Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
27.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

31/4-9

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.
    31/4-9
    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.
    31/4-9
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 8501 - 129 SP 610
    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 Hydro Produksjon 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.
    534-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.
    44
    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,
    23.01.1987
    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.
    07.03.1987
    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.
    07.03.1989
    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.
    06.01.2014
    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.
    APPRAISAL
    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.
    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.
    FENSFJORD FM
    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.
    147.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2480.0
    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).
    2480.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    100
    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.
    DRAKE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 32' 2.29'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 5' 26.92'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6711042.08
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    504983.64
    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.
    1026

  • Wellbore history
    General
    Well 31/4-9 was drilled as an appraisal well on the Brage Field on the Bjørgvin Arch in the North Sea. The main objective was to establish the OWC and confirm reservoir trends, hydrocarbon column and reserve potential in the east flank of the structure. TD was prognosed at 2500 m, 70 m into the Dunlin Group.
    Operations and results
    Appraisal well 31/4-9 was spudded with the semi-submersible installation Polar Pioneer on 23 January 1987 and drilled to TD at 2480 m in the Early Jurassic Drake Formation. No significant problem was encountered in the operations. The well was drilled with spud mud down to 974 m, with KCl/polymer mud from 974 m to 2027 m, and with NaCl/CaCO3/polymer mud from 2027 m to TD.
    The Fensfjord reservoir came in at 2168.5 m and consisted mainly of fine to medium grained sandstones grading into and interbedded with siltstones. The Fensfjord Formation was oil bearing down to the oil-water contact at 2172 m. The Brent sandstone was found to be water bearing. Oil shows were described in the cored sections from 2103.5 m in the Draupne Formation down to 2222 m in the Fensfjord Formation.
    An attempt to take two cores in the Tertiary claystones failed. Eight cores were cut with good recovery in the interval 2103 to 2222 m in the Heather and Fensfjord formations. RFT oil samples were taken at 2171.5 m topmost in the Fensfjord Formation
    The well was permanently abandoned on 7 March 1987 as an oil appraisal well.
    Testing
    Two drill stem tests were performed in the Fensfjord Formation.
    DST 1 tested water from the interval 2193.1-2208.1 m through a 50.8 mm choke. The maximum production rate was 577.5 Sm3/day. An injection test was also performed with a maximum injection rate of 576 Sm3/day. Flowing bottom hole temperature was 90.8 deg C.
    DST 2 tested oil from the interval 2169.6-2171.6 m through a 12.7 mm choke. The maximum flow rate for the oil was 311.1 Sm3/day and for the gas 23253 Sm3/day. DST 2 also produced 7-8% water and emulsion on average. The GOR was 75 Sm3/Sm3, the oil gravity was 0.875 g/cm3, and the gas gravity was 0.769 (air=l) with 0.5 - 1.0 % CO2. Flowing bottom hole temperature was 88.1 deg 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]
    980.00
    2480.00

  • 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
    3
    2105.0
    2106.8
    [m ]
    4
    2107.0
    2114.9
    [m ]
    5
    2116.5
    2131.5
    [m ]
    6
    2132.5
    2151.1
    [m ]
    7
    2149.5
    2164.5
    [m ]
    8
    2164.5
    2176.5
    [m ]
    9
    2176.5
    2194.4
    [m ]
    10
    2194.0
    2222.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    116.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Oil samples at the Norwegian Offshore Directorate
    Oil samples at the Norwegian Offshore Directorate
    Test type
    Bottle number
    Top depth
    MD [m]
    Bottom depth
    MD [m]
    Fluid type
    Test time
    Samples available
    DST
    DST2
    2169.60
    2171.60
    OIL
    01.03.1987 - 00:00
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.28
    pdf
    0.86
    pdf
    0.57

  • 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
    3.54
    .pdf
    14.45

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2193
    2208
    50.8
    2.0
    2170
    2172
    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
    90
    2.0
    88
    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
    2.0
    311
    23253
    0.875
    0.769
    75

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL CST VDL GR
    1500
    2389
    CST
    2008
    2471
    DIL LSS GR SP
    945
    1855
    DITE LDL CNL NGT
    1998
    2471
    DLL MSFL SDT GR
    1998
    2471
    GR
    170
    945
    MWD - GR RES
    181
    2480
    RFT
    2120
    2409
    RFT
    2171
    0
    SHDT
    1998
    2474
    VSP
    360
    2466

  • 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
    254.0
    36
    254.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    974.0
    17 1/2
    974.0
    0.00
    LOT
    INTERM.
    9 5/8
    1998.0
    12 1/4
    2077.0
    0.00
    LOT
    LINER
    7
    2479.0
    8 3/8
    2480.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    169
    1.20
    29.0
    10.0
    WATERBASED
    09.03.1987
    253
    1.03
    WATERBASED
    26.01.1987
    466
    1.03
    99.0
    99.0
    WATERBASED
    26.01.1987
    849
    1.20
    29.0
    10.0
    WATERBASED
    06.03.1987
    920
    1.03
    99.0
    99.0
    WATERBASED
    26.01.1987
    970
    1.03
    WATERBASED
    27.01.1987
    974
    0.00
    25.0
    15.0
    WATERBASED
    29.01.1987
    974
    1.03
    99.0
    99.0
    WATERBASED
    28.01.1987
    1087
    1.25
    27.0
    18.0
    WATERBASED
    30.01.1987
    1363
    1.25
    25.0
    17.0
    WATERBASED
    02.02.1987
    1458
    1.40
    27.0
    15.0
    WATERBASED
    02.02.1987
    1800
    1.20
    29.0
    10.0
    WATERBASED
    05.03.1987
    1962
    1.40
    30.0
    17.0
    WATERBASED
    04.02.1987
    2027
    1.40
    34.0
    20.0
    WATERBASED
    02.02.1987
    2027
    0.00
    31.0
    18.0
    WATERBASED
    03.02.1987
    2033
    1.20
    28.0
    9.0
    WATERBASED
    05.02.1987
    2105
    1.20
    30.0
    11.0
    WATERBASED
    09.02.1987
    2115
    1.20
    27.0
    8.0
    WATERBASED
    09.02.1987
    2141
    1.20
    28.0
    9.0
    WATERBASED
    09.02.1987
    2159
    1.20
    29.0
    10.0
    WATERBASED
    04.03.1987
    2177
    0.00
    36.0
    12.0
    WATERBASED
    27.02.1987
    2177
    0.00
    35.0
    11.0
    WATERBASED
    02.03.1987
    2177
    0.00
    35.0
    12.0
    WATERBASED
    02.03.1987
    2177
    0.00
    29.0
    10.0
    WATERBASED
    03.03.1987
    2177
    1.21
    25.0
    7.0
    WATERBASED
    09.02.1987
    2222
    1.21
    27.0
    10.0
    WATERBASED
    10.02.1987
    2242
    1.20
    33.0
    10.0
    WATERBASED
    20.02.1987
    2242
    0.00
    33.0
    10.0
    WATERBASED
    23.02.1987
    2242
    0.00
    33.0
    10.0
    WATERBASED
    24.02.1987
    2242
    0.00
    30.0
    10.0
    WATERBASED
    25.02.1987
    2242
    0.00
    36.0
    12.0
    WATERBASED
    26.02.1987
    2377
    1.21
    29.0
    10.0
    WATERBASED
    11.02.1987
    2394
    1.20
    31.0
    10.0
    WATERBASED
    19.02.1987
    2479
    1.20
    26.0
    8.0
    WATERBASED
    18.02.1987
    2479
    0.00
    25.0
    8.0
    WATERBASED
    18.02.1987
    2479
    0.00
    25.0
    7.0
    WATERBASED
    18.02.1987
    2479
    0.00
    31.0
    10.0
    WATERBASED
    18.02.1987
    2480
    1.20
    26.0
    10.0
    WATERBASED
    12.02.1987
    2480
    0.00
    26.0
    10.0
    WATERBASED
    13.02.1987
    2480
    0.00
    26.0
    10.0
    WATERBASED
    18.02.1987

  • 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