Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
24.11.2024 - 01:27
Time of last synchronization with Norwegian Offshore Directorate's internal systems

30/4-2

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.
    30/4-2
    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
    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.
    30/4-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    802-55 SP 93.8
    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.
    230-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.
    183
    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,
    16.11.1979
    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.
    16.05.1980
    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.
    16.05.1982
    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.
    10.04.2015
    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/CONDENSATE
    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.
    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.
    BRENT GP
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    123.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4775.0
    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).
    4764.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    8
    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.
    HEGRE GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 31' 1.1'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 2' 46.22'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6709524.95
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    447628.55
    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.
    378

  • Wellbore history
    General
    Well 30/4-2 was drilled test an easterly dipping fault block on the western margin of the Viking Graben. The primary target was the Brent Group, which had already been proven to contain gas condensate by well 30/7-6 located 3 km to the South on the same structure. Secondary objectives were to test Palaeocene and Lower Eocene sandstones, and the Statfjord Formation. Well 30/7-2 had earlier encountered a hydrocarbon column with dry gas overlying heavy oil in the uppermost part of the Eocene Frigg Formation.
    Operations and results
    Well 30/4-2 was spudded with the semi-submersible installation SEDCO 707 on 16 November 1979 and drilled to TD at 4775 m in the Triassic Hegre Group. Bad weather caused some delay, and on 12 March, the drill string was hung-off due to adverse weather conditions. Whilst retrieving the running assembly an influx from the well was observed. The influx was bull-headed and it took five days before the well was in stable conditions again. Otherwise, no significant incident happened in the operations. The well was drilled with seawater and gel down to 1096 m, with lignosulphonate/Drispac/Gypsum mud from 1096 m to 2530 m, and with lignosulphonate/Poly-rx from 2530 to TD.
    The Frigg Formation was encountered water-wet without shows at 1820 m, 36.5 m below the OWC defined in the 30/7-2 Frigg discovery. The Brent Group was encountered at 3779 m. Brent contained gas/condensate and had excellent poroperm characteristics. The gas-water contact established between 3876.5 m and 3893.5 m in the Ness Formation. The Statfjord Formation was encountered water-wet at 4337 m with only some poor shows in the top. Pressure analysis showed that it was not communicating with the Brent Group.
    Thirteen full-hole cores were cut in well 30/4-2: two in the Tertiary, ten in the Jurassic Brent Group and one in the Dunlin formation. A total of 143.7 m core was recovered. A segregated RFT sample was take at 3827.5 m
    The well was permanently abandoned on 16 May 1980 as a gas/condensate appraisal well.
    Testing
    One drill stem test was performed from the interval 3832 to 3838.1 m. The test produced 811300 Sm3 gas and 174 Sm3 condensate /day through two downhole 1/2" chokes and a 38/64" surface choke. The GOR was 4663 Sm3/Sm3, the oil gravity was 45 °API, and the gas gravity was 0.64 (air = 1). The maximum gauge temperature in the test was 134.4 °C.

  • 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]
    288.00
    4774.00

  • 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
    2
    2043.0
    2047.4
    [m ]
    3
    3784.0
    3784.9
    [m ]
    4
    3788.8
    3805.4
    [m ]
    5
    3805.4
    3822.3
    [m ]
    6
    3823.5
    3829.9
    [m ]
    7
    3829.9
    3834.7
    [m ]
    8
    3834.7
    3852.8
    [m ]
    9
    3853.1
    3871.3
    [m ]
    10
    3871.5
    3873.0
    [m ]
    11
    3873.0
    3891.4
    [m ]
    12
    3891.4
    3909.7
    [m ]
    13
    4239.5
    4257.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    142.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1070.0
    [m]
    DC
    GEOCH
    1100.0
    [m]
    DC
    GEOCH
    1110.0
    [m]
    DC
    GEOCH
    1160.0
    [m]
    DC
    GEOCH
    1190.0
    [m]
    DC
    GEOCH
    1220.0
    [m]
    DC
    GEOCH
    1250.0
    [m]
    DC
    GEOCH
    1280.0
    [m]
    DC
    GEOCH
    1310.0
    [m]
    DC
    GEOCH
    1340.0
    [m]
    DC
    GEOCH
    1370.0
    [m]
    DC
    GEOCH
    1400.0
    [m]
    DC
    GEOCH
    1430.0
    [m]
    DC
    GEOCH
    1460.0
    [m]
    DC
    GEOCH
    1490.0
    [m]
    DC
    GEOCH
    1520.0
    [m]
    DC
    GEOCH
    1550.0
    [m]
    DC
    GEOCH
    1580.0
    [m]
    DC
    GEOCH
    1610.0
    [m]
    DC
    GEOCH
    1640.0
    [m]
    DC
    GEOCH
    1670.0
    [m]
    DC
    GEOCH
    1710.0
    [m]
    DC
    GEOCH
    1740.0
    [m]
    DC
    GEOCH
    1769.0
    [m]
    DC
    GEOCH
    1796.0
    [m]
    DC
    GEOCH
    1823.0
    [m]
    DC
    GEOCH
    1850.0
    [m]
    DC
    GEOCH
    1877.0
    [m]
    DC
    GEOCH
    1904.0
    [m]
    DC
    GEOCH
    1931.0
    [m]
    DC
    GEOCH
    1958.0
    [m]
    DC
    GEOCH
    1994.0
    [m]
    DC
    GEOCH
    2021.0
    [m]
    DC
    GEOCH
    2045.0
    [m]
    DC
    GEOCH
    2075.0
    [m]
    DC
    GEOCH
    2102.0
    [m]
    DC
    GEOCH
    2130.0
    [m]
    DC
    GEOCH
    2160.0
    [m]
    DC
    GEOCH
    2190.0
    [m]
    DC
    GEOCH
    2220.0
    [m]
    DC
    GEOCH
    2250.0
    [m]
    DC
    GEOCH
    2280.0
    [m]
    DC
    GEOCH
    2310.0
    [m]
    DC
    GEOCH
    2340.0
    [m]
    DC
    GEOCH

  • Lithostratigraphy

  • 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
    78.46

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3807
    3813
    15.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    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
    6818
    812000
    0.802
    0.640
    199

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL
    2100
    2716
    CBL
    3505
    4153
    CBL
    3515
    4174
    CST
    0
    0
    DLL
    3717
    3964
    FDC CNL
    1120
    2115
    FDC CNL
    3925
    4196
    FDC CNL
    4184
    4772
    HDT
    3717
    4196
    HDT
    4185
    4501
    HRT
    2000
    2897
    ISF SON
    284
    1137
    ISF SON
    1100
    2525
    ISF SON
    1745
    2117
    ISF SON
    2490
    3723
    ISF SON
    3695
    3716
    ISF SON
    3925
    4197
    ISF SON
    4190
    3393
    ISF SON
    4405
    4775
    RDC CNL
    3717
    3966
    RFT
    3161
    3701
    RFT
    3782
    3782
    RFT
    3785
    3947
    RFT
    4349
    4476
    VS
    284
    3725
    VS
    3725
    4532

  • 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
    261.0
    36
    264.0
    0.00
    LOT
    SURF.COND.
    20
    1105.0
    26
    1111.0
    1.53
    LOT
    INTERM.
    13 3/8
    2499.0
    17 1/2
    2506.0
    1.79
    LOT
    INTERM.
    9 5/8
    3694.0
    12 1/4
    3692.0
    2.09
    LOT
    LINER
    7
    4170.0
    8 1/2
    4172.0
    2.27
    LOT
    OPEN HOLE
    4751.0
    6
    4751.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    946
    1.06
    waterbased
    1532
    1.19
    waterbased
    2091
    1.28
    waterbased
    2977
    1.65
    waterbased
    3455
    1.70
    waterbased
    3942
    2.04
    waterbased
    4751
    2.09
    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