Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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25.11.2024 - 01:30
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7019/1-1

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  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    7019/1-1
    Type
    Wellbore type. Legal values: EXPLORATION, DEVELOPMENT, OTHER (see 'Purpose' for more information)
    EXPLORATION
    Purpose
    Final classification of the wellbore.

    Legal values for exploration wellbores:
    WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS.

    Legal values for development wellbores:
    OBSERVATION, PRODUCTION, INJECTION, INJECTION-CCS, OBSERVATION-CCS.

    Legal values for other wellbores:
    SOIL DRILLING (drilling in connection with track surveys and other subsurface surveys to investigate the soil conditions prior to placement of facilities),
    SHALLOW GAS (drilling to investigate shallow gas before the first 'real' drilling on the location),
    PILOT (drilling to investigate the geology and fluid connectors for location of the main wellbore),
    SCIENTIFIC (drilling according to Law of Scientific research and exploration),
    STRATIGRAPHIC (driling according to Law of Petroleum activities §2-1).
    WILDCAT
    Status
    Status for the wellbore. Legal values are:

    BLOWOUT: A blowout has occurred in the well.
    CLOSED: A development wellbore that has been closed in a shorter or longer periode. Also applies to development wellbores where drilling is completed, but production/injection has not yet been reported.
    DRILLING: The well is in the drilling phase - can be active drilling, logging, testing or plugging,
    JUNKED: The drilling operation has been terminated due to technical problems.
    P&A: Exploration: The well is plugged and abandoned, and can not be reentered for further use. Development wells: The production/injection from/to the well is stopped and the well is plugged. The wellhead is removed or else made unavailable for further well operations.
    PLUGGED: The wellbore has been plugged, but the upper parts of the wellbore can be re-used. A sidetrack might be drilled at a later stage.
    PRODUCING: It was produced from the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    INJECTING: It was injected to the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    PREDRILLED: The upper part of the well has been drilled, usually as part of a batch-drilling campaign covering several wellbores.
    RE-CLASS TO DEV: Exploration wellbore that is reclassified to a development wellbore.
    RE-CLASS TO TEST: Exploration wellbore that is reclassified to test production.
    SUSPENDED: The drilling operation in the wellbore has been temporarily stopped. The current plan is to continue drilling later on.
    P&A
    Factmaps in new window
    Main area
    Name of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.
    BARENTS SEA
    Discovery
    Name of the discovery the wellbore is related to.
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    7019/1-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    94 TRM3D inline 1026 & crossline 1050
    Production licence
    Official designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion).
    Drilling operator
    Name of the licensee starting the drilling operation on behalf of the active production license (well head position). This will usually equal the operator of the production license.
    Norsk Agip AS
    Drill permit
    The drilling permit number together with the version of the drilling permit as stated in the drilling permit granted by the Norwegian Offshore Directorate.
    984-L
    Drilling facility
    Norwegian Offshore Directorate's name of the facility which the wellbore was drilled from.
    Drilling days
    Number of days from wellbore entry to wellbore completion.
    59
    Entered date
    The date when he wellbore was spudded. For sidetracks: The date when new formation was drilled by kicking off from the mother-wellbore,
    06.10.2000
    Completed date
    Exploration wellbores from moveable facilities:
    For floating facilities - date when anchor handling is started. For jackups - date the jacking-down started. Exploration wellbores from fixed facilities and all development wellbores:
    Date when the wellbore is at total depth, and last casing, liner or screen is set. In case of immediate plugging of the wellbore, completed date equals the date the last plug i set in the wellbore.
    Date when the wellbore is at total depth, and last casing, liner or screen is set. In case of immediate plugging of the wellbore, completed date equals the date the last plug i set in the wellbore.
    03.12.2000
    Release date
    Date when raw data which has been reported to the authorities from the wellbore is not confidential any longer. Normally 2 years after finishing the drilling. May be earlier if the area of the production license is relinquished.
    03.12.2002
    Publication date
    Date quality control of the wellbore information was completed, so it can be published on the internet as a 'Well Data Summary Sheet' wellbore with more information available than other wellbores.
    11.02.2003
    Purpose - planned
    Pre-drill purpose of the wellbore. Legal values for exploration wellbores: WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS. Example of legal values for development wellbores: OBSERVATION, PRODUCTION, INJECTION.
    WILDCAT
    Reentry
    Status whether the wellbore has been re-entered (YES) or not (NO). Re-entered wellbores are not included in the count when wellbores are presented in statistical overviews.
    NO
    Content
    For exploration wellbores, status of discovery.

    Legal values:
    DRY, SHOWS (trace amounts of hydrocarbons), GAS, GAS/CONDENSATE, OIL or OIL/GAS.
    SHOWS (GAS SHOWS, OIL SHOWS or OIL/GAS SHOWS) are detected as fluorescent cut (organic extract), petroleum odour, or visual stain on cuttings or cores, or as increased gas reading on the mud-loggers gas detection equipment.
    Legal values for WILDCAT-CCS and APPRAISAL-CCS: WATER

    For development wellbores, type of produced/injected fluid.
    Legal values:
    WATER, CUTTINGS, NOT AVAILABLE, OIL, GAS/CONDENSATE, OIL/GAS, CO2, GAS, WATER/GAS, NOT APPLICABLE.
    GAS
    Discovery wellbore
    Indicator which tells if the wellbore made a new discovery. Legal values: YES, NO. Prior to press-release or other information regarding drilling results, the indicator will be “NO” as a default.
    YES
    1st level with HC, age
    Age of lithostratigraphic unit, 1st level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE. See also Norwegian Offshore Directorate bulletins.
    MIDDLE JURASSIC
    1st level with HC, formation
    Name of lithostartigraphic unit, 1st level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP. See also Norwegian Offshore Directorate bulletins.
    STØ FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    24.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    190.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3003.0
    Final vertical depth (TVD) [m RKB]
    Vertical elevation from total depth to kelly bushing. Shown only for released wells. Referred to as true vertical depth (TVD).
    2998.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    7.9
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    108
    Oldest penetrated age
    Age (according to Geologic Time Scale 2004 by F. M. Gradstein, et al. (2004)) of the oldest penetrated formation. May differ from age at TD for example in deviated wellbores. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EARLY PERMIAN, EARLY TRIASSIC, EOCENE.
    EARLY JURASSIC
    Oldest penetrated formation
    Name of the oldest lithostratigraphic unit penetrated by the wellbore. Shown only for released wells. In most wellbores this is formation or group at total depth. May differ from formation or group at TD for example in wellbores drilled with high deviation or through faults. Examples of legal values: AMUNDSEN FM, BALDER FM, BASEMENT, BLODØKS FM, BRYNE FM, BURTON FM, COOK FM, DRAKE FM, DRAUPNE FM, EKOFISK FM, DUNLIN GP.
    TUBÅEN FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    70° 55' 5.1'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    19° 4' 22.44'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7869589.80
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    429692.26
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    34
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    4145

  • Wellbore history
    General
    Well 7019/1-1 was drilled in the central-western part of block 7019/1. The primary target of the well was to test the hydrocarbon potential of the Middle Jurassic through Upper Triassic Stø Formation sandstone of the Kapp Toscana Group. Lower Basal clastics of the Early Cretaceous Knurr Formation were a secondary target.
    Operations and results
    Exploration well 7019/1-1 was spudded with the semi-submersible installation "Transocean Arctic" on 6 October 2000. The seabed soil/formation was found to be very hard with embedded boulders and drilling progress was slow. The rig was thus moved 10 m and the well was re-spudded and drilled to TD at 3003 m, 141 m into the Early Jurassic Tubåen Formation. The well was drilled with Seawater and High Viscous sweeps with pre-hydrated bentonite mud down to 665 m, and with Formate brine / XC Polymer / PAC from 665 m to TD. The reservoir of the Stø Formation was encountered at 2447 m and was found to be gas bearing. The Gas/Water contact was encountered at 2597 m. Shows were observed down to 2610 m. Poor shows were also noted through the Nordmela Formation and into the top of the Tubåen Formation to 2865 m. The Basal Clastics of the Knurr Formation were also found HC bearing at 2211 m with poor shows down to 2220 m. No HC/water contact was seen in this reservoir. Three cores were cut, one in the Knurr Formation, and two in the Stø Formation. Gas from the Lower Cretaceous reservoir was sampled with MDT at 2246 m. Gas samples from the Jurassic Stø formation were taken during the DST. The well was permanently abandoned as a gas discovery on 3 December 2000.
    Testing
    A test was performed in the interval 2526 to 2563 m in the Stø Formation. The well flowed 606000 m3 gas per day (no liquid) from a 40/64 choke. Gas gravity was 1,133 (air = 1), CO2 content 60 - 70%, and H2S content 6 - 13 PPM. The test was stopped during the clean up phase due to the high CO2.

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    YES
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    670.00
    3001.00

  • Cores at the Norwegian Offshore Directorate
    Cores at the Norwegian Offshore Directorate
    Core sample number
    Core sample - top depth
    Core sample - bottom depth
    Core sample depth - uom
    1
    2220.0
    2234.3
    [m ]
    2
    2457.0
    2463.8
    [m ]
    3
    2561.0
    2568.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    28.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2220-2225m
    Core photo at depth: 2225-2230m
    Core photo at depth: 2457-2462m
    Core photo at depth: 2462-2464m
    Core photo at depth: 2562-2566m
    2220-2225m
    2225-2230m
    2457-2462m
    2462-2464m
    2562-2566m
    Core photo at depth: 2566-2568m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2566-2568m

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.39

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.55

  • Documents – reported by the production licence (period for duty of secrecy expired)
    Documents – reported by the production licence (period for duty of secrecy expired)
    Document name
    Document format
    Document size [MB]
    .pdf
    1.80
    .pdf
    2.24

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    FMI DSI
    2004
    3002
    HALS PEX
    2002
    2523
    HRLA PEX
    2004
    3002
    MDT
    2212
    2544
    MDT GR
    2246
    3984
    MDT GR
    2246
    2951
    MDT GR
    2601
    0
    MSCT
    2496
    2548
    MSCT
    2952
    0
    MWD MPR - GR DIR RES
    2015
    2875
    MWD MPR - GR DIR RES SONIC
    348
    665
    MWD MPR - GR DIR RES SONIC
    670
    2015
    VSP
    2002
    3001

  • Casing and leak–off tests
    Casing and leak–off tests
    Casing type
    Casing diam.
    [inch]
    Casing depth
    [m]
    Hole diam.
    [inch]
    Hole depth
    [m]
    LOT/FIT mud eqv.
    [g/cm3]
    Formation test type
    CONDUCTOR
    30
    336.0
    36
    343.0
    0.00
    LOT
    SURF.COND.
    20
    658.0
    26
    665.0
    1.65
    LOT
    INTERM.
    9 5/8
    2004.0
    12 1/4
    2015.0
    1.73
    LOT
    LINER
    7
    3003.0
    8 1/2
    3003.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    224
    1.03
    SW/BENTONITE
    600
    1.03
    SW/BENTONITE
    650
    1.03
    SW/BENTONITE
    650
    1.03
    SW/BENTONITE
    720
    1.30
    10.0
    FORMATE/POLYMER
    1807
    1.30
    11.0
    FORMATE
    2015
    1.39
    13.0
    FORMATE
    2095
    1.39
    13.0
    FORMATE
    2221
    1.39
    11.0
    FORMATE
    2237
    1.39
    12.0
    FORMATE
    2295
    1.39
    13.0
    FORMATE
    2335
    1.39
    13.0
    FORMATE
    2381
    1.39
    13.0
    FORMATE
    2410
    1.39
    13.0
    FORMATE
    2434
    1.39
    11.0
    FORMATE
    2459
    1.39
    14.0
    FORMATE
    2465
    1.39
    13.0
    FORMATE
    2512
    1.39
    13.0
    FORMATE
    2530
    1.35
    12.0
    FORMATE
    2550
    1.35
    13.0
    FORMATE
    2557
    1.25
    9.0
    FORMATE
    2569
    1.25
    10.0
    FORMATE
    2633
    1.25
    FORMATE-POLYMER
    2633
    1.25
    FORMATE-POLYMER
    2657
    1.25
    10.0
    FORMATE
    2727
    1.25
    9.0
    FORMATE
    2794
    1.25
    11.0
    FORMATE
    2847
    1.25
    10.0
    FORMATE
    2988
    1.25
    10.0
    FORMATE
    3003
    1.25
    FORMATE POLYMER

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    2221.25
    [m ]
    2227.55
    [m ]
    2228.25
    [m ]

  • Pressure plots
    Pressure plots
    The pore pressure data is sourced from well logs if no other source is specified. In some wells where pore pressure logs do not exist, information from Drill stem tests and kicks have been used. The data has been reported to the NPD, and further processed and quality controlled by IHS Markit.
    Pressure plots
    Document name
    Document format
    Document size [MB]
    pdf
    0.19