Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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19.06.2024 - 01:33
Time of last synchronization with Norwegian Offshore Directorate's internal systems

2/1-10

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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.
    2/1-10
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    2/1-10
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    GYDA 3D IN LINE 122 X- LINE 1006
    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.
    703-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.
    67
    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,
    09.11.1991
    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.
    14.01.1992
    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.
    14.01.1994
    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.
    24.09.2002
    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 SHOWS
    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.
    NO
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.0
    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).
    4525.0
    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).
    4523.1
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    6.65
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    163
    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.
    TRIASSIC
    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.
    SKAGERRAK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 57' 53.61'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 1' 19.7'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6313619.42
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    501346.22
    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.
    1865
  • Wellbore history

    General
    The well 2/1-10 was drilled on a prospect located within PL 164, 7.8km Northwest of Gyda Platform. The primary objective was to test the Upper Jurassic Ula Formation, if successfully, to prove a volume of oil that was commercial as a tie back development to the Gyda Platform. A secondary target was a younger Ula Formation interval.
    Operations and results
    The wildcat well 2/1-10 was spudded on 9 November 1991 with the semi-submersible installation "Ross Isle", and was completed 14 January 1992 in the Triassic Skagerrak Formation. The well was drilled with sea water and hi-vis pills down to 1101 m and with KCl polymer mud from 1101 m to TD. The upper part of the Ula Formation was encountered at 4189.5 m, 50 m deeper than originally predicted. A 133 m thick Ula Formation was encountered instead of the most likely prognosed model of 15 to 30 m thick Ula formation (intra Farsund) sandstone, separated from underlying Ula Sandstone by a 50 to 60 m thick Farsund mudstone. The Ula Formation was cored from 4194 m to 4289.5 m. Fair quality shows was observed in uppermost 5 meter of sandstone only. 2/1-10 was plugged and abandoned as dry well.
    Testing
    No drill stem test was performed
  • 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]
    1110.00
    4525.00
  • 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
    4193.0
    4219.0
    [m ]
    2
    4219.0
    4246.0
    [m ]
    3
    4246.0
    4272.7
    [m ]
    4
    4272.7
    4278.5
    [m ]
    5
    4278.5
    4288.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    95.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 4193-4198m
    Core photo at depth: 4198-4203m
    Core photo at depth: 4203-4208m
    Core photo at depth: 4208-4213m
    Core photo at depth: 4213-4218m
    4193-4198m
    4198-4203m
    4203-4208m
    4208-4213m
    4213-4218m
    Core photo at depth: 4218-4221m
    Core photo at depth: 4221-4226m
    Core photo at depth: 4226-4231m
    Core photo at depth: 4231-4236m
    Core photo at depth: 4236-4241m
    4218-4221m
    4221-4226m
    4226-4231m
    4231-4236m
    4236-4241m
    Core photo at depth: 4241-4246m
    Core photo at depth: 4246-4250m
    Core photo at depth: 4250-4255m
    Core photo at depth: 4255-4260m
    Core photo at depth: 4260-4265m
    4241-4246m
    4246-4250m
    4250-4255m
    4255-4260m
    4260-4265m
    Core photo at depth: 4265-4270m
    Core photo at depth: 4270-4274m
    Core photo at depth: 4274-4279m
    Core photo at depth: 4279-4284m
    Core photo at depth: 4284-4288m
    4265-4270m
    4270-4274m
    4274-4279m
    4279-4284m
    4284-4288m
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    4127.0
    [m]
    DC
    PETROSTR
    4133.0
    [m]
    DC
    PETROS
    4139.0
    [m]
    DC
    PETROS
    4145.0
    [m]
    DC
    PETROS
    4151.0
    [m]
    DC
    PETROS
    4157.0
    [m]
    DC
    PETROS
    4163.0
    [m]
    DC
    PETROS
    4169.0
    [m]
    DC
    PETROS
    4175.0
    [m]
    DC
    PETROS
    4181.0
    [m]
    DC
    PETROS
    4187.0
    [m]
    DC
    PETROS
    4194.4
    [m]
    C
    PETROS
    4196.1
    [m]
    C
    PETROS
    4198.7
    [m]
    C
    PETROS
    4203.2
    [m]
    C
    PETROS
    4204.0
    [m]
    C
    PETROS
    4205.0
    [m]
    DC
    PETROS
    4210.7
    [m]
    C
    PETROS
    4213.0
    [m]
    C
    PETROS
    4219.3
    [m]
    C
    PETROS
    4224.4
    [m]
    C
    PETROS
    4230.1
    [m]
    C
    PETROS
    4230.3
    [m]
    C
    PETROS
    4233.2
    [m]
    C
    PETROS
    4239.6
    [m]
    C
    PETROS
    4245.5
    [m]
    C
    PETROS
    4247.5
    [m]
    C
    PETROS
    4252.8
    [m]
    C
    PETROS
    4256.6
    [m]
    C
    PETROS
    4260.3
    [m]
    C
    PETROS
    4262.3
    [m]
    C
    PETROS
    4266.1
    [m]
    C
    PETROS
    4271.4
    [m]
    C
    PETROS
    4274.5
    [m]
    C
    PETROS
    4277.0
    [m]
    DC
    PETROS
    4279.4
    [m]
    C
    PETROS
    4287.4
    [m]
    C
    PETROS
    4307.0
    [m]
    DC
    PETROS
    4319.0
    [m]
    DC
    PETROS
    4331.0
    [m]
    DC
    PETROS
    4343.0
    [m]
    DC
    PETROS
    4355.0
    [m]
    DC
    PETROS
    4361.0
    [m]
    DC
    PETROS
    4373.0
    [m]
    DC
    PETROS
    4385.0
    [m]
    DC
    PETROS
    4397.0
    [m]
    DC
    PETROS
    4403.0
    [m]
    DC
    PETROS
    4415.0
    [m]
    DC
    PETROS
    4427.0
    [m]
    DC
    PETROS
    4433.0
    [m]
    DC
    PETROS
    4442.0
    [m]
    DC
    PETROS
  • Lithostratigraphy

  • Composite logs

    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.61
  • 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
    1.75
    pdf
    9.65
    PDF
    22.86
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CST GR
    3840
    4515
    DIL LLS GR
    89
    3241
    DLL MSFL SDT GR
    3233
    4525
    LDL CNL GR
    4050
    4525
    MWD
    89
    4525
    RFT GR
    4193
    4463
    RFT GR
    4226
    4226
    SHDT GR
    3800
    4525
    VSP
    1000
    4375
  • 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
    160.0
    36
    161.0
    0.00
    LOT
    INTERM.
    13 3/8
    1096.0
    17 1/2
    1100.0
    1.99
    LOT
    INTERM.
    9 5/8
    3234.0
    12 1/4
    3236.0
    1.94
    LOT
    LINER
    7
    4525.0
    8 1/2
    4525.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    687
    1.60
    28.0
    3.8
    WATER BASED
    14.01.1992
    817
    1.59
    30.0
    4.8
    WATER BASED
    14.01.1992
    1100
    1.08
    WATER BASED
    15.11.1991
    1100
    1.07
    WATER BASED
    19.11.1991
    1100
    1.08
    WATER BASED
    13.11.1991
    1100
    1.08
    WATER BASED
    15.11.1991
    1100
    1.07
    54.0
    15.4
    WATER BASED
    19.11.1991
    1100
    1.03
    WATER BASED
    19.11.1991
    1101
    1.40
    32.0
    9.1
    WATER BASED
    20.11.1991
    1250
    1.45
    29.0
    8.2
    WATER BASED
    20.11.1991
    1636
    1.57
    32.0
    8.6
    WATER BASED
    20.11.1991
    1763
    1.60
    35.0
    8.6
    OIL BASED
    21.11.1991
    2023
    1.60
    41.0
    9.1
    WATER BASED
    22.11.1991
    2172
    1.60
    41.0
    7.7
    WATER BASED
    25.11.1991
    2290
    1.60
    45.0
    9.6
    WATER BASED
    25.11.1991
    2502
    1.60
    43.0
    9.1
    WATER BASED
    25.11.1991
    2710
    1.60
    44.0
    8.2
    WATER BASED
    26.11.1991
    2864
    1.60
    41.0
    7.7
    WATER BASED
    27.11.1991
    2906
    1.60
    44.0
    8.2
    WATER BASED
    28.11.1991
    3002
    1.60
    43.0
    9.2
    WATER BASED
    29.11.1991
    3060
    1.60
    49.0
    10.6
    WATER BASED
    02.12.1991
    3119
    1.60
    40.0
    9.1
    WATER BASED
    02.12.1991
    3128
    1.57
    47.0
    7.2
    WATER BASED
    14.01.1992
    3128
    1.57
    40.0
    6.7
    WATER BASED
    14.01.1992
    3162
    1.60
    49.0
    10.6
    WATER BASED
    02.12.1991
    3242
    1.60
    47.0
    10.8
    WATER BASED
    04.12.1991
    3242
    1.60
    45.0
    9.3
    WATER BASED
    05.12.1991
    3242
    1.61
    61.0
    13.4
    WATER BASED
    05.12.1991
    3242
    1.61
    44.0
    10.6
    WATER BASED
    06.12.1991
    3313
    1.30
    35.0
    12.0
    WATER BASED
    09.12.1991
    3366
    1.55
    42.0
    13.0
    WATER BASED
    09.12.1991
    3420
    1.55
    38.0
    11.0
    WATER BASED
    09.12.1991
    3572
    1.55
    43.0
    12.0
    WATER BASED
    11.12.1991
    3695
    1.55
    40.0
    11.0
    WATER BASED
    12.12.1991
    3721
    1.55
    40.0
    11.0
    WATER BASED
    12.12.1991
    3772
    1.55
    43.0
    11.5
    WATER BASED
    13.12.1991
    3817
    1.55
    40.0
    10.6
    WATER BASED
    16.12.1991
    3900
    1.55
    37.0
    8.6
    WATER BASED
    16.12.1991
    3954
    1.55
    46.0
    11.5
    WATER BASED
    16.12.1991
    3992
    1.55
    43.0
    10.1
    WATER BASED
    17.12.1991
    4092
    1.57
    51.0
    10.6
    WATER BASED
    09.01.1992
    4121
    1.55
    44.0
    11.0
    WATER BASED
    18.12.1991
    4193
    1.55
    43.0
    10.6
    WATER BASED
    19.12.1991
    4221
    1.55
    42.0
    10.6
    WATER BASED
    20.12.1991
    4244
    1.56
    41.0
    9.1
    WATER BASED
    23.12.1991
    4272
    1.55
    44.0
    9.6
    WATER BASED
    23.12.1991
    4277
    1.55
    41.0
    9.1
    WATER BASED
    23.12.1991
    4287
    1.55
    42.0
    9.6
    WATER BASED
    27.12.1991
    4328
    1.55
    48.0
    11.0
    WATER BASED
    27.12.1991
    4424
    1.55
    49.0
    11.5
    WATER BASED
    27.12.1991
    4443
    1.55
    52.0
    13.4
    WATER BASED
    27.12.1991
    4443
    1.55
    49.0
    12.0
    WATER BASED
    30.12.1991
    4443
    1.55
    50.0
    13.0
    WATER BASED
    30.12.1991
    4525
    1.55
    50.0
    12.0
    WATER BASED
    30.12.1991
    4525
    1.55
    49.0
    10.6
    WATER BASED
    06.01.1992
    4525
    1.55
    42.0
    8.6
    WATER BASED
    06.01.1992
    4525
    1.55
    49.0
    10.6
    WATER BASED
    06.01.1992
    4525
    1.55
    48.0
    10.6
    WATER BASED
    06.01.1992
    4525
    1.55
    42.0
    8.6
    WATER BASED
    06.01.1992
    4525
    1.55
    48.0
    10.6
    WATER BASED
    06.01.1992
    4525
    1.55
    42.0
    8.6
    WATER BASED
    06.01.1992
    4525
    1.55
    53.0
    10.6
    WATER BASED
    08.01.1992
    4525
    1.55
    48.0
    10.6
    WATER BASED
    06.01.1992
    4525
    1.55
    49.0
    10.6
    WATER BASED
    06.01.1992
    4525
    1.57
    57.0
    13.0
    WATER BASED
    07.01.1992
  • 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