Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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05.11.2024 - 01:27
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2/1-3

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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.
    2/1-3
    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.
    NORTH SEA
    Field
    Name of the field the wellbore is related to.
    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.
    2/1-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    2-109 SP.782
    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.
    BP Norway Limited U.A.
    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.
    229-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.
    148
    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,
    03.11.1979
    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.
    29.03.1980
    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.
    29.03.1982
    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.
    12.03.2011
    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.
    OIL
    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.
    LATE 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.
    ULA FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    30.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    66.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4297.0
    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).
    4296.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    162
    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.
    LATE PERMIAN
    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.
    ZECHSTEIN GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 54' 41.39'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 6' 30.39'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6307680.64
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    506603.55
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    31
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    251

  • Wellbore history
    General
    Well 2/1-3 was drilled on the Cod Terrace on the margin between the southern Vestland Arch and the Central Trough in the North Sea. The primary objective of the well was to test Late Jurassic sandstone within a fault sealed dip closure, against the downthrown side of a westerly heading fault complex at the base of the Cretaceous. Triassic sandstone was a secondary objective.
    Operations and results
    Wildcat well 2/1-3 was spudded with the semi-submersible installation SEDCO H on 3 November 1979 and drilled to TD at 4297 in the Late Permian Zechstein Group. The well was drilled with Seawater down to 625 m and with Lignosulphonate mud from 625 m to TD.
    Top of the Tyne Group, Mandal Formation, was encountered at 3791 m, with the Late Jurassic sandstone at 3819.5 m. The Late Jurassic sandstone reservoir was oil-bearing all through. The reservoir is a 59.5 m thick homogeneous fine to medium grained sandstone with a porosity from 15% to 22%. The sandstone grades into a well cemented argillaceous siltstone below. No oil/water contact was established. Oil shows were recorded in Tor Formation limestone at 3000 - 3005 m, throughout the Late Jurassic reservoir sandstone, and in Middle Jurassic Bryne Formation sandstone at 4020 to 4040 m.
    Four cores were cut from 3823.0 to 3893.5 m in the Ula Formation reservoir sandstones.
    The well was permanently abandoned on 29 March 1980 as an oil discovery.
    Testing
    Three drill stem tests were performed in the Late Jurassic sandstones.
    DST 1A perforated the interval 3863 to 3872.1 m and produced 226 Sm3 oil and 18689 Sm3 gas per day through a 40/64" choke. The GOR was reported to be 150 Sm3/Sm3 and the oil gravity was 41 deg API. The maximum bottom hole temperature recorded in the test was 151.1 deg C.
    DST 2 perforated the interval 3838.5 to 3844.6 m and produced 1051 Sm3 oil and 54991 Sm3 gas per day through a 32/64" choke. The GOR was reported to be 116 Sm3/Sm3 and the oil gravity was 39 deg API. The maximum bottom hole temperature recorded in the test was 150.0 deg C.
    DST 3 perforated the interval 3819.0 to 3825.1 m and produced 933 Sm3 oil and 39077 Sm3 gas per day through a 32/64" choke. The GOR was reported to be 108 Sm3/Sm3 and the oil gravity was 38 deg API. The maximum bottom hole temperature recorded in the test was 150.8 deg C.

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    NO
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    180.00
    4296.00

  • 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
    3823.0
    3832.2
    [m ]
    2
    3838.0
    3855.7
    [m ]
    3
    3856.4
    3862.2
    [m ]
    4
    3875.0
    3893.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    51.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3823-3827m
    Core photo at depth: 3827-3832m
    Core photo at depth: 3832-3832m
    Core photo at depth: 3838-3842m
    Core photo at depth: 3842-3847m
    3823-3827m
    3827-3832m
    3832-3832m
    3838-3842m
    3842-3847m
    Core photo at depth: 3847-3851m
    Core photo at depth: 3851-3855m
    Core photo at depth: 3856-3860m
    Core photo at depth: 3860-3862m
    Core photo at depth: 3875-3878m
    3847-3851m
    3851-3855m
    3856-3860m
    3860-3862m
    3875-3878m
    Core photo at depth: 3879-3884m
    Core photo at depth: 3884-3888m
    Core photo at depth: 3888-3893m
    Core photo at depth: 3893-3893m
    Core photo at depth:  
    3879-3884m
    3884-3888m
    3888-3893m
    3893-3893m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3792.0
    [m]
    DC
    PETROSTR
    3801.0
    [m]
    DC
    PETROS
    3804.0
    [m]
    DC
    PETROS
    3810.0
    [m]
    DC
    PETROS
    3816.0
    [m]
    DC
    PETROS
    3822.0
    [m]
    DC
    PETROS
    3823.0
    [m]
    C
    PETROS
    3825.8
    [m]
    C
    PETROS
    3844.8
    [m]
    C
    PETROS
    3848.1
    [m]
    C
    PETROS
    3853.1
    [m]
    C
    PETROS
    3858.5
    [m]
    C
    PETROS
    3862.0
    [m]
    C
    PETROS
    3876.0
    [m]
    C
    PETROS
    3877.0
    [m]
    C
    PETROS
    3877.8
    [m]
    C
    PETROS
    3877.8
    [m]
    C
    PETROS
    3881.3
    [m]
    C
    PETROS
    3883.1
    [m]
    C
    PETROS
    3885.8
    [m]
    C
    PETROS
    3887.7
    [m]
    C
    PETROS
    3889.4
    [m]
    C
    PETROS
    3891.2
    [m]
    C
    PETROS
    3893.5
    [m]
    C
    PETROS
    3897.0
    [m]
    DC
    PETROS
    3903.0
    [m]
    DC
    PETROS
    3909.0
    [m]
    DC
    PETROS
    3915.0
    [m]
    DC
    PETROS
    3921.0
    [m]
    DC
    PETROS
    3927.0
    [m]
    DC
    PETROS
    3933.0
    [m]
    DC
    PETROS
    3939.0
    [m]
    DC
    PETROS
    3945.0
    [m]
    DC
    PETROS
    3951.0
    [m]
    DC
    PETROS
    3957.0
    [m]
    DC
    PETROS
    3963.0
    [m]
    DC
    PETROS
    3969.0
    [m]
    DC
    PETROS
    3975.0
    [m]
    DC
    PETROS
    3981.0
    [m]
    DC
    PETROS
    3987.0
    [m]
    DC
    PETROS
    3993.0
    [m]
    DC
    PETROS

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.71

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.17
    pdf
    1.43
    pdf
    2.85
    pdf
    7.44

  • 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
    2.51
    pdf
    7.23

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3863
    3872
    15.9
    2.0
    3839
    3845
    12.7
    3.0
    3819
    3825
    12.7
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.0
    3.0
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    1.0
    226
    19000
    0.820
    150
    2.0
    1051
    55000
    0.830
    116
    3.0
    933
    39000
    0.835
    108

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CALI
    625
    1825
    CBL VDL GR
    3395
    3927
    CDL CNL GR
    3538
    4270
    CDM
    3587
    4221
    CDM AP
    3587
    4221
    DLL MLL
    3587
    3940
    FMT
    0
    0
    GR CAL
    550
    0
    IEL BHC GR AC
    30
    4273
    TEMP
    95
    2250
    VELOCITY
    30
    4273

  • 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
    139.0
    36
    143.0
    0.00
    LOT
    SURF.COND.
    18 5/8
    595.0
    24
    608.0
    1.81
    LOT
    INTERM.
    13 3/8
    1899.0
    17 1/2
    1910.0
    1.92
    LOT
    INTERM.
    9 5/8
    3558.0
    12 1/4
    3566.0
    2.00
    LOT
    LINER
    7
    3935.0
    8 1/2
    4267.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    930
    1.15
    waterbased
    1422
    1.30
    waterbased
    2227
    1.57
    waterbased
    2813
    1.60
    waterbased
    3409
    1.63
    waterbased
    4297
    1.68
    waterbased

  • 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
    0.22