Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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01.11.2024 - 01:26
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2/7-19 R

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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.
    2/7-19 R
    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
    Multilateral
    Indicator telling if the parent well is multilateral, meaning it has more than one branch radiating from the main borehole. Example of legal values: YES, NO. See also Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    NO
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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.
    2/7-19
    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.
    262-L2
    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.
    59
    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,
    15.01.1990
    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.
    14.03.1990
    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.
    14.03.1992
    Plugged and abondon date
    Date when the P&A-operations of the wellbore was finished, as reported by the operator to the Norwegian Offshore Directorate throught DDRS (Daily Drilling Reporting System). Only applied once pr. wellhead/surface location.
    14.03.1990
    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.
    17.06.2009
    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
    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.
    LATE 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.
    ULA FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    22.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    73.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4873.0
    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).
    4873.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    179
    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 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.
    ZECHSTEIN 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' 19.1'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 6' 12.2'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6243913.56
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    506391.96
    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.
    1512

  • Wellbore history
    General
    Well 2/7-19 R is a re-entry of well 2/7-19, which was drilled in 1980/81 by the semi-submersible Borgsten Dolphin. The well encountered gas in Early Cretaceous sandstones, but was suspended in February 1981 due to a BOP system that was not rated to allow a DST test to be performed. RFT tests measurements indicated a possible wellhead pressure of 11200 psi, while the BOP was rated to 10000 psi. A 7" liner was run to a depth of 4839 m and cemented, but not perforated. The purpose of the re-entry was to test 43 m of gross pay distributed in four sand lenses from 4712 to 4839 m. The DST test was designed such that it would be possible to keep the well for future production if flow rates were commercial.
    Operations and results
    Wildcat well 2/7-19 was re-entered (2/7-19 R) with the semi-submersible installation Ross Isle on 15 January 1990.
    During drilling of the 2/7-19 well, only gas was encountered. The test in the re-entry showed that the reservoir rocks were tight, but a positive feature was that oil was encountered during testing. The test confirmed the earlier anticipated formation pressure of 860 to 895 bar.
    The well was permanently abandoned on 14 March 1990 as an oil appraisal.
    Testing
    One DST test was performed from four sand lenses in the intervals 4712 - 4727 m, 4762 - 4783 m (Ula Formation), 4800 - 4818 m Ula/Bryne Formations), and 4830 - 4838 m (Bryne Formation). The total net pay in the perforated sections was 23 m. After acid treatment the well produced hydrocarbons at a rate of 34.8 Sm3 oil and 15631 Sm3 gas /d through an 11.91 mm choke. The CO2 content of the separator gas was 4.4%. The GOR was 449 Sm3/Sm3 but this figure is uncertain due to slugging of the well and poor rate measurements. The matrix/acid job performed was not effective. The stable shut-in temperature at 4628 m (gauge depth) was 169 deg C, while maximum recorded flowing temperature was 172 deg C. It was not established which of the four perforated sections that contributed to the flow.

  • 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
    4711.60
    4838.40
    16.02.1990 - 00:00
    YES

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    4711
    4838
    12.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.700
    169
    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
    35
    15631
    449

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.21
    pdf
    1.01

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    364
    1.32
    8.0
    16.8
    WATER BASED
    12.03.1990
    1106
    1.32
    5.0
    6.7
    WATER BASED
    09.03.1990
    1106
    1.32
    5.0
    6.7
    WATER BASED
    12.03.1990
    3399
    2.06
    58.0
    19.6
    OIL BASED
    28.02.1990
    3399
    1.82
    10.0
    19.2
    WATER BASED
    02.03.1990
    3399
    1.82
    11.0
    19.6
    WATER BASED
    05.03.1990
    3399
    1.82
    10.0
    18.2
    WATER BASED
    05.03.1990
    3399
    1.82
    11.0
    16.8
    WATER BASED
    05.03.1990
    3399
    1.82
    10.0
    16.8
    WATER BASED
    06.03.1990
    3399
    1.82
    10.0
    17.2
    WATER BASED
    07.03.1990
    3399
    1.68
    8.0
    12.9
    WATER BASED
    08.03.1990
    3399
    1.82
    11.0
    20.6
    WATER BASED
    02.03.1990
    4545
    2.10
    61.0
    14.4
    OIL BASED
    28.02.1990
    4545
    2.04
    53.0
    9.6
    OIL BASED
    28.02.1990
    4545
    2.09
    58.0
    13.9
    OIL BASED
    28.02.1990
    4545
    2.06
    58.0
    19.6
    OIL BASED
    28.02.1990
    4719
    2.04
    52.0
    10.5
    OIL BASED
    22.02.1990
    4719
    2.04
    51.0
    10.5
    OIL BASED
    23.02.1990
    4863
    2.04
    43.0
    12.0
    OIL BASED
    12.02.1990
    4863
    2.04
    48.0
    12.9
    OIL BASED
    19.02.1990
    4863
    2.05
    33.0
    10.1
    OIL BASED
    05.02.1990
    4863
    2.06
    54.0
    17.2
    OIL BASED
    05.02.1990
    4863
    2.05
    52.0
    12.4
    OIL BASED
    05.02.1990
    4863
    2.04
    50.0
    10.5
    OIL BASED
    05.02.1990
    4863
    2.04
    49.0
    13.4
    OIL BASED
    06.02.1990
    4863
    2.04
    42.0
    10.1
    OIL BASED
    07.02.1990
    4863
    2.04
    51.0
    13.4
    OIL BASED
    08.02.1990
    4863
    2.04
    45.0
    14.4
    OIL BASED
    09.02.1990
    4863
    2.10
    46.0
    12.9
    OIL BASED
    12.02.1990
    4863
    2.04
    50.0
    14.4
    OIL BASED
    12.02.1990
    4863
    2.04
    43.0
    12.0
    OIL BASED
    13.02.1990
    4863
    2.04
    43.0
    12.0
    OIL BASED
    14.02.1990
    4863
    2.01
    48.0
    8.6
    OIL BASED
    15.02.1990
    4863
    2.04
    50.0
    14.4
    OIL BASED
    16.02.1990
    4863
    2.04
    49.0
    13.4
    OIL BASED
    19.02.1990
    4863
    2.04
    51.0
    14.8
    OIL BASED
    19.02.1990
    4863
    2.04
    51.0
    11.0
    OIL BASED
    20.02.1990
    4863
    2.04
    50.0
    10.5
    OIL BASED
    21.02.1990

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    4800.0
    [m]
    DC
    IKU
    4839.0
    [m]
    DC
    IKU
    4852.0
    [m]
    DC
    IKU
    4867.0
    [m]
    DC
    IKU