Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.11.2024 - 09:09
Time of last synchronization with Norwegian Offshore Directorate's internal systems

15/3-4

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.
    15/3-4
    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
    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.
    15/3-4
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    line 783 402 SP 490
    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.
    304-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.
    179
    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,
    03.10.1981
    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.
    30.03.1982
    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.
    30.03.1984
    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.
    10.08.2013
    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.
    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
    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.
    107.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4259.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    139
    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.
    SKAGERRAK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 49' 5.28'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 52' 59.82'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6520489.03
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    435502.74
    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.
    314

  • Wellbore history
    General
    Well 15/3-4 was drilled on the Gudrun Terrace, east of the 15/3-1 S Gudrun Discovery in the North Sea. The main objective of the well was to test sandstones of the Late and Middle Jurassic, which were found to contain gas and condensate in wells 15/3-1 S and 15/3-3. The secondary target was the Eocene sands where oil shows were encountered in well 15/5-3.
    Operations and results
    Wildcat well 15/3-4 was spudded with the semi-submersible installation Borgsten Dolphin on 3 October 1981and drilled to TD at 4259 m in the Triassic Skagerrak Formation. After the 13 3/8" casing had been cemented drilling was interrupted for 13 days due to a combination of bad weather and repairs on the BOP stack. When running in hole at TD the drill string stuck leaving a fish with top at 4098 m. Hence, no logs were run between 4098 m and TD.
    The Eocene sands from 1628 to 2025 m (Grid Formation sands) were found water bearing. The Brent Group was encountered with top Hugin Formation at 3786 m and top Sleipner Formation at 3856 m. Sandstones in the Brent Group contained oil and gas in four different intervals: 3786 to 3817 m, 3819.5 to 3826.5 m, 3849.9 to 3854.8 m, and 3872.2 to 3876.4 m. The four zones were in different pressure regimes. The interval from 3819.5 to 3826.5 m had a low hydrocarbon saturation based on the logs, but the cores from this section had good shows with a similar bulk hydrocarbon composition as in the uppermost interval. Triassic sands below 4050 m were found water bearing. Good oil shows were seen on all cores from the Hugin Formation, otherwise no shows were reported from the well.
    Five cores were cut in the well. Core 1 was cut in the Grid Formation from 1678 to 1694 m with 27% recovery. Coring of the Grid sands was difficult due to their unconsolidated nature. Cores 2 - 5 were cut in the interval 3792 to 3839 m in the Hugin Formation with recovery from 65% to 100%. RFT fluid samples were taken at 3802.5 m (water, mud and filtrate), 3823.5 m (water, mud and filtrate), and 3850.2 m (gas and water). FIT fluid samples were taken at 3822.5 m (water and dissolved gas), 3852.6 m (oil, gas and water), and 3873.5 m (oil, gas and water).
    The well was permanently abandoned on 30 March 1982 as an oil and gas discovery.
    Testing
    One DST was performed through perforations in the interval 3789 to 3807.5 m. The test produced 615 Sm3 oil and 245000 Sm3 Gas/day through a 40/64" choke. The GOR was 400 Sm3/Sm3, the oil density was 0.816 g/cm3, and the gas gravity was 0.803 (air = 1). The gas contained 7.4 % CO2. Bottom hole temperature during the DST, at reference depth 3800 m, was 127.8 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]
    210.00
    4254.00

  • 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
    1678.0
    1683.0
    [m ]
    2
    3792.0
    3795.6
    [m ]
    3
    3796.1
    3806.0
    [m ]
    4
    3806.0
    3821.1
    [m ]
    5
    3821.0
    3839.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    51.9
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: High: 1678-1682m
    Core photo at depth: Low: 1678-1682m
    Core photo at depth: High: 1682-1683m
    Core photo at depth: Low: 1682-1683m
    Core photo at depth: High: 3792-3795m
    High: 1678-1682m
    Low: 1678-1682m
    High: 1682-1683m
    Low: 1682-1683m
    High: 3792-3795m
    Core photo at depth: Low: 3792-3795m
    Core photo at depth: High: 3796-3799m
    Core photo at depth: Low: 3796-3799m
    Core photo at depth: High: 3799-3803m
    Core photo at depth: Low: 3799-3803m
    Low: 3792-3795m
    High: 3796-3799m
    Low: 3796-3799m
    High: 3799-3803m
    Low: 3799-3803m
    Core photo at depth: High: 3803-3807m
    Core photo at depth: Low: 3803-3807m
    Core photo at depth: High: 3813-3816m
    Core photo at depth: Low: 3813-3816m
    Core photo at depth: High: 3816-3819m
    High: 3803-3807m
    Low: 3803-3807m
    High: 3813-3816m
    Low: 3813-3816m
    High: 3816-3819m
    Core photo at depth: Low: 3816-3819m
    Core photo at depth: High: 3820-3824m
    Core photo at depth: Low: 3820-3824m
    Core photo at depth: High: 3824-3827m
    Core photo at depth: Low: 3824-3827m
    Low: 3816-3819m
    High: 3820-3824m
    Low: 3820-3824m
    High: 3824-3827m
    Low: 3824-3827m
    Core photo at depth: High: 3827-3832m
    Core photo at depth: Low: 3827-3832m
    Core photo at depth: High: 3832-3836m
    Core photo at depth: Low: 3832-3836m
    Core photo at depth: High: 3836-3839m
    High: 3827-3832m
    Low: 3827-3832m
    High: 3832-3836m
    Low: 3832-3836m
    High: 3836-3839m
    Core photo at depth: Low: 3836-3839m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Low: 3836-3839m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1501.0
    [m]
    SWC
    HYDRO
    1530.0
    [m]
    SWC
    HYDRO
    1561.5
    [m]
    SWC
    HYDRO
    1593.0
    [m]
    SWC
    HYDRO
    1630.0
    [m]
    SWC
    HYDRO
    1697.0
    [m]
    SWC
    HYDRO
    1718.0
    [m]
    SWC
    HYDRO
    1738.0
    [m]
    SWC
    HYDRO
    1754.0
    [m]
    SWC
    HYDRO
    1778.0
    [m]
    SWC
    HYDRO
    1800.0
    [m]
    SWC
    HYDRO
    1824.5
    [m]
    SWC
    HYDRO
    1856.0
    [m]
    SWC
    HYDRO
    1874.0
    [m]
    SWC
    HYDRO
    1909.0
    [m]
    SWC
    HYDRO
    1954.5
    [m]
    SWC
    HYDRO
    1983.5
    [m]
    SWC
    HYDRO
    2000.0
    [m]
    SWC
    HYDRO
    2032.0
    [m]
    SWC
    HYDRO
    2058.5
    [m]
    SWC
    HYDRO
    2071.0
    [m]
    SWC
    HYDRO
    2085.0
    [m]
    SWC
    HYDRO
    2098.0
    [m]
    SWC
    HYDRO
    2172.0
    [m]
    SWC
    HYDRO
    2182.0
    [m]
    SWC
    HYDRO
    2194.0
    [m]
    SWC
    HYDRO
    3792.7
    [m]
    C
    APT
    3797.8
    [m]
    C
    APT
    3802.2
    [m]
    C
    APT
    3813.3
    [m]
    C
    APT
    3817.1
    [m]
    C
    APT
    3821.0
    [m]
    C
    APT
    3821.4
    [m]
    C
    APT
    3830.6
    [m]
    C
    APT
    3833.5
    [m]
    C
    APT
    3839.1
    [m]
    C
    APT

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.17
    pdf
    0.21
    pdf
    0.25
    pdf
    0.59

  • 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
    2.52
    pdf
    24.14

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3789
    3807
    15.8
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    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
    615
    245000
    0.816
    0.803
    399

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    3436
    0
    0
    BGT
    921
    2823
    CBL
    175
    2819
    CBL
    3382
    3946
    CST
    2850
    3700
    CST
    3720
    3949
    CST
    3949
    4095
    CYBERLOOK
    3775
    3830
    HDT CYBERDIP
    2819
    4095
    ISF GR BHC SL
    132
    4094
    LDT CNL GR CAL
    192
    4096
    MSFL DLL GR CAL
    3682
    3935
    NGT
    3682
    3946
    RFT
    3802
    3850
    RFT
    3823
    3823

  • 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
    192.0
    36
    192.0
    0.00
    LOT
    SURF.COND.
    20
    921.0
    26
    937.0
    1.45
    LOT
    INTERM.
    13 3/8
    2818.0
    17 1/2
    2833.0
    1.78
    LOT
    INTERM.
    9 5/8
    3681.0
    12 1/4
    3700.0
    2.05
    LOT
    LINER
    7
    3946.0
    8 1/2
    3948.0
    2.07
    LOT
    OPEN HOLE
    4259.0
    5 7/8
    4259.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    220
    1.07
    66.0
    waterbased
    540
    1.10
    65.0
    waterbased
    1240
    1.17
    45.0
    waterbased
    1730
    1.24
    58.0
    waterbased
    2020
    1.24
    75.0
    waterbased
    2330
    1.29
    65.0
    waterbased
    3110
    1.34
    54.0
    waterbased
    3330
    0.00
    waterbased
    3380
    1.38
    54.0
    waterbased
    3615
    1.55
    54.0
    waterbased
    3970
    1.50
    58.0
    waterbased

  • 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
    0.21