Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.11.2024 - 09:09
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25/7-3

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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.
    25/7-3
    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
    Multilateral
    Indicator telling if the parent well is multilateral, meaning it has more than one branch radiating from the main borehole. Example of legal values: YES, NO. See also Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    NO
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    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.
    25/7-3
    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.
    Conoco Norway Inc.
    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.
    819-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.
    33
    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,
    27.07.1995
    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.
    28.08.1995
    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.
    28.08.1997
    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.
    29.08.2003
    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
    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.
    PALEOCENE
    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.
    HEIMDAL 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.
    127.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2540.0
    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).
    2539.2
    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.
    95
    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 CRETACEOUS
    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.
    TOR FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 26' 8.81'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 19' 28'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6588925.44
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    461677.84
    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.
    2623

  • Wellbore history
    General
    Well 25/7-3 was a discretionary exploration well approximately 3 km south-south west of well 25/8-5 S which discovered oil in the Elli structure. Block 25/7 is situated in the South Viking Graben on the western side of the Utsira High, a basement high that tilts slightly towards the east. The South Viking Graben has an asymmetrical profile bounded in the west by the Brae/Crawford Fault Zone and the Utsira High to the east. The Elli structure is located on a basement terrace stepping up to the Utsira High from the Graben area.
    The primary objective of well 25/7-3 was to prove commercial reserves in Elli South by testing the hydrocarbon potential of the Paleocene Upper Heimdal Formation. Secondary objectives were to define fluid contacts within the Heimdal Formation, to provide sufficient data for development planning start-up, find a possible point of production should the results be positive, and to obtain a good well tie to the top Cretaceous and top Balder seismic reflectors.
    Operations and results
    Exploration well 25/7-3 was spudded with the semi-submersible installation "Deepsea Bergen" on 27 July 1995 and drilled to TD at 2540 m in the Late Cretaceous Tor Formation. The AFE estimated time for the well was 28.1 days dry hole plus 10.5 days to DST. Actual estimated drilling time was 23.6 days, and testing was 9.8 days. The well was drilled with bentonite spud mud down to 1186 m and with "ANCO 2000" mud with ANCO 208 glycol additive from 1186 m to TD. Top Lista Formation came in at 2052 m, ca 20 shallower than prognosed. Top Heimdal Formation was found at 2094 m. The Heimdal Formation was hydrocarbon bearing with an OWC at 2114.5 m.
    Two cores were cut in the Heimdal Formation, both with full recovery. The first core was cut 2099-2110.6 m, and the second at 2111-2130.2 m. Shows were described in the cores down to a depth of 2117 m. A total of 20 FMT pressure tests were taken, with 19 successfully recorded. An FMT oil sample was taken at the depth of 2112 m. The fluid was described as medium to dark brown with moderate viscosity and dull to intermediate white to pale yellow direct fluorescence. The well was permanently abandoned on 28 August 1995 as an oil discovery, named the 25/7-3 Jotun Discovery.
    Testing
    One drill stem test was performed in the Heimdal Formation sandstones (2096.4-2107.4 m). Final oil flow was 739 Sm3/day and final gas flow was 29207 Sm3/day.

  • 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]
    1200.00
    2540.00

  • 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
    2099.0
    2110.6
    [m ]
    2
    2111.0
    2130.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    30.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2099-2110m
    Core photo at depth: 2099-2110m
    Core photo at depth: 2099-2110m
    Core photo at depth: 2099-2110m
    Core photo at depth: 2099-2110m
    2099-2110m
    2099-2110m
    2099-2110m
    2099-2110m
    2099-2110m
    Core photo at depth: 2099-2110m
    Core photo at depth: 2099-2110m
    Core photo at depth: 2099-2110m
    Core photo at depth: 2099-2110m
    Core photo at depth: 2099-2110m
    2099-2110m
    2099-2110m
    2099-2110m
    2099-2110m
    2099-2110m
    Core photo at depth: 2099-2110m
    Core photo at depth: 2099-2110m
    Core photo at depth: 2099-2110m
    Core photo at depth: 2099-2110m
    Core photo at depth: 2099-2110m
    2099-2110m
    2099-2110m
    2099-2110m
    2099-2110m
    2099-2110m
    Core photo at depth: 2099-2110m
    Core photo at depth: 2099-2110m
    Core photo at depth: 2099-2110m
    Core photo at depth: 2099-2110m
    Core photo at depth: 2099-2110m
    2099-2110m
    2099-2110m
    2099-2110m
    2099-2110m
    2099-2110m
    Core photo at depth: 2099-2110m
    Core photo at depth: 2099-2110m
    Core photo at depth: 2099-2110m
    Core photo at depth: 2111-2130m
    Core photo at depth: 2111-2130m
    2099-2110m
    2099-2110m
    2099-2110m
    2111-2130m
    2111-2130m
    Core photo at depth: 2111-2130m
    Core photo at depth: 2111-2130m
    Core photo at depth: 2111-2130m
    Core photo at depth: 2111-2130m
    Core photo at depth: 2111-2130m
    2111-2130m
    2111-2130m
    2111-2130m
    2111-2130m
    2111-2130m
    Core photo at depth: 2111-2130m
    Core photo at depth: 2111-2130m
    Core photo at depth: 2111-2130m
    Core photo at depth: 2111-2130m
    Core photo at depth: 2111-2130m
    2111-2130m
    2111-2130m
    2111-2130m
    2111-2130m
    2111-2130m
    Core photo at depth: 2111-2130m
    Core photo at depth: 2111-2130m
    Core photo at depth: 2111-2130m
    Core photo at depth: 2111-2130m
    Core photo at depth: 2110-2130m
    2111-2130m
    2111-2130m
    2111-2130m
    2111-2130m
    2110-2130m
    Core photo at depth: 2111-2130m
    Core photo at depth: 2111-2130m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2111-2130m
    2111-2130m

  • 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
    DST1
    2107.40
    2096.40
    OIL
    22.08.1995 - 02:00
    YES

  • 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
    223.0
    36
    223.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    1179.0
    17 1/2
    1180.0
    1.56
    LOT
    INTERM.
    9 5/8
    1958.0
    12 1/4
    1960.0
    1.70
    LOT
    LINER
    7
    2540.0
    8 1/2
    2540.0
    0.00
    LOT

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2096
    2107
    25.4
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.000
    17.000
    83
    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
    739
    29207
    0.839
    39

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DLL MLL GR
    1955
    2530
    FMT GR
    2097
    2270
    HDIP GR
    1945
    2534
    MWD - DIR GR SN
    227
    1186
    MWD - DIR GR SN
    1186
    1966
    MWD DPR - DIR GR SN
    1966
    2540
    SWC
    1962
    2483
    SWC
    1973
    2081
    VSP
    1000
    2520
    ZDL CN MAC SL
    1955
    2528

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.40

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.76
    pdf
    1.05

  • 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
    150.93

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    172
    1.03
    SPUD MUD
    792
    1.03
    SPUD MUD
    1186
    1.46
    16.0
    KCL/glycol
    1966
    1.50
    13.3
    ANCO 2000

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1620.0
    [m]
    DC
    RRI
    1760.0
    [m]
    DC
    RRI
    1780.0
    [m]
    DC
    RRI
    1800.0
    [m]
    DC
    RRI
    1820.0
    [m]
    DC
    RRI
    1840.0
    [m]
    DC
    RRI
    1860.0
    [m]
    DC
    RRI
    1880.0
    [m]
    DC
    RRI
    1900.0
    [m]
    DC
    RRI
    1920.0
    [m]
    DC
    RRI
    1930.0
    [m]
    DC
    RRI
    1940.0
    [m]
    DC
    RRI
    1960.0
    [m]
    DC
    RRI
    2001.0
    [m]
    DC
    RRI
    2019.0
    [m]
    DC
    RRI
    2140.0
    [m]
    DC
    RRI
    2160.0
    [m]
    DC
    RRI
    2240.0
    [m]
    DC
    RRI
    2260.0
    [m]
    DC
    RRI
    2280.0
    [m]
    DC
    RRI
    2300.0
    [m]
    DC
    RRI
    2350.0
    [m]
    DC
    RRI
    2380.0
    [m]
    DC
    RRI
    2400.0
    [m]
    DC
    RRI
    2440.0
    [m]
    DC
    RRI
    2480.0
    [m]
    DC
    RRI
    2500.0
    [m]
    DC
    RRI
    2520.0
    [m]
    DC
    RRI
    2540.0
    [m]
    DC
    RRI