Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

7122/7-3

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    7122/7-3
    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
    Press release
    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.
    BARENTS 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.
    7122/7-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NA01M1 3D inline:1399 & crossline 3119
    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.
    Eni Norge AS
    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.
    1105-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.
    77
    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,
    24.10.2005
    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.
    08.01.2006
    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.
    08.01.2008
    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.
    09.01.2008
    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/GAS
    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 TRIASSIC
    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.
    TUBÅEN 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.
    TRIASSIC
    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.
    SNADD 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.
    MIDDLE TRIASSIC
    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.
    KOBBE 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.
    343.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2726.0
    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).
    2725.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.7
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    73
    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.
    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.
    TEMPELFJORDEN GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    71° 15' 17.53'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    22° 16' 4.6'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7906512.67
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    545476.82
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    34
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    5214

  • Wellbore history
    General
    Well 7122/7-3 was drilled on the Goliat Field, which is located approximately 55 km to the south-east of the Snøhvit Field. The Goliat structure is located on the crestal part of a major northeast-southwest trending roll-over anticline situated in the southeastern part of the Hammerfest Basin, along the Troms-Finmark Fault. The primary purpose of the well was to appraise the hydrocarbon potential of the Early Jurassic / Late Triassic (the 7122/7-1 Goliat Discovery). The secondary purpose was to test the potential throughout the Triassic and Late Permian. Permian was the drilling commitment for the licence.
    Operations and results
    Well 7122/7-3 was spudded with the semi-submersible installation Eirik Raude on 24 October 2005 and drilled to TD at 2726 m in limestone/claystone of the Late Permian Røye Formation. No serious problem was encountered in the operations. The well was drilled with seawater/high viscous sweeps with pre-hydrated bentonite mud down to 538 m and with K/Na Format Polymer mud from 538 m to TD.
    The top of the Tubåen reservoir was found at 1087 m, 5 m deeper than prognosis. The reservoir had a gas cap with a GOC at 1145.6 m and oil below. No OWC was found. Top Snadd Formation reservoir was encountered at 1180 m, 23 m shallower than prognosis. The reservoir was oil bearing with a true OWC at 1199.5 m and was in a pressure regime different from the Tubåen reservoir pressure. The third reservoir was found in the Kobbe Formation at 1808 m, 29 m shallower than the prognosis. The reservoir was oil bearing. Oil was confirmed down to 1875.3 m by MDT fluid scanning, and the oil water contact was interpreted to be at 1878 m based on intersection between oil and water gradients.
    The Kobbe Formation oil differs from the upper Tubåen and Snadd oils, which are geochemically very similar. The Kobbe oil is not biodegraded while the upper oil reservoirs are slightly biodegraded (removal of C8 ? C15 n-alkanes, but intact C15+ n-alkanes). Other geochemical differences, such as a very light stable carbon isotope composition in the Kobbe oil compared to the upper oils, indicate that the Kobbe oil and the upper oils have different source rocks.
    Seven cores were cored in the well. Cores 1 and 2 were cut from 1082 to 1104 from the Late Jurassic Fuglen Formation and into the Late Triassic Kap Toscana Group, core 3 was cut from 1146.5 to 1156 m in the Kap Toscana Group, core 4 was cut from 1187 to 1192 m in the Late Triassic Snadd Formation, cores 5 and 6 were cut from 1812 to 1836 m in the Middle Triassic Kobbe Formation, and core 7 was cut from 2519 to 2521 m in the Early Triassic Havert Formation. MDT fluid samples were taken at 1095.3 m (Tubåen Formation ; gas), 1148.5 m (Tubåen Formation; oil), 1195.6 m (Snadd Formation; oil), 1202.1 m (Snadd Formation; water), 1812 m (Kobbe Formation; oil), 1874.5 m (Kobbe Formation; oil), and at 1931.2 m (Kobbe Formation; water).
    The well was permanently abandoned on 8 January 2006 as a discovery well.
    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]
    540.00
    2725.00

  • 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
    1082.0
    1085.3
    [m ]
    2
    1086.0
    1105.0
    [m ]
    3
    1146.0
    1156.8
    [m ]
    4
    1187.0
    1189.5
    [m ]
    5
    1812.0
    1823.2
    [m ]
    6
    1824.0
    1834.3
    [m ]
    7
    2519.0
    2520.9
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    58.9
    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
    1082.3
    [m]
    C
    ICHRON
    1083.3
    [m]
    C
    ICHRON
    1086.5
    [m]
    C
    ICHRON
    1087.0
    [m]
    C
    ICHRON
    1149.5
    [m]
    C
    ICHRON
    1151.5
    [m]
    C
    ICHRON
    1154.7
    [m]
    C
    ICHRON
    1156.6
    [m]
    C
    ICHRON
    1187.1
    [m]
    C
    ICHRON
    1189.5
    [m]
    C
    ICHRON
    1814.7
    [m]
    C
    ICHRON
    1816.2
    [m]
    C
    ICHRON
    1822.6
    [m]
    C
    ICHRON
    1824.4
    [m]
    C
    ICHRON
    1831.6
    [m]
    C
    ICHRON
    1832.9
    [m]
    C
    ICHRON
    1833.3
    [m]
    C
    ICHRON

  • 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
    MDT
    0.00
    1195.60
    30.11.2005 - 00:00
    YES
    MDT
    1812.00
    0.00
    17.12.2005 - 00:00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.40

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.75
    pdf
    5.05

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    - LEHQT ECRD
    1693
    2409
    - LEHQT ECRO
    995
    1714
    CMR HLRA TLO HGNS ECS HWGS ACTS
    995
    1714
    CMR HRLA TLD HGNS ECS HNGS ACTS
    1693
    2409
    CMR PPC GR ACTS
    995
    1712
    DSI HRLA TLD HGNS ACTS ECRD
    2350
    2727
    FMI PPC GR ACTS
    995
    1714
    LWD - GR RES DIR
    524
    989
    LWD - GR RES DIR ECD
    1000
    2415
    MDT GR ACTS ACRD
    1808
    2206
    MDT GR ACTS ECRD
    1000
    1700
    MDT GR ACTS ECRD
    2350
    2727
    MDT GR ACTS ECRD DUAL PACKER
    1148
    1195
    MSCT GR
    1105
    1653
    MSCT GR
    1719
    2381
    MSIP DENS GR CAL
    477
    1001
    MSIP FMI PPPC GR ACTS
    1693
    2410
    VSP GR
    850
    2721

  • 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
    416.0
    36
    421.0
    0.00
    LOT
    SURF.COND.
    20
    529.0
    26
    530.0
    1.35
    LOT
    SURF.COND.
    13 3/8
    995.0
    16
    1000.0
    2.62
    LOT
    INTERM.
    9 5/8
    1694.0
    12 1/4
    1712.0
    1.19
    LOT
    LINER
    7
    2405.0
    8 1/2
    2420.0
    0.00
    LOT
    OPEN HOLE
    2726.0
    6
    2726.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    372
    1.03
    SPUD MUD
    400
    1.25
    19.0
    FORMATE POLYMER
    538
    1.20
    12.0
    FORMPRO
    900
    1.20
    12.0
    FORMATE POLYMER
    1056
    1.30
    12.0
    FORMATE POLYMER
    1230
    1.30
    15.0
    FORMATE POLYMER
    1712
    1.34
    15.0
    FORMATE POLYMER
    1816
    1.36
    14.0
    FORMATE POLYMER
    2420
    1.54
    21.0
    FORMATE POLYMER
    2540
    1.55
    17.0
    FORMATE POLYMER
    2726
    1.54
    19.0
    FORMATE POLYMER

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    1087.80
    [m ]
    1813.25
    [m ]
    1818.25
    [m ]
    1828.75
    [m ]
    1819.02
    [m ]
    1826.45
    [m ]

  • 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
    0.29