pull bottom GLM valve and leave open. 4. RU E-LINE, RIH and chemical cut the tubing in the middle of the 1st full joint above the seals. 5. Set BPV in tubing. Install VR plug in annulus valve. Prepare Location for Nordic 3. GENERAL WORKOVER PROCEDURE: 1. MIRU Nordic Rig. Lay hard-line to tree. Pull BPV and VR plug. Load pits with seawater. Displace tubing and annulus with seawater. SI well and monitor pressure to determine kill weight. Load pits with kill weight mud. Displace tubing and annulus with kill weight mud through open bottom GLM. SI . o well and monitor pressure to ensure well is dead. Set BPV. 4. ND / NU and test BOPE. ~ 5. Screw in landing joint. POOH laying down completion. 6. Load, strap and drift 3-1/2" drill pipe. 7. RIH with overshot, engage fish, POOH with seals. 8. PU packer milling assembly and RIH picking up 3-1/2" drill pipe off the rack. 9. Mill up Baker permanent packer and push it to bottom. 10. RIH and fish packer. 11. RIH with cleanout assembly. R C iv D OEO 7 2000 Alaska Off & Gas Cons. Anchorage Commission 12. Cleanout to below bottom of C sand perforation, and POOH laying down 3-1/2" drill pipe. 13. RIH with bottom packer assembly on E-line and set packer. 14. Load, strap and drift 3.5" tubing. 15. RIH with 3.5" selective completion assembly as per schematic. 16. Spaceout with tubing pups and land tubing hanger. 17. Pressure test tubing and annulus. ~ 18. ND / NU and test tree. 19. Displace well to seawater and freeze protect with diesel to +\- 2000' TVD. PJR 11/20/00 1H-01 Workover Schematic 9-5/8" 36# J-55 @ 4,808' C4, C3, Sand Perfs 7,304' - 7,394' MD Cl Sand Perfs 7,438'-7,466' MD A4 Sand Perfs 7,648' - 7,684' MD 7" 26# K-55 @ 7,859' Fill 3-1/2" 5M FMC Gen IV tubing hanger with 3.5" L-80 9.3# EUE 8rd Mod pin down. ( or existing 4" DSS-HTC 3' pup w / XO to 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing- contingency) XO 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing / 4" DSS-HTC (contingency) 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing to the tubing hanger. 3-1/2" Camco DS Landing Nipple with 2.875" ID No-Go profile set @ +/- 500' MD. 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing to the 'DS' Nipple with 3-1/2" x 1" Camco 'KBUG' GLM's w/DV's spaced out as follows. GLM # MD TVD RECEIVED I TBD TBD DEC 2 ? ~0011 2 TBD TBD 3 TBD TBD 4 TBD TBD Alaska Oil & Gas Cons. Commission 5 TaD TaD Anchorage Note: Each GLM should have 6' L-80 handling pups installed on top and bottom. 3-1/2" x 1-1/2" 'MMG' GLM w/DCR Dump Kill Valve (3000 psi casing to tubing shear). 6' L-80 handling pups installed on top and bottom of mandrel. 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 6' Handling Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker '80-40' PBR. Baker 7" x 3-1/2" 'FHL' Retrievable Packer @ 7,130'. Minimum ID through the packer 3.00". 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing to Packer. 3-1/2" x 1-1/2" 'MMG' GLM w/ 6' L-80 handling pups installed on top and bottom of mandrel. 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing to GLM. 3-1/2, L-80, Special Clearance BTC Mod Tubing w/Rickert Blast Rings. XO coupling to 3-1/2" EUE 8rd on top joint. Enough Blast Rings to cover all C-Sand Perfs w/at least 5' overlap above & below perfs. 3-1/2", L-80, 9.3# EUE 8rd Mod Pup Joints as required to begin blast rings 5' below bottom C-Sand Perforations (XO coupling to 3-1/2" BTC Mod on top). Baker Sliding Sleeve with Camco 2.81" DS Profile @ 7,496' ( Lock has 2.856" NO-GO ring). 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker 'GBH-22' Locator Seal Assembly (5' seals w/Iocator). Baker 'FB-I' Hydraulic Set Permanent Packer w/5' Seal Bore Extension @ 7,516' (4" ID through SBE - 2.985" min bore through seals). 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 3-1/2" Camco D Nipple @7,540' w/2.75" No-Go Profile 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker 3-1/2" Shear Out Sub w/ WL Re-entry Guide. Tubing tail @ 7,552' MD. PBTD @ 7,485' - Fill tagged on 1/6/00 PBTD @ 7,774' (EFFECTIVE DEPTH)- Actual 7" casing PBTD to FC. TD @ 7,880' 12/21/00 P JR AOGCC Znd"iv~dua'l We'i 1 Geo]ogXi'ca'J kiat~er'~¥a] s Inve~t~or"y PERkJZT DATA T DATA ..... PLUS 93 .... 006 557~ ~ OH CDR./CDN 93 ..... 006 CBT L 6000'~7760 93"'006 CDN~"LWD ~, a-SS8"~'7880~ OH/k~WP 9s~ ..... 006 '~DR ~:: .,~ ..... .. ~:. N H A N C E ki E N T ~ r', H ~ 7 J 88 ~" 79 ,~ 2 93-~006 CD R.~. LWD (~ h. 838~" ? 880 93,~.'006 GET L 6000,'-77~"t 93 .... 006 GCT ~ F;'. U N D A T E .... t::! E C: V D 0a./' 02/' 1993 0 8//0 7 / 1 9 9 3 .q" /' 1 9 9 3 0 .... t 01/ "1 q 9 :~ OS,/OZ:/,' . ..... 08//23/ 1993 os/os,/i 99::~ 09/01/' 1993 03 /30 / 199 , , -- A r' e d r" y d '¥ 'k,c h s amp '1 e s r'e q u ~' r" e d o ,, ~ ye's nd r'ec~'i'ved'? ARCO Alaska, Inc.~(~' ~,, Post Office B{~ J0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 9, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 'Dear Mr. Johnston' Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION Perforate Stimulate Stimulate Perforate Stimulate Stimulate Stimulate Stimulate Perforate Other (conversion) Other (conversion) If you have any questions, please call me at 263-4241. · ,. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering RECEIVED NOV 1 2 199; Alaska 0il & 8as Cons. Conulflsston ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCornpany STATE OF ALASKA ~ OIL AND G/~ CONSERVATION COMMEx~,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development X ARCO Alaska. Inc. Exploratory _ RKB 96 feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service m Kuparuk River Unit 4. Location of well at surface 8. Well number 732' FNL, 1151' FEL, Sec. 33, T12N, R10E, UM 1H-01 At top of productive interval 9. Permit number/approval number 2518' FNL, 768' FWL, Sec. 34, T12N, R10E, UM 93-06 _ At effective depth 10, APl number '~ 1554' FSL, 913' FWL, Sec. 34, T12N, R10E, UM s0-029-22330 At total depth 11, Field/Pool 1510' FSL~ 944' FWL~ Sec. 34~ T12N~ R10E~ UM Kuparuk River Field/Oil Pool 12. Present well condition summary Total Depth: measured 7 8 8 0 feet Plugs (measured) None true vertical 6850 feet Effective depth: measured 7 7 7 4 feet Junk (measured) None true vertical 6758 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 7 8' I 6" 200 Sx CS II 1 21 ' 7 8' Surface 4667' 9.625" 975 Sx PF "C" & 4808' 4245' Intermediate 425 Sx Prem. G Production 7821' 7" 265 Sx Prem. G 7859' 6 83 2' Liner Perforation depth: measured 7304'-7394', 7438'-7466', 7648'-7684' true vertical 6353'-6430', 6468'-6492', 6649'-6680' Tubing (size, grade, and measured depth) R E £ E IV E D 4", 11#/ft., J-55 @ 4381', 3.5", 9.3#/ft., J-55 @ 4381'-7236' Packers and SSSV (type and measured depth) PKR: Baker FB-1 @ 7200'; SSSV: Camco TRDP-4A-RO ~ 1799' NOV 1 2 199~ 13. Stimulation or cement squeeze summary Acidized "C134" sands on 10/28/93. Alaska 0il & I~as Cons. Commission Intervals treated (measured) Anchorage 7304'-7394', 7438'-7466' Treatment description including volumes used and final pressure Bullheaded 10 bbl diesel~ 9 mscf N2~ 89 bbl 10.7% HCl w/500 scf/bbl N2. 14. Reoresentative Daily Averaoe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2 0 5 0 1432 1104 725 295 Subsequent to operation 2 3 3 9 1679 1259 750 306 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. Title Date Form 10-404 Rev 06/15/88 ( SUBMIT IN DUPLICATE ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT CONTRACTOR DOCV~.£L REMARKs IPBDT · DISTRICT- STATE I IDATE , / ' IOPERA¥iON AT REPORT TIME - D[~/s DoLL I ~o~/e~ c~: ~? ? ?&/ ,,cc/i; I/0o PT .Sm_~F~£ /_/w'Es To /220 PSI - ~, 5'b ?~rl To !z// ?/,4 ~,E. /x/'J' . /Z.~O. 12.+0 lZYO 1255-. !~1o tSBY lSFO ~r~rlllrD I~E~EI V r NOV 1 2,1,995 VII I uiv vviJui VVnllillyywyI- Anchorage [-'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Factor Visibility Report lTM -'2, °F i® °F ~'/~u,' ~mil. esIWlnd~/el,knotslSlgne~,, ~ ARCO Alaska, Inc, q_~ Post Offi¢~ ~x 100360 Anchorage, ,,laska 99510-0360 Telephone 907 276 1215 October 7, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION ~l--~ --1A-03 Stimulate ~% i3z. -1G-12 Stimulate 9-~o~ ~1 H-01 Perforate -- 2C-09 Stimulate 8~I- ~.7. ~..- 3H- 14 Stimulate ~7-1z5 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering RECEIVED 0 CT 1 1 199,:3 Alaska 0il & Gas Cons. bummisstu' Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B-6003-C STATE OF ALASKA ALA~,~ OILAND GAS CONSERVATION COMMIS~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Stimulate Plugging Pull tubing ~ Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 732' FNL, 1151' FEL, Sec. 33, T12N, At top of productive interval 2518' FNL, 768' FWL, Sec. 34, T12N, At effective depth 1554' FSL, 913' FWL, Sec. 34, T12N, At total depth 1510' FSL, 944' FWL, Sec. 34~ T12N, 12. Present well condition summary Total Depth: R10E, UM R10E, UM R10E, UM R10E, UM measured 7 8 8 0 feet true vertical 6850 feet 6. Datum elevation (DF or KB) RKB 96 7. Unit or Property name Kuparuk River Unit 8. Well number 1H-01 9. Permit number/approval number 93-06 10. APl number 50-0;~9-22330 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth: measured 7 7 7 4 feet true vertical 6758 feet Junk (measured) None Casing Length Size Structural Conductor 7 8' 1 6" Surface 4 6 6 7' 9.625" Intermediate Production 7 8 21 ' 7" Liner Perforation depth: measured 7304'-7394', true vertical 6353'-6430', Cemented Measured depth True vertical depth 200 Sx CS II 121' 78' 975 Sx PF "C" & 4808' 4 2 4 5' 425 Sx Prem. G 265 Sx Prem. G 7859' 6 8 3 2' 7648'-7684' 6649'-6680' REC£ VF-D 0CT 1 1 1993 Alaska Oil & Gas Cons. tJorm-nissiO¢ Anchorage Tubing (size, grade, and measured depth) 4", 11#/ft., J-55 @ 4381', 3.5", 9.3#/ft., J-55 @ 4381'-7236' Packers and SSSV (type and measured depth) PKR: Baker FB-1 @ 7200'; SSSV: Camco TRDP-4A-RO @ 1799' 13. Stimulation or cement squeeze summary. Perforated "C34" sands on 9/24/93 @ 6 spf. Intervals treated (measured) 7304'-7394' Treatment description including volumes used and final pressure N/A 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 5 4 8 - 248 2193 1350 248 1 7 7 7 747 2172 850 300 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 15. Status of well classification as: Oil X Gas Suspended Service 7. I here/~ certify that the foregoing is true and correct to the best of my knowledge. Sicjned ., Title /~)'~ ~-----~-~ Form 10-404 Rev 06/15/88 Date ¢--?- ~3 SUBMIT IN DUPLICATE ARCO Alaska, Inc?) Subsidiary of Atlantic Rlct~fleld Company WELL SERVICE REPORT WELL I H-,I CONTRACTOR REMARKS J IPBDT FIELD. DISTRICT. STATE opERATION AT REPORT TIME AFc,: q~/ 77~1 DAYS 1 DATE Il\L, T 1 '1 1995 Anchorage [-'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ARCO Alaska, Inc. Date: August 20, 1993 Transmittal #: 8838 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following ~ items. receipt and return one signed copy of this transmittal. cj-~_7 i~I Y-23 Y-23 ~1Y-23 '1' z,,1~,~...~./1 H-14 H-14 IiH'13 C~b'-t~ H-13 H-13 i Y-17' (::r'5--~ 1Y-17 Y-17 ~'5-"O~ -'" 1 H-01 -.-1 H-02 ct..5 .. 2..,~ .....-1H-09 ,,/CDN LWD/Depth Corrected "~C D R Very-enhanced LWD/Depth Corrected · cE;DR LWD/Depth Corrected '.,-CDR LWD/Depth Corrected v-CDR Enhancement LWD/Depth Corrected ~,-CDR Enhancement LWD/Depth Corrected ¢CDN LWD/Depth Corrected ~.-CDR LWD/Depth Corrected v'CDR Enhancement LWD/ Depth Corrected C/CDR ~"' CDN ,,/CDR Enhancement LWD/ Depth Corrected v.-CDR Enhancement LWD/ Depth Corrected v. CDR Enhancement LWD/ Depth Corrected 7-06-93 7-06-93 7-06-93 5-18-93 5-18-93 6-01-93 6-01-93 6-01-93 6-18-93 6-18-93 6-18-93 3-05-93 3-05-93 4-26-93 Receipt Acknowledged: DISTRIBUTION: Please acknowledge 3739-7499 3746-7497 3739-7499 4695-10524 4786-10522 6368-10165 6360-10167 6360-10167 4338-8025 4320-8045 7360-8045 7188-7942 7388-8037 1 O855-1175O Date: STATE Of ALASKA ALA'Sr''A OIL AND GAS CONSERVATION COMME:~ION REPORT OF SUNDRY WELL OPERATIOpe,NfoSe 1. Operations Performed: Operation Shutdown ~ Stimulate X Plugging_ __ rat . _ '- ~ Pull tubing Alter casing Repair well Other 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ RKB 96 Stratigraphic _ 7. Unit or Property name Service __ Kuparuk River Unit 8. Well number 1H-01 9. Permit number/approval number 93-06 10. APl number $0-02~)-22330 11. Field/Pool Kuparuk River Field/Oil Pool 4. Location of well at surface 732' FNL, 1151' FEL, Sec. 33, T12N, At top of productive interval 2518' FNL, 768' FWL, Sec. 34, T12N, At effective depth 1554' FSL, 913' FWL, Sec. 34, T12N, At total depth 1510' FSL, 944' FWL, Sec. 34, T12N, R10E, UM R10E, UM R10E, UM R10E, UM 12. Present well condition summary Total Depth: measured 7 8 8 0 true vertical 6850 feet Plugs (measured) None feet feint Effective depth: measured 7 7 7 4 true vertical 6758 feet Junk (measured) None feet Casing Length Size Structural Conductor 7 8' 1 6" Surface 4 6 6 7' 9.6 2 5" Intermediate Production 7 8 2 1 ' 7" Liner Perforation depth: measured 7648'-7684' true vertical 6649'-6680' Tubing (size, grade, and measured depth) Cemented Measured depth 200 Sx CS II 121' 975 Sx PF "C" & 4808' 425 Sx Prem. G 265 Sx Prem. G 7859' True vertical depth 78' 4245' 6832' RECEiVeD 4", 11#/ft., J-55 @ 4381', 3.5", 9.3#/ft., J-55 @ 4381'-7236' Packers and SSSV (type and measured depth) PKR: Baker FB-1 @ 7200'; SSSV: Camco TRDP-4A-RO @ 1799' 13. Stimulation or cement squeeze summary Refractured "A" sands on 7/17/93. -Intervals treated (measured) 7648'-7684' Treatment description including volumes used and final pressure 14. Aiaska Oil & Gas (;ci'.,s. fjor~-~-nissit':,~. A.chorag,. Pumped 118 MLbs of 12/18 and 16/20 ceramic proppant into formationrfp was 5475 psi. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 7 -0- 4 1300 120 7 0 0 //' 21 35 750 170 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas __ Suspended __ Service Si~]nedForm7. I hereb~.~,certifY~l 0-404~ M ,~ ~//~_.~Revthat06/1the, 5/88foregoing is true and correctTitletO ~~~the best of my knowledge.~.F~~~_ ...- , SUBMIT IN DUPLICATE FRAC./.STIHU~ATION SUHMAR,Y WELL NO: I ~" I AFE: Service Co: -- ~~'~'1,. , : --: Annulus Press: .~;P_~f) Perfs: STAGE , , VOL FLUID . -- Begin Frac: Zone: %'~~~ Test Lines To~ PROP i ii i j r _ i i_1 mi E(-P ,, _ RAT. E' _ PRESS, URE i ~ _ ii __ ISIP: F1 ut d to Recover: ir Sand In Csg: Job Complete: . , , Rt~-SUpe~ TA/mJk/3100/104 ~ ~ ~vo~[e*~ ~~~_~q ~~ ~ .A)aska Oil & Gas ~6~or~.~,~ Anchorage ~t,f .... 15 Hin: ~0_~'_ Avg Press: ~~ _ psi J i i ORIGINAL ' ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI~SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [~] GAS r--'l SUSPENDED r---1 ABANDONED [] SERVICE r'~ 2 Name of Operator 7 Permit Number ~'r~,~,~v~.~_~l~ ARCO Alaska, Inc 93-06 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22330 4 Location of well at surface 9 Unit or Lease Name 732' FNL, 1151' FEL, SEC 33, T 12N, R 10E, UM ~0MP/F.T[ ' KUPARUK RIVER At Top Producing Interval t~t 10 Well Number 1764' FSL, 768' FWL, SEC 34, T 12N, R 10E, UM ~ 1H-01 AtTotal Depth L~~,~~i ~ 11 Fieldand Pool 1510' FSL, 944' FWL, SEC 34, T 12N, R 10E, UM -- KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. KUPARUK RIVER RKB 96', PAD 54' GLI ADL 25639 ALK 464 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. J15 Water Depth, if offshore J16 No. of Completions 22-Jan-93 29-Jan-93 06/08/93 (0000 Hrs)-COMPI 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 MD, 6850' TVD 7774' MD, 6758' TVD YES ]'~ NO [~]I 1798' feet MD 1590' MD APPROX 7880' 22 Type Electric or Other Logs Run CDN, CDR, CET, CBT, GCT 23 CASING, LINER AND CEMENTING RECORD I SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT'RECORD 16" 62.5# H-40 SURF 121' 24" 200 SX PFC CMT 9.625" 36# J-55 SURF 4808' 12.25" 975 SX PF E, 425 SX CLASS G 7" 26# J-55 SURF 7859' 8.5" 265 SX CLASS G CMT 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) 4"/3.5" J-55 11#/9.3# 2758'/7236' 7200' 7648'-7684' MD @ 4 SPF W/4-1/2" CSG GUN 6649'-6680' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ¢ FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RE¢£1VED JUL - 1 1993 Alaska 0il & L'~a$ Cons. Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REvErsE SIDE 29. 30. ~',. GE(~OGIC ~ 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 ~ 7269' 8323' BASE KupARuK C 7456' 8484' TOP KUPARUK A 7611' 8617' ;;" ~.BASE'KUPARUK A 7748' 6736' . . . -, . ... 31. LIST OF ATTACHMENTS REPORT OF OPERATIONS, 2 COPIES OF DIRECTIONAL SURVEY 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. Signed ~ .__/~//~~~'~ ~ Title ~'t~--[ ~/"~/ ~.~ DATE INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' ClassifiCation of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached Supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27! Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OPERATION. PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 1H-01 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER ADL 25639 ALK 464 50-029-22330 93-06 ACCEPT: 01/22/93 03:30 SPUD: 01/22/93 08:30 RELEASE: 06/07/93 11:59 OPERATION: DRLG RIG: PARKER 245 WO/C RIG: NORDIC 1 01/23/93 ( 1) PARKER 245 TD: 1513' (1513) 01/24/93 (2) PARKER 245 TD: 4758' (3245) 01/25/93 (3) PARKER 245 TD: 4828' ( 70) DRILLING 9-5/8"@ 4807' MW:10.4 VIS: 74 MOVE RIG FROM WELL 1H-15 TO 1H-01. ACCEPT RIG @ 15:30 HRS 01/22/93. NU & FUNCTION TEST DIVERTER. DOUG AMOS OF AOGCC WAIVED WITNESSING TEST. PU 12-1/4" BHA & ORIENT TOOLS. DRLG F/121'-1513' DRILLING 9-5/8"@ 4807' MW:10.6 VIS: 78 DRILL & SURV F/1513'-1657'. REPAIR FILL UP LINE VALVE. DRILL & SURVEY F/1657'-2248' CIRC OUT GAS CUT MUD. PU RISER. MUD CUT TO 9.8 PG. DRILL & SURVEY F/2248'-2584'. SERV RIG & TOP DRIVE. DRILL & SURVEY F/2584'-3703' CIRC OUT GAS CUT MUD. MUD CUT TO 9.7 PPG. DRILL & SURV' F/3703'-4410' CIRC OUT GAS CUT MUD. MUD CUT TO 9.4 PPG. RAISE MUD WT TO 10.7 PPG. DRILL & SURVEY F/4410'-4561' CONTROL DRILL @ 200 FT/HR. CIRC OUT GAS CUT MUD. MUD CUT TO 9.8 PPG. DRILL & SURV F/4561'-4758' POH 9-5/8"@ 4807' MW:10.6 VIS: 44 DRILL & SURVEY F/4758'-4828' CIRC & COND MUD. MAKE 10 STDS SHORT TRIP TO CHECK FOR GAS. TIGHT @ 4094', 4064', & 3950'. REAM F/4100'-3926' RIH. NO FILL. NO GAS. CIRC & COND MUD. POH. TIGHT F;4050'-2220' WASH & REAM STDS OUT OF HOLE W/TOP DRIVE. HOLE PACKING OFF. LOSING MUD @ 2200'. GAS CUT MUD TO 10.2 PPG. CHANGE OUT INSERTS, GRABS, & SAVER SUB ON TOP DRIVE. POOH. WASH & REAM F/1755'-1294' FIN POH. LD BHA. PU HOLE OPENER & NB STAB. MU BHA. RIH. FILL PIPE @ 1200' & 2900'. BRIDGE @ 3011' REAM F/3000'-3076' WASH F/3076'-3100'. RIH. '0' FILL ON BTM. CIRC & COND MUD. POH. RECEIVED d U L - 1 Alaska Oil & Gas Cons. bommissior~ Anchorage WELL: 1H-01 API: 50-029-22330 PERMIT: 93-06 PAGE: 2 01/26/93 ( 4) PARKER 245 TD: 4828'( o) 01/27/93 ( 5) PARKER 245 TD: 6520' (1692) 01/28/93 ( 6) PARKER 245 TD: 7684' (1164) 01/29/93 (7) PARKER 245 TD: 7880' ( 196) TEST BOP 9-5/8"@ 4807' MW: 8.5 VIS: 29 POOH-RECOVERED SURVEY @ HW-LD BHA. RU CASER-HOLD SAFETY MEETING. RAN 120 JTS 9-5/8" 36# J-55 BT & C CSG. TAGGED UP @ 4788' RU CMT HEAD. WASHED 20' TO 4808' CIRC & COND MUD. NO GAS. .SET & CMT'D 9-5/8" CSG @ 4~08' SHOE @ 4808', FC @ 4722' HALLIBURTON CMT'D W/25 BBLS WA~ER AHEAD, 975 SX PF E + 1/45 FLOCELE & TAILED IN W/425 SX G + 2% CC + 1/4# FLOCELE. DISPLACE W/20 BBLS WATER & 345 BBLS WATER BACK MUD. CIRC 56 BBLS CMT TO SURF-ii.8 PPG. PLUG DOWN & J. C. @ 2030 PM. PLUG DID NOT BMP. FLOATS HELD. RD CMT & CSG EQUIP. ND 20" DIVERTER. WASH OUT FLOW LINES & DIVERTER VALVES. CLEAN & INSTALL 9-5/8" PACKOFF. SCREW ON SPEED HEAD. TORQUE TO 13K FT/LBS. NU BOP. TEST BOP. AOGCC REP LOU GRIMALDI WAIVED WITNESSING TEST. DRILL, LOG, & SURVEY 9-5/8"@ 4807' MW: 8.8 VIS: 31 RD TEST EQUIP. BLOW DOWN LINES & CHOKE MANIFOLD. RUN WEAR BUSHING. BREAK DOWN & REASSENBLE TURBINE, PU BHA, ORIENT MWD, INSTALL R/A SOURCE. TEST MWD @ HWDP. RIH TO 4500' · CUT DRLG LINE 130'. SERV RIG & TOP DRIVE. RIH, TAG CMT @ 4715', CIRC, TEST CSG 2000 PSI FOR 1/2 HR. LOST 50 PSI. DRILL WIPER PLUGS, FC, CMT, FS, C/O OPEN HOLE, DRILL NEW FORMATION TO 4838' CIRC. PERFORM FORMATION INTEGRITY TEST,=4266' TVD, WITH 8.6 PG MUD, PRESS FORMATION TO 865 PSI=12.5 PPG EMW, HELD 5 MIN, NO LEAK OFF. DRILL, LOG & MWD SURVEY. 9-5/8"@ 4807' MW:10.5 VIS: 42 DRILL, LOG, & MWD SURVEY TO 7382'. CHECK WELL FOR FLOW, WELL FLOWING SLIGHTLY. CBU. NO PIT GAIN WHILE CIRC. CHECK FLOW, WELL STILL FLOWING, RAISE MUD WT FROM 10 PPG TO 10.3 PPG, CHECK FLOW, WELL DEAD. DRILL, LOG & MWD SURVEY TO 7684' POH FOR 7" CSG 7"@ 7858' MW:10.5 VIS: 42 DRILL TO 7694' PMP SLUG, POH TO LWD TOOLS. REMOVE SOURCE FROM LWD TOOLS, DOWNLOAD INFO, LD LWD TOOLS & MWD. LD TURBINE, MU NEW BHA, PPOGRAM TOOLS, INSTALL R/A SOURCE, TEST MWD @ HWDP. RIH TO 9-5/8" SHOE. FILL PIPE & SERVICE TOP DRIVE. RIH TO 7624' FILL PIPE, REAM FROM 7624' TO 7694' FOR LWD LOGS. DRILL, LOG & SURVEY TO 7880' POH TO 7400', RIH TO 7880', NO TIGHT HOLE & NO FILL. CIRC HOLE CLEAN. POH FOR 7" CSG. RECEIVED JUl .... -1 199; Alaska Oil & Gas Oo~ls. Anchorage WELL: 1H-01 API: 50-029-22330 PERMIT: 93-06 PAGE: 3 01/30/93 ( 8) PARKER 245 TD: 7880'( 06/07/93 (10) TD: 7850 PB: 7774 06/08/93 (11) TD: 7850 PB: 7774 o) 7"8 7858' MW:10.5 VIS: 0 LD BHA FOR INSPECTION. PULL WEAR RING. RU & RUN 7" 26# J-55 CSG. CIRC & RECIP CSG, PMP 947 BBLS. CMT 7" CSG W/265 X CMT. BMP PLUG W/3500 PSI, HELD 1/2 HR FOR STATE TEST, GOOD TEST, BLED OFF, FLOATS HELD. PU STACK, SET CSG SLIPS W/155,000 MET, BLOW DN LANDING JT., MAKE ROUGH CUT ON 7", SET DOWN STACK. ND STACK, SET ON STUMP. MAKE FINAL CUT ON 7" CSG, INSTALL PACKOFF & NU 11" 3M X7-1/16" 5M WELLHEAD. TEST TO 3000 PSI, GOOD TEST. FLUSH ANN W/100 BBL WATER, FREEZE PROTECT ANN W/80 BBLS DIESEL. RELEASE RIG 8 04:30 HRS 01/30/93. MOVING TO 1H-02. PULL TBG JEWELRY TO FLOOR 7"8 7858' MW:10.5 NaC1/Br MOVE RIG F/1H-15 TO 1H-01. ACCEPT RIG 8 2000 HRS 06/06/93. CHECK WELL FOR PRESS. ND TREE. NU BOPE. SET TEST PLUG. TEST BOP'S. RU SWS TO PERF. MU GUN #1, TEST LUB TO 1000 PSI. RIH. SHOT F/7668'-7684' 8 4 SPF, 180 DEG PHASING, ORIENTED 155 DEG CCW W/4-1/2" CSG GUN ALTERNATING 34B HJ & 43C ULTRA PACK. POH. MU GUN #2 & RIH. SHOT 7648'-7668' AS ABOVE. POH. MU 5.95" GAUGE RING & JB ON SWS WL. RIH TO 7640' POH. WENT SLICK IN & OUT. RD JB, PU PKR/TAIL PIPE ASSY ON SWS WL & RIH. SET PKR 8 7193' (BTM OF TBG TAIL 8 7229'). POH & RD SWS. PULL TBG JEWELRY TO FLOOR. RIG RELEASED 7"8 7858' MW:10.5 NaC1/Br RU FLOOR TO RUN TBG. BRING IN GLM'S & 4" SLIPS & ELEVATORS. RIH W/3-1/2" X 4" COMPLETION. TAG UP, SPACE OUT. TEST CONTROL LINE & TBG HGR TO 5000 PSI-OK. LAND TBG. RILDS. DROP BALL & WAIT FOR IT TO SEAT. PRESS TBG & ANN TO 1000 PSI. CLOSE SSSV. BLEED TBG TO 500 PSI FOR 15 MIN SSSV TEST-OK. OPEN SSSV. PRESS TBG & ANN TO 2500 PSI FOR 15 MIN-OK. PRESS TBG TO 3000 PSI-BALL SHEARED. PULL LANDING JT. SET BPV. ND BOP'S, NU TREE. TEST TREE TO 250 PSI & 5000 PSI. TEST PACKOFF TO 5000 PSI. FREEZE PROTECT WELL W/ll BBLS DIESEL CIRC DOWN 4" X 7" ANN & 6 BBLS DIESEL BULLHEADED DOWN TBG(1 BPM 8 1800 PSI). RD LINES & SECURE WELL. RIG RELEASED 8 2400 HRS 06/07/93. SIGNATURE: (drilling s'upe~inte~dent) I DATE: RECEIVED J U I.. - 1 t99 Alaska 0~1 ~ <~s [;on~. Anchorage SUB - S URFA CE DIRECTIONAL r~ UIDANCE I'~ ONTINUOUS ~ OOL SURVEY Date_ [ r_~,///. ./('~ - R E CE :.I,V E D d U I... - ! 199:~ Alaska Oi~l'& Bas oon~. burn,misSUs' A(~ska u?~ Anchorage Company ARCO ALASKA, INC. . ii i i ii i i Well Name 1H-01 (732' FNL, 1151' FEL, SEC 33, T12N, RIOE, tiN) Field/Location KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 93084 Loqqed By: SCHWARTZ Date 19-FEB-93 Computed By' SINES * SCHLUMBERGER OCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA INC. 1H-OI RECEIVED Alaska Oil & Gas Cons. Anchorage KUPARUK RIVER NORTH SLOPE, ALASKA SURVEY DATE' 19-FEB-93 ENGINEER- SCHWARTZ METHODS OF COMPUTATION TOOL LOCATION: MINIMUM CURVATURE INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 34 DEG 25 MIN EAST COMPUTATION DATE: 22-MAR-93 PAGE I ARCO ALASKA INC. 1H-O1 KUPARUK RIVER NORTH SLOPE, ALASKA TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 O0 100 O0 200 O0 3OO O0 400 O0 500 O0 6OO O0 700 O0 800 O0 900 O0 0.00 100.00 200.00 299.99 399.92 499.76 599.46 698.71 797.18 894.54 DATE OF SURVEY- 19-FEB-93 KELLY BUSHING ELEVATION' 96.00 FT ENGINEER' SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH 0 0 N 0 0 E 0 29 S 14 3 W 0 27 S 19 13 W I 10 S 28 14 E 2 48 S 43 45 E 3 42 S 34 16 E 5 24 S 27 2O E 8 36 S 27 25 E 18 11 30 S 29 27 E 54 14 53 S 28 41 E -96 O0 4 O0 104 O0 203 99 303 92 403 76 5O3 46 602 71 701 798 FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 0 23 0 75 I 71 5 20 10 90 18 48 30 49 47 75 70 41 0 O0 0 76 0 06 2 4O I 16 1 O2 3 45 2 34 2 28 3 48 0 O0 N 0 39 S 1 14 S 2 29 S 4 84 S 9 36 S 15 89 S 26 69 S 41 93 S 61 82 S 0 O0 E 0 16W 0 34 W 0 31 W 2 12 E 5 63 E 9 49 E 14 99 E 23 28 E 34 35 E 0 O0 N 0 0 E 0 1 2 5 10 18 30 47 70 42 S 21 42 W 19 S 16 38 W 31 S 7 43 W 29 S 23 39 E 92 S 31 2 E 51 S 3O 52 E 61 S 29 20 E 96 S 29 2 E 72 S 29 4 E 1000 OO 1100 1200 1300 1400 1500 1600 1700 1800 1900 O0 1084 O0 1177 O0 1267 O0 1356 O0 1444 O0 1531 O0 1617 O0 1702 O0 1787 990 32 44 988 09 1081 98 1171 gl 1260 51 1348 46 1435 76 1521 894 32 18 23 44 20 58 09 23 15 98 26 6 91 28 7 51 29 22 46 29 49 76 31 10 67 1606.67 32 22 10 1691.10 32 26 S 30 3 E S 31 39 E S 31 55 E S33 17 E S 34 5O E S 34 24 E S33 31 E S 32 46 E S 32 58 E S 32 43 E 98 96 132 67 170 22 211 88 257 6O 305 82 355 21 405 71 458 51 512 O7 3 23 2 32 2 61 3 07 1 76 0 72 0 63 2 24 0 48 0 31 86.83 S 115.78 S 65 147.73 S 85 182.89 S 107 220 69 S 133 260 34 S 161 301 31S 188 343 61S 216 388 O1S 244 433 01S 274 74 E 133 54 E 170 94 E 212 65 E 258 10 E 306 69 E 355 30 E 406 90 E 458 O0 E 512 48 36 E 99 39 S 29 7 E 14 S 29 35 E 71 S 3O 4 E 37 S 3O 33 E O1 S 31 12 E 16 S 31 45 E 52 S 32 3 E 02 S 32 11E 83 S 32 16 E 42 S 32 19 E 2000 O0 1871.38 1775.38 32 39 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 1955.56 1859.56 32 41 O0 2039.72 1943.72 32 42 O0 2123.92 2027.92 32 36 O0 2208.24 2112.24 32 27 O0 2292.62 2196.62 32 34 O0 2376.45 2280.45 33 23 O0 2459.87 2363.87 33 32 O0 2543.25 2447.25 33 18 O0 2627.19 2531.19 32 40 S 32 37 E S 32 27 E S 32 14 E S 31 53 E S 31 34 E S 31 29 E S 32 43 E S 32 37 E S 33 18 E S 35 30 E 1054 565 88 619 82 673 80 727 70 781 40 834 99 889 46 944 59 999 77 11 0 32 0 12 0 34 0 32 0 24 I O8 0 36 0 17 1 84 0 38 478 31 S 303 07 E 566 24 S 32 22 E 523 569 615 660 706 752 799 845 890 85 S 332 45 S 360 19 S 389 93 S 417 74 S 445 88 S 474 3O S 5O4 73 S 534 41S 565 05 E 620 98 E 674 59 E 728 84 E 781 8O E 835 82 E 890 61E 945 47 E 1000 39 E 1054 22 S 32 22 E 23 S 32 22 E 18 S 32 21E 94 S 32 18 E 59 S 32 15 E 10 S 32 14 E 26 S 32 16 E 46 S 32 17 E 75 S 32 25 E 3000.00 2711.56 2615.56 32 20 3100.00 2796.09 2700.09 32 14 3200.00 2880.72 2784.72 32 7 3300.00 2965.47 2869.47 31 59 3400.00 3050.43 2954.43 31 41 3500.00 3135.18 3039.18 32 49 3600.00 3218.69 3122.69 33 32 3700.00 3302.20 3206.20 33 11 3800 O0 3386 22 3290 22 32 31 3900 O0 3470 59 3374 59 32 26 S 35 19 E 1107.79 S 35 24 E 1161.21 S 35 21 E 1214.48 S 35 13 E 1267.54 S 34 37 E 1320.28 S 34 11 E 1373.37 S 34 9 E 1428.37 S 33 40 E 1483.37 S 33 17 E 1537 59 5 34 52 E 1591 27 0 10 0 16 0 29 0 32 o 43 2 33 o 43 o 42 o lO o 59 934.19 S 596 47 E 1108 37 S 32 33 E 977.76 S 627 38 E 1161 74 S 32 41E 1021.20 S 658 23 E 1214 96 S 32 48 E 1064.53 S 688 88 E 1267 98 S 32 54 E 1107.77 S 719 08 E 1320 69 S 32 59 E 1151 59 S 749 04 E 1373 76 S 33 3 E 1197 10 S 779 95 E 1428,76 S 33 5 E 1242 74 S 810.63 E 1483,76 S 33 7 E 1287 99 S 840.52 E 1537,98 S 33 8 E 1332 50 S 870.53 E 1591,66 S 33 9 E ArC0 ALASKA INC. lh-O1 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 22-MAR-93 PAGE 2 DATE OF SURVEY: 19-FEB-93 KELLY BUSHING ELEVATION: 96.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH 1-RUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPI'H DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DE~/IOO FEET FEET FEET DEG 4000 O0 3555 12 3459 12 32 6 4100 4200 4300 4400 4500 4600 4700 4800 490O O0 3640 O0 3725 O0 3810 O0 3896 O0 3981 O0 4066 O0 4151 O0 4237 O0 4323 03 3544 25 3629 78 3714 47 3800 54 3885 44 3970 70 4055 62 4141 94 4227 03 31 44 25 31 21 78 31 4 47 31 12 54 32 2 44 31 45 7O 31 10 62 30 26 94 30 34 S 35 1E 1644 70 S 34 45 E 1697 S 34 52 E 1749 S 35 5 E 1801 S 35 15 E 1853 S 35 29 E 1905 S 35 31E 1958 S 35 26 E 2010 S 35 50 E 2061 S 35 45 E 2112 52 84 66 20 74 59 82 97 45 0 . 54 0 25 0 34 0 33 1 05 0 17 0 42 0 93 0 88 1 76 1376 25 S 901 19 E 1645 06 S 33 13 1419 1462 1505 1547 1590 1633 1675 1717 1758 59 S 931 57 S 961 05 S 990 19 S 1020 05 S 1051 07 S 1081 63 S 1112 21S 1141 40 E 1697 24 E 1750 91E 1801 60 E 1853 O0 E 1906 71E 1958 01E 2011 81E 2062 87 S 33 16 17 S 33 19 96 S 33 22 48 S 33 25 O1 S 33 28 83 S 33 31 05 S 33 34 17 S 33 37 _- _- E E E E 03 S 1171 53 E 2112 62 S 33 41 E 5000 O0 4409 59 4313 59 31 21 5100 O0 4494 5200 O0 4578 5300 O0 4661 5400 O0 4745 5500 O0 4828 5600 O0 4912 5700.00 4996 5800.00 5080 5900.00 5163 81 4398 56 4482 87 4565 35 4649 92 4732 64 4816 50 4900 08 4984 26 5067 81 32 11 56 33 35 87 33 28 35 33 21 92 33 16 64 33 5 50 32 58 08 33 41 26 33 48 S 34 24 E 2164.05 S 33 27 E 2216.37 S 32 15 E 2270.98 S 32 14 E 2326.25 S 32 15 E 2381.27 S 32 10 E 2436.14 S 31 55 E 2490.79 S 31 56 E 2545.20 S 35 28 E 2600.10 S 35 57 E 2655.59 0 14 3 59 0 17 0 37 0 15 0 15 0 09 0 29 0 92 0 66 1800.39 S 1201 02 E 2164.22 S 33 42 E 1843.72 S 1230 1889.75 S 1259 1936.53 S 1289 1983 11S 1318 2029 59 S 1347 2075 94 S 1376 2122 19 S 1405 2167 98 S 1435 2213 04 S 1468 34 E 2216.53 S 33 43 e 79 E 2271.17 S 33 41E 28 E 2326.46 S 33 39 E 63 E 2381.50 S 33 37 E 89 E 2436.40 S 33 35 E 91 E 2491.07 S 33 33 E 68 E 2545.52 S 33 31 E 97 E 2600.42 S 33 31 E 40 E 2655.89 S 33 34 E 6000 O0 5246 08 5150 08 34 17 6100 6200 6300 6400 6500 6600 670O 6800 6900 O0 5328 O0 5412 O0 5495 O0 5580 O0 5664 O0 5749 O0 5835 O0 5920 O0 6006 90 5232 11 5316 95 5399 16 5484 44 5568 56 5653 12 5739 63 5824 14 5910 90 33 51 11 33 29 95 32 44 16 32 35 44 32 23 56 31 11 12 31 14 63 31 13 14 31 16 7000 O0 6091 65 5995 65 31 8 7100 7200 7300 7400 7500 7600 7700 7800 7880 O0 6177 O0 6263 O0 6349 O0 6435 O0 6521 O0 6607 O0 6694 O0 6780 O0 6849 28 6081 22 6167 30 6253 54 6339 71 6425 83 6511 04 6598 59 6684 84 6753 28 30 58 22 3O 37 30 30 31 54 30 25 71 3O 34 83 3O 33 04 30 7 59 3O 3 84 30 3 S 37 58 E 2711 57 S 38 6 E 2767 S 38 14 E 2822 S 41 11E 2877 S 40 59 E 2930 S 4O 34 E 2984 S 38 7 E 3036 S 38 7 E 3088 S 38 4 E 3139 S 38 5 E 3191 50 84 11 67 16 46 11 86 59 S 38 5 E 3243 34 S 36 48 E 3294 S 34 42 E 3346 S 34 32 E 3396 S 34 35 E 3447 S 34 22 E 3498 S 35 I E 3549 S 35 11E 3599 S 35 11E 3649 S 35 11E 3689 9O O2 91 53 28 10 76 85 9O 0 35 0 35 0 79 0 24 0 O9 1 47 0 32 0 15 0 17 0 04 0.18 2.20 0.26 0.43 0 O2 0 16 0 17 1 19 0 O0 0 O0 2257 78 S 1502 15 E 2711 83 S 33 38 E 2301 2345 2387 2428 2468 2509 2550 2591 2631 95 S 1536 56 S 1570 43 S 1605 11S 1641 81S 1676 53 S 1709 25 S 1741 08 S 1773 89 S 1805 62 E 2767 89 E 2823 78 E 2877 18 E 293O 41E 2984 5O E 3O36 45 E 3088 43 E 3139 40 E 3191 7O S 33 43 E O0 S 33 49 E 21 S 33 55 E 73 S 34 3 E 18 S 34 11E 47 S 34 16 E 12 S 34 20 E 86 S 34 23 E 59 S 34 27 E 2672 71 S 1837 37 E 3243 35 S 34 30 E 2713 2755 2797 2838 2880 2922 2963 3004 3037 54 S 1868 22 S 1898 14 S 1927 78 S 1956 64 S 1984 42 S 2013 86 S 2043 86 S 2071 60 S 2094 99 E 3294 6O E 3346 46 E 3396 23 E 3447 93 E 3498 87 E 3549 O2 E 3599 79 E 3649 87 E 3689 91 S 34 33 E 03 S 34 34 E 93 S 34 34 E 54 S 34 34 E 29 S 34 34 E 11 S 34 34 E 78 S 34 35 E 87 S 34 35 E 92 S 34 36 E COMPUTATION DATE: 22-MAR-93 PAGE 4 ARCO ALASKa INC. 1H-O1 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 1g-FEB-93 KELLY BUSHING ELEVATION: 96.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SL/3-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE BEASURF_D VERTICAL VERTICAL DEVIATION AZIBUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIBUTH DEPTH DEPTH DEPTH DEG BIN DEG BIN FEET DEG/IO0 FEET FEET FEET DEG BIN 0 O0 1000 2000 3000 4000 5000 6000 7000 7880 0 O0 -96 O0 0 0 N 0 0 E O0 990 32 894 O0 1871 38 1775 O0 2711 56 2615 O0 3555 12 3459 O0 4409 59 4313 O0 5246 08 5150 O0 6091 65 5995 O0 6849 84 6753 0 O0 32 18 23 S 30 3 E 98 38 32 39 S 32 37 E 565 56 32 20 S 35 19 E 1107 12 32 6 S 35 1 E 1644 59 31 21 S 34 24 E 2164 08 34 17 S 37 58 E 2711 65 31 8 S 38 5 E 3243 84 30 3 S 35 11 E 3689 96 88 79 7O O5 57 34 9O 0 O0 3 0 0 0 0 0 0 0 0 O0 N 23 86 32 478 10 934 54 1376 14 1800 35 2257 18 2672 O0 3037 0 O0 E 83 S 48 31S 303 19 S 596 25 S 901 39 S 1201 78 S 1502 71S 1837 60 S 2094 0 O0 N 0 0 e 36 E 99 07 E 566 47 E 1108 19 E 1645 02 E 2164 15 E 2711 37 E 3243 87 E 3689 39 S 29 7 E 24 S 32 22 E 37 S 32 33 E O6 S 33 13 E 22 S 33 42 E 83 S 33 38 E 35 S 34 30 E 92 S 34 36 E COMPUTATION DATE' 22-MAR-93 PAGE 5 ARCO ALASKA INC. 1H-O1 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 19-FEB-93 KELLY BUSHING ELEVATION- 96.00 FT ENGINEER' SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 96 O0 196 O0 296 O1 396 O7 496 24 596 52 697 26 798 79 901 51 0.00 96.00 196.00 296.00 396.00 496.00 596.00 696.00 796.00 896.00 -96 O0 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 70O 8O0 0 0 N 0 0 E 0 28 S 13 43 W 0 26 S 18 59 W I 5 S 25 18 E 2 45 S 44 9 E 3 40 S 34 27 E 5 17 S 27 31 E 8 32 S 27 22 E O0 11 28 S 29 27 E O0 14 56 S 28 40 E 0 oo 0 21 0 73 1 63 5 O1 10 66 18 15 30 08 47 51 70 80 0 O0 0 88 0 O0 2 46 3. 22 0 98 3 56 2 40 2 22 3 44 0 O0 N 0 36 S 1 11S 2 22 S 4 71S 9 16 S 15 60 S 26 32 S 41 72 S 62 16 S 0 O0 E 0 15 W 0 33W 0 35 W 1 99 E 5 49 E 9 34 E 14 80 E 23 16 E 34 54 E 0 O0 N 0 0 E 0 1 2 5 10 18 3O 47 71 39 S 22 21W 16 S 16 34 W 25 S 8 59 W 11 S 22 54 E 68 S 30 58 E 18 S 30 55 E 20 S 29 21E 72 S 29 2 E 11 S 29 4 E 1005 98 1112 1220 1331 1444 1559 1674 1792 1910 2029 996 O0 39 1096 62 1196 32 1296 46 1396 17 1496 65 1596 11 1696 55 1796 25 1896 900 O0 18 35 O0 1000 O0 1100 O0 1200 O0 1300 O0 1400 O0 1500 O0 1600 O0 1700 O0 1800 S 30 11E O0 21 15 S 31 44 E O0 23 49 S 32 3 E O0 26 53 S 33 57 E O0 28 49 S 34 49 E O0 29 38 S 33 54 E O0 30 40 S 32 57 E O0 32 19 S 32 56 E O0 32 28 S 32 41 E O0 32 40 S 32 29 E 100 84 137 11 178 44 225 86 278 78 334 97 392 71 454 30 517.73 581.65 3 18 2 34 3 O4 2 38 1 39 0 64 2 O9 0 59 0 28 0 31 88 46 S 119 154 194 238 284 332 384 437 491 49.30 E 101 27 S 29 8 E 57 S 68.07 E 137 71S 89.90 E 178 53 S 115.69 E 226 08 S 145.75 E 279 46 S 177.46 E 335 68 S 209.24 E 393 48 S 242.61 E 454 77 S 277.06 E 518 61S 311.56 E 582 59 S 29 39 E 93 S 30 10 E 33 S 30 44 E 15 S 31 28 E 28 S 31 57 E O1 S 32 10 E 62 S 32 15 E 08 S 32 20 E 02 S 32 22 E 2148 05 1996 O0 1900 O0 32 41 2266 2385 2504 2623 2743 2862 2981 3099 3218 85 2096 50 2196 O1 2296 41 2396 36 2496 92 2596 58 2696 89 2796 O4 2896 O0 2000 O0 2100 O0 2200 O0 2300 O0 2400 O0 2500 O0 260O O0 2700 O0 2800 O0 32 38 O0 32 28 O0 32 36 O0 33 27 O0 33 35 O0 32 48 O0 32 22 O0 32 14 O0 32 5 S 32 28 E 645.75 S 31 58 E 709.85 S 31 37 E 773 63 S 31 31E 837 14 S 32 45 E 9O2 34 S 32 35 E 968 55 S 35 19 E 1034 06 S 35 19 E 1097 93 S 35 24 E 1161 15 S 35 20 E 1224 07 0 21 0 03 0 21 1 22 0 15 0 22 0 73 0 21 0 16 0.25 545.74 S 345 97 E 646 16 S 32 22 E 600.03 S 38O 654.30 S 413 708.58 S 446 763.72 S 481 819.50 S 517 874.07 S 553 926.15 S 590 977.72 S 627 1029.03 S 663 14 E 710 76 E 774 92 E 837 79 E 902 52 E 969 78 E 1034 77 E 1098 35 E 1161 78 E 1224 31 S 32 21E 15 S 32 18 E 75 S 32 14 E 99 S 32 15 E 23 S 32 16 E 74 S 32 21E 52 S 32 32 E 68 S 32 41E 54 S 32 49 E 3335 97 2996 O0 2900 O0 31 53 3453 3572 3692 3811 3930 4048 4165 4282 4399 60 3096 78 3196 58 3296 59 3396 10 3496 20 3596 73 3696 75 3796 45 3896 O0 3000 O0 3100 O0 3200 O0 3300 O0 3400 O0 3500 O0 3600 O0 3700 O0 3800 O0 31 56 O0 33 34 O0 33 13 O0 32 30 O0 32 22 O0 31 52 O0 31 29 O0 31 7 O0 31 11 S 35 2 E 1286 57 S 34 21E 1348 S 34 12 E 1413 S 33 42 E 1479 S 33 22 E 1543 S 35 4 E 1607 S 34 54 E 1670 S 34 47 E 1731 S 35 2 E 1792 S 35 14 E 1852 5O 33 31 82 40 23 98 75 91 0.52 1.25 0.27 0.43 0.29 0.40 0.42 0.47 0 1 . 04 1080 10 S 699 83 e 1287 O0 S 32 56 E 1131 1184 1239 1293 1345 1397 1447 1497 1546 03 S 735 65 S 771 36 S 808 19 S 843 72 S 879 18 S 915 91S 951 76 S 985 96 S 1020 O5 E 1348 50 E 1413 37 E 1479 95 E 1544 77 E 1607 82 E 1670 04 E 1732 80 E 1793 43 E 1853 9O S 33 1E 72 S 33 4 E 69 S 33 7 E 21 S 33 8 E 78 S 33 10 E 58 S 33 15 E 31 S 33 18 E 07 S 33 21E 20 S 33 25 E ARCO AlasKa INC. 1H-01 KUPARUK RIVER NORTH SLOPE, ALASKa COMPUTATION DATE: 22-MAR-93 PAGE 6 DATE OF SURVEY: 19-FEB-93 KELLY BUSHING ELEVATION: 96.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN 4517 05 3996 O0 3900 O0 32 0 4634 4751 4867 4984 5101 5220 5340 5460 5580 74 4096 65 4196 60 4296 09 4396 41 4496 94 4596 90 4696 62 4796 14 4896 O0 4000 O0 4100 O0 4200 O0 4300 O0 4400 O0 4500 O0 4600 O0 4700 O0 4800 O0 31 36 O0 30 44 O0 30 16 O0 31 19 O0 32 13 O0 33 37 O0 33 25 O0 33 18 O0 33 6 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEG MIN FEET S 35 31E 1914 78 S 35 29 E 1976 83 S 35 38 E 2037 37 S 36 14 E 2096 05 S 34 27 E 2155 S 33 25 E 2217 S 32 14 E 2282 S 32 13 E 2348 S 32 12 E 2414 S 31 58 E 2479 79 12 57 77 54 95 DEG/IO0 FEET FEET FEET DEG MIN 0 33 0 5O 0 58 0 77 0 26 3 53 o 11 0 04 0 O6 0 19 1597 41 S 1056.25 E 1915 04 S 33 28 E 1647 1697 1744 1793 1844 1899 1955 2011 2066 92 S 1092.30 E 1977 23 S 1127.45 E 2037 76 S 1161 90 E 2096 57 S 1196 35 E 2155 35 S 1230 75 E 2217 55 S 1265 97 E 2282 60 S 1301 30 E 2348 29 S 1336 38 E 2414 74 S 1371 17 E 2480 06 S 33 32 E 58 S 33 36 E 24 S 33 40 E 95 S 33 42 E 29 S 33 43 E 76 S 33 41E 99 S 33 38 E 79 S 33 36 E 23 S 33 34 E 5699 40 4996 O0 4900.00 32 58 5819 13 5096 5939 47 5196 6O60 34 5296 6180 66 5396 6300 06 5496 6418 80 5596 6537 24 5696 6654.27 5796 6771.20 5896 O0 5000.00 33 42 O0 5100.00 34 3 O0 5200 O0 34 1 O0 5300 O0 33 35 O0 5400 O0 32 44 O0 5500 O0 32 36 O0 5600 O0 31 46 O0 5700 O0 31 9 O0 5800 O0 31 14 6888.13 5996 O0 5900 O0 31 15 7005 09 6096 7121 7238 7354 7470 7586 7702 7817 7880 82 6196 09 6296 16 6396 15 6496 26 6596 26 6696 80 6796 O0 6849 O0 6000 O0 6100 O0 6200 O0 6300 O0 6400 O0 6500 O0 6600 O0 6700 84 6753 O0 31 8 O0 30 51 O0 30 37 O0 30 22 O0 30 33 O0 30 33 O0 30 6 O0 30 3 84 30 3 S 31 56 E 2544 87 S 35 39 E 2610 S 36 46 E 2677 S 37 58 E 2745 S 38 12 E 2812 S 41 11E 2877 S 40 59 E 2940 S 39 22 E 3003 S 38 8 E 3O64 S 38 4 E 3124 71 61 39 18 14 73 83 47 97 S 38 5 E 3185 45 S 38 5 E 3245 S 35 58 E 3306 S 34 33 E 3365 S 34 41E 3424 S 34 22 E 3483 S 34 57 E 3542 S 35 11E 3600 S 35 11E 3658 S 35 11E 3689 97 11 42 34 11 12 90 76 90 0 28 0 41 1 84 0 57 0 48 0 24 0 13 2 95 0 18 0 14 0 O1 0 12 2 21 0 28 0 38 0 26 0 23 1 18 0 O0 0 O0 2121 92 S 1405 51 E 2545 19 S 33 31 E 2176 2230 2284 2337 2387 2435 2483 2531 2579 62 S 1442 78 S 1481 5O S 1522 16 S 1564 45 S 1605 76 S 1647 96 S 1689 62 S 1726 32 S 1764 15 E 2611 46 E 2677 98 E 2745 28 E 2812 81E 2877 81E 2940 10 E 3003 83 E 3064 23 E 3124 O2 S 33 32 E 89 S 33 35 E 62 S 33 41E 34 S 33 48 E 25 S 33 55 E 78 S 34 5 E 85 S 34 13 E 48 S 34 18 E 97 S 34 22 E 2627 04 S 1801 60 E 3185.45 S 34 27 E 2674 2722 2771 2819 2868 2916 2964 3012 3037 78 S 1838 56 S 1875 18 S 1909 71S 1943 12 S 1976 70 S 2009 79 S 2043 15 S 2076 60 S 2094 99 E 3245.97 S 34 31E 65 E 3306.12 S 34 34 E 62 E 3365.43 S 34 34 E 05 E 3424 36 S 34 34 E 37 E 3483 12 S 34 34 E 87 E 3542 13 S 34 34 E 67 E 3600 91 S 34 35 E 93 E 3658 78 S 34 35 E 87 E 3689 92 S 34 36 E RECEIVED d U L - 1 199;] Alaska Oil & Gas Cons. Commissior~ Anchorage ARCO ALASKA INC. 1H-01 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER g 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK a aCt LAST READING BASE KUPARUK A PBll) 7" CASING COMPUTATION DATE: 22-MAR-93 PAGE 7 DATE OF sUrVEY: 19-FEB-93 KELLY BUSHING ELEVATION: 96.00 ET INTERPOLA1ED VALUES FOR CHOSEN HORIZONS ENGINEER: SCHWARTZ SURFACE LOCATION = 732' FNL ~ 1151' FEL, SEC33 T12N RiOE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 4808 O0 7269 O0 7456 O0 7611 O0 7712 O0 7748 O0 7774 O0 7859 O0 7880 O0 4244 53 6322 60 6483 81 6617 30 6704 42 6735 58 6758 09 6831 67 6849 84 4148 53 6226 60 6387 81 6521 30 6608 42 6639 58 6662 09 6735 67 6753 84 1720 48 S 2784 15 S 2862 19 S 2927 O0 S 2968 78 S 2983 58 S 2994 22 S 3029 O1S 3037 60 S 1144 18 E 1918 54 E 1972 31E 2017 08 E 2046 49 E 2056 80 E 2064 29 E 2088 81E 2094 87 E RECEIVED J U L - 1 1993 Alaska Oil & Gas Cons. OommisCD Anchorage ARCO ALASKA INC. 1h-O1 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 22-MAR-93 PAGE 8 DATE OF SURVEY: 19-FEB-93 KELLY BUSHING ELEVATION: 96.00 FT ENGINEER: SCHWARTZ MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK a BASE KUPARUK a PBTD TD SURFACE LOCATION = 732' FNL 2 1151' FEL, SEC33 T12N RIOE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 7269 O0 7456 O0 7611 O0 7748 O0 7774 O0 7880 O0 6322 60 6483 81 6617 30 6735 58 6758 09 6849 84 6226 60 6387 81 6521 30 6639 58 6662 09 6753 84 2784 15 S 2862 19 S 2927 O0 S 2983 58 S 2994 22 S 3O37 6O S 1918 54 E 1972 31E 2017 O8 E 2056 80 E 2064 29 E 2094 87 E FINAL WELL LOCATION AT TI:): TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 7880.00 6849.84 6753.84 3689.92 S 34 36 E DIRECTIONAL SURVEY COMPANY FIELD ARCO ALASKA INC. KUPARUK RIVER WELL 1 H-01 COUNTRY RUN USA ONE DATE LOGGED 20 - FEB DEPTH UNIT FEET - 93 REFERENCE 93084 RE(ZEIVED J U L - 1 1993 Alaska Oil & Gas Cons. CommissiOn Anchorage All Interpretations are opinions based on inferences from electrical or other measurements and we ~ar~.~"~)-'~0~ ' ' guarantee the accuracy or correctness of any interpretations, and we shall not, except in the case of gross or wllfull negligence on our part, be liable or responsible for any loss. costs, damages or expenses incurred or sustained by anyone resulting from any interpretation made by any of our officers, agents or employees These interpretations are also subject to our (3eneral Terr~s and Conditions as set out in our current price Schedule. WELL: (732' 1H-01 FNL, 1151' FEL, SEC 33, T12N, RIOE, UH) HORIZONTAL PROJECTION NORTH 3000 2000 1000 - 1 OOO -2000 -3000 -4000 SOUTH -5000 -3000 WE~gT REF 93084 SCALE = I / 1000 IN/FT :::: :::: :::: :::: :;::,:::: :::: :::: :::: :.::.::::::: .... ::::,:::: :::: :::: :::: ::.: :::: :::: :::: :: ....... :::: .::: :::: :::; :;:: :::: :::: :::: .::: :::: :::: ::::,.::. ...... ~ '': :::: :::: :::: :::: :::: :::: :::: :::: .::. .::: .. ::. ..................... ..................... ................................... ........................................... :::: :::: ::::::::. .:.:.:::::: :::: :::: ii: .. :.. :~!:,!i:: i. -2000 -1000 0 1000 2000 3000 4000 5000 EAST RECEIVED JUL, - 1 1993 Alaska Oil & Gas Cons. bu~tn~SStO" Anchorage WELL- 1H-O1 (732' FNL, 1151' FEL, SEC 3.3, T12N, RIOE, UI4) VERTICAL PROdECTION 326.00 -2000 -1000 0 0 1000 2000 3000 4000 5000 6000 ........ . .:..~.., ,...,..,.,. :,,~ ,::: iiii'i'ili i~'[SOi)Oi'ii,ii'i; iii! ,, , , .!...!...!.!...!.!...~...! ..... !...)...!...! ..... !...!...!..!..~..!.!..! .... !...!...!...! ...... !!...!..! ...... !...!..!..! !..!..!.!..!..!.!.! !.!.! ~..,~..!..! ...... !...!.!..! !.~!! i ....... , i. i .~ i ! i i ~ : ~ ..... i i i'i i'!' i'i'i i i : i i ' ! i !'i ! i : ! i ' : ; ; :"i ..... i" i ..... ! ............ : :: ..... : i i : : ~ ~ ' ~ ' : ~ :1000( : : : ; ! : i i ! i ! ! ! i ! : i : : ~ i . : : i i : : ; ; i i . i ! ; i i ~ i.i !...!.!.!..! i-i.i i-i i..-i... ! i-! !- !.! ! i i-i ! i i i.:i , i i i i ! :.i. : , ~ , i.i i ! i i. !.i ; i. ~-i-..i.i i..!..!..i...i..! i..! .; : i.i. ! i i.i i i i i i ! : : . : : i i i t ~ : : : · .......... ........ :: ...... : :.:..-:.--:..---:-..:.--:-..: ...... :-:..:-.:-.-: .......... :.:.:--:-: :.:.-:.: !.:,!..i,.i.::.:! :::: i~ i.:i i.. i ;'; i' i'iT!'i'"i"i !'i'i"!'!'i'i i';"i'! i'i i ! ! ; ; i ; i ; ~ i i'i'; ; · : : : : : : · · : , . · i--i..-i.-!'--.i-'.i..-i--! ..... i..i...L..i.....L..i..i...L..i...i.L.i ..L..i...L..L.~...i...iL..:..i.: ..... i ..... ~.i...;.. :~.i i...i...:..i : i .......... ;.; ................ · ::::,:.:: .::: :::: :::: :t: :: : : i-.~.--i--i-~-i---i--i---i ..... i---~.--i...i-.i--!.-~.-i---~ .... ~...!..-!..-~-!-.-~-~-!..;-.i-..~.-~..i .-i-i--i.-i .... i...i.~.i~-~i, :..~..~.~ ::..~ ~..~..~ ..... i ! ! i ~ i-i i-i .... ! i..i..i .... i..i.i.i...i i i ! i.! ! ! , i i i i : 14e. 00 PROJECTION ON VERTICAL PLANE 326.00 148.00 SCALED IN VERTICAL DEPTHS HORIZ ,SCALE = I / lO00 IN/FT AOGCC GEOLOGICAL MATERIALS INVENTORY LIST PEFlldlT/I~,~} - (~)~/~ WELLNAME k/~C} ///~/ COMPLETION DATE _._~. ~;~t. ~ CO. CONTACT ' check offer list data as' it' i'S recei~'~l.*l'ist received date for 407. if not reqUired fist as NFl 4o7' I * ?///~ ~/ drilling hi'ston/ ~,~'-~."'~VI'"] w~. tests ~e des'criPtio~/A COred interval~ ,/,, ,COre a,,nalysis ~/~ L._ dry ditch InterValS ' dleital~ata ' - ,,,,1,,,[,,, ,, , [ [ i ~ [ , [ , [ J , ,,, [llll[ , ,Jl, [ [ 11 , , [ [ [ , ] [ [ 11 I I I L J 11 I I ] I Il I ] [ LOG TYPE RUN INTERVALS SCALE NO. (to the nearest foot] , ~ linch/100'! , , . ] .il,ill, I.,lJI Il ] ~! .ill ~l ~t.k,',O Or~ l~, lilt[ . . .................. L I I IlIilIlI I I I I II I I I II . Il IIIll Iii I Ii I I I I I Ii I J I t I Ii t .J II II I I I I II I I I I I I ii! ................. II I I I I II I I Ii J I J , Ii I II II~ [ I I I I LII I I II I ~JJ ~ [ Il II I 111 I I I . I!lll I Il II I I II J I I I II I JII II I Ill Il I I I I ALASKA OIL AND GAS CONSERVATION COMMISSION TO: Dave Johnsto~ Commissioner~'-- THRU: Blair Wondzel P.I. Supervisor FROM: ~ Grimaldi Petr. Inspector DATE: 6-7-93 SUBJECT: RigXBope imp. Nordic Arco well 1H-I Kupamk River field P~93-6 MONDAY 6-7-93 1 traveled to Arcos 1-H pad in the Kupantk river field to make a Rig~ope inspection on Nordic fig #1. Nordic rig #1 is presently running completion's on 1-H pad. I found the fig to be in good shape with all equipment in place and in apparent good condition. The area surrounding the fig and camp was _~ .......21_ ..J...! ......... :_l'... _ clean anu orueny provmtng for ' '-" ........ ~'"- "-" ' ' ......... ' .......... -' '- goou access, Doll ~reuen ~,~.rco rep.) conveyeu to file that iL ia one of his toppriority's. This pad has 15 more completion's. S ,UMMARy:' I made a RIGXBOPE inspection on Nordic rig #1 completing wells on I-H pad in the Kuparuk River field. ARCO Alaska, inc. Date: April 30, 1992 Transmittal #: 8725 RETURN TO: ARCO Alaska, inc. Attn: Nikki Stiller Kuparuk Operations File Clerk ATe-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the followin~..._,.,pen items. acknowledge receipt and return one signed copyot tl3is transmittal. Please ~~1 H.15 1H-15 ~~-~11H'02 H-02 H-20 CDR-LWD/Depth Corrected CDN-LWD/Depth Corrected CDN-LWD/Depth Corrected CDR-LWD/Depth Corrected CDN-LWD/Depth Corrected CDR-LWD/Depth Corrected CDR-LWD/Depth Corrected CDN-LWD/Depth Corrected 1/15-21/93 1/15-21/93 2/2-5/93 2/2-5/93 1/26-29/93 1/26-29/93 12/21-27/92 1 2/21-27/92 5945-10332 5945-10332 4458-8090 4458-8090 4838-7880 4838-7880 3973-10300 3973-10300 Receipt Acknowledged: Date: DISTRIBUTION: D&M Drilling VendorPackage( Johnston) NSK State of Alaska(+Sepia) £C£1V£D ARCO Alaska, inc. Date' April 2, 1993 Transmittal #: 8701 RETURN TO: ARCO Alaska, Inc. Attn: Nikki Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 q2--" I'~ -1H-17 (:j~ .-- C) 5 ..,1 H- 1 5 Transmitted here with are the following items. one signe.~opy of this transmittal. --1 H-1 6 ~E-.-.~ LIS Tape and Listing cl%.-cl'~ --2M-04 ~-~%"/[ c/2.-'7~ .,- 2M-09 ~ ol?...lO5 --2M-01 Please acknowledge receipt and return 01-10-93 CDR/CDN & Enhanced Resolution CDR LIS Tape and Listing 01 - 1 5 - 9 3 CDR/CDN In 2 Bit Run LIS Tape and Listing 0 2 - 2 0 - 93 CDR/CDN in 2 Bit Runs. 1 Mad-Pass & Resistivity --.1 H-2 0 ~%'77.. LIS Tape and Usting 1 2- 2 7,-9 2 CDR/CDN In 3 Bit Runs. Phasor Enhanced cf.~ .--O~ -1 H- 01 ~'7i~,LIS Tape and Listing 01- 2 9 - 9 3 tCDR/CDN in 2 Bit Runs/Enhanced Resistivity ct'~,---0~'------1 H - 0 2"~'~%Lob LIS Tape and Listing 0 2 - 0 5 - 9 3 CDR/CDN & QRO Enhanced Resistivty LIS Tape and Usting 0 9 - 2 6 - 9 2 CDR Data from Bit Runs 1 & 2/HLDT/LDWG Format LIS Tape and Usting 0 8 - 1 8 - 9 2 CDR/CDN 1 Bit Run in LDWG Format & HLDT Data LIS Tape and Listing 1 0 - 2 9 - 9 2 CDR Bit Runs I & 2/Hi Resolution CDR Processed HLDT & 3 Passes CNTG 93013 93O07 93038 92735 93O45 93O56 92586 · 92511 92640 ReCeipt Acknowledged' - ............................ Date' - ......... · DISTRIBUTION: Bob Ocanas State of Alaska 'RECEIVED APR 0 2 199 Alaska 0il & 6as Cons. Commission Anchorage ARCO Alaska, Inc. Date: March 26, 1993 Transmittal #: 8697 RETURN TO: Transmitted here with are the following items. one signed copy of this transmittal. ARCO Alaska, Inc. Attn' Nikki Stiller Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Please acknowledge receipt and return --1H-01 .. Sub-Surface Directional' SurveY Sub-Surface Directional Survey Sub-Surface Directional Survey Receipt Acknowledged: DISTRIBUTION: 02-20-93 02-20-93. - 02-19-93 D&M State of Alaska (2 copies) 93077 93085 93084 Date' /~LC'CE/VED S 0 1993 ALASKA OIL AND GAS CONSERVATION COMMISSION January 20, 1993 A. W. McBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 WALTER J. HIGKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Re: Kuparuk River Unit 1H-O1 ARCO Alaska, Inc. Permit No: 93-06 Sur. Loc. 732'FNL, ll51'FEL, Sec. 33, T12N, R10E, UM Btmhole Loc. 1446'FSL, 975'FWL, Sec. 34, T12N, RiOE, UM Dear Mr. McBride: 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 agenoies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF T~ COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~) p,inled on recycled paper b y C. I~. STATE OF ALASKA . ~,,,~ OIL AND GAS CONSERVATION COMMIS~,,,..61 PERMIT TO DRILL 2O AAC 25.OO5 1 a. Type of Work Drill X Redrill ri 1 b Type of Well Exploratory m-J Stratioraphic Test r-J Development Oil X Re-Entry ri Deel~n J-J Service ri Development Gas J-J SinoleZone J-J Multil:JleZone X 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 96', Pad 54' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchoracje, AK 99510-0360 ADL 25639~ ALK 464 4, Location of well at surface 7. Unit or property Name 1 1, Type Bond (see 20 AAC 25,025) 732' FNL, 1151' FEL, Sec. 33, T12N, R10E, UM Kuparuk River Unit Statewide At top of produclJve interval (@ TARGET ) 8. Well number Number 1745' FSL, 770' FWL, Sec. 34, T12N, R10E, UM 1H-01 #U630610 At total depth 9. Approximate spud date Amount 1446, FSL, 975' FWL, Sec. 34, T12N, R10E, UM 01/22/93 $200,000 1 2. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) prope~ ~ine 1H-02 (Proposed) 7,994' MD 1446 ~ TD feet 15.4' ~ 825' MD feet 2560 6,921' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 500 feet Maximum hole an¢lle 33°. ~-= Maximumsu~face 2,520 Ds~ ^t mm~ demh (TVD~ 3,139 ~'~ 18. Casing program Setting Del~h size Specifications Top Bottom Quantibj of cement Hole Casing , Weight Grade Coupling Length MD TVD MD TVD (include stage data} 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +P00 CF 12.25" 9.625" 36.0# J-55 BTC 4,786' 41' 41' 4,827' 4,256' 600 Sx Permafrost E & 420 Sx Class G 8.5" 7" 26.0# J-55 BTCMOE 4,866' 41' 41' 4,907' 4,323' HF-ERW 8.5" 7" 26.0# J-55 BTC 3,087' 4,907' 4,323' 7,994' 6,921' 210SxClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ~u°r~dacU;t°rRECEIVED Intermediate Production ~ h Perforation depth:measured Alaska 0ii & 6as Cons. true verticalAnchorage 20. Attachments Filing fee X Property plat r-i BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot r'l Refraction analysis r-I Seabed report r'l 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Si~ned _ _/~./~~ ~ Title Area Drillincj Engineer Date Commission Use Onl)/ / / ,, Permit Number I APlnumber I Approval date I See cover letter for ~;~,.~ -0~" 50- 0 .~-~? - 2~ ~_. '~' .~ / -~.~, ~_~ -"~.,r~ other requirements Conditions of approval Samples required D Yes ]~J No Mud Icg required D Yes .]~ NO . drooen u,,de measures E! Yes No rec,ona. surve reouired Yes El No Required working pressure forBOPE J-J 2M J~j 3M ri 5M ri 1OM ri 15M Other: Approved b]f [-~a¥,id W. J~hnston Commissioner the commission Date ...... o , , 10. 11. 12. 13. 14. 15. 16. 17. 18. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1H-01 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4,827')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (7,994') 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.) Pressure test to 3500 psi. ND BOPE and install lower production tree assembly. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVED JAN 1 2 3993 Alaska Oil & Gas Cons. Co~t~jsSiOr~ Anchorags Casing Design/Cement Calculations 12-Jan-93 Surface Csg MD: Surface Csg TVD: Production Csg A MD: Production Csg A TVD: Production Csg B MD: Production Csg B TVD: Top of West Sak, TMD: Top of Target, TMD: Top of Target, TVD: Estimated Mud Weight: Surface Casing Choice: Production Csg A Choice: Production Csg B Choice: Production Casing Frac. Pressure 4,827 ft 4,256 ft 4,907 ft 4,323 ft 7,994 ft 6,921 ft 4,093 ft 7,322 ft 6,356 ff 9.8 ppg 3,500 psi Maximum anticipated surface pressure TVD surface shoe = 4,256 ft {(13.5'0.052)-0.11}*TVDshoe =1 2,520 psil Estimated BH pressure at top of target zone Anticipated Mud Weight = Top of Target Zone, TVD = 100 psi Overbalance - =1 9.8 ppg 6,356 ft 3,239 psi 3139 psiJ Surface lead' Top West Sak, TMD = 4,093 ft Design lead bottom 500 ft above the Top of West Sak = 3,593 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 1,125 cf Excess factor = 15% Cement volume required = 1,294 cf Yield for Permafrost Cmt = 2.17 Cement volume required =1 600 sxI Surface tail: TMD shoe = 4,827 ft (surface TD - 500' above West Sak) * (Annulus area) = 386 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4340 cf/If Cmt required in casing = 35 cf Total cmt = 421 cf Excess factor = 15% Cement volume required = 484 cf Yield for Class G cmt = 1.15 Cement volume required =1 420 sxI RECEIVED Casing Design/Cement Calculations 12-Jan-93 Production tail: TMD = 7,994 ft Top of Target, TM D = 7,322 ft Want TOC 500' above top of target = 6,822 ft Annulus area (9" Hole) = 0.1745 (TD-TOC)*Annulus area = 205 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.2148 Cmt required in casing = 17 cf Total cmt = 222 cf Excess factor = 15% Cement volume required = 255 cf Yield for Class G cmt = 1.23 Cement volume required =1 210 sxI -. Surface (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud TENSION - Minimum Desion Factors are: T{ob)=l.5 and T{is)=l.8 _ - Casing Rated For: Length = Casing Wt (lb/E) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =1 564000 lb 4,827 ft 36.00 Ib/ft 173772.0 lb 25197.4 lb 148574.6 lb 3.81 Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/E) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ 639000 lb 4,827 ft 36.00 Ib/ft 173772.0 lb 25197.4 lb 148574.6 lb Production A (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =1 415000 lb 7,994 ft 26.00 Ib/ft 207844.0 lb 30720.3 lb 177123.7 lb 2.3J Production A (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ RECEIVED 490000 lb 7,994 ft 26.00 Ib/ft 207844.0 lb 30720.3 lb 177123.7 lb :2.8] Casing Design / Cement Calculations Production B (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/fi) = Dead Wt in ,Air = Buoyancy = Tension (Pipe Body) = Design Factor =[ Production B (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 =[ BURST-Minimum Design Factor= Surface Casing: Casing Rated For: Burst = Maximum surface pressure J/~,~ 'J 2 ~,993 Max Shut-in Pres Design Factor ~la$~a Oil .& Gas Cons. Commission, Production Csg A: 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 Production Csg B: 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 - Minimum Design Factor = 1.0 Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' TVD 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 =1 Production Csg A 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 =[ Production Csg B 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 =1 12-Jan-93 415000 lb 3,087 ft 26.00 Ib/ft 80262.0 lb 11863.1 lb 68398.9 lb 6.1J 490000 lb 3,087 ft 26.00 Ib/ft 80262.0 lb 11863.1 lb 68398.9 lb 7.2J 3520 psi 2519.6 psi 1.41 4980 psi 5703 psi 2001 psi 3702 psi 1.3J 4980 psi 7027 psi 3203 psi 3824 psi 1.31 2020 psi 0.510 Ib/ft 1233 psi 1 .Si 4320 psi 0.510 Ib/ft 2203 psi 4320 psi 0.510 Ib/ft 3527 psi 1.21 Casing Design / Cement Calculations 12-Jan-93 Surface Casing Choices OD ID Ib/ft Grade Metal X-Section I 9.625 8.681 47 L-80 13.5724 sq. in. 2 9.625 8.835 40 L-80 11.4538 sq. in. 3 9.625 8.921 36 ~J-5~5 10.2545 sq. in. 4 10.750 9.950 45.5 J-55 13.0062 sq. in. Jt Strength Body Strength Collapse Burst 1161000 lb 1086000 lb 4750 psi 6870 psi 979000 lb 916000 lb 3090~psi 5750 p~i 639000 lb 564000 lb 2020 psi 3520 psi 931000 lb 715000 lb 2090 psi 3580 psi Production Casing Choices OD ID I b/ft Grade Metal X-Section Jt Strength I 7.000 6.276 26 L-80 7.5491 sq. in. 667000 lb 2 7.000 6.276 26 J-55 7.5491 sq. in. 490000 lb Body Strength Collapse Burst 604000 lb 5410 ,psi 7240~psi 415000/Ib 4320~ psi 4980 psi RECEIVED Created by ' jones For: ~T~S / S-'TOLTZ Doie plotted · 31-Dec-92 Plot Reference is 1 Version #4. Coordinates (:re in feet reference slot #1. ~ True Vertical Depths are reference wellheod.i 300 0 300 600 900 1200 _ 1500_ . 1800. ' 2100. _ - 27~_ - - - 36~ _ _ 39~_ _ _ _ _ 5~_ _ 5700. _ . 6900. 72~ RKB ELEVATION: 96' ARCO ALASKA, Inc. Structure : Pad 1H Well : 1 Field : Kuparuk River Unit Location : North Slope, Alaska JSURFACE LOCATION: J 7,32' FNL, 1151' FEL SEC. ,3.3, T12N, R10E Scale 1 : 100.00 0 200 I 1 I I KOP TVD=500 TMD=500 DEP=O 6.00 12.oo BUILD 5 DEG / 100' 18.oo 24-.00 ,30.00 EOC TVD=1551 TMD=1590 DEP=$02 B/ PERMAFROST TVD=1622 TMD=1697 DEP=$61 T/ UGNU SNDS TVD=5096 TMD=`34-49 DEP=1506 S 34.4~ DEG E 3398' (TO TARGET) Easf --> 400 600 800 1000 1200 1400 16001800 I II II II II II II II T/ W SAK SNDS TVD=5658 TMD:4093 DEP=1654 B/ w SAK SNDS TVD=¢056 TMD=4589 DEP=1922 ~X\',¥ 9 5/8" CSG PT "~. TVD=4256 TMD=4827 DEP=2051 k,x A/B MODIFIED CSG PT AVERAGE ANGLE ~, TVD=4525 TMD=4.907 OEP=2094 3;8.68 DEG ~ K-lO 'i¥D=4566 TMD=5195 DEP=2250 ~ ~ J TARGET LOCA11ON'. J SEC. ,34, T12N, RIOE · TARGET ~ TVD=6356 N, TMD=7322 ~ DEP=3398 SOUTH 2805 EAST 1921 K-5 1%'0=5891 TMD=6769 DEP=3100 TARGET - T/ KUP SNDS TVD=6356 TMD--?3~ DEP=3398 \ T/ ZONE C TVD=6`391TMD=7363 DEP=3421 ~,X ~X ~ T/ ZONE A TVD=6655 TM0=7677 0EP=,3590 B/ KUP SNOS TVD=6753 TMD=7794 OEP=565,3 I i I I i I I I I I I I i I I I I i I I i I I I I 0 300 600 900 1200 1500 1800 2104:1 2400 2700 3000 $300 3600 Scole 1 : 150.00 Yerficol Secfion on 145.$8 ozlmufh with reference 0.00 N, 0.00 Ir from slot ~1 i I I 20OO I I 22OO ~ J _2000V ~2200 ~2400 ~2600 TD LOCATION: 1446' FSL, g75' FWL SEC. 34, T12N, R10E RECEIVED Alaska Oil & Gas Cons. 7 6 1. 16' - 2000 PSI STARTING HEAD 2. 11' - 3000 PSI CA~NG HEAD 3. 11' - 3000 PSI X 13-&t6, - ~-r'000-- PSI SPACER SPCX3L 4. 13-5/8' - 5000 PSI PIPE RAIDS 5. 13-5/8" - 5(XX) PSI DRLG SPCX:)L W/ CHOKE AND Kill UNES 6. 13-5/6, - ~ P~ ~~ ~M W/ PiPE RAMS ON TOP, BUND RAMS ON BTM 7. 13-5/6, - 5000 PSI ANNULAR ACCU~TC~ CAP,N?,rI~ T~ST 1; CHECK AND FILL ACCUMULATOR RESERVOIR TO PI:IC3PER LEVEL WITH HYDRAULIC FLUID. 2. ASSU~ THAT ACCUMULATOR PRES~tJRE IS 3000 PSI ~ 1500 ~ I:X3WNSTREAM OF THE REGULATOR. 3. C~SERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND ~ THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHAR~NG PUMP OFF. 4, ~ ON THE IADC REFIORT. THE ACCEPTABLE LOWER UMIT IS 45 SEC, ONDS ~NG TIME AND 1200 PSI REMAINING STACK TI~ST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL 2. CHECK THAT ALL ~ SCREWS AJ~ FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK~ SCI::IEW~ IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPAS~ VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSi AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO,%300__ ~ AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSJ. 5. OPEN ANNULAR PREVENTOR AND MANUN. kaLL AND CHOKE LINE VALVES. CLOSE TOP PIPE RA,M~ AND HCR VALVES ON KILL AND CI-K3KE UNES. 6. TEST TO 250 PSI AND ~._-1000__ PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, UNES, AND CHOKES WITH A 250 PSI LOW AND 3(XX) PSt HIGH. TEST A~ IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLO~NG I:K3SITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE Bo'FroM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSi AND 3(XX) PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BUND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO ~ PSI. 12. TEST KELLY CC~KS AND INSIDE BOP TO 3(XX) PSi WITH KOOMEY PUMP. 13. I:IECORD TEST INr--ORMATION ON I~t..OWCXJT PREVENTER TEST FORM ~ AND SEND TO DRIUJNG SUPERVISOR. 14. PERFORM COMPLETE BOPE~ONCEA WEEKAND FUNC~Y OPERATE BOPE ONLY. f SRE DRILLING FLUID PROGRAM Well 1H-01 Spud to 9-5/8" surface casing Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 9.0-10.5 15-25 15-35 45-75* 5-15 15-4O 10-12 9.5-10 +10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System' ' I ~ 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 See Well Plan 10-18 8-12 35-50 2-4 4-8 4-5 thru Kuparuk 9.5-10 <12% 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/ff. This shows that formation breakdown would occur before a surface pressure of 2,516 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 1H-01 is 1H-02 (proposed). As designed, the minimum distance between the two wells would be 15.4' @ 825' MD. The wells would diverge from that point. Incidental fluids developed from ddlling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well ddlled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 55-75 sec/qt to drill gravel beds. Adjust FV to 45-55 sec/qt below gravel beds. ~' KUPARUK RIVER U~i ~_T 20" DIVERTER SCHEMATIC si 6 4 J5 5 3 2' 1 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION . UPON INmAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WEII RORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASK~ INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FFIOM 20AAC25.035(b) 1. 16' CONDUCTOR 2. SUP~)N WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16'- 2000 PSI BALL VALVES 4. 20' - 2,000 PSI DRILLING SPOOl. WITH TWO 10' OUTLETS. 5. 10' HCR GATE VALVES WITH 10' DIVERTER LINES, A SINCd. E VALVE OPENS AUTOMATICN. LY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROl. LED TO ACHIEVE DOWNWIND DIVERSION. 6. 20'-2000 PSI ANNULAR PREVENTER ~ ~ '~" ~ ~V '~ ~ ULP 8/14/91 rtl <-- West Scale 1' 50.00 1 400 1550 1500 1250 1200 1150 11 O0 1050 1000 950 900 Nil i~§00 Proposed Well ~1/2/1 900 ~ 2900 ~°~~oo ~4oo 1 ~00 ~°°~°~oo ,,oo ~oo ~o~ 700 900 25001 ~00 1100 3100 1300 1500 5OO o 550 '-' - 0 · 0 600 o _ 65O _ 700 0 E - ' I _ 750 ~ - I _ 800 J - V _ 850 _ 9OO _ 95O _ 1000 Wesf Scale 1 ' 50.00 1050 1000 950 900 850 800 750 700 650 600 150O 300 4300 4500 4700 4900 5100 5300 5500 O8oo O0 7O0 ARCO ALASKA, Inc. $truc~re : Pod 1H Proposed Well #1 / 15 field: Kuparuk I~rEr Unit Loootlon: North SlopE, Alo~ka 65O 70O 750 8OO _ 850 _ 9OO _ 95O _ 1000 _ 1050 1100 1150 12OO 0 i I RECEIVED JAN 1 2 ~99~ ,Alaska OJJ & Gas Cons. Commission A~lchorag~ 1H-1CI./tT.XLS S~:ate: Well: Field: State Permit ,4,&~,~,~ KLIPARLIK 9.9.86 Work Sheet: Date: Vo,~e L?atculations 1/18,t'33 Casing Type Casing Size -Inches Casing Length - Feel Hole Diameter -Inches Cement- Sacks 111 Cement-Yield 111 CemenI - Cubic f{ 111 Cement- Cubic It111 Cement- Sacks 112 Cemerd - Yield 112 Cement- Cubic ft112 Cement- Cubic ~ ~2 Cern[ - Sacks ~3 Cemer~ - Yield ~3 Cemen~ - Cubic (~ ~3 Cemen~ - Cu~c ~ ~3 Cement- Cubic it / Vol Cement - Fill Factor Conduclor 16.000 80.000 24.000 0.000 0.000 0.000 200.000 0.000 0.000 0.000 0.000 200.000 1.432 Surface 9.625 4,786.000 12.250 GO0.OOO 2.170 1,302.000 1,302.000 420.000 1.150 483.000 483.000 0.000 0.000 0.000 0.000 1.785.000 1.191 Line~ 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 ~DIV/O! Casing Type Casing Size -Inches Casing Depth - Fee{ Hole Diameter-Inches Cement- Sack~ 111 Cemenl - Yield 111 Cement- Cubic ft~1 C~ent - Cubic ~t~1 C~- S~k~ ~2 Cemen~ - Yield ~2 Cemen~ - C~ic R ~2 Cement - Cubic ~[ ~2 Ce~n~ - Sack~ ~3 Cement - Yield ~3 Cement - Cubic R~3 Cement - Cubic ~~3 Cement- Cubic ft /Vol Cement-Interval ft Top of Cement- Feet Intermediate 111 O. O00 0.000 D. OOO O. O0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ~IDIV/O{ ~DIV/O! IN:ermediate 112 O. OOO 0.000 O. O00 0.00 0.00 0.00 0.00 0.00 0.00 O. O0 0.00 O. OO 0.00 O. O0 O. O0 0.00 11DIV/O{ IIDIV/O{ Production 7.000 7,994.000 8.500 210.00 1.23 258.30 258.30 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 258.30 2,036.96 5,957.0 lvle~sured Depth ! State: Alaska Borough: Well: 1H-01 Field: Kuparuk River St. Perm # 93-06 1H-OI.XLS Date 1/18/93 Engr: M. Minder Casing interval Interval Size Bottom Top Length Description Description Description Tension lA 16 121 41 2.A. 9.625 4256 41 3A 7 6921 41 4A 0 0 0 5A 0 0 0 6A 0 0 0 7A 0 0 0 8A 0 0 0 9A 0 0 0 !0A 0 0 0 0 0 0 0 0 0 0 Lbs Grade Thread Lbs 62.5 H-40 WELD 0 36 J-55 BTC 0 26 J-55 TC MOD 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 lB 219 3B 4B 5B 6B 7B 8B 9B 1 OB Mud Hydraulic Collapse Wieght Gradient Gradient ppg psi/ft psi/ff 9.0 0.468 0.368 10.0 0.520 0.420 9.9 0.515 0.415 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -.0.1 O0 0.0 0.000 -0.1 O0 0.0 0.000 -0.1 O0 0.0 0.000 -0.100 Maximum Minimum Pressure Yield psi psi BDF N/A 1640 ####### 2530 3520 1.4 2530 4980 2.0 0 0 #DIM/O! 0 0 #DlVi0! 0 0 #DIV/O.I 0 0 #DIV/O! 0 0 #DN/0! 0 0 #DiVl0! 0 0 #DIV/0! Tension Strength K/Lbs 1C 5 2C 172.296 3C 207.844 4C 0 5C 0 6C 0 7C 0 8C 0 9C 0 10C 0 K/Lbs TI)F 736 147.20 564 3.27 415 2.00 o #DIV/O! 0 #DiV/O! 0 #DIViO! 0 #DIV/0! 0 #DIV./O! 0 #DIV./O! 0 #DIV/O! Collapse Collapse Pr-Bot-Psi 45 1788 2871 0 0 0 0 0 0 0 Resist. CDF 670 15.047 2020 1.130 4320 1.505 0 #DIV./O! 0 #DIVIO! 0 #DIV./0! 0 #DIVI0! 0 #DIVI0! 0 #DIVI0! 0 #DIV/0! ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ::* APPROVE DATE [. thru (3) Admin ~ //)/.~?//~'¢ Ztl~ru :~3 ]- - [ 10 & 13] [14 thru 22] Company 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ [23 thru 28] (6) Other [29 thru 31] . 10. 11. 12. 13 14 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. geology' engineer i n9.'~ DWJ MT~ RAD l) ~-7_o RPC~_ BE~ JDH~ LG rev 12/92 jo/6.011 29. 30. 31. 32. 33. Does operator have a bond in force .............. ' .................... Is a conservation order needed ....................................... Is administrative approval needed ..................... . ............... Is lease ntrnber appropriate .........................................: ~ Does well have a unique name ~ number ................................ Is conductor string provided . Lease & Well YES NO Will surface casing protect al 1 zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all knov~ productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wel l bore separation proposed ............................. Is a diverter System required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~Oo psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... REMARKS FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone number of contact to supply weekly progress data ...... Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Additional MERIDIAIxJ' // remarks' UM WEL~ TYPE' Exp/Dev Inj. , Redrill Rev o -I -rz ~0 c,-~ -I 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. * ****************************** COMPANY NA~ : ARCO ALASKA FIELD ~A~E : KUPAR!JK NIVER FO~OUGH : MORT}'{ SLOPE STATE : ~LASK~ ~PT NI.!~;R : 50-0~9-22330-00 REF~;~ENCE NO : 93n45 RECEIVED APR 02 1995 Alaska Oil & Gas Cons. Commission Anchorage ?aVe Verification Listin~ cblumberger Alaska Comput. in~ Center 3-MAR-1993 ~]:5~ **** REEb NEAD~R D.ATF : 9310~/ 3 O~I~IN : FL!C CONTINUATION ~ : P~EV!O!.JS REEL : : . R~VER ~NIT,!H-0!,50-029-22330-00 CO~EMT ARCO A!,ASKA, INC ,KUPARUK ~I' **** TAPE HEADER **** SERVICE NA~E : EDIT D~TF : ~3/03/ 3 OmI~IN : ~b~C TAPF.NA~E : 93045 CONTINUATION ~ : ~ P~VIOUS TAPE : CO~ENT : ARCO KUPARUK RIVER 0NIT ~WD/PAD hOGS A~I MUMBE~: OPERATOR: LOGCING T~ CREATION DATE: JOB DAT~ ,JOB MUgBER: LOGGI~G ENGINEER: SURFACE LOCATIOW SECTION: TOWNSHIP: P~NGE: FNL: F[,EVAT~O~(FT FPOM ~SL O) KELI,Y DER~!CK FLOOR: ~FLL CASING RECORD BIT ; o4s LEV.AD B~RRY ~$T STRING ~iO STRIgG !H'0t 500202~3000 ARCO ALASK.~, liNC. SChLUMBErGER wELL SERVICES 03-MAR-9] BIT RU~! 93045 LEVAD R~RRY 33 732 t151 96.00 96.00 54.00 {]PEN H[ILE CASING 9PlL!,ERS ~IT $lZF (I~) SIZE (IN) cblumberoer Alaska Comput!~q Center 3RD STRIMG PRODUCTION STRING FIEbD ENGINEER'S ********** RUN I ********** ~!T TO R~S 65.4' IT TO GR 75 8 , TO DEb!' 133 BIT TO NEIIT' 14.6.~' "DR!LI.,FD !M~ERVAL 4828' TO 769~, ********** a~ ~ ********** ~IT TO NEUT,B,.6~ WASH~OWN I'N} ~VA[,~ 7624' TO 76~4 DRILLED ~'MT~.RVAL 9694' TO 7880 . TD M 01634 O~ 29-dAN-93. ~TRI~ DE~,I$ITY 2 65 (OM/CC). WLUID DENSITY TO ~tJD SYSTE~, DATA FRO~ DOWNHOLE ME~'ORY. SOFTWARE VERSION V4.0C, $ $ **** FILE HEADER **** FILM NA~E : EDIT .001 v~Slo~ : 0o1~o7 ~AX REC SIZE : !024 FILE TYPE : bO LAST FILE : PAGE · EDITED ~E~E[) ~Wg De~th ~hifted and cl{pped curves; all bit runs merqed. DEPTH [MC~E~EMT 0.5000 # wRU TOOL CODE START DEPTH CDR 4~29.0 B~SFLINE CUNVE FOR SHIFTS: GR C~!RVE S~IFT D~I~ (~E~SI~ED DEPTM) ~SELI~E DEPTH 7667.5 7654.0 76]6.5 7605.5 7564.0 7509,5 STOP DEPT~ 787~.0 767~.5 7&65.0 7647.5 761R.0 7574.0 7520.0 chlu~ber~er A!as.~a Co~put~n~ Center ]-,'e{.aR-,199~ 1t:54 ...PA ~E: 7505, 7463, 7456, 7.437. 7405, 7381, 373. 7316. 295, 7253. 718!. 7~.50 7120 7099 7084 7011. 6963 ~9~7. 6920, 6R 57. 68oa 6702. 66e~, 6646 6594. 6509. 6460. 638~. 6334. 6296. 6264. 622~. 6~9~. 6~57: 6~15. 6060. 6038. ~007. 5996. 7516,0 7.472,5 7467,0 7.447,0 7a27,5 7415,0 7390,5 7383,5 7355,0 7326.0 7306,5 72~3.5 7 ! 91.5 7160.0 7t. 08.5 7094,0 7020,0. 697~,5 6956.5 6929.0 6865,5 6852.0 6816.5 676! .5 67!.0.5 6694,5 6654,5 661.5.5 660~.0 6517.0 6466,5 63ee.5 634.0.5 6302. ~ 6270,5 6229,0 62!4.5 6198.0 6.~ 75.0 6162,5 6066.0 6043,5 6002.5 !O~,O ~WRGED DATA SOLI~CE ~W ~!~ ~t!N NO, 1 4828.0 7~94,0 ~!ERGE BASE 7880.0 'chlumberqer AlasKa Como,,)tlng Center ~','~AR-!993 1!:54 PAGE: TH~i D~;PTH ADjUST,~IENTS SH[iWN ABC. YE REFLECT MwD GR TO WlRELIN:E GR OF t9-F~g'-93, ALL OTHER CU~VES EDITED FILE A~E AT .5 .SA[~.PLING ~ATE. T~{~ SA~PLiNG I.N F:!~,E ~4 WILL BE CBOSER" TO ACTU .L LIS ~ORUAT DATA ** DATA FORMAT SPECIFICATION R~,"COPD ** ** SET TYPE - 64EM **' TYPE I 66 0 ~ 66 0 3 73 4 66 5 66 7 65 8 6~ 0,5 9 65 11 66 12 !~ 6~ 13 66 0 !4 65 FT !5 66 16 66 1 0 66 0 ** SET TYPE - CMaN ** NAMV SMRV ;! 7 ADI API A I FII,E NUMB MUM . .IZ~ REP P~ ESS ID ORDER # LOG TYPE CLASS ~tlD !~[IM~ Sh~P ELEM CODE (HEX) '" ............... ........ .............. ...... "T ........... X ........... ..... D~PT FT .. 99~7 0 000 O0 . 1 1 ~ 6~ .... OOO00 ~uOg ~WD G/C3 619987 O0 000 nO 0 1 1 ! 4 68 OOO0000000 RP ~WB ROP NMI G/C3 6199P7 O0 o00 O0 0 BN/M 619987 O0 000 OO 0 I~ 6199~7 O0 O00 ~0 n PU-S 619987 O0 000 O0 0 OHm. 6109~7 O0 000 O0 0 OU~ G199~7 O0 000 OO 0 F/~ 6199~7 O0 000 O0 0 GAPl 619087 O0 000 O0 619987 O0 OOO OC 0 619997 O0 000 O0 0 CPS 6109~7 O0 000 O0 0 1 1 l 4 68 0000000000 ! 1 I 4 68 0000000000 t I ~. 4 68 0000000000 I ! 1 4 6~ O00000OO00 I 1 I 4 68 OOO0000000 1 ! t. a 68 0000000000 1 1 t 4 6~ 0000000000 ! 1 ~ 4 6~ O000OO0000 1 1 ! 4 6~ O000OO0000 1 1. ! ~ 6~ mO00000000 1 ~ 1 4 69 0000000000 Tape Verl~tcat. ion List.incl ChlUmberc~er A!oska ComDutino Ca~ter PAGE: NAMF SE~V UM!T SERV apl ID ORDER ~ LOG TYP H~F~ ~WD CPg ~IO987 O0 0 TAB ~WD 6199~7 O0 00 TABD ~WD 6199~7 00 O0 GTC~ ~WD S 61~987 00 00 N?CW ~W9 $ 6199~7 00 O0 DTC~ MWD ~ 61~9~7 00 00 ~TC~ ~WD S 6~9987 00 O0 ...... ......... 0 00 I I .. 6 B 0 0 On 0 I ~ I 4 68 0 0 00 0 1 { ! 4 6~ 0 0 00 0 1 ~ ! 4 68 0 0 O0 0 1 1 ~. 4 6~ 0 0 O0 0 1 1 I 4 68 0 0 O0 0 1 ,! 1 4 68 0 000000000 O00000OO0 000000000 OOOO00000 000000000 000000000 ** DATA ** . , 'q' 000 'RHOB. MWD D~PT , 78: 2 . C.~LN, ~WD -gg9.~50 NDHI,~WD ROP, ~WD 94,324 GR.MWD H~A,~W9 -999 ~50 HE A ~WD ~TCK, ~WD -999~ ~ '~ , ...... 25~ ~4TCK C~LN.MWD 8,954 WPHI,MWD ROP, ~WD 31.035 GR. ~wD H.E~. MWD 265,042 GTCK, ~WD ! ,000 NTCK, MWD ALN,,WD 9,1~7 NPHI.F{wD POP,~WD I 1. 7.645 HF;Na,~WD 259,B44 GTC~ .MWD 1. 000 NTCK, ~w[) D~PT. 7600.000 CabN.,WD 9,!01 ~OP. wWm 48.7~5 GR. H~q. ~w9 279,250 {-{EFA. MWD GTCK ~Wn -999 .~50 D~PT, 7500,000 ~HOB.~WD CSLN,~WD 8,943 gPgI.MWD ROP. ~WD 35,277 ~R. ~WD HFNa.~WD 30~.943 GTCg.UWD 1,000 ~TCK. NwD [}FpT. 7400.000 CnLN.~D 8.939 NPHI.~WD Prim. ~WD ~1.082 GR.~WD M~qA.MU~D 307.063 GTCO. N~VD I .OqO %~TCK. ~w~ -999,250 D~}{O,MWD -999,250 PEF, -999.250 P~,~WD -999.250 RP. -999.~50 NSI,~WD 1.OOO -g99,250 TAB,BW[) -999.250 T&BD, -999,~50 DTC~,MWD -999,~50~;CR 2 457 DRHO.~WO 0 015 86,087 NSI.MWD -999.~50 -999,750 DTCN.NWD -999.~50 RTCN. 2,42~ D~i].~WD 0.044 PEF. 33.700 PA.~D 3.736 ~P. 70,414 F;SI,~WD 0,000 RSI, 6.310 TAB.UWD 0.66~ TABD. {.000 ~TC~,~W~ -999.~50 ~TC~. 455 D~n,~WD 0 0~7 2~ .... *~-.,,: , ~ .. 74~09~ ~:SI.~W~ 0.000 7 169 TA~%,MWD 1.787 -999~250 DTCK.~wQ -999.250 RTCW. ~.~74 DRHO.~WD -0.005 PEP. -999.~50 DTCK.UWD -999.~50 RTC~. ~.490 D~}i~].~wU 0.007 24.900 ~,~WD ~.]2~ R~. 9.09& Ta~.~wD 1.461 -999.~50 DTCN.uWD ~.000 RTCK. -999,250 -999,250 1,000 -999,250 -999,~50 3,86i 2,11.2 0.000 3,350 '999.250 5,430 3,019 0,000 3.301 -999,250 4.371. 3,260 0.000 -g99,250 1.000 3,778 4.661 0,000 3.672 -g99.750 3,651 3,203 0,000 3.864 -999.250 ;ChlUmber~!or 'AlaS~:~ ComPutinO Center )P T. 7300.000 RHOB.~WD ~LN,~D 9.537 N~HI.,~WD ~O~.~W9 78,259 GR.MWD ~E~.~WD 266,639 GTCK,~WD 1,000 NTCK,~WO DEPT, 7200,000 C~L~,~WD 9,237 ~O~.~wO I1B.4~O H~N.A,.~WD 269,750 HEF~,~WD O~PT, 7100,000 C~bN,MWD 8,895 NP~I:,~WD ~OP.~WD 91.372 H~NA,~WO 255,305 G~CR,MWD -999,250 NTCK,~WD O~PT, 70OO,000 CALN,,WD 8,876 NP~!,NWD ~FNA,~WD 274,500 GTC~.~WD -999,250 NTCK.MWD DFPT, 6900,000 ROP.~WD 16 ' ,79! NP~I,~WQ 156 GTCW.~WD 1,090 NTCK.~WO DFPT. 6800,000 C&LN.~WO 8,846 ROD.~WD 206,898 HEN~,~WO 270,500 GTC~,MWD -999,~50 NTC~.~WD D~PT. 6700,000 ~HOB,~WD CADN.MWD B,782 ~OP.~WD 167,500 GR,MWD ~Na.~WO 2~6,250 GTC~.~wD -9o9,250 ~TCK.MWD DFDT. 6600,000 ~HOB.MWD CaLN,~WD P.770 ~OP.~WD 263,820 GR.i~wD H~N~,~W~ 256,109 GTC~.WWD -999.~50 Cab~.uwO 8,643 qPNI.MWD P[]P.~WD 21~.7~4 H~Na.~WO 259.643 GTC~.UW9 -999.250 NTCK.~WQ ~-MAR-t99~ 11:54 31!200 90 !!7 NSI,~,{WO 6,873 TAB,~WD -999 ~50 D~CK ~WD 45.~00 ~02.00~ ~,0 0 DTCK,~WD 2.460 DRwO,~wD 99~ 76 NSI,MwD .~5,I24 999,P50 DTCK.gWD ~,499 ORHO.MWD 35.532 !55,41~ ~SI,MWD 6,307 TAB.MwD -999,~50 DTCK,~WD 2.410 DRHO.~WD 155:...64 NSI,~WD -999~50 DTC~.~WD 2,460 DRHO, 36,300 144,903 6 !62 T~B,~wD -099~250 DTCK,MWi) 2,5!0 DRHO,~WD 30 266 P&,~WD B6:172 NSI,~WD -g99.250 DTCK.mwD 2,44.5 38.260 DA.MWD 106.992 5.~45 TAS.~qWD -999.250 DTC~,~WD ~.423 35.137 114.].72 ~SI,~WD 5.~99 TAB.MwD -999,~50 DTCKo~WO -99 0.022 3.025 0.o00 2.!~1 9o950 0.010 !.34! 0,000 0.996 9,250 0.01~ J.511 0,000 0,716 9.250 0.024 2.191. 0.000 0.674 9,~50 0.017 231! 0:000 0 588 0.005 1.~40 0,000 0.594 9,250 0.015 3,127 0,000 0.428 9.250 0.026 !.737 0.000 0.437 9.~50 0.005 2.235 0.00O 0.607 9.250 PEF.MWD RP,~WD RTCK,~WD RP.~WD RTC~,MWD PEF.mWD RSi.~WD RTCK,mWD PEF,NWD RP.~wD ~$!,~WO T~BD.~WO RTCK.UWD PEF.mwD RP,mWO TABD.~WD RTC~.mWD P~F.~WD ~P,mWD R$I,~WD T~BD.~wD RTCK.mW~ PEF.~WD PSI.~WD TABD.~WD RTCK.~W~ P~F.~WD RSI.~WD T~BD.~WD RTCW.~WD PEF.~wD PST.VWD T~D.MWD PAGE: 5,0~9 2,837 0,000 5.635 -999,250 4,078 i.270 0,000 2.971 -999,~50 3,657 1,501 0,000 1,728 1,000 4,029 2,18B 0,000 1,457 -999,250 3,739 2,183 0,000 1,3~0 -999.250 3.298 !.1~6 0.000 1.~03 1.000 3,352 2.917 0,000 0,907 1.000 3.389 1.95~ 0.000 0.834 1.000 3.2~1 2,200 0,000 0,944 -999.250 ..IS Ta~e yerlff_cat]on Listino ;chl!lmberger Alaska ComPuting Center DEPT, 6400,000 RHOB, GTCK, ~D -999,250 ~TCK D~PT, 6300,000 C:~LN,MWD 8,696 NPHI, ~4WD ~O~. aWD I ! 5. 476 ~R, ~WD GTCK, ~WD -999,250 NTCK- ~qwD CaI.,N.~WD '~' :772 NPHI,~WD ~OP, ~WD 169,6~9 ~R, HEN~,~Wf) 256,O31 GTCO, ~WD -999,250 NTCK. MWD DE:PT 6100 000 POP. ~'W9 144,226 GR. ~4WD H.~N .~. gWD 258 ,.250 GTCK. MWD -999,250 NTCK,MWD D~?PT, MWD 6000. 000 RH. OB, CAI.,~. 8,858 NPHI, POP, ~W[) ! 16. 880 GR. aWD H~U~,~WD 257,250 HEFt, ~WD GTCO. -9 g. 250 DEPT 5900 000 ~H~g" MWD HFN.~ .uW9 257.500 HE~A.MND GTCK.~WD 1,000 NTCK,MWD DFPT. 5800,000 C~L~,MWD 9,500 MPHI. ~WD H~:N.~. ~wD 263,375 HEFA.~WD DFPT. 5700,000 ~HOB. MWD CA[,~3. ~WD 8,613 MP~I. ~wD POD. ~WB 254.30t GR. E~N~.~WB 264.750 gEF[.MWD GTCK.UwD -909,250 NTCK.MWO OFpT. 5600.000 ~HOB.~WD CaLSI.~WD 8,b56 POP.~WD 171,878 GR.~WO HF~.~WD 263,500 HEFA.UWD GTC~,,WD -999. 250 NTCK. MWD 993 1. 1.:54 5,34.5 1,000 DTCK,~WD 2.332 DR~0,~WD 38.600 136,46~ ~$I, WD 5,52~ TAB.~WD ~ 344 DRHO.~4WO 3:529 .... l .go9 6,169 -999.250 DTC~.~wO ~ 348 DRH 3.1ooo $6,P45 N$I.~WD 5,46~ TAB,MWD .ooo 98.372 N~I.~WD 6.453 TAB,~WD -999.250 DTC~,UWD 35: oo 79.~42 ~SI.~W~ 6.155 TAB,~WO -g99.~50 DTCK,~wQ 36.~00 RA,MWD 82 486 NSI.qWD 6:078 T~R.~WD -99g.250 DTCK,MWD 2,360 DR!!0.UWD 34,~00 6.138 TA!I.aWD -99go~50 -0,015 2.559 0,379 '999'250 0,005 !.216 0 000 -999.250 -0.008 1.324 0.000 0 767 0.00~ 1-700 I 000 0:397 1.000 00~ 0,000 0.867 -999.250 0'0o4 0.000 0.~5o -999.250 0.018 2.106 1.000 0.425 -g99.~50 -0.019 2.399 0.000 0.546 1.000 -0.009 2.474 O.nO0 0.367 -g99.250 PEF,MWD RP,MWD TABD,~WD RTCK,~WD PP,g~WD RSI.~WD TABD,~WD RTCK.~ND PEF,~WD ~P,MWD ~S!.~WD TABD,.~WD RTCK.MWD P~F MWD RP:~:WD RSI,~WD TABD,MW9 ~TC~,~mD PEF,~w~ RP,~WD RSI.~WD TABD.~WD RTCK.~wD PEF,~.WB TaFD,~WD PEF,~wD RTCK,~WD PEF.~WD RP.~WD TABD,uWQ PEF,~wD TaBD.~WD RTCK.~WD 6.7 3,709 2,218 0,000 0,854 -999,250 · 3,063 1,123 0,000 0,697 !,000 3,144 0'996 0,000 !.346 -999,250 0o000 1,106 -999,250 043 0,000 1.458 '999,250 2,857 2,205 0.000 1,742 -999.250 2,~91 2,04] 0,000 1.153 -999,250 2.~15 2,282 1.000 1.030 -999,250 2,9!9 2,355 0.000 0,772 -999,250 Verification Listing :cb!umberger Alaska Comsutfno Center D ~ P T, 550 C), 000 R ~ O B, ~ w D . ..~.WD 8,672 NPNI, ~.~Wr) P 0 ~, ~ w D 286,87 .l C R, 7! W D ~.a, ~wD 258,750 GTCK, ~4WO -999,250 NTCK. D~PT. 5400,000 ~, ~D 256,250 HEFt, GTC~,~WO I ,0 .. 0 NTCK DFPT, 5300,000 RHOB,MWD CALN,MWD 8,652 H~N,~. ~,~WO 255,000 GTC~.~W~ -999,250 NTCK,MWD DEPT 5200.000 mOP,~WD ~83,632 GR, ~WD H~J.a, ~WD 260,500 HEFA,~WD CTCff.~w~ -099.~50 ~TCK, ~WD Df~PT 5~00 000 ~o~,uw~ ~29.495 HEN~.~WO 259,634 HEFA,MWD GTCO, ~WD -999, ~50 NTCK, DFPT, 5000,000 C.~LN. ~WD 8.7 1 ! ~PH!, POP. ~Wn 318.0 31 HFk~ ,'uWP 257,500 MEFA. ~'P GTC~.~WD -909,250 NTCK, ~wD PFpT. 4900,000 RHOB.MWD C~LN.u~D 8,607 NPUI.qWD POp. ~WD 422,675 GR. MWD HENa.-WD ~,0~0 HEFa..MWD GTCR. ~wn i. 000 D~PT. 4807,000 ~HOB.MWD CaLN.gWD !0,]25 NPHI, ~WD ~O~. ~aWD 502. 245 GR, MWI3 HFN~ .~WO 23! .OOO HEFA. ~:WD GTCK.-W~ I .000 NTCK.~WD ** END OF DATA ** 3'~AR-1993 11:54 2.~OB DR}IO,MwD 34' 00 ~A,MWD B6,450 NSI.~WD 6,063 TAB,~WD -999,250 OTCK,MWD ~.292 DRHO*~WD 33,500 95,844 NSI,~WO 6,16~ T~B.~WO -999.~50 DTCK.~WD 5.780 TAB.~WD -999.~50 DTCK.~WD ,327 DR~O ~wr) 8~.983 NS!,~ND 6,145 TAB,MWD -~99.~50 DTCK,NwD ~ D~O.~WD 8~, ~ 45 NS!,MWD 6,238 TAB.~W~ -999,250 DTCK,~WD 2,289 9;[ o9 6.155 1.000 DTCK,MWD 2.30~ ORHO.~WD 40.100 R~.~WP Bl.16g NSi,MwD 5,295 TA~.~w9 -990,~50 [)TCK,~wO 3.907 D~HFI.~WO 45,900 RA,MWD 38.405 NSI,MWD 4.505 -~9m.250 OTCK.~NF3 0 014 0,000 0.366 9.250 0.01.1 ~.608 0,000 0.352 9,250 0,OO0 4.?II 0,000 0o426 9.250 0.011 ~.~57 0.000 0.3~0 9.250 0 ~21 0.000 0.489 9,~50 0.009 3.414 0,0OO 1.000 0.076 2.727 0.000 0.303 9.250 0 91 So O.OO0 1.576 9.250 PEF.MWD RSI,MWD T~BD.gWD RTCK,~WQ RgI.~WD TABD.~WD PEF.uWD TgBD,~WD RTC~.~WD P~F,~WD ~P,~WD TABD.~WD RTCK.~WD PEF,~wD ~P.MwD ~SI,~WD TABD.MWD RTCK,~wD PEF.~WD RP.,~WO ~SI.gWO 'T~BD.MWD RTCK.~WD PEF.~WD RP,~WD R$I.~WD TAED..WD PEF.~WB ~P.uWD RTCK.~WD P AGE: 2,699 2,331 0.000 0,7~9 1,000 2,751 2,493 ,000 '999.250 2.449 3,601 0.000 0,676 -999,250 2.,903 2.7?5 0,000 0.630 -999,250 2,@48 2,748 0,000 0.731 1.000 2,849 3.251 0,000 0,764 -999,250 2,B6B 2.536 0.000 0,636 -999,250 -999,250 -999.250 0,000 2.087 1.000 Tame Veri~flcation Listinq ;chlumberrler Alaska Com~)~..~t!ng Cemter 3-MAR-I993 11:5~ PAGE: F!L~ ~AME : EDIT ,00! SERVICE : V~RS!ON D~T~ : 93/03/ 3 ~X REC SIZ~ : 1024 F~L~ TYPE **** FILE HEADER **** FILM NAME : EDIT .002 SERvicE : FLIC V~SlO~ ~ 001~07 DATE ~ 03/03/ 3 ~X R~C SIZE : !024 FIL~ TYPE : LO FILM ~EADER FIL~ NUMBER 2 Curves and log header data for each bit run lm seuarate ~iles. BIT RUN NiJ~ER: 1 DEPTH INCREmEnT: 0,5000 # VENDOR TOOL CODE START DEPTN '"'"'""" .... CD~ ~.0 CPN 4~2~.0 bOG HEADER DATA DATE LOGGED: SOFTWARE: SURWACE SCETWA~E VERSION: DOWNHOL~ S[)WTW~RE VERSION: DATA TYPE (~E~ORY DP REAL-TIHE): TD DRILLE~ TOP I.,0~ INTERVAL (~T): ~OTTO~ LmG INTERVAL miT ROTATING SPEED WOLE I~CLINATI~N uINIMUM ANGt, EI TOOL STRING (TOP TO ~OTTOM) VENDOR TOOL CODE TOOL TYPE CDN ~!.IT~OM/POR[)s~TY CAR R~S!STIVITY STOP DEPTH .7694.0 LOGOS-1.6.2 v4,0C 7694.0 4828.0 7694.0 ~chlumher~et Alaska Com;:~ut~,~O Center 3-~AR-1993 1!:54 $ ~0~'~0[,~,,i AND CASINC~ D.~TA D~ILLERS CASING DEPT},~ ~O~EWObE CONDITIONS ~UO D~NSITY tLB/G) MUD VISC[]SITY (S) MUD P}~: ~UD CHLORIDES (PPM) FLU!I) LOSS (C]): RESISTIVITY (OH~4~4 AT TEmPErATUrE DEGF) ~[JD ~T ~[sASURED TEMPER.~,I ~UD AT ~AX CIRCUbATIbIG TEMPERATURE: ~UO F'ILT~ATE ~T ~T ~UD C6K~ AT 8.500 4807.0 !0,60 2.640 2,740 65.0 65.0 MAT~I~ DENSITY: SANDSTONE 2.65 8,500 BIT TO ~E$ 65 4', BIT TO BIT TO ~EUT 1~0~7'. D~iLL~D INTERVAl, 4828' TO 769~. ~A. TRIX DE~S'ITY .65 (G~/CC), FLUID DENS~TY 1.0' ((;~/~C) ROTATTONAL BULK DENSITY' P~;OCESSI~G i.~SED. ~ARIT~C ADDED TO ~tJD ,qYST~, DATA 80FTWaR~ VERSION V4.0C. I, TS FORMAT PAGE: ** D~TA FqR~AT SPECIFICATION ~ECO~D ** SET TYPE - 64~g ** TYP~ ~DR CODE VAI,UK 1 66 ~ 2 66 0 ~ 7] 6O ~ 66 ~ 5 66 6 7] 7 65 ~ 6~ 0,5 ~IS ?a~e verif]ication Listino ~chlUmberoer Alaska Comr>utinq Center PAGE: NAM~ S~RV UN:IT I'D D~ p~ FT PMF bw! DCAL LW! IN DP!.!I LWt PU TwPH LW! PU ATR Lw! OHM~ ROPE LWi G~ LWI GAPI ~FA LWI CPS ~'YPE - CNAN ** .,VICE APl ~PI ~P APT Fib ~(]~B U F. PR Pr~ CESS ORDEP ~ LOG TYPE CheSS ~,~[}[) NUmB SA~P ~LEM CODE (HEX) TAB LW! 61 99~7 0 'r~BD LW1 61ggsZ 2 619987 O0 000 O0 0 2 { ! 4 68 0000000000 619987 O0 000 O0 0 ~ , 1 4 68 0000000000 ~9~7 oo ooo oo o ~ ~ ~. ~ ~8 oooooooooo 619987 O0 000 O0 n ~ ~ 1 4 68 0000000000 ~~, oo ooo oo o ~ ~, , 4 6~ oooooooooo 619987 O0 000 O0 n 2 I ! 4 68 0000000000 619987 O0 000 O0 0 2 ~ ! 4 68 0000000000 619987 00 000 OO 0 ~ I I 4 68 0000000000 ~~7 oo ooo oo o ~ ~ i ~ 6~ oooooooooo o ooo oo o ~ ~ , 4 ~ ** DAT~ ** DEPT. 7694.000 DCaY:.LW1 -999.250 PSP.LWI =909,250 HFF~.LW~ -999.250 DEPT. 7600.000 DCAL.LW~ -999.250 PSP.LWi 2.638 HFF~.LWI -999.250 9FPT. 7500.000 DCAt,.bW! 0.489 PS~.LW~ 4.417 HFF~.I,wI 7.323 ~HOB.LW1, -999.250 DRHO.LW! -999.250 PEF.Lw! OPP~I.bW! -990.250 TNPH.L, Wl -999.250 ATR.bW! ROPE.DWI 8.423 GR.LW1 -999.250 HENA.LWl T~B.LWI -99~.250 TARD.Lw1 -999.250 PH~B.LW1 :99q.~50 DRM© bWl -999 250 PEF.LW! DP~I.[,W! ~99.~50 TNPH:Lwl -q99:250 ATP.[,w1 Rt]PE,bw! 40,812 ~R Lw! 76 777 HEN,~ r. ~ L~I 2 353 TaBD.b~l -999~950 PHOB.LWI 2.428 DPHO.bW1 0.0!~ PEF.LWl DPMI.bW! 13.500 T~PH. bw} 30.700 ROPE.I, W1 41.795 ~.bwl 70.32~ HEN~.I,W! T~B.LW1 ~ .794 TABD. bWl 3.~64 -999.250 -999.250 =q99.250 -999.250 2.786 -999.250 4.024 4.672 287.500 Tame ver!ftcation Listing ;cblumberc4er AlasKa ComP,,,lt.!.n~. Center DCAL,LW! 0,524 PS~ , !...~w ! 2,898 H~F~,L~ 9, !~1 T~B.LWl 0 ~ P T 7 ] 00 · 000 DCAL:LWI 0,6,43 DP~I.Lw PS~,LWt 30,660 ROPE,bWI H~F~, LWI 7,250 TAB, LW EPT 72'00,000 PS~.I,.,Wl ! .268 ~OPE..LWI H~F~, I..~l 5,07] TAB, DTPT. 7100.000 DCAI .L~I 0.,44~ DPHI,LW! ~5~.LW1 !.511 DC~L,LWt 0,269 DP~I.L~I S~pT 69oo.ooo PS~*LW! ~,366 ~OPE,LWI HFF.~,LW1 5, ! 73 TAB.LW OFPT, 6800,000 DCAt,, LW~ 0, ]~6 DPHI,bW1 PSR.LW~ 1,520 ROPE.LW! H~Fh. LW~ 5. 797 TaB.LW DEPT 6700.000 DC~I.:LW1 O.]~l DPHI.LWl mSm. LW1 2,206 HEFa, LW1 7,199 TAB, DmPT. 6600.000 DCAL.I, W1 o,3g~ DPHI.LW1 PSP.LWl 0,6~4 ~OPE.LW1 HFFS. LW~ 5, ~8 TAB, LW DFPT. 6500,000 RHOB,LWI DCAL.LWl o,348 ~PRI,LWI PSg.Lw1 1,875 gOPE.LW! HFF~. LWI 5. 665 TA~. LW DFPT. 6400.000 0CAL.LW1 0.510 DPHI,LWl PSP.LW1 2,609 ~O~E.LW1 HWF~_ .. ,;,Wl_. 5,649 T~,LW! 3'~R-t993 !!:54 2 524 7 600 !02 56O 1,757 1~.438 ,. '9oo 54.71] 2.02.! ~,4~7 1 O,797 2,47t, 10,900 6 9.4 ~ 9 o,6~3i ~.453 ~.000 185.460 0o671 2.43] t93,~5~ 0,639 2,459 11,600 132,354 0.594 2 439 236.937 0.521 2.264 2~ 7.0 0.456 2.490 9,700 27~,017 2,480 I0,300 ~44,805 0,386 DRHO,SW! TMPH,LWI GR,LW1 TABD,LW! DRHO,LWl TNPH,LWl GR,LW1 TABD,LWl DRgO,LWI T~H,LWl GR,LW1 TABO,DWi DRHO,Lw!. TNPN,LW1 GR,LWl TABD,hW1. DPHO,LWl TNPH,bWI GR,LwI TABn DRHO,hW1 TNPH.bWl GR,LW1 TABD,LW1 TNPg,bWl TABD,bW! TNPH,bwl GR,Lw1 TABD,LW1 TNPl~.DW1 GR.LW! TABD,UWI DRMO,tlW~ TNP~,LWt G~,LW1 TAB~).Lw! TNPH,!,W1 ~R.LW1 TA~D.~W! 0.016 24.,900 80.355 4.!75 0.024 2~.76o 39520 0..O30 43.~oo 93.745 2.082 0,016 42,000 93'914 1.696 0.O0g ~9,500 149.63] 1.454 0.010 ~63.7~8 1.400 -0.001 3~ 500 1.103 o 063 93.g88 0.994 -0.03! 36.300 137,364 0,91.7 0.o16 38.200 113.596 O.947 0.003 37. goo 124.~3g 0.89~ PEF.LW! AT~.LW! HENA,LWl ..'E~. '"w ATR.L '! H E N A. !_, W ~[ ~TR, !.tENA,LWi PEF.LW! AT~,LW! PEF,LW1 gTR:,LW! PEF,L~I PEF.LWl AT~.LWl HE~A.LWl PEF. L ',~ 1 ATR. LW ! HENa,LWl PEF.LW! AT~.LW! HE~iA.LW! PEP.LW1 PEF,L~! ATP,LW! HENA.LW1 PAGE: 3,135 307,450 4,580 ~8.853 275,525 4,~.77 O0 3.565 1.609 249.500 3,855 2,173 261,000 4,7~7 2,399 254,000 3,285 1,776 264.000 3 36b 2: o4 291,500 2,345 0,994 253.500 3,637 2.160 255,500 3,055 2.729 253.500 12 ,IS WaDe Verificati~on Listina ;cblUmber.qer ,alaska ComDutinO Canter 6300,0 O0 DCA!.:.LWI 0,179 DPHI,LWI PSR.LW1 ! ,198 L W 1 5.390 T,~ 5. b W I 6~00.000 DC~L:LWI 0,232 PS~,LW! 1 ,$57 ~OPE,LWi Lw i. 6,463 ~CIL"LW! 0,09.] DPHI,LWI Lw1 1 256 ~0 E..LW1 :LW~ 5:270 TAB, LW! 6000,000 DCAf;.LWI 0.~52 DPHI.L, Wl [,w~, 9.442 ~OPE,.LW1 L W ! 5.909 T 590~ 000 RHOB.bWl DCAL.LWI .:26~ DPHI.DW! HF'.F.~, LWI. 6,494 TAB,LW1 DCAL.Dwl 0,000 DP~!.LWI PS~. LW ~. ~ 019 qCP~, LWl. 5700.000 RHOB.LW! DC,AL.LW ! 0.1~7 DP~!.LW1 PS~.LW! 2. 142 LWI 5.8~5 5600.000 ~HOB.LW1 DCAT,LW1 0.166 Pg~.LWI 2,391 ROPE.DWI DWi 6. 390 TAB. LW 55on.o00 RHO~.LWl DCAL ~ I.,W ~ O.O00 ~PNI .DWi LW ! 5. ~B3 TAB. LWI 5400.000 RHOB.LW1 DCAL.I~WI 0.016 DPH I. I..,w ! 5W! 2. 421 ~OPE. 5W 1 I.W 1 5,7 ] 8 5300. O O0 OCAL.LWi 0.349 °S~.!,Wl 3,4~ POO~.LW1 LW1 5. 390 TAB. LW ]-'~A~-.1993 11:54 2.~B4 DRHO.bWl 22.200 TNPH.LWl 163.640 GR.SWl 0,383 TABD.LW1 2,336 ORHO.LW! I~. 1 O0 ~PH. 153,...524 ~,LwI 0.763;~ TABD,GWl ~,997 DRHO,SW1 21,400 168,439 G~,Lwl 19 ~ 50o 0,676 TaBD,LW1 ~ 339 l ~ 1900 298.464 GR,:LW1 0.709 2.~76 D~HO.LW1 232. 16 '" GP,LWI 0.4~ T~BD~LWl 17,500 TNPH,LWl ~36,B39 G~,SW1 0,608 TABD,bW! 2. ]47 DPHO,LWl 1~.400 TNPH.LWl 308. 563 GR 0.37~ TA~D.LW1 2 307 DRMO.LWl 279.048 GR.Lw! 0.364 TAR~.LW1 ~.~B7 DRHO.bW! 2~.000 319.005 GR.LWl 0.353 TABD.LWl 16.900 TNnH.LWl 19~. 373 0,419 Tt~Ba,bWl · .400 1.29.~19 0.680 5 0 O0 163680 t.339 0.020 40.200 13J .416 1.183 0.00] 36 9o0 ~0 O11 93.417 1.636 0.02'1 36.700 84,556 1.,161 0 006 i : oo 80.63~ 1.028 -0.009 33.100 77.918 0.772 -0.010 34.0O0 83.049 0.734 -0.006 38.500 96.908 0.682 0.025 37.300 60.7:~ 0.672 PAGE: 2,769 1,26~ 253,250 2,922 J.,B07 255,7~0 3,i65 1 4!i 25o1500 2,963 2,636 262,500 2809 2:562 269,000 2,861 2.030 256.750 3073 258,250 2,~6B 2,506 260.750 2,752 2.380 261,000 2,741 2.509 262.500 2,619 4.003 256.750 ~Chlumberger A. laska ComDuti~O Ce~ter D~PT' 5100.000 DCAL,LW! 0.070 DP~i,LWt PS~.LW1 2.59~ ROPE,LW! H'EV~.LW! 6.008 T~B.LWt D~PT, 5000.000 DCAL,Lw1 0.J84 DP~I.[.W1 PSR.LW~ 3,209 RDPE.LW! HEF~. bW! 5,51.3 T~B. LW D~]PT* 4900,000 ~CAL. LW! O, !47 DP PS~.LW1 2.639 NFFa. LW1 5.794 Tfi~. LW DEPT 4800'000 RHOB.LWl PS~ LW1 1,879 D~PT', 4700.000 RHOB'LWI DC.A !... LW ! 0,9~6 PSW,LWt -999,250 ROPE. LW! H~a · LWI 3,866 TAB DF~T. 46]8.000 DCAL.LWI -9o9. ~50 DPHI PS~.LWI -999,250 ROPE.LWi **** FISE TRAILER FIL~ HAME : EDIT .0fl2 SERVICE : FLIC V~R$I~N ! 001A~7 D~T? : 93/03/ m~x REC SIZE : 1024 FTLE TYPE ~ LAST FILE : 3'~AR-1993 1!:54 ORHO 276,6~7 0,375 TABQ,SWi 2.334 D~HO.bW1 19.100 V" _ NPH 0.462 TABD.5WI t~.342 D~HO.LWi .700 TNPH,LWi 35~127 6R,LWt 0.346 TABD,LW1 ~,349 1~ ~0 T~PH.LWl 9s: 7 o.2 ] 2.s6s 4S6.221 1.576 2,511 ~99,250 GR.LW1 9o 250 TAnD t,wl 86,.932 0.628 . -0.011 35.80O 82.7~2 0'704 0 005 39'600 . ~9. J38 0.765 -0.00] 35.100 88.927 0,602 ~0.519 4.200 40,282 2.087 286 -999]250 -999.250 -999.~50 -990.250 -999.250 -gg9,250 PEF H~NA.LW! PEF.Lw~ ITR,Lw! PEF.LW1 ATR.LW1 HEN~.[,wt PEF.LWI HENA.[~W1 PEF.LWl ATR.LW1 HENA,LWI PEF.LWJ ATR.LW! H~N~. bw! PEF. LW ~ ATR.LWl HEN~.LWl 253,750 ~,897 2.732 25~.000 ~75 ~',380 . 255.750 2,99] 2,745 248,440 12,090 0.141 220,250 100.000 -999,250 216,000 -999.250 -999,250 -999,250 !.4 ~!$ Taoe ver.{i, fication Listinm ;chlUmberger AlasKa Comf.>uting Center **** FILE }~EA:DER **** FILM MA~E ., EDIT .00] ~X REC S:tZE : ~024 FIL~ TYPE : L0 3-MAR-!99] 1!:54 PA~E: 15 F!b~ NUmBeR 3 R~W NWD Curves and log header data ~or each bit ru~ i~ separate f~.Ies. BIT RUN NUMBE~: 2 DMPTH INCREMENT: 0,5000 VENDOR TOOL CODE START DF, PT}I CDN 7694,0 LOG ~{EADER DATA DATE LOGGED: SOFTWAPE: SURFACE SOFTWAR ...... VERSION: DCWNHOLE SOFTWARE VERSION: DATA TYPE (ME~ORY OR TD D~ILLER (FT): . TOP LOG INTERVAL BOTTOM LOG INTERVAL mit ~OTATING SPEED (RP~): ~OLE INCLINATION. (DEC) ~INIMUM ANGLE: ~XIMUM A. NGLE ~ TOOL ST~ING (TOP TO BOTTO~) VENDOR TOOL, COD~ TOOL TYPE CDN NF.i,ITRON/poRoSI TY CDR ~ESI~TIVITY S ~EHOI.,E AND CASING DATA OPEN ~OLE 8IT $TZ~ DRTUbERS CASING DEPTH RORE~OLE CONDITIONS ~UO TYPE: ~-~UD DENSITY (LB/G): MUD VYSCOSITY (S)~ STOP 7880,0 29-JAN-93 V4,0C 7~80,0 7694,0 7880,0 ....... 1.8 P(~8059 4807.0 !,0.60 Alaska Computln~ Cente~ PAGE: 1¸6 R~S~STIV!TY AT MEASURED AT ~X CIRCULATING TEMPE~ATU~E~ FILTRATE CAKE AT 2,640 65.0 2,740 65,0 MATRIX DENSITY: HOI,~ COnRaC 1,0,~ TOOL STANDOFF (IN): ~WR FREQUENCY SANDSTO'N~ 2.65 8,500 ********** 2 ********** BIT TO RES 15,4', BiT TO GR 25,5',~ BIT TO DEN 81.6~' BIT TG NE!~T 88.6' W~SHDOWN INTERVAL 76~4' TO 7694 , DR!LL~D'I~TE~V~t, ~694' T~ 7~80. TD 4 ON: 29-0AN-93. OILE~SITY ~.65 {GM/CC), fLUID DENSITY !,0 (GM/CC) M~TR!X 0 NOTA~IO .~b BULK D:EMSITY PROCESSING USED, B.A.~ITE ADDED TO MUD SYSTEM, DATA. F~O~ DOWNH[]LE NE~ORY', DOWN'RObE SOFTWARE VERS?ON V4.0C, $ [.,IS FORMAT D~TA ** nATA FORNAT SPECIFICATION RECORD ** ** SET TYPE - 64E~ ** TYPE' REP~ COD~ V~l,U~i 1 66 0 2 66 0 3 73 60 4 66 1 5 66 6 73 7 65 8 68 n.5 9 65 FT 11 66 17 12 6n !~ 6~ 15 66 68 16 66 0 66 1 3-~:~R-1993 1!~54 17 ~hB~ g~RV UN ~PI E LOG TY? DFPT FT 619~7 Oo 000 RN08 t.,~2 G/C3 619987 O0 D~NO LW2 G/C3 61.9987 O0 DEF [,W2 619987 O0 DC~L L~2 IN 619987 O0 DPNT LW2 PU 61,9987 O0 T~P~ LW2 PU 6199~7 O0 hTR' LW2 ON~M 6199~7 00 PSR LW2 ON~ 619987 00 RO~E LW2 F/HR 6199~7 O0 G~ LW~ GAPI 619987 O0 H~N~ [.,W2 CPS 619987 O0 ~F~ !~W~ CPS 619987 O0 T~ LW2 6!9987 O0 TaBD I,,W2 619987 A P . P L 3ii.: B $ I ....... OO 0 3 1 1 4 68 0000000000 000 O0 0 3 1. I 4 68 0000000000 000 O0 0 3 I I 4 68 O00nO00000 000 O0 0 3 1 I 4 68 0000000000 000 O0 0 3 ! I 4 68 O00000OO00 000 O0 0 3 I ~ 4 6~ 0000000000 000 00 0 3 I. 1 4 68 0000000000 O00 O0 0 3 ! I 4 6~ 0000000000 000 O0 0 3 I I 4 68 000000O000 0OO O0 0 3 1 I 4 68 0000000000 000 O0 0 3 ! 1 4 68 0000000000 000 O0 O 3 1 1 4 68 0000000000 000 O0 0 3 ! I 4 68 0000000000 000 O0 0 3 I. ! 4 68 0000000000 000 O0 0 3 I 1 4 68 O000000000 ** DAT~ ** DEPT. DCAL,t~iW2 HFV.~iLW2 D~PT. DCAI,~.LW2 HFF,~.b~2 DFPT NFVa.LW2 DF~T. D C A L. L w 2 PS~. LW 2 ~.Lw~ 7879 500 RHOB'LW2 -990.~250 0R~] LW2 '999'250 PEF.LW2 999'250 DpNi. LW2 -99~,~~50 TNPN'LW2 -999 250 AT~ -999,259 ROPE,LW2 24, ~24. GR,LW2 -999. 250 HENA. I...w2 -999.250 TAB, bw2 -999,~ 50 TABBY, bW 2 -999: ~50 7~nO 000 ~Hoa LW2 999 250 DRNO LW2 -999,250 ..E~ -999,250 DPH!.Lw2 -999.250 TNPH,LW2 -999.250 1.8!4 ROPE.LW2 34.111 GR,LW2 88.526 H~N~.LW2 -999.250 TAB.LW~ 0.487 TAB~.LW2 -999.~50 0.371 ~P~i:!,.,W2 ~.606 TNP~.Lw2 30.600 AT~.LW~ ],067 ~OPE.LW2 25.!40 ~R.LW2 74.530 7.485 T~R.LW2 0.778 TABD,LW2 3.317 7600.000 RHOB.bw~ ~.a47 DR~O.LW2 0.030 PEF.LW2 0.5~ hPgI.LW2 12.300 TNPH.bW2 34.!00 AT~.LW2 -999.250 ROPE.LW2 -999.~50 GR,LW2 82.044 6.363 TAB.LW2 -999.~50 TABD.hw2 -999.~5~ 7531.000 ~gOB.LW2 -999.250 DPM[3 . -999.250 DPHI.LW~ 999.~50 T~,PH'LW2 PEF.!,W2 - ,~ .bw2 -999.~50 aT~.LW2 -9og.250 ~OPE.LW2 -099.250 GR.LW2 -999.250 7.2]0 Ta~.LW2 -99g.250 TABD.LW~ -999 250 -9992250 -999,250 -999.,250 1.852 -999.250 3.679 3.236 289.650 4.075 -999,250 268,750 -g99.250 -999.250 -999,250 ** END OF r~ ~ chl. Umberqer'A..,iaska Comput nc., Center 3-VAR-!993 1~:54 PAGE: !8 **** F!L~ TRAILER **** FILE ~A~E : EDIT .003 SERVICE : PblC VEm$IO~ ~ 001~07 D~TM : 93103/ 3 ~a~ R~C SIZE : 10~4 F!L~ TYPE : LO LAST FILE ~ **** FILE MEADER **** F!bM NAME : EDIT .004 SERVICE VERSION : 00~07 DAT~ : 93/03/ 3 ~AX REC SIZE FILE TYPE : LO L~ST FI[~ FIL~ H~ADER FILM ~UNMER 4 Raw MWD Curve~ and 1o~ header data ~or each bit. run in separate files. BIT RUM NUMBER: DEPTH IMCWE~E~T: 0.! # FILF SUMMARY VENDOR TOOL CODE START DEPT~ "g'""'""'" CD~ S LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VMRSIOiq: DATA TYPE (MEMORY OR TD D~II,!~ER TOP [,OG ~NTE~VAL BOTTO~ [,aG INTERVAL BIT WOTATI~G SPEED UOLE INCLINATION CDEG) ~IN!~U~ ANGLE: ~AXI~UM AN~bE: STOP DEPTM 7 . , 0 7880.0 TOO[, STRING (TOP TO BOTTOm) V~ND~R TOOL CO~E TOOL TYPE CDN ~I E[.!TROi.~ / OROS!TY CD~ RESISTIVITY 29-j;~N-93 LOGOS-i 7880.0 4~29.0 788~.0 ~DSOl.~ ~GS059 Alaska Com~u~l~o Ce~eF $ DRILLerS C~$ING DEPTN ~O~EHOLE CONDITIONS ~UD TYPE: ~D DENSITY (LS/G): ~UO VISCOSITY (S): ~UD PH: FLUID LOSS (C3]~ RESIST ........... o.:IVITY (OH~ AT ~"~:~PE~ATL~E OEGF) ~UD AT SE, ASURED TE~:PERAT~.~RE ~[JD AT ~!X CIRCULATING ~[,IO FILTRATE hT ~UD CAKE AT NEUTRON TOOL ~ATRI~ DENSITY: HOLE COPRECTION (IN): FkEOU~CY (~Z): .50 10,60 P.640 ~,740 65.0 65.0 2.65 8,500 ~E~.ARKS': THIS FILE CONTAINS THE SAMPLING TICKS FRO~ T~E ~ERGFO ~WD FILE. THIS DATA IS AS CLOSE TO T}.~E ACTUAL RATE OF ~OU!SITION ~S POSSIBLE. $ LIS FOR~.AT DATA PAGE:: 19 DaTA FORMAT SPECIFICATION ~ECORD ** ** SET TYPE - 6dEB ** ! 66 2 66 0 3 73 ~o 4 66 255 5 66 7 65 8 68 0,1 9 65 FT !1 66 51 !2 68 13 66 0 ;chlumberaer . !,,aska Cnm., utlno Center 3-M~R-!993 PAGE: 2O TYPE !4 65 ~T !,~ ~6 6~ 16 66 o 66 ** SET ID DEPT FT' ~TCK 003 S N~C~ o0~ 8 D~CK O03 S R~CK 003 S TYPE - C~N ** SERVIC~ .PI apI apl API F ~UMB tlMg S! E REPR pR ORDER # bOG TYPE CheSS Mild 619987 00 OOO O0 0 4 I 1 4 6~ 0000000000 6199~7 O0 000 O0 0 4 1 1 4 68 O00000OO00 6199~7 O0 000 O0 0 4 1 I 4 68 0000000000 6199~7 O0 0OO O0 0 4 I 1 4 68 0000000000 619987 O0 000 00 0 4 ! 1 4 68 0000000000 ** D,A. TA ** DEP? 4642o601 ~TCK.OO3 -999.250 NTCK.003 !.000 DTCK.O03 RTCK:003 -999.250 .... D~p? 4699.900 CTcK.no~ -~99.25o NTCK.O03 -999.25o DTCK.0O3 RTC~:O03 -999,~50 ' ..... D pT. 700.10 TCK.OOa -999. $0 CK.O03 -ggg. 50 TCK.O0 RTCK.O03 -999,2~0 D~PT 4799 900 GTCK,003 -999.250 NTCK.003 -q99.~50 DTCK.003 RTCK~003 -999:250 D~PT. 4800,101 GTCK.00~ -999,250 NTC~.00] -999.250 DTCK.003 RTC~.OO) -9q9.250 RTC~,003 -999.250 DEPT. 4900.101 GTCK,00] -999.~50 gTCO.Q0] -999.~50 DTCK.003 RTCK,O03 -99Q,250 DEPT, 4999.900 GTCK.00] -999.250 R?C~.003 -999,250 D~D~. ~O00.10l GTCK.O03 -999.250 ~)TCK,00] -999.250 9TCK.O03 RTCK.003 -999.250 D~PW, 5099.900 GTCK.003 !.000 NTCK.O0~ -999.~50 DTCK.O03 RTCK.00] -9~9.250 -999.250 -999,250 -999,250 -9~9.250 -999,250 -999,250 -999,250 -999,250 -999,250 -9~9.250 !,,.i[$ T~r~e verification Listin~ Schlumberger A!asKa Com~:3tinQ Center DEPT, RTCK,O0] DEPT. ~TC~.00~ FPT c 2oo) DEPT, RTC~.001~ DEPT, DEPT, RTC~,O03 D~PT, PTC~.003 ~pT' ~TC~.003 DEPT ~TC~'003 . DEpT, RTC~.003 EPT D~PT, ~TCK,003 DF~T D~mT. RTCK.00] D~PT, DEpT, ~TC~,003 DEPT, RTC~.OO) 5100,101 GTCK.003 -999.250 5199,900 -999,250 5200.101 GTCK.003 -999'250 5299,900 ~TCK.003 -999,250 5300.I01 G~c~:'oo3 -999.25o 5399.900 GTCE.003 -999,250 ~400o101 GTC~ 003 999.25O 5499,900 GTCK.O03 -999,250 : ~500.~01 999.~50 5599,900 GTCK,O03 -999,250 -999,2~0 5700.101 GTCt,003 -999,~50 5799.900 GTCK.O03 -999,250 5800.1~1 ~TCK.003 -999.250 5~09.900 GTCK.003 ~900.~01 GTCK.003 -999o250 3-MAR-1. 993 1,l:54 1.000 NTCK.003 -999.250 -999,950 N?CKo003 -999,250 NTCK.003 -999.250 NTCK.003 -999.~50 -999.~50 NTC~.003 -999.~50 NTCK.O03 -999,250 NTCK.O03 -999,~50 NTCK'003 -999.250 NTCK.00] -999.250 NTCK.003 -999.250 -99~,250 NTCK,O03 -999.250 NTCK,O0] !.000 NTCK,003 -999.250 ~TCK.003 -999.250 ~,:. 000 !. 000 1.000 -999.250 -999.:250 '999.250 -999.~50 -999.250 -999.250 -999.250 -999'250 -999.250 -999.25o -999.P50 1.000 -999.250 DTC~.O03 DTCK.003 DTCK.003 DTCK.O0~ DTCK.003 DTC~.003 DTCK.O03 DTCK.003 DTCK.003 DTCK.O03 DTCK.003 DTCK.O03 DTCK.003 DTCK.O03 DTCK.003 DTCK.O03 DTCK.00] PAGE: -999.250 -999.250 -999.250 -999.250 -999.250 -999,250 -999.250 -999'250 -999,250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999,250 -999,250 2l LIS Tare Verification hlstino Schlumberger AlasKa ComPuting Center DEPT. 5909.900 GTCK.003 RTCK.00~ !.000 DEPT. 6000.!01 ~TCK 003 RTCK,00~ -999,250 ........... " DFPT, 6099.900 GTCK.003 RTCK,003 -999.250 DFPT. 6100.!0! GTCK.00] RTC~.OO3 !,000 DEPT, 6199.900 GTCK.003 RTCK,003 -999,250 DEPT. 6200.t01 GTCK.00~ RTCK.O03 -999,250 .... DFPT, 6299,900 GTCK,003 ~TCK.003 -999,~50 D~PT. 6300,10~ GTCKi,003 RTC~.O03 -999.25d ..... DFPT, 6399,900 ~TCK,003 RTCK,003 -999,250 DFPT, 6400.101 GTCK.003 ~TCK.003 1.000 DFPT, 6499.900 GTCK,003 ~TCK.00] -999.250 DEPT, 6500.101 GTCK,003 ~TCk'.003 1.000 DEPT. 6599,900 GTCK,003 RTCK,OO] -999.~50 DFPT. 6600.1~! GTCK.003 RTCK.003 '999.250 DEPT. 6699.900 GTCK.00] PTCK.O03 -999,250 ~FPT, 6700.101 GTCK.003 RTC~,003 ~,000 DFPT. 6790,900 GTCK,O03 RTCW,00] '999,250 DEPT, 6800.10! GTCK.003 RTCW.00] -999.250 3-EAR-!.993 11:54 1.000 ~?CK.003 -999.250 -999.250 ~TCK.003 1.000 ~TC~.O03 -999.~50 MTCK.003 1.000 ~TC~.O03 -999,250 ~TCK.00] -999.250 NTCK.003 -999.250 NTCK,003 -999,~50 NTCK.00] -990.~50 MTCK,O03 -999,~50 MTCK,003 -999,250 ~TCK,OO3 -999.~50 NTCK,003 -999.~50 -999.250 NTCK.003 -999,250 -999.250 MTC~.00] 1.000 -990.950 -999'950 -999.250 1.000 -999.~50 -999'~50 -999.250 -999.250 -999.~50 !.000 -999.250 -999.750 -999,~50 1.000 -~99.25n -999.250 -999.~50 DTCK.003 DTCK.O03 DTCK.00] DTCK.003 DTCK.003 DTCK.003 DTCKo003 DTC~,003 DTCK.003 DTCK.O03 DTCK.O0~ DTCK.003 DTCK.003 5TCK.003 DTC~.O03 D~C~.003 DTCK.003 DTCK.O03 PAGE: -999,250 -999.250 -999.250 -999,250 -999.250 .. -999,250 -999.250 1.000 -999,250 -999,250 -999.250 -999,~50 -999,250 -999,250 -999.~50 -999,~50 1.000 -999.250 !~!S Ta~e Ver!~ication I, istinq ~chlUmber~er AlasKa C'o~,putino Center DFPT' 6899,900 GTCK.003 RTCK,OO] -999,250 O~PT'. 6900,101 GTCK,003 RTCK,00] -999,250 6999.900 GTCK.003 RTCK,OO3 -999,250 DEPT, 7000.101 GTCK,003 PTCK,O0] -999,2~0 D~PT, 7009,900 GTCK 003 ~TCK.O03 -999,250 ' D~PT. 7100,!0! GTCK~003 RTCK.O0] -999,250 , DrDT 7199.900 GTCK,003 D~PT. 7200.!01 GTCK.O03 RTCK.O03 -999,250 D~PT, 7299,900 GTCK 003 gTCK' ()0] -999. ?50 v3oo iol vCK 003 ~F~T. 7399.900 GTCK.003 RTCK,O03 -990,250 DEPT. 7¢00.101 GTCK.003 ~TC~.O0] -999.250 1.ooo DF~T. 7SOO,IOI GTCK.003 RTCW.O03 -999,250 9~P'r. ~599.900 GTCK.O03 ,TCK,00] -999.250 ~p? 76oo.~o! ~TC~ ~TC~]00~ 1.000 "~ DEPT. 7699.900 GTCK.O03 ~TCK.O0] -999.250 3-aa~-!993 I!:54 -990,250 NTCK'O03 -999,~50 NTCK,O03 -999,250 -999.250 NTCK.O03 -990.~50 NTCK.O0] '999.250 NTCK,003 -999.250 NTCK,003 !,000 NTC~.O03 !,000 NTCK.003 t.O00 NTCK.003 ~.000 NTCK.O03 -999.250 ~TCK.O03 -999.250 gTCK.O03 -q99.~50 1.O00 NTCK.003 ~,000 ~.000 ~!TCK,003 -999.250 -999.250 -999.250 -999.250 -999.250 -999.~50 -999.~50 -999.~50 -999.250 -g99.~50 -999,250 1.000 -999.250 1.000 -999.~50 -999.259 1.000 DTCK.O03 DTCK.O0] DTCK.O03 OTCK.O03 DTCK.O03 DTCK.O03 DTCK.O0] DTCK.O03 OTCK,003 DTCK.O0] DTCK.00~ DTCK.O03 DTCK.O03 DTCK.O03 DTCK.O03 DTCK.O03 DTCK.00] PAGE: -999.250 1,000 -999,250 1.000 -999,250 -999,250 -999,250 -999,250 -999.250 1,000 -999,250 -999.250 -999,250 -999.250 -999.250 -999.250 -999,250 2.3 ~chl. umberqer .... A !asKa Co~putlno Center · . 7700.10! GTCK. 003 D~PT, 77.~9,900 ~'r,c~<. 00] ~. 0~)0 D~PT, 7800.101 GTCK'003 RTC~.003 ~ DEPT. 0 7866, ~00 ** E~D OF DATA 3-~AR-1993 1I:54 ~.000 ~TCK.O03 -999.250 ~TCK.003 1,000 ~TCK.003 -999,~50 ~TCK,()03 !.000 DTCK.003 -999.250 OTCK.O03 -999.~50 DTC~.003 -990'.~50 DTC~,003 PAGE: 24 -999.250 -999.250 -999.~50 -999.250 **** FILE TRAILER FILE ~ANE : ~DiT .004 V~RSION ~ 001A07 DAT~ : 93/03/ 3 ~aX REC SIZE : ~024 FIL~ TYPE ~ LO LAS~ FILE **** FILE FIL~ ~]A~E : EDIT ,0o5 S~v!CE : FLIC V~$ION : 001A07 D~T~ : 93103/ 3 ~X R~C SIZE : !024 FILF TYPE FI!.,F HEADER EDITED ~E~GED ~WD DePth sbifte~ and cl{DPed CUrVeS; all blt rubs merged. D~PTH IBIC~E~ENT 0.5000 FILE SUmMArY KRU TOOb COD~ START DEPT!! $ # gASF~L!~JE CURVE FOP S}~IFTS: CURVE S~IWT DATA (~F~SU~ED DEPT~) STO? DEPT~ .......... EQUIVAI~f]NI UNSglFTMD OEPT~{ .......... Schl, Umber~jer Alaska Com. puti, no CeDter 25 # $ RESISTIVT¥ DAT~. $ LIS FORMAT OATA ** DATR FORMAT $PECIFICATIOM RECORD ** ** SET TYPE - 64MB ** TYPE REPR.CODE V~bl~E 1 66 0 2 66 0 4 66 ~ 66 6 7~ 7 65 8 68 0,5 9 65 WT 11 66 36 13 66 0 ~4 65 FT 16 66 0 66 ** SET mYPE - Cw~M ** DFpw FT 619987 00 000 O0 0 5 1 1 4 6~ ATPW 001 OHMg 6199~7 09 000 00 0 5 ! I 4 68 pspw 00I 0~ 6109~7 o0 OOO O0 0 5 1 I 4 68 ATE~ 00! OH~ 6199~7 O0 000 O0 0 5 I 1 4 68 PSEo 001 0~ 6199~7 00 000 O0 0 5 1 1 4 68 ATVm 001 OHMU &!99~7 O0 000 00 0 5 ~ ~ 4 68 PSV~ ~0~. O~M~ 619987 O0 000 00 0 5 J. I 4 68 0000000000 0000000000 OnOO000000 00o0000000 0000000000 0000000000 0000000000 mm~mmmm~mmmm~mmmmmmmmmmmmmm~mMmm~m~m~mmmmm~mm~mmmmmmmmmmmmmMmmmmm~mmm~mm~mm#mmmm~mMmmm Tame verification !.,istlnO ~chlumberqer AlasKa Computing Center DaTa DEPT. 7877.500 ATPH.O0! PgEP.O01 5.080 ATVR.O01 DEPT. 7800 000 ~TP~.O01 PSE~.001 ~106 ATVR.001 DFPT. 7700.000 ~TPH.001 PSER.O01 3.137 ATVR.OO1 DEPT. 7600.000 ATP~.O01 P~E~.O01 3.21U ~TV~.O01 DEPT. 7500.000 A~PH.001 PSEm. OO!, 4.836 &TVR.O01 ~EDT 7400.000 9~PT 7250.500 PSEUDO01 ' 1.391 ATVR.O01 END OF DATA 3-~4AR-1903 11154 4.443 PSPH.,)O1 10.018 PSVR.O01 2o!57 PSPH.O01 ~.210 PSVR,O01 3.260 .PSPH.O01 3.180 PSVR.O0! 3.447 PSPH.001 3.306 PSVRo001 4.899 PSPH.O01 5.300 ~$vR.o01 3 ~93 PS.P~I.001 3:05 2.973 DSPH.O01 g.906 PSVR.00! 1.458 1.43~ PSVR.001 4.186 8,773 2.069 2.11.5 3.167 3.094 3.329 3.197 4.620 4.974 , ~.937 2.~78 1.3~4 ~.360 ATER.O01 ATE¢.O01 ATER.O01 ATER.O01 ATER,O01 ATER.O01 ATER.O0~ AT~;R.O0! 5.467 2.196 3.2~9 3,327 5.144 .:z5 2.835 1,466 **** FILE TRAIt, ER **** FILM NA~E : EDIT .005 SERVICE : FLIC D~T~ ~ 03/03/ 3 ~lX REC SIZE ~ 1024 FIL~ TYPE ~ LO LAST FILE ~ **** TAD~ TRAI!.,E~ **** SERVICE N~E : EDIT O~IClN : FLIC TAPE NA~E ! 93045 CONTINUATION ~ ~ ~ PREVIOUS T,~PE : CO~UENT : ARC© ALASKA, INC.,KU'PARUK RIflER U~:! I T , ! H-01,50-029-22330-00 ~cblumberoer Alaska Computing.' Center 993 1 !~: 54 PAGE: 27 D~T~ ~ 93103/ 3 REE[~ NA~ : 03045 CONT1NU~T~O~ ~ : CO~gf]~T : ARCO ALaSkA, INC.,K[!PARUK RIVER UNIT,tg-O1,50-029-22330-00
