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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2/7-16

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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.
    2/7-16
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    2/7-16
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    PG-2/7-F
    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.
    245-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.
    115
    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,
    20.03.1980
    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.
    12.07.1980
    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.
    12.07.1982
    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.
    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.
    SHOWS
    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
    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.
    71.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4818.0
    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).
    4812.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.75
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    125
    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 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.
    ÅSGARD FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 25' 21.68'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 5' 41.87'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6253268.30
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    505858.17
    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.
    232

  • Wellbore history
    General
    Wildcat well 2/7-16 was drilled on a structure on a broad terrace to the south of Edda field and with a geological environment similar to Edda. The primary objective was to test the potential for hydrocarbon production from Danian and Late Cretaceous Limestones on a low relief structural closure. Secondary objective was a possible stratigraphic trap potential in Early Cretaceous sandstones.
    Operations and results
    Well 2/7-16 was spudded with the semi-submersible installation Nortrym on 20 March 1980 and drilled to TD at 4818 m in the Early Cretaceous Ågard Formation. The well was drilled with Seawater/Native Solids mud down to the 13 3/8" casing point at 1523 m, with Seawater/Lignosulphonate from 1523 m to the 9 5/8" casing point at 3794 m, and with Calcium chloride/Sodium chloride XC polymer mud from 3794 m to TD.
    Hydrocarbon shows were encountered in the Danian and Upper Cretaceous limestone. The porosity was poorly developed and testing verified the zones to be non-productive. Early Cretaceous had shows in limestones, claystones, shales, and marls, but no sandstones were found.
    Thirteen conventional cores were cut continuously from 3182 m to 3402 m in the Ekofisk and Tor Formations Formations. Twenty-five RFT measurements were attempted in the gross interval 3823.8 - 4783.6 m. A fluid sample was obtained at 4587.9 m. It contained 50 ml formation water and 39 cubic feet (1.1 Sm3) gas.
    The well was permanently abandoned on 12 July 1980 as a dry well with shows.
    Testing
    Two drill stem tests were conducted. DST 1 at 3279.7 to 3288.8 m in the Tor Formation produced 660 barrels (105 m3) of water /day, with traces of oil and gas. DST 2 from the intervals 3193.1 - 3199.8 and 3201.4 - 3215.4 m in the Ekofisk Formation produced 28.8 barrels (4.6 m3) water /day with no oil or gas before acid treatment. Well died completely after acid, with only a very weak flow of acid gas.

  • 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]
    637.00
    4817.00

  • 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
    10441.0
    10501.0
    [ft ]
    2
    10501.0
    10558.9
    [ft ]
    3
    10560.0
    10619.6
    [ft ]
    4
    10621.0
    10661.1
    [ft ]
    5
    10681.0
    10729.0
    [ft ]
    6
    10730.0
    10788.0
    [ft ]
    7
    10790.0
    10841.6
    [ft ]
    8
    10843.0
    10901.6
    [ft ]
    9
    10903.0
    10908.6
    [ft ]
    10
    10921.0
    10981.0
    [ft ]
    11
    10981.0
    11038.6
    [ft ]
    12
    11041.0
    11101.0
    [ft ]
    13
    11101.0
    11161.0
    [ft ]
    14
    11163.0
    11172.0
    [ft ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    209.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Lithostratigraphy

  • 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
    31.79
    pdf
    3.09

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3254
    3263
    0.0
    2.0
    3168
    3190
    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
    2.0
    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
    2.0

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DLL BHC GR SP
    3793
    4816
    FDC CNL GR CAL
    2834
    4817
    HDT
    1524
    3805
    ISF BHC GR CAL SP
    164
    3814
    ML MLL
    3791
    4817
    VELOCITY
    625
    4818

  • 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
    139.0
    36
    140.0
    0.00
    LOT
    SURF.COND.
    20
    587.0
    26
    605.0
    1.53
    LOT
    INTERM.
    13 3/8
    1497.0
    17 1/2
    1513.0
    2.04
    LOT
    INTERM.
    9 5/8
    3769.0
    12 1/4
    3788.0
    2.09
    LOT
    LINER
    7
    4818.0
    8 1/2
    4818.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    627
    1.13
    80.0
    WATER BASED
    12.07.1980
    1201
    1.25
    48.0
    WATER BASED
    12.07.1980
    1538
    1.37
    34.0
    WATER BASED
    12.07.1980
    2306
    1.73
    58.0
    WATER BASED
    12.07.1980
    2561
    1.72
    47.0
    WATER BASED
    12.07.1980
    2824
    1.72
    62.0
    WATER BASED
    12.07.1980
    3201
    1.70
    60.0
    WATER BASED
    12.07.1980
    3220
    1.69
    56.0
    WATER BASED
    12.07.1980
    3432
    1.49
    58.0
    WATER BASED
    12.07.1980
    4115
    1.64
    65.0
    WATER BASED
    12.07.1980
    4674
    1.78
    55.0
    WATER BASED
    12.07.1980
    4817
    1.88
    47.0
    WATER BASED
    12.07.1980

  • 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