Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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sodir.no          Norsk
22.12.2024 - 01:25
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25/4-1

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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.
    25/4-1
    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
    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.
    25/4-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LINE 681 203.
    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.
    69-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.
    162
    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,
    01.07.1972
    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.
    09.12.1972
    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.
    09.12.1974
    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.
    15.02.2006
    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.
    OIL/GAS
    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
    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.
    VESTLAND GP
    3rd level with HC, age
    Age of lithostratigraphic unit, 3rd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    EARLY JURASSIC
    3rd level with HC, formation
    Name of lithostartigraphic unit, 3rd 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.
    STATFJORD GP
    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.
    122.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4060.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    130
    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.
    SMITH BANK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 34' 27.3'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 13' 22.6'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6604408.11
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    456100.43
    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.
    359

  • Wellbore history
    General
    Well 25/4-1 is the discovery well on the Heimdal Field. The primary objective was Paleocene sand development (which was confirmed by the well), while Jurassic sands were regarded as a secondary objective. Planned depth was 3500 m.
    The well is Type Well for the Heimdal Formation.
    Operations and results
    Wildcat well 25/4-1 was spudded with the semi-submersible installation Neptune 7 on 1 July 1972 and drilled to TD at 4060 m in the Triassic Smith Bank Formation. From 2600 m to 3580 m the well built some angle (maximum 5 deg), resulting in a 3 m deviation between measured and true vertical depth at 3580 m. In addition, logger's depth is 6 m deeper than driller's depth from seabed to 3525 m. Below 3525 m driller's depth is equal to logger's depth. This history quotes logger’s depth if not otherwise stated. While drilling at 3178 m the well started to flow and a lost circulation situation followed. The situation was adequately dealt with. The well was drilled water based all through.
    The well penetrated a 356 m thick Heimdal Formation from 2067 m to 2423 m. The reservoir was composed of more or less unconsolidated sands with interbedded shales and carbonates. The formation was gas filled down to a gas/oil contact at 2173 and contained oil in a thin zone down to a shale at 2177 m. The OWC could not be seen in the well. The upper Cenomanian rested unconformably on a 14 m thick Oxfordian/Callovian Draupne Formation sequence, which in turn rested unconformably on the Middle Jurassic Vestland Group at 3185 m. Several permeable reservoirs were penetrated from 3185 m to 3512.5 m (3179 m to 3506.5 m drillers depth) in the Middle Jurassic to Late Triassic. Four of these were hydrocarbon bearing, with separate fluid contacts. Oil was found from 3185 m to an OWC at 3195 m in the Hugin and Sleipner formations. The Statfjord Formation held gas from 3292.5 m to a GOC at 3297 m with oil from 3297 m to an OWC at 3303.5 m. In addition, a thin gas zone was found further down in the Statfjord Formation, from 3508 m to 3512.5 m. No contact was seen here. Finally the Late Triassic Smith Bank Formation had gas in a thin zone from 3532 m down to a GWC at 3533.5 m.
    An extensive coring programme was carried out with 18 cores and a total of 254 m core recovered. Cores were cut in the Balder Formation (core 1), Heimdal Formation (cores 2, 3, and 4), Tryggvason Formation (core 5), and the Sleipner and Statfjord formations (cores 6 to 18).
    Four drill stem tests were conducted. DST 1/Statfjord flowed from the interval 3307 m to 3321 m (3301 m to 3315 m drillers depth) in the Statfjord Formation and produced only 50 Sm3 water. The DST temperature was 112 °C. DST 2 in Sleipner produced only water and filtrate without any hydrocarbons. DST 3 flowed from the interval 3185 m to 3190 m (3179 m to 3184 m drillers depth) near top Sleipner Formation and produced 190000 Sm3 gas, 74 Sm3 oil and 384 Sm3 water pr day through a 1" choke. The DST temperature was 104 °C. DST 4 (called DST 1/Heimdal in well reports) flowed from the interval 2115 m to 2128 m in the Heimdal Formation and produced 952000 Sm3 gas and 85 Sm3 condensate pr day through a 1" choke. The temperature in this test, measured at 2099 m, was 71 °C.
    choke. DST 1/Statfjord flowed from the interval 3307 m to 3321 m (3301 m to 3315 m drillers depth) in the Statfjord Formation and produced only 50 Sm3 water.

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    NO
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    450.00
    4060.00

  • 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
    1936.0
    1944.0
    [m ]
    2
    2078.0
    2095.3
    [m ]
    3
    2096.0
    2114.0
    [m ]
    4
    2409.4
    2413.5
    [m ]
    5
    3088.0
    3092.5
    [m ]
    6
    3188.0
    3195.0
    [m ]
    7
    3195.0
    3204.0
    [m ]
    8
    3204.0
    3222.4
    [m ]
    9
    3222.4
    3234.8
    [m ]
    10
    3288.0
    3306.0
    [m ]
    11
    3306.0
    3316.0
    [m ]
    12
    3316.0
    3333.9
    [m ]
    13
    3334.0
    3352.0
    [m ]
    14
    3370.0
    3388.0
    [m ]
    15
    3388.0
    3406.0
    [m ]
    16
    3407.3
    3418.0
    [m ]
    17
    3418.0
    3436.0
    [m ]
    18
    3436.0
    3454.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    245.5
    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
    1610.0
    [m]
    DC
    OD
    1620.0
    [m]
    DC
    OD
    1640.0
    [m]
    DC
    OD
    1660.0
    [m]
    DC
    OD
    1680.0
    [m]
    DC
    OD
    1690.0
    [m]
    DC
    OD
    1720.0
    [m]
    DC
    OD
    1740.0
    [m]
    DC
    OD
    1760.0
    [m]
    DC
    OD
    1780.0
    [m]
    DC
    OD
    1800.0
    [m]
    DC
    OD
    1820.0
    [m]
    DC
    OD
    1840.0
    [m]
    DC
    OD
    1860.0
    [m]
    DC
    OD
    1880.0
    [m]
    DC
    OD
    1900.0
    [m]
    DC
    OD
    1920.0
    [m]
    DC
    OD
    1945.0
    [m]
    DC
    OD
    1960.0
    [m]
    DC
    OD
    1980.0
    [m]
    DC
    OD
    2000.0
    [m]
    DC
    OD
    2020.0
    [m]
    DC
    OD
    2040.0
    [m]
    DC
    OD
    2060.0
    [m]
    DC
    OD
    2075.0
    [m]
    DC
    OD
    2088.0
    [m]
    DC
    OD
    2115.0
    [m]
    DC
    OD
    2120.0
    [m]
    DC
    OD
    2140.0
    [m]
    DC
    OD
    2160.0
    [m]
    DC
    OD
    2180.0
    [m]
    DC
    OD
    2200.0
    [m]
    DC
    OD
    2220.0
    [m]
    DC
    OD
    2245.0
    [m]
    DC
    OD
    2260.0
    [m]
    DC
    OD
    2280.0
    [m]
    DC
    OD
    2300.0
    [m]
    DC
    OD
    2320.0
    [m]
    DC
    OD
    2340.0
    [m]
    DC
    OD
    2360.0
    [m]
    DC
    OD
    2380.0
    [m]
    DC
    OD
    2400.0
    [m]
    DC
    OD
    2420.0
    [m]
    DC
    OD
    2440.0
    [m]
    DC
    OD
    2460.0
    [m]
    DC
    OD
    2480.0
    [m]
    DC
    OD
    2500.0
    [m]
    DC
    OD
    2515.0
    [m]
    DC
    OD
    2540.0
    [m]
    DC
    OD
    2560.0
    [m]
    DC
    OD
    2570.0
    [m]
    DC
    OD
    2600.0
    [m]
    DC
    OD
    3705.0
    [m]
    DC
    3725.0
    [m]
    DC
    3745.0
    [m]
    DC
    3765.0
    [m]
    DC
    3785.0
    [m]
    DC
    3805.0
    [m]
    DC
    3825.0
    [m]
    DC
    3845.0
    [m]
    DC
    3865.0
    [m]
    DC
    3885.0
    [m]
    DC
    3905.0
    [m]
    DC
    3925.0
    [m]
    DC
    3945.0
    [m]
    DC
    3965.0
    [m]
    DC
    3985.0
    [m]
    DC
    4005.0
    [m]
    DC
    4025.0
    [m]
    DC
    4035.0
    [m]
    DC
    4055.0
    [m]
    DC

  • 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
    0.00
    0.00
    WATER
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.51

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.07
    pdf
    1.14
    pdf
    1.58

  • 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
    20.98
    pdf
    1.89

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3300
    3314
    0.0
    2.0
    3208
    3213
    0.0
    3.0
    3179
    3184
    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
    2.0
    3.0
    29.000
    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
    3.0
    74
    180000
    0.797
    2432

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL
    1850
    2946
    CNT FDC
    2946
    3527
    FDC CNT GR
    1922
    2626
    GR
    120
    1915
    GR CBL CCL
    2877
    3523
    GR SL
    1922
    2626
    GR SL
    2946
    3173
    GR SL
    3150
    3423
    GR SL
    3150
    3525
    GR SL
    3525
    4055
    HDT
    1922
    2626
    HDT
    2946
    3485
    IES
    441
    1915
    IES
    1922
    2626
    IES
    2590
    2950
    IES
    2946
    3173
    IES
    2946
    3528
    IES
    3150
    3423
    IES
    3525
    4061
    LL9
    1922
    2626
    LL9
    2946
    3520
    ML MLL
    1922
    2626
    ML MLL
    2946
    3530
    ML MLL
    3526
    4060
    SL
    441
    1915
    SL GR
    2590
    2950

  • 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
    181.0
    36
    182.0
    0.00
    LOT
    SURF.COND.
    20
    442.0
    26
    450.0
    0.00
    LOT
    INTERM.
    13 3/8
    1917.0
    17 1/2
    1920.0
    0.00
    LOT
    INTERM.
    9 5/8
    2942.0
    12 1/4
    2950.0
    0.00
    LOT
    LINER
    7
    3524.0
    8 1/2
    3524.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    170
    1.05
    seawater
    450
    1.15
    seawater
    1800
    1.25
    50.0
    seawater
    2800
    1.25
    50.0
    seawater
    3500
    2.10
    seawater

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    2104.00
    [m ]
    2412.00
    [m ]
    3222.00
    [m ]
    3229.00
    [m ]
    3229.00
    [m ]
    3230.00
    [m ]
    3295.00
    [m ]
    3224.00
    [m ]
    3296.00
    [m ]
    3380.00
    [m ]
    3298.00
    [m ]
    3298.00
    [m ]
    3324.00
    [m ]

  • 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
    0.23