Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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sodir.no          Norsk
03.11.2024 - 01:26
Time of last synchronization with Norwegian Offshore Directorate's internal systems

2/7-19

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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
    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.
    SUSPENDED
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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
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    PG 030615 SP.12
    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-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.
    154
    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,
    02.09.1980
    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.
    02.02.1981
    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.
    02.02.1983
    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
    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.
    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.
    25.0
    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).
    4876.0
    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).
    4876.0
    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.
    154
    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.
    1367

  • Wellbore history
    >
    General
    Well 2/7-19 is located ca 10 km west of the Embla and Eldfisk fields in the southern Norwegian North Sea. The objective was to test the Danian - Late cretaceous limestone, and sandstones of the Early Cretaceous and Jurassic on a low relief structure. Well 2/7-19 was the third attempt to drill this prospect. The first two attempts, 2/7-17 and 2/7-18, were junked because of mechanical problems.
    Operations and results
    Well 2/7-19 was spudded with the semi-submersible installation Borgny Dolphin on 2 September 1980 and drilled to TD at 4877 m in the Late Permian Zechstein Group. A total of 154 days on the location were used to drill and abandon the well. The well was drilled to a depth of 4785 m with 16.0 ppg mud. This was on 17 November. An estimated 12 m of Early Cretaceous sandstone had been penetrated and the drilling gas had increased after entering this zone, with some indications of hydrocarbons. The well was static with 16.0 ppg density mud, however the weight was raised to come out of the hole and commence coring. Upon raising the mud weight to 16.3 ppg a pack-off occurred which broke down a formation and circulation was lost. Circulation was re-established with 16.0 ppg mud. The mud weight was then raised in stages from 16.2 ppg to give an adequate trip margin to log. Logs were run, after which lost circulation problems again occurred. It took up to January 8 1981 before problems were cured and drilling could commence. The well was drilled with seawater and pre-hydrated bentonite down to 593 m, with seawater/bentonite/native solids from 593 m to 1600 m, and with seawater/Drispac/lignosulphonate from 1600 m to TD.
    No hydrocarbons were encountered in the Danian - Late Cretaceous limestone. Some fluorescence was observed on limestones in the Tor Formation and in the Hidra Formation. Gas-bearing sands of the Ula Formation were encountered. Oil shows were recorded in these sands, generally described as dull yellow fluorescence and slow yellow cut.
    One conventional core was cut from 3143.7 - 3162.0 m in the top of the Ekofisk Formation. One RFT fluid sample was recovered from 4772.2 m in an Ula Formation sandstone unit. The sample consisted of 50% gas-cut mud, where the gas gravity was 0.78 (air = 1). The RFT results indicated pressures too high to be safely tested with the rig equipment and BOP's on the rig at that time.
    The well was suspended on 19 June 1989 pending further evaluation and possible testing.
    Testing
    No drill stem test was performed.

  • 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]
    586.00
    4876.00

  • 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
    10314.0
    10370.3
    [ft ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    17.2
    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
    4547.0
    [m]
    DC
    OD
    4580.0
    [m]
    DC
    OD
    4583.0
    [m]
    DC
    HRS
    4593.0
    [m]
    DC
    OD
    4596.0
    [m]
    DC
    HRS
    4596.0
    [m]
    DC
    OD
    4608.0
    [m]
    DC
    HRS
    4617.0
    [m]
    DC
    OD
    4620.0
    [m]
    DC
    OD
    4623.0
    [m]
    DC
    HRS
    4626.0
    [m]
    DC
    OD
    4635.0
    [m]
    DC
    HRS
    4647.0
    [m]
    DC
    HRS
    4647.0
    [m]
    DC
    OD
    4666.0
    [m]
    DC
    OD
    4684.0
    [m]
    DC
    OD
    4705.0
    [m]
    DC
    OD
    4721.0
    [m]
    DC
    OD
    4736.0
    [m]
    DC
    OD
    4754.0
    [m]
    DC
    OD
    4760.0
    [m]
    DC
    HRS
    4766.0
    [m]
    DC
    HRS
    4766.0
    [m]
    DC
    OD
    4781.0
    [m]
    DC
    OD
    4785.0
    [m]
    DC
    HRS
    4800.0
    [m]
    DC
    OD
    4803.0
    [m]
    DC
    OD
    4821.0
    [m]
    DC
    OD
    4839.0
    [m]
    DC
    OD
    4852.0
    [m]
    DC
    OD
    4858.0
    [m]
    DC
    OD
    4867.0
    [m]
    DC
    OD
    4873.0
    [m]
    DC
    OD

  • 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
    0.00
    0.00
    30.10.2000 - 00:00
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.26
    pdf
    0.96

  • 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
    14.71
    pdf
    7.45
    pdf
    4.03

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    1448
    4836
    CDM
    3781
    4849
    CDM AP
    3784
    4877
    DIL SONIC
    3781
    4784
    FDC CNL
    2896
    4877
    GR
    91
    586
    ISF BHC
    1586
    3794
    ISF BHC MSFL
    4267
    4877
    ISF SONIC GR
    586
    1595
    MPT ML MLL
    3784
    4877
    RFT
    0
    0
    VELOCITY
    586
    4877

  • 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
    153.9
    36
    154.5
    0.00
    LOT
    SURF.COND.
    20
    585.5
    26
    593.4
    1.40
    LOT
    INTERM.
    13 3/8
    1585.9
    17 1/2
    1600.2
    1.87
    LOT
    INTERM.
    9 5/8
    3780.4
    12 1/4
    3799.9
    2.02
    LOT
    LINER
    7
    4872.2
    8 1/2
    4876.8
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    134
    2.12
    71.0
    27.3
    OIL BASED
    22.01.1990
    134
    2.04
    20.0
    19.2
    WATER BASED
    22.01.1990
    149
    2.04
    20.0
    16.8
    WATER BASED
    22.01.1990
    291
    2.04
    20.0
    8.1
    WATER BASED
    22.01.1990
    1006
    1.14
    35.0
    WATER BASED
    02.02.1981
    1356
    2.04
    20.0
    13.9
    WATER BASED
    22.01.1990
    1443
    1.62
    55.0
    WATER BASED
    02.02.1981
    1544
    2.04
    19.0
    9.6
    WATER BASED
    22.01.1990
    1582
    2.04
    19.0
    14.4
    WATER BASED
    22.01.1990
    1600
    1.19
    42.0
    WATER BASED
    02.02.1981
    2065
    1.62
    54.0
    WATER BASED
    02.02.1981
    3001
    2.04
    21.0
    6.7
    WATER BASED
    22.01.1990
    3120
    1.71
    55.0
    WATER BASED
    02.02.1981
    3437
    1.71
    52.0
    WATER BASED
    02.02.1981
    3463
    2.04
    22.0
    9.6
    WATER BASED
    22.01.1990
    3800
    1.73
    45.0
    WATER BASED
    02.02.1981
    4065
    1.92
    52.0
    WATER BASED
    02.02.1981
    4163
    1.92
    47.0
    WATER BASED
    02.02.1981
    4459
    1.92
    56.0
    WATER BASED
    02.02.1981
    4604
    1.92
    50.0
    WATER BASED
    02.02.1981
    4785
    1.96
    62.0
    WATER BASED
    02.02.1981
    4862
    2.05
    18.0
    9.1
    WATER BASED
    22.01.1990
    4863
    2.04
    19.0
    9.6
    WATER BASED
    23.01.1990
    4863
    2.04
    55.0
    14.4
    OIL BASED
    25.01.1990
    4863
    2.04
    55.0
    8.1
    OIL BASED
    26.01.1990
    4863
    2.04
    39.0
    14.4
    OIL BASED
    29.01.1990
    4863
    2.04
    34.0
    9.6
    OIL BASED
    29.01.1990
    4863
    2.04
    34.0
    9.6
    OIL BASED
    30.01.1990
    4863
    2.05
    33.0
    10.1
    OIL BASED
    31.01.1990
    4863
    2.05
    33.0
    10.1
    OIL BASED
    01.02.1990
    4863
    2.05
    22.0
    5.3
    WATER BASED
    24.01.1990
    4863
    2.04
    55.0
    8.1
    OIL BASED
    29.01.1990
    4863
    2.04
    34.0
    9.6
    OIL BASED
    29.01.1990
    4985
    2.01
    47.0
    WATER BASED
    02.02.1981

  • 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