Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
25.11.2024 - 01:30
Time of last synchronization with Norwegian Offshore Directorate's internal systems

2/2-4

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    2/2-4
    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).
    APPRAISAL
    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
    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.
    2/2-4
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    SG 8652 - 102 SP. 218
    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.
    Saga Petroleum ASA
    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.
    574-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.
    53
    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,
    16.04.1988
    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.
    07.06.1988
    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.
    07.06.1990
    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.
    02.03.2004
    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.
    NO
    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.
    OLIGOCENE
    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.
    VADE FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    26.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    59.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4020.0
    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).
    4017.5
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    138
    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 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.
    SMITH BANK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 47' 40.88'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 39' 34.46'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6294866.66
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    540289.63
    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.
    1188

  • Wellbore history
    General
    Well 2/2-4 was drilled on the northern segment of the Alpha structure in the southeastern corner of block 2/2 on the northeastern flank of the Central Graben in the Ula-Gyda Fault zone. The structure is a salt induced dome in an area exposed to extensional tectonism where rollover mechanism may have influenced the final structure. The southern segment well 2/2-1, separated from the northern by a normal fault, proved gas in Oligocene and oil in Late Jurassic sandstones.
    The main objective of the well was to test the reservoir potential of Late Jurassic Ula Sandstone and to test a possible communication with the Alpha South structure. If hydrocarbon bearing, the objective was to prove an oil column thick enough for commercial exploitation of the Alpha structure.
    Operations and results
    Wildcat well 2/2-4 was spudded with Wilh. Wilhelmsen semi-submersible rig Treasure Saga on16 April 1988 and drilled to TD at 4020 m in the Triassic Smith Bank Formation. The well was drilled with spud mud down to 915 m, with KCl mud from 915 m to 3310 m, and with gel mud from 3310 m to TD. It was drilled down to top Jurassic and 9 5/8" casing was set.
    Oligocene came in at 2084 m with sand with small amounts of gas. Eight pressure points in the interval gave a water gradient of 1.0 g/cc and a gas gradient of 0.21 g/cc. The gas/water contact was defined at 2110.5 m, the same as in 2/2-1. Estimated porosity from logs was max. 27%. The main target Ula reservoir was encountered at 3324 m, but was found water wet. Only residual oil was found in the uppermost part of the Ula sandstone and in siltstone of the Bryne Formation. No cores were cut. One FMT segregated sample recovered gas from 2109 m in Oligocene. The gas was very dry with 97% methane. The well was abandoned on 7 June 1988 as a gas appraisal 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]
    210.00
    4019.00

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2120.0
    [m]
    DC
    RRI
    2160.0
    [m]
    DC
    RRI
    2180.0
    [m]
    DC
    RRI
    2197.0
    [m]
    SWC
    RRI
    2220.0
    [m]
    DC
    RRI
    2240.0
    [m]
    DC
    RRI
    2260.0
    [m]
    DC
    RRI
    2279.0
    [m]
    SWC
    RRI
    2300.0
    [m]
    DC
    RRI
    2320.0
    [m]
    DC
    RRI
    2660.0
    [m]
    DC
    RRI
    2690.0
    [m]
    DC
    RRI
    3218.0
    [m]
    SWC
    RRI
    3225.0
    [m]
    DC
    RRI
    3235.0
    [m]
    DC
    RRI
    3317.0
    [m]
    DC
    RRI
    3335.0
    [m]
    DC
    RRI
    3416.0
    [m]
    DC
    RRI
    3435.0
    [m]
    DC
    RRI
    3446.0
    [m]
    DC
    RRI
    3476.0
    [m]
    DC
    RRI
    3485.0
    [m]
    DC
    RRI
    3494.0
    [m]
    DC
    RRI
    3506.0
    [m]
    DC
    RRI
    3515.0
    [m]
    DC
    RRI
    3524.0
    [m]
    DC
    RRI
    3545.0
    [m]
    DC
    RRI
    3554.0
    [m]
    DC
    RRI
    3566.0
    [m]
    DC
    RRI
    3575.0
    [m]
    DC
    RRI
    3584.0
    [m]
    DC
    RRI
    3605.0
    [m]
    DC
    RRI
    3614.0
    [m]
    DC
    RRI
    3626.0
    [m]
    DC
    RRI
    3635.0
    [m]
    DC
    RRI
    3644.0
    [m]
    DC
    RRI
    3656.0
    [m]
    DC
    RRI
    3665.0
    [m]
    DC
    RRI
    3674.0
    [m]
    DC
    RRI
    3680.0
    [m]
    DC
    RRI
    3695.0
    [m]
    DC
    RRI
    3704.0
    [m]
    DC
    RRI
    3725.0
    [m]
    DC
    RRI
    3734.0
    [m]
    DC
    RRI
    3755.0
    [m]
    DC
    RRI
    3785.0
    [m]
    DC
    RRI
    3806.0
    [m]
    DC
    RRI
    3815.0
    [m]
    DC
    RRI
    3824.0
    [m]
    DC
    RRI
    3836.0
    [m]
    DC
    RRI
    3875.0
    [m]
    DC
    RRI
    3884.0
    [m]
    DC
    RRI
    3908.0
    [m]
    DC
    GEUS
    3911.0
    [m]
    DC
    GEUS
    3914.0
    [m]
    DC
    RRI
    3917.0
    [m]
    DC
    GEUS
    3920.0
    [m]
    DC
    GEUS
    3923.0
    [m]
    DC
    GEUS
    3926.0
    [m]
    DC
    RRI
    3935.0
    [m]
    DC
    RRI
    3944.0
    [m]
    DC
    RRI
    3968.0
    [m]
    DC
    RRI
    3986.0
    [m]
    DC
    RRI
    4016.0
    [m]
    DC
    RRI

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.87

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.80

  • 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
    12.39

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CDL CNL GR
    2304
    3309
    CDL CNL GR
    2304
    3309
    CDL CNL GR
    3295
    4020
    CDL CNL LS BHC GR
    898
    2296
    COREGUN
    0
    0
    COREGUN
    0
    0
    COREGUN
    0
    0
    DIFL LS BHC GR
    2304
    3310
    DIFL LS BHC GR
    3265
    4020
    DIPLOG
    2304
    3309
    DIPLOG
    3300
    4020
    DLL MLL GR
    898
    2298
    FMT
    2086
    2177
    FMT
    3327
    3868
    FMT
    3327
    3868
    MWD - GR RES DEV
    207
    4020
    VSP
    2000
    4020

  • 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
    207.0
    36
    207.0
    0.00
    LOT
    SURF.COND.
    20
    897.0
    26
    915.0
    1.65
    LOT
    INTERM.
    13 3/8
    2304.0
    17 1/2
    2319.0
    1.77
    LOT
    INTERM.
    9 5/8
    3295.0
    12 1/4
    3321.0
    2.04
    LOT
    OPEN HOLE
    4020.0
    8 1/2
    4020.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    120
    1.46
    15.0
    4.4
    WATER BASED
    07.06.1988
    123
    1.05
    WATER BASED
    18.04.1988
    207
    1.05
    4.0
    13.0
    WATER BASED
    19.04.1988
    400
    1.13
    4.0
    12.0
    WATER BASED
    20.04.1988
    770
    1.12
    4.0
    12.0
    WATER BASED
    22.04.1988
    915
    1.12
    5.0
    10.1
    WATER BASED
    22.04.1988
    915
    1.15
    WATER BASED
    27.04.1988
    915
    1.15
    4.0
    9.6
    WATER BASED
    27.04.1988
    1060
    1.16
    20.0
    8.7
    WATER BASED
    27.04.1988
    1405
    1.23
    22.0
    9.1
    WATER BASED
    27.04.1988
    1730
    1.40
    24.0
    7.7
    WATER BASED
    28.04.1988
    1764
    1.42
    31.0
    7.7
    WATER BASED
    29.04.1988
    1925
    1.42
    29.0
    6.8
    WATER BASED
    02.05.1988
    2035
    1.42
    26.0
    6.3
    WATER BASED
    02.05.1988
    2064
    1.42
    27.0
    5.8
    WATER BASED
    02.05.1988
    2209
    1.42
    24.0
    5.3
    WATER BASED
    03.05.1988
    2245
    1.42
    23.0
    5.8
    WATER BASED
    04.05.1988
    2319
    1.42
    17.0
    3.9
    WATER BASED
    06.05.1988
    2319
    1.42
    17.0
    3.9
    WATER BASED
    09.05.1988
    2319
    1.42
    18.0
    3.9
    WATER BASED
    05.05.1988
    2319
    1.42
    16.0
    4.4
    WATER BASED
    09.05.1988
    2450
    1.42
    17.0
    5.3
    WATER BASED
    10.05.1988
    2598
    1.45
    21.0
    7.2
    WATER BASED
    13.05.1988
    2703
    1.45
    18.0
    7.7
    WATER BASED
    13.05.1988
    2793
    1.45
    16.0
    4.8
    WATER BASED
    16.05.1988
    2793
    1.45
    19.0
    7.7
    WATER BASED
    13.05.1988
    2932
    1.50
    15.0
    4.8
    WATER BASED
    16.05.1988
    3086
    1.50
    15.0
    4.8
    WATER BASED
    16.05.1988
    3100
    1.52
    20.0
    5.3
    WATER BASED
    24.05.1988
    3100
    1.52
    21.0
    5.8
    WATER BASED
    24.05.1988
    3100
    1.52
    22.0
    4.8
    WATER BASED
    24.05.1988
    3146
    1.46
    15.0
    4.4
    WATER BASED
    07.06.1988
    3157
    1.50
    16.0
    4.4
    WATER BASED
    18.05.1988
    3177
    1.50
    16.0
    4.4
    WATER BASED
    18.05.1988
    3226
    1.52
    18.0
    6.3
    WATER BASED
    19.05.1988
    3283
    1.52
    19.0
    5.3
    WATER BASED
    20.05.1988
    3310
    1.52
    21.0
    5.8
    WATER BASED
    24.05.1988
    3321
    1.48
    15.0
    5.3
    WATER BASED
    25.05.1988
    3538
    1.48
    22.0
    6.3
    WATER BASED
    26.05.1988
    3709
    1.48
    30.0
    8.2
    WATER BASED
    30.05.1988
    3859
    1.48
    32.0
    8.2
    WATER BASED
    30.05.1988
    3902
    1.48
    32.0
    9.1
    WATER BASED
    30.05.1988
    4009
    1.48
    29.0
    7.2
    WATER BASED
    30.05.1988
    4020
    1.48
    23.0
    5.3
    WATER BASED
    31.05.1988
    4020
    1.48
    22.0
    6.3
    WATER BASED
    01.06.1988
    4020
    1.48
    22.0
    6.3
    WATER BASED
    02.06.1988
    4020
    1.46
    21.0
    6.3
    WATER BASED
    03.06.1988
    4020
    1.46
    17.0
    4.4
    WATER BASED
    07.06.1988
    4020
    1.46
    20.0
    5.3
    WATER BASED
    07.06.1988

  • 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