Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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27.04.2024 - 01:34
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2/7-14

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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.
    2/7-14
    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.
    SUSPENDED
    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.
    2/7-14
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    PS 562915 SP.116
    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.
    221-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.
    165
    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,
    09.08.1979
    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.
    20.01.1980
    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.
    20.01.1982
    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.
    02.04.2007
    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 Norwegian Offshore Directorate 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 Norwegian Offshore Directorate 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.
    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).
    3390.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    124
    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° 29' 20.3'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 14' 2.65'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6260666.80
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    514414.24
    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.
    116

  • Wellbore history
    General
    Well 2/7-14 was drilled to delineate the southern limits of the Ekofisk Field in the southern Norwegian North Sea. The primary target was the Danian limestone. It was anticipated that the proposed location would have a similar structural position as development well 2/4-A-3 and a comparable amount of Danian net pay. The secondary target was the Late Cretaceous limestone, which was untested on the southern nose of the Ekofisk Field.
    Operations and results
    Appraisal well 2/7-14 was spudded with the semi-submersible installation Haakon Magnus on 9 August 1979 and drilled to TD at 3390 m in Late Cretaceous limestone. The well was drilled with Bentonite/Flosal spud mud to 20" casing point at 609 m, with Seawater/Native solids mud from 609 m to 13 3/8" casing point at 1526 m, with Drispac/ Lignosulphonate dispersed, inhibitive mud from 1526 m to 9 5/8" casing point at 3068 m, and with Bentonite/ Lignite/Drispac low fluid loss mud from 3068 m to TD.
    Top Paleocene was encountered at 3045 m. Top of the Danian Limestone was penetrated at 3146 m, 15 m low to prognosis, with 52 m of Danian net pay, compared to 86 m Danian net pay in well 2/4-A-3. The Danian reservoir pressures were found to be less than virgin Ekofisk pressures, evidence that the interval had been drained by the nearby well 2/4-A-3. The Late Cretaceous was encountered at 3257 m, 13 m low to prognosis. The section flowed oil with a large volume of associated water in DST 2.
    A total of 119 m core was recovered in 13 cores from the Paleocene and Late Cretaceous in the interval 3123 - 3306 m. No fluid sample was taken on wire line.
    The well was suspended on 20 January 1980 as an oil appraisal.
    Testing
    Five drill stem tests were made through perforations in the 7" liner.
    DST 1 at 3346.7 - 3349.8 m in the Late Cretaceous Limestone recovered 12 m3 water cushion plus 21 m3 formation fluid (85% water, 15% oil and water emulsion).
    DST 2 at 3261.4 - 3279.7 m in the Late Cretaceous Limestone produced in the final flow 227 Sm3 oil and 31430 Sm3 gas and 1445 m3 water /day on a 25.4 mm choke. The GOR was 139 Sm3/Sm3, the oil gravity was 30.4 deg API, and the gas gravity was 0.82.
    DST 3 at 3225.7 - 3235.2 m in the lower Danian Limestone produced in the final flow 586516 Sm3 gas and 401 Sm3 water /day on a 20.6 mm choke.
    DST 4 at 3189.5 - 3211.4 m in the middle Danian Limestone produced in the final flow 553 Sm3 oil and 86366 Sm3 gas with less than 1% water /day on a 15.1 mm choke. The GOR was reported to be 239 Sm3/Sm3, the oil gravity was 34.6 deg API, and the gas gravity was 0.682.
    DST 5 at 3150.5 - 3168.7 m in the upper Danian Limestone produced in the final flow 76 Sm3 oil and 14368 Sm3 gas with 5% sediment and water /day on a 7.9 mm choke. The GOR was 190 Sm3/Sm3, the oil gravity was 32.9 deg API, and the gas gravity was 0.697.

  • 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]
    375.00
    3386.00

  • 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
    10240.0
    10290.0
    [ft ]
    2
    10299.0
    10342.0
    [ft ]
    3
    10358.0
    10367.9
    [ft ]
    4
    10377.0
    10400.0
    [ft ]
    5
    10400.0
    10445.6
    [ft ]
    6
    10451.0
    10455.0
    [ft ]
    7
    10476.0
    10514.6
    [ft ]
    8
    10533.0
    10557.0
    [ft ]
    9
    10600.0
    10627.0
    [ft ]
    10
    10630.0
    10654.8
    [ft ]
    11
    10745.9
    10783.0
    [ft ]
    12
    10798.0
    10817.0
    [ft ]
    13
    10819.0
    10845.7
    [ft ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    113.6
    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
    10601.7
    [ft]
    C
    OD
    10604.6
    [ft]
    C
    OD
    10607.3
    [ft]
    C
    OD
    10607.7
    [ft]
    C
    OD
    10610.4
    [ft]
    C
    OD
    10612.3
    [ft]
    C
    OD
    10613.4
    [ft]
    C
    OD
    10614.4
    [ft]
    C
    OD
    10615.3
    [ft]
    C
    OD
    10617.6
    [ft]
    C
    OD
    10619.1
    [ft]
    C
    OD
    10622.2
    [ft]
    C
    OD
    10625.3
    [ft]
    C
    OD
    10631.1
    [ft]
    C
    OD
    10633.6
    [ft]
    C
    OD
    10636.2
    [ft]
    C
    OD
    10638.7
    [ft]
    C
    OD
    10644.3
    [ft]
    C
    OD
    10646.6
    [ft]
    C
    OD
    10649.7
    [ft]
    C
    OD
    10652.5
    [ft]
    C
    OD
    10652.6
    [ft]
    C
    OD
    10656.2
    [ft]
    C
    OD
    10658.7
    [ft]
    C
    OD

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    96
    1783
    3002
    3002
    3018
    3033
    3134
    3146
    3146
    3257

  • 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
    2.28
    pdf
    11.81
    pdf
    15.17

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3321
    3324
    25.4
    2.0
    3236
    3254
    0.0
    3.0
    3200
    3210
    0.0
    4.0
    3164
    3186
    0.0
    5.0
    3125
    3143
    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
    14.000
    3.0
    4.0
    5.0
    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
    227
    31000
    0.874
    0.820
    139
    3.0
    59000
    4.0
    553
    86000
    0.852
    0.682
    239
    5.0
    76
    14000
    0.861
    0.697
    190

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL
    92
    3356
    CBL GR
    2896
    3356
    CBL VDL
    3067
    3354
    CDM
    3074
    3383
    CDM FIL
    3074
    3383
    CNL
    2894
    3354
    DLL MSFL
    3074
    3383
    FDC CNL
    3074
    3383
    ISF SONIC GR
    61
    3383
    TEMP
    2304
    3341
    VELOCITY
    365
    3383

  • 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
    123.0
    36
    126.0
    0.00
    LOT
    SURF.COND.
    20
    340.0
    26
    354.0
    1.42
    LOT
    INTERM.
    13 3/8
    1501.0
    17 1/2
    1516.0
    2.08
    LOT
    INTERM.
    9 5/8
    3043.0
    12 1/4
    3053.0
    1.66
    LOT
    LINER
    7
    3345.0
    8 1/2
    3365.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    123
    1.68
    24.0
    5.7
    WATER BASED
    04.09.1989
    123
    1.68
    23.0
    5.7
    WATER BASED
    04.09.1989
    123
    1.60
    WATER BASED
    04.09.1989
    145
    1.60
    23.0
    WATER BASED
    04.09.1989
    291
    1.60
    22.0
    WATER BASED
    04.09.1989
    1462
    1.60
    24.0
    WATER BASED
    04.09.1989
    1462
    1.60
    WATER BASED
    04.09.1989
    1462
    1.60
    22.0
    WATER BASED
    04.09.1989
    1462
    1.60
    22.0
    WATER BASED
    04.09.1989
    1462
    1.60
    19.0
    WATER BASED
    04.09.1989
    1462
    1.60
    18.0
    WATER BASED
    04.09.1989
    1462
    1.60
    WATER BASED
    04.09.1989

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    14001.00
    [ft ]
    14002.00
    [ft ]
    14003.00
    [ft ]
    14004.00
    [ft ]
    14005.00
    [ft ]
    14006.00
    [ft ]
    14007.00
    [ft ]
    14008.00
    [ft ]
    14009.00
    [ft ]
    14010.00
    [ft ]
    14011.00
    [ft ]
    14012.00
    [ft ]
    14013.00
    [ft ]
    14014.00
    [ft ]
    14015.00
    [ft ]
    14016.00
    [ft ]
    14017.00
    [ft ]
    14018.00
    [ft ]
    14019.00
    [ft ]
    14020.00
    [ft ]
    14021.00
    [ft ]
    14022.00
    [ft ]
    14023.00
    [ft ]

  • 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
    0.22