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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25/3-1

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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.
    25/3-1
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    25/3-1
    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.
    Elf Petroleum Norge 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.
    613-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.
    63
    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,
    05.07.1989
    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.
    05.09.1989
    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.
    05.09.1991
    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.
    25.06.2005
    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.
    DRY
    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.
    22.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    114.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3922.0
    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).
    3921.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.8
    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.
    STATFJORD GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 55' 52.99'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 46' 21.34'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6643946.88
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    487288.97
    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.
    1419

  • Wellbore history
    General
    Well 25/3-1 was designed to drill a narrow NNW-SSE trending horst structure on the Utsira High. The main objective for the well was to test the hydrocarbon potential of the Middle Jurassic Vestland Group sandstones, and the Lower Jurassic Statfjord Formation sandstones. The site survey indicated two high amplitude events at two different levels west (135 m MSL) and northwest (180 m MSL) of the proposed well location that could indicate shallow gas.
    Operations and results
    Wildcat well 25/3-1 was spudded with the semi-submersible installation West Vanguard on 4 July 1989and drilled to TD at 3922 m in Late Triassic sediments of the Statfjord Formation. To assure safe operation in possible shallow gas zones, the interval (198 to 720 m) was drilled as a 17 1/2 " pilot hole before opening to 26" hole. Drilling went on without any serious problems. No shallow gas was encountered.
    The Vestland Group reservoir was reached 65 m deeper than expected. The reservoir was thinner than expected, and of relatively bad quality and water bearing. The Statfjord Formation was reached 128 m deeper than expected, and also water bearing. Very weak shows were recorded in two samples from 2165 m and 2170 m in the Balder Formation; otherwise no shows were recorded while drilling. Geochemical source rock screening found very good Type II kerogen (oil) source potential in the Draupne Formation and good Type II-III kerogen (gas + light oil) source potential in the Heather shales and the Vestland Group coals and shales. The well has reached early maturity probably at ca 2700 m, so the Draupne shale is in the very early oil window.
    Two cores were cut. Core no 1 was cut from 3112 to 3130 m in the Vestland Group, and no 2 from 3858 to 3876 m in the Statfjord Formation. The RFT tool was run, but due to obstruction in the hole representative pressure points were not obtained. No fluid sample was taken.
    The well was permanently abandoned on 5 September 1989 as a dry hole.
    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]
    200.00
    3922.00

  • 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
    3112.0
    3129.9
    [m ]
    2
    3858.0
    3873.9
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    33.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3112-3117m
    Core photo at depth: 3117-3122m
    Core photo at depth: 3122-3127m
    Core photo at depth: 3127-3129m
    Core photo at depth: 3858-3863m
    3112-3117m
    3117-3122m
    3122-3127m
    3127-3129m
    3858-3863m
    Core photo at depth: 3863-3868m
    Core photo at depth: 3868-3873m
    Core photo at depth: 3873-3874m
    Core photo at depth:  
    Core photo at depth:  
    3863-3868m
    3868-3873m
    3873-3874m

  • 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
    197.0
    36
    198.0
    0.00
    LOT
    INTERM.
    20
    703.0
    26
    720.0
    1.33
    LOT
    INTERM.
    13 3/8
    1983.0
    17 1/2
    1998.0
    1.66
    LOT
    INTERM.
    9 5/8
    2991.0
    12 1/4
    3005.0
    1.93
    LOT
    OPEN HOLE
    3922.0
    8 1/2
    3922.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    1750
    2990
    CBL VDL GR CCL
    1360
    1984
    CDM AP
    1998
    2970
    CDM AP
    2997
    3918
    CDM AP
    3100
    3918
    DIL DDBHC GR AMS SP
    703
    1998
    DIL DDBHC GR AMS SP
    1984
    2995
    DIL GR SLS MSFL AMS
    2993
    3921
    FMS GR
    2993
    3922
    LDL CNL NGS AMS
    2993
    3922
    LDL GR AMS
    703
    1998
    LDL GR AMS
    1984
    2995
    MSD
    1998
    2970
    MWD
    199
    3922
    NGT RATIOS
    2993
    3922
    SHDT GR AMS
    1984
    2993
    STL GR
    2003
    2985
    VELOCITY
    707
    3921

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.62

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    2.60

  • 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
    15.41

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    909
    1.09
    16.0
    9.8
    WATER BASED
    14.07.1989
    1243
    1.13
    19.0
    10.7
    WATER BASED
    14.07.1989
    1840
    1.20
    22.0
    11.7
    WATER BASED
    17.07.1989
    1858
    1.21
    26.0
    12.7
    WATER BASED
    18.07.1989
    1948
    1.20
    23.0
    12.2
    WATER BASED
    19.07.1989
    1998
    1.20
    22.0
    12.2
    WATER BASED
    20.07.1989
    3071
    1.25
    26.0
    7.3
    WATER BASED
    10.08.1989
    3118
    1.25
    31.0
    5.8
    WATER BASED
    11.08.1989
    3198
    1.25
    34.0
    12.7
    WATER BASED
    14.08.1989
    3291
    1.25
    32.0
    12.7
    WATER BASED
    14.08.1989
    3353
    1.25
    30.0
    11.7
    WATER BASED
    14.08.1989
    3395
    1.25
    28.0
    11.7
    WATER BASED
    15.08.1989
    3429
    1.30
    31.0
    11.7
    WATER BASED
    22.08.1989
    3456
    1.26
    30.0
    11.7
    WATER BASED
    16.08.1989
    3491
    1.30
    31.0
    13.7
    WATER BASED
    17.08.1989
    3569
    1.30
    31.0
    12.7
    WATER BASED
    22.08.1989
    3719
    1.35
    33.0
    14.7
    WATER BASED
    22.08.1989
    3774
    1.35
    34.0
    13.7
    WATER BASED
    22.08.1989
    3858
    1.35
    34.0
    11.7
    WATER BASED
    24.08.1989
    3858
    1.35
    34.0
    11.7
    WATER BASED
    24.08.1989
    3871
    1.45
    37.0
    12.7
    WATER BASED
    25.08.1989

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1680.0
    [m]
    DC
    RRI
    1700.0
    [m]
    DC
    RRI
    1720.0
    [m]
    DC
    RRI
    1740.0
    [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
    1940.0
    [m]
    DC
    RRI
    1960.0
    [m]
    DC
    RRI
    1980.0
    [m]
    DC
    RRI
    2000.0
    [m]
    DC
    RRI
    2020.0
    [m]
    DC
    RRI
    2040.0
    [m]
    DC
    RRI
    2060.0
    [m]
    DC
    RRI
    2080.0
    [m]
    DC
    RRI
    2100.0
    [m]
    DC
    RRI
    2120.0
    [m]
    DC
    RRI
    2140.0
    [m]
    DC
    RRI
    2160.0
    [m]
    DC
    RRI
    2180.0
    [m]
    DC
    RRI
    2200.0
    [m]
    DC
    RRI
    2220.0
    [m]
    DC
    RRI
    2240.0
    [m]
    DC
    RRI
    2260.0
    [m]
    DC
    RRI
    2280.0
    [m]
    DC
    RRI
    2310.0
    [m]
    DC
    RRI
    2330.0
    [m]
    DC
    RRI
    2350.0
    [m]
    DC
    RRI
    2370.0
    [m]
    DC
    RRI
    2390.0
    [m]
    DC
    RRI
    2410.0
    [m]
    DC
    RRI
    2430.0
    [m]
    DC
    RRI
    3112.0
    [m]
    C
    RRI
    3116.0
    [m]
    C
    RRI
    3119.0
    [m]
    C
    RRI
    3126.0
    [m]
    C
    RRI
    3128.0
    [m]
    C
    RRI
    3325.0
    [m]
    DC
    RRI
    3340.0
    [m]
    DC
    RRI