Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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23.07.2024 - 01:26
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25/5-4

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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.
    25/5-4
    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).
    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
    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.
    25/5-4
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    EL 8902 - 308 & SP. 660
    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.
    661-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.
    76
    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,
    22.12.1990
    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.
    07.03.1991
    Plugged and abondon date
    Date when the P&A-operations of the wellbore was finished, as reported by the operator to the Norwegian Offshore Directorate throught DDRS (Daily Drilling Reporting System). Only applied once pr. wellhead/surface location.
    25.07.2015
    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.
    07.03.1993
    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.
    15.08.2008
    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.
    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.
    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.
    HUGIN FM
    2nd level with HC, age
    Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    MIDDLE JURASSIC
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd 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.
    SLEIPNER FM
    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.
    120.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3185.0
    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).
    3184.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    111
    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.
    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° 36' 33.22'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 28' 32.07'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6608163.57
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    470403.24
    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.
    1691
  • Wellbore history

    Well 25/5-4 is located approximately in the centre between the 5/5-5 Discovery and the Frøy and Skirne Fields in the northern North Sea. The prospect was defined at Intra Statfjord Formation level, consisting of two compartments offset by an E-W fault. No significant closure was expected at Base Cretaceous. The main target was the Middle Jurassic Vestland Group sandstones. Early Jurassic Statfjord sandstones was secondary target. The expected fluid was most likely oil. No shallow gas was expected.
    Operations and results
    Wildcat well 25/5-4 was spudded with the semi-submersible installation Dyvi Stena on 22 December 1990 and drilled to TD at 3185 m in Early Jurassic sediments of the Statfjord Formation. Only minor problems were encountered during drilling the Hordaland Group. The well was drilled with sea water and bentonite down to 1208 m, with a KCl mud from 1208 m to 2805 m, and with lignosulphonate mud from to 2805 m to TD.
    The results for the main seismic markers were close to prognoses (from 17 to 36 m higher than prognosis). Sandy water bearing reservoirs were encountered in the basal Tertiary Heimdal and Ty Formations. The Vestland Group reservoir (Hugin + Sleipner Formations) was encountered from 2895 to 2941 m and was completely filled with a retrograde condensate. Extracts of core material showed a significant increase in extractable organic matter below 2932 m, and the EOM was significantly more oil-like (saturates > 55%) than the upper part of the reservoir. The Statfjord Formation proved good reservoir quality but was water bearing. Organic geochemical data proved excellent source rock characteristics in several levels throughout the Jurassic, with oil prone kerogen in the Draupne and Heather Formations, and gas - condensate prone kerogen in the Vestland Group and Statfjord Formation. The source potential of Draupne is similar to the one known in the surrounding wells, while the Heather has better characteristics. The extreme base of Heather (below 2889) exhibits a very good source rock potential. The mineralogical composition of the Draupne shales differs from the Heather formation (X-ray diffraction), the latter being more calcareous (18 to 26% of calcite instead of 0 to 14%). Vitrinite reflection indicates beginning of the oil window (%Ro = 0.55) at ca 3000 m in the Dunlin Group, below the best source rocks in the well.
    Three conventional cores were cut, two from 2904 to 2949 m in the Hugin and Sleipner Formations, and one from 3059 to 3077 m at top Statfjord Formation. Segregated FMT samples were taken at 2929.5 and 2935.2 m in the Sleipner Formation. The 2 3/4 gal chambers in both samples were opened offshore and both contained about 1500 litres gas, 0.8 litres condensate and 1 litre mud filtrate.
    The well was suspended on 7 March as a gas/condensate discovery. The well was planned to be re-used as a producer.
    Testing
    One DST tests was performed in the interval 2923 - 2933 m and flowed at a rate of 759600 Sm3/d gas and 223 Sm3/d condensate through a 20.3 mm choke. The gas-condensate ratio was ca 3500 Sm3/Sm3. The condensate density was 0.76 g/cm3 and the gas gravity (air = 1) was 0.70. The maximum flowing temperature was 105 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]
    510.00
    3185.00
  • 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
    2904.0
    2921.9
    [m ]
    2
    2922.0
    2947.4
    [m ]
    3
    3059.0
    3075.6
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    59.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Lithostratigraphy

  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.21
  • 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
    124.10
    PDF
    9.55
  • Drill stem tests (DST)

    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2933
    2923
    20.6
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    14.000
    29.000
    104
    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
    223
    759600
    0.760
    0.720
    3398
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CAL LDL GST GR
    1199
    2789
    CBL
    680
    1199
    CBL VDL
    1050
    2794
    CNL LDT NGT
    2792
    2987
    CST GR
    1521
    2783
    CST GR
    2794
    3153
    DIP GR
    1199
    2791
    DLL ML GR
    2792
    2987
    GR BHC DIL
    1199
    2790
    GR DIP
    2792
    3180
    GR SP SLS DIL
    2792
    3181
    MWD - GR RES DIR
    206
    3185
    NGT CNL LDT
    2885
    3181
    PSV
    1800
    3181
    RFT
    2897
    2932
    RFT GR
    2792
    3181
  • 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
    206.0
    36
    207.0
    0.00
    LOT
    INTERM.
    13 3/8
    1198.0
    17 1/2
    1200.0
    1.98
    LOT
    INTERM.
    9 5/8
    2794.0
    12 1/4
    2796.0
    1.80
    LOT
    LINER
    7
    3173.0
    8 1/2
    3185.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1291
    1.24
    22.0
    7.8
    WATER BASED
    11.01.1991
    1463
    1.25
    25.0
    8.8
    WATER BASED
    14.01.1991
    2620
    1.33
    30.0
    12.7
    WATER BASED
    23.01.1991
    2620
    1.33
    33.0
    13.2
    WATER BASED
    24.01.1991
    2620
    1.34
    33.0
    11.7
    WATER BASED
    25.01.1991
    2898
    1.20
    38.0
    15.6
    WATER BASED
    07.02.1991
    2900
    1.20
    34.0
    13.7
    WATER BASED
    11.02.1991
    2985
    1.20
    40.0
    18.6
    WATER BASED
    11.02.1991
    3015
    1.25
    37.0
    14.7
    WATER BASED
    12.02.1991
    3057
    1.25
    42.0
    18.1
    WATER BASED
    14.02.1991
  • 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
    0.24