Factpages Norwegian petroleum directorate
Factpages Norwegian petroleum directorate
NPD          Norsk
05.06.2023 - 01:35
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2/7-10

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  • General information

    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on NPD guidelines for designation of wells and wellbores.
    2/7-10
    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 NPD.
    INJECTING: It was injected to the wellbore at the time of the operators last monthly report to the NPD.
    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
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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
    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 NPD guidelines for designation of wells and wellbores.
    2/7-10
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LINE 56 2830 SP.1430
    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.
    Phillips Petroleum Company Norway
    Drill permit
    The drilling permit number together with the version of the drilling permit as stated in the drilling permit granted by the NPD.
    96-L
    Drilling facility
    NPD's name of the facility which the wellbore was drilled from.
    Drilling days
    Number of days from wellbore entry to wellbore completion.
    61
    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,
    06.10.1973
    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.
    05.12.1973
    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.
    05.12.1975
    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.
    18.01.2007
    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.
    APPRAISAL
    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 NPD 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 NPD bulletins.
    EKOFISK 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.
    LATE CRETACEOUS
    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.
    TOR FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    37.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    72.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3370.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.75
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    108
    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 CRETACEOUS
    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.
    TOR FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 28' 31.7'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 4' 59.7'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6259142.67
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    505128.45
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    31
    NPDID wellbore
    NPD's unique id for the wellbore.
    269
  • Wellbore history

    General
    Well 2/7-10 was drilled on the Edda structure in the southern North Sea. The principal zone of interest was the Danian Limestone, which was found hydrocarbon-bearing ca 13 km to the northeast on the Ekofisk field, and which held commercial quantities of oil and gas in the 2/7-4 well on the Edda structure just over a mile to the southeast. The Danian sequence was expected to be ca 90 m thick. The Late Cretaceous was a secondary objective and could contain hydrocarbons if porosity was present.
    Operations and results
    Well 2/7-10 was spudded with the jack-up installation Zapata Nordic on 6 October 1973 and drilled to TD at 3370 m in the Late Cretaceous Tor Formation. Bad weather caused some technical problems and delayed operations for some days. The well was drilled water based, but with 3-4 % addition of oil below 2691 m. The Danian limestone sequence (Ekofisk Formation) was encountered at 3191 m. It was 90 m thick as prognosed but with only 6 m of gross pay, which, after acidization, yielded nothing commercial. The equivalent interval in the 2/7-4 well produced commercial oil and gas on the deepest of three drill stem tests. The Late Cretaceous Tor Formation, however, was found to have 31 m of potential pay, which correlates well with the 2/7-4 interval. It flowed commercial amounts of oil and gas after acid, on two drill stem tests. The upper one of these compared well with the equivalent horizon in the 2/7-4, although less productive. Shows were recorded from top of the Ekofisk and all through the limestone/chalk section down to ca 3338 m in the Tor Formation.
    No cores were cut and no wire line fluid samples taken in the 2/7-10 well
    The well was permanently abandoned on 5 December 1973 as an oil appraisal.
    Testing
    Five successful DST's were carried out in the well. Maximum flow data after acidization follows:  DST 1 from the interval 3313 - 3322 m (Tor Formation) produced 233 m3 water, 12.2 Sm3 oil, and 32300 Sm3 gas /day. DST 3 from 3289 - 3301 m (Tor Formation) produced 715 Sm3 oil and 132500 Sm3 gas /day. The GOR was 185 Sm3/Sm3 and the oil gravity was 40.6 deg API. DST 5 from 3245 - 3261 (Ekofisk Formation) m produced on average 22 m3 water/day. It stopped flowing after 6 hours. DST 6 from 3219 - 3237 m (Ekofisk Formation) produced a total of 5.4 M3 water. DST 7 from 3203 - 3210 m ((Ekofisk Formation) gave a weak flow of water with traces of oil. DST 2 and DST 4 from 3289 - 3301 m were mis-runs.
  • Lithostratigraphy

    Lithostratigraphy
    Top depth [m]
    Lithostrat. unit
    109
    1774
    3029
    3029
    3043
    3094
    3163
    3191
    3191
    3281
  • Composite logs

    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.29
  • 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
    3.71
    pdf
    3.97
  • Drill stem tests (DST)

    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3313
    3322
    0.0
    3.0
    3289
    3301
    0.0
    5.0
    3245
    3261
    0.0
    6.0
    3219
    3237
    0.0
    7.0
    3203
    3210
    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
    3.0
    5.0
    6.0
    7.0
    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
    3.0
    5.0
    6.0
    7.0
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BHC
    493
    1226
    BHC C
    1219
    3370
    CBL
    2311
    3340
    CDM AP
    2886
    3369
    FDC
    3018
    3370
    GR
    109
    493
    IES
    493
    3370
    PML
    3018
    3370
    SNP
    3018
    3370
    VELOCITY
    493
    3370
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    139
    1.05
    75.0
    water-based
    501
    1.25
    40.0
    water-based
    899
    1.26
    12.0
    water-based
    1275
    1.40
    43.0
    water-based
    2113
    1.64
    51.0
    water-based
    2448
    1.66
    51.0
    water-based
    2912
    1.71
    58.0
    water-based
    3275
    1.72
    57.0
    water-based
    3368
    1.72
    53.0
    water-based