Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.11.2024 - 09:09
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2/7-31

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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.
    2/7-31
    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
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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
    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.
    2/7-31
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    BPN 9102-163 2& SP 982
    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 Norwegian Offshore Directorate.
    943-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.
    148
    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,
    13.01.1999
    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.
    09.06.1999
    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.
    09.06.2001
    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.
    29.05.2002
    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.
    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.
    EARLY CRETACEOUS
    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.
    TUXEN 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 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.
    ULA FM
    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 PERMIAN
    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.
    ROTLIEGEND GP
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    47.5
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    72.8
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4968.2
    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).
    4965.6
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    6.9
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    176
    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 PERMIAN
    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.
    ROTLIEGEND GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 20' 12.4'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 5' 15.4'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6243705.05
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    505416.77
    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.
    3573

  • Wellbore history
    General
    The objectives of drilling the 2/7-31 Ebba Prospect well were to test the hydrocarbon potential of the Permian Rotliegend and Jurassic Lower Ula sandstones in a fault closed structural trap. The prospect was located 10 km west of the Embla field and 1 km west of the Phillips 2/7-19 well, which tested hydrocarbons in the Jurassic Lower Ula Formation. Further, the well should establish proven economic reserves and obtain open hole wire line logs, cores and production tests in both formations.
    Operations and results
    Well 2/7-31 was spudded with the jack-up rig "Mærsk Galant" on 13 January 1999 and drilling was completed on 5 May 1999 at 4968 m in the Permian Rotliegend Group. It was drilled with spud mud down to 593 m and with oil based Versaport mud from 593 to TD.
    Hydrocarbons were encountered first in the Lower Cretaceous Tuxen Formation (Top 4372.1 m), then in the sandstones of the Jurassic Lower Ula (Top 4483.6 m) and Bryne (Top 4634.2 m) Formations, and finally in the sandstone of the Permian Rotliegend Group (Top 4750m). All zones were evaluated either by MWD/LWD log or open and cased hole wire line data. Wire line formation pressure tests were taken throughout the Rotliegend section and oil samples were recovered from two FMT tests at 4793 m and 4812 m. Planned coring of the Jurassic sandstones was cancelled due to operational difficulties in the HPHT environment encountered in this well. Coring in the Rotliegend faced a similar fate but the setting of a liner stabilized the well and one core was taken from the interval 4795.7 - 4798.2 m and three in the interval 4811.3 - 4850.9 m. The well was suspended as an oil discovery.
    Testing
    A DST was performed over the Ula Sandstone interval 4565.9 - 4623.8 m. The well flowed at an average stabilized rate of 283 Sm3 oil and 120000 Sm3 gas on a 16/64" choke.

  • 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]
    466.00
    4968.00

  • 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
    15734.0
    15741.6
    [ft ]
    2
    15785.0
    15877.6
    [ft ]
    3
    15877.6
    15905.6
    [ft ]
    4
    15908.0
    15915.3
    [ft ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    41.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 15734-15791ft
    Core photo at depth: 15791-15806ft
    Core photo at depth: 15806-15821ft
    Core photo at depth: 15821-15836ft
    Core photo at depth: 15836-15851ft
    15734-15791ft
    15791-15806ft
    15806-15821ft
    15821-15836ft
    15836-15851ft
    Core photo at depth: 15851-15866ft
    Core photo at depth: 15866-15880ft
    Core photo at depth: 15880-15895ft
    Core photo at depth: 15895-15911ft
    Core photo at depth: 15911-15915ft
    15851-15866ft
    15866-15880ft
    15880-15895ft
    15895-15911ft
    15911-15915ft

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    14560.0
    [m]
    DC
    PETROS
    14920.0
    [m]
    DC
    PETROS
    15330.0
    [m]
    DC
    PETROSTA

  • 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
    0.00
    0.00
    23.05.1999 - 23:00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.80

  • 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
    319.61

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    4623
    4565
    6.3
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    163
    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
    282
    120360
    0.702
    426

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBIL HDIP GR
    4763
    4849
    FMT
    3157
    4198
    FMT
    4783
    4937
    HDIL MAC ZDL GR
    1943
    4230
    HDIL XMAC CN GR
    4763
    4965
    HDIL XMAC GR
    4763
    4849
    ISF LSS GR
    157
    770
    MRIL
    4774
    4854
    MWD CDR ADN DIR
    4258
    4968
    SBT
    1993
    4229
    SWC
    4778
    4954
    VSP
    152
    4846
    ZDL CN GR
    4763
    4967
    ZDL CN XMAC GR
    4763
    4849

  • 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
    222.5
    36
    225.0
    0.00
    LOT
    SURF.COND.
    20
    584.3
    26
    586.0
    0.00
    LOT
    INTERM.
    13 3/8
    1946.8
    17 1/2
    1950.0
    1.67
    LOT
    INTERM.
    9 7/8
    4253.8
    12 1/4
    4255.0
    1.95
    LOT
    LINER
    7 3/4
    4968.0
    8 1/2
    4968.0
    2.15
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    134
    1.03
    12.0
    BENTONITE
    227
    1.26
    15.0
    BENTONITE
    253
    1.14
    6.0
    BENTONITE
    584
    1.13
    8.0
    BENTONITE
    649
    1.43
    29.0
    VERSAPORT
    1006
    1.43
    23.0
    VERSAPORT
    1574
    1.43
    21.0
    VERSAPORT
    1798
    1.56
    25.0
    VERSAPORT
    1947
    1.67
    22.0
    VERSAPORT
    1951
    1.56
    24.0
    VERSAPORT
    2052
    1.67
    24.0
    VERSAPORT
    2350
    1.67
    25.0
    VERSAPORT
    2934
    1.70
    24.0
    VERSAPORT
    3186
    1.67
    20.0
    VERSAPORT
    3207
    1.67
    22.0
    VERSAPORT
    3537
    1.67
    22.0
    VERSAPORT
    3827
    1.67
    24.0
    VERSAPORT
    3895
    1.67
    25.0
    VERSAPORT
    3900
    1.67
    25.0
    VERSAPORT
    3995
    2.16
    90.0
    VERSAPORT
    4020
    2.16
    91.0
    VERSAPORT
    4045
    1.67
    28.0
    VERSAPORT
    4165
    1.71
    29.0
    VERSAPORT
    4167
    2.12
    46.0
    VERSAPORT
    4225
    1.80
    34.0
    VERSAPORT
    4233
    1.80
    38.0
    VERSAPORT
    4243
    1.82
    32.0
    VERSAPORT
    4245
    1.80
    33.0
    VERSAPORT
    4251
    1.80
    27.0
    VERSAPORT
    4259
    1.80
    32.0
    VERSAPORT
    4369
    2.16
    82.0
    VERSAPORT
    4372
    2.00
    38.0
    VERSAPORT
    4382
    2.12
    46.0
    VERSAPORT
    4407
    2.12
    42.0
    VERSAPORT
    4449
    2.12
    44.0
    VERSAPORT
    4477
    2.12
    43.0
    VERSAPORT
    4510
    2.12
    47.0
    VERSAPORT
    4539
    2.14
    45.0
    VERSAPORT
    4542
    2.16
    49.0
    VERSAPORT
    4546
    2.16
    49.0
    VERSAPORT
    4599
    2.16
    48.0
    VERSAPORT
    4671
    2.16
    50.0
    VERSAPORT
    4686
    2.16
    49.0
    VERSAPORT
    4705
    2.06
    49.0
    VERSAPORT
    4722
    2.14
    51.0
    VERSAPORT
    4755
    2.16
    50.0
    VERSAPORT
    4756
    2.16
    52.0
    VERSAPORT
    4759
    2.16
    57.0
    VERSAPORT
    4764
    2.16
    51.0
    VERSAPORT
    4775
    2.06
    43.0
    VERSAPORT
    4781
    2.06
    42.0
    VERSAPORT
    4795
    2.10
    47.0
    VERSAPORT
    4798
    2.06
    41.0
    VERSAPORT
    4811
    2.06
    45.0
    VERSAPORT
    4839
    2.06
    48.0
    VERSAPORT
    4848
    2.06
    48.0
    VERSAPORT
    4851
    2.06
    49.0
    VERSAPORT
    4925
    2.06
    52.0
    VERSAPORT
    4968
    1.70
    BRINE
    4968
    2.16
    81.0
    VERSAPORT