Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
05.11.2024 - 01:27
Time of last synchronization with Norwegian Offshore Directorate's internal systems

25/11-5

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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.
    25/11-5
    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).
    APPRAISAL
    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.
    25/11-5
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LINE SC 73-15 & sp 2125
    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.
    Esso Exploration and Production Norway A/S
    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.
    106-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.
    36
    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,
    03.04.1974
    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.
    08.05.1974
    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.
    08.05.1976
    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.
    30.04.2010
    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
    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
    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.
    EOCENE
    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.
    INTRA BALDER FM SS
    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.
    PALEOCENE
    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.
    HERMOD FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.5
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    124.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2164.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    60
    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.
    NO GROUP DEFINED
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 12' 9.32'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 21' 55.58'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6562934.90
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    463755.93
    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.
    366

  • Wellbore history
    General
    Well 25/11-5 was drilled ca 4 km north west of the 25/11-1 Balder discovery well on the Utsira High in the North Sea. The well was designed to evaluate a sand build up and/or structural closure at the Middle Paleocene horizon top. The location was mapped structurally high to the adjacent wells 25/11-1, 25/11-2, 25/10-1, and 25/10-3.
    Operations and results
    Appraisal well 25/11-5 was spudded with the drillship Drillmaster on 3 April 1974 and drilled to TD at 2164 m in Triassic red-grey clays, and grey-green shale. Sloughing shale was the only drilling problem and this was overcome by converting the Drispac mud system to a ligno-gel seawater mud system. The well was drilled with Drispac from approximately 1000 to 1400 m, and with lignosulphonate/gel/seawater from ca 1400 m to TD.
    The well penetrated the Utsira Formation and a Skade Formation sand and then entered a ca 700 m thick section of shales belonging to the lower Hordaland Group before top Balder formation was encountered at 1661 m. Significant oil bearing sands in the interval from 1714 to 1771 m were confirmed by sidewall cores and Schlumberger electric logs. The lower part of this interval tested oil at good rates. Additional shows in traces of sand in cuttings at 1838 - 1847 m were believed to be sloughings from the oil sand above.
    One conventional core was cut from 1723.3 to 1725.5 m. Six attempts at FIT's were attempted with one successful at 1744.1 m. This test recovered 0.33 Sm3 gas, 4.5 l oil, 2.3 l filtrate and 0.8 l mud.
    The well was permanently abandoned on 8 May1974 as an oil appraisal.
    Testing
    A test through perforations at 1750 to 1765 m in the Hermod Formation produced at an average rate of 634 Sm3 oil and 29283 Sm3 gas /day. The GOR was 46.1 Sm3/Sm3 and the oil gravity was 24.2 deg API (0.91 g/cm3).

  • 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]
    198.12
    2164.08

  • 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
    5654.0
    5661.0
    [ft ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    2.1
    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
    1726.4
    [m]
    C
    RRI
    1727.4
    [m]
    C
    RRI
    1728.4
    [m]
    C
    RRI
    1729.1
    [m]
    C
    RRI
    1730.4
    [m]
    C
    RRI
    1730.9
    [m]
    C
    RRI
    1731.4
    [m]
    C
    RRI
    1731.7
    [m]
    C
    RRI
    1732.0
    [m]
    C
    RRI
    1732.7
    [m]
    C
    RRI
    1732.8
    [m]
    C
    RRI
    2450.0
    [ft]
    DC
    2480.0
    [ft]
    DC
    2540.0
    [ft]
    DC
    2630.0
    [ft]
    DC
    2720.0
    [ft]
    DC
    2810.0
    [ft]
    DC
    2900.0
    [ft]
    DC
    2990.0
    [ft]
    DC
    3080.0
    [ft]
    DC
    3170.0
    [ft]
    DC
    3260.0
    [ft]
    DC
    3350.0
    [ft]
    DC
    3440.0
    [ft]
    DC
    3530.0
    [ft]
    DC
    3620.0
    [ft]
    DC
    3710.0
    [ft]
    DC
    3800.0
    [ft]
    DC
    3890.0
    [ft]
    DC
    3920.0
    [ft]
    DC
    3980.0
    [ft]
    DC
    4070.0
    [ft]
    DC
    4110.0
    [ft]
    DC
    4170.0
    [ft]
    DC
    4270.0
    [ft]
    DC
    4290.0
    [ft]
    DC
    4330.0
    [ft]
    DC
    4370.0
    [ft]
    DC
    4470.0
    [ft]
    DC
    4490.0
    [ft]
    DC
    4530.0
    [ft]
    DC
    4570.0
    [ft]
    DC
    4650.0
    [ft]
    DC
    4740.0
    [ft]
    DC
    4830.0
    [ft]
    DC
    4920.0
    [ft]
    DC
    5010.0
    [ft]
    DC
    5100.0
    [ft]
    DC
    5190.0
    [ft]
    DC
    5220.0
    [ft]
    DC
    5250.0
    [ft]
    DC
    5280.0
    [ft]
    DC
    5280.0
    [ft]
    DC
    5310.0
    [ft]
    DC
    5340.0
    [ft]
    DC
    5370.0
    [ft]
    DC
    5400.0
    [ft]
    SWC
    5400.0
    [ft]
    DC
    5430.0
    [ft]
    DC
    5460.0
    [ft]
    DC
    5470.0
    [ft]
    SWC
    5508.0
    [ft]
    SWC
    5546.0
    [ft]
    SWC
    5560.0
    [ft]
    DC
    5570.0
    [ft]
    DC
    5580.0
    [ft]
    DC
    5600.0
    [ft]
    DC
    5616.0
    [ft]
    SWC
    5620.0
    [ft]
    DC
    5633.0
    [ft]
    DC
    5654.0
    [ft]
    C
    5666.0
    [ft]
    SWC
    5670.0
    [ft]
    DC
    5687.0
    [ft]
    SWC
    5698.0
    [ft]
    SWC
    5700.0
    [ft]
    DC
    5710.0
    [ft]
    SWC
    5730.0
    [ft]
    DC
    5760.0
    [ft]
    DC
    5790.0
    [ft]
    DC
    5820.0
    [ft]
    DC
    5826.0
    [ft]
    SWC
    5850.0
    [ft]
    DC
    5866.0
    [ft]
    SWC
    5880.0
    [ft]
    DC
    5910.0
    [ft]
    DC
    5940.0
    [ft]
    DC
    5970.0
    [ft]
    DC
    6000.0
    [ft]
    DC
    6030.0
    [ft]
    DC
    6060.0
    [ft]
    DC
    6120.0
    [ft]
    DC
    6164.0
    [ft]
    SWC
    6210.0
    [ft]
    DC
    6274.0
    [ft]
    SWC
    6300.0
    [ft]
    DC
    6400.0
    [ft]
    DC
    6410.0
    [ft]
    DC
    6440.0
    [ft]
    DC
    6480.0
    [ft]
    DC
    6490.0
    [ft]
    DC
    6580.0
    [ft]
    DC
    6680.0
    [ft]
    DC
    6737.0
    [ft]
    SWC
    6790.0
    [ft]
    DC
    6840.0
    [ft]
    DC
    RRI
    6880.0
    [ft]
    DC
    6980.0
    [ft]
    DC
    7080.0
    [ft]
    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
    DST1
    1750.00
    1765.00
    30.04.1974 - 00:00
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.82

  • 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
    1.35
    pdf
    4.69

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    1750
    1765
    0.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    17.800
    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
    636
    28371
    0.910
    44

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DIL
    396
    2162
    DIPMETER
    1397
    2162
    FDC CNL
    1397
    2163
    SGR
    396
    2161
    VELOCITY
    457
    2154

  • 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
    187.0
    36
    190.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    397.0
    17 1/2
    411.0
    0.00
    LOT
    INTERM.
    9 5/8
    1397.0
    12 1/4
    1412.0
    0.00
    LOT
    LINER
    7
    1890.0
    8 1/2
    2164.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    188
    0.00
    seawater/ge
    1400
    1.23
    seawater/lg
    2163
    1.22
    water/spers