Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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26.11.2024 - 01:27
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2/1-13 S

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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.
    2/1-13 S
    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
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    2/1-13
    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.
    Talisman Energy 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.
    1212-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.
    121
    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,
    07.11.2008
    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.
    07.03.2009
    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.
    03.01.2011
    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.
    03.01.2011
    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/GAS 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.
    41.3
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    69.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4435.0
    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).
    4358.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    21.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    161
    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.
    TRIASSIC
    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.
    SKAGERRAK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 47' 9.5'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 2' 29.72'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6293703.09
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    502541.05
    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.
    5975

  • Wellbore history
    General
    Well 2/1-13 S was drilled on the TR3 prospect located on the south-western margin of the Hidra High, 14 km southwest of Gyda, 8 kilometres southwest of the Gyda South Field and 1.5 kilometres southwest of the closest well 2/1-11. The well was drilled in a more crestal position than 2/1-11. The primary target of the well was fluvial channel sands of the Triassic Skagerrak Formation. Secondary objective was the Bryne reservoir.
    Operations and results
    Well 2/1-13 S was spudded with the jack-up installation Maersk Guardian on 6 November 2008 and drilled to TD at 4435 m in the Triassic Skagerrak Formation. The 36" top hole was drilled to 214 m, followed by a 12 1/4" pilot hole to 620 m to check for shallow gas. Although some gas was encountered it was not of sufficient quantity or pressure to cause concern. Further drilling proceeded without significant problems down to TD in the 16" section at 2416 m. When running the 13 3/8" casing, it could not pass 2093 m. Due to due to well bore stability problems and the long rat hole left as a consequence of setting the casing shoe high, the well was sidetracked below the casing shoe. This technical sidetrack, 2/1-13 ST2, was drilled to final TD. The well was drilled with Pre ‐ hydrated Bentonite/CMC/seawater down to 620 m, with Versatec oil based mud from 620 m to 4149 m, and with Warp HTHP oil based mud from 4149 m to TD.
    The top of the reservoir was encountered 63 m shallower than prognosed, at 4241 m (4124 m TVD SS) and had 1m of possible pay in sandstones in the interval 4252 to 4276 m. Shows were seen throughout this interval. No OWC was recognised on the logs, but ODT was at 4362 m (4152.0 m TVD SS). The stratigraphy of the reservoir is somewhat uncertain, but it is believed that the upper part down to 4362 m belong to the Bryne Formation, while the underlying sand belong to the Skagerrak Formation. The Skagerrak Formation was dry.
    One core was cut in the Bryne Formation from 4274 to 4301 m. The RCI tool was run on wire line to take pressure points, but only the Skagerrak Formation gave valid pressures, proving a water gradient of 1.05 sg. The Bryne Formation proved to be tight. No fluid samples were taken.
    The well was permanently abandoned on 7 March 2008 as a dry well with oil and gas shows.
    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]
    250.00
    2410.00

  • 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
    4274.0
    4301.1
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    27.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • 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
    36
    206.0
    30
    214.0
    0.00
    LOT
    SURF.COND.
    20
    618.0
    24
    620.0
    1.67
    LOT
    INTERM.
    13 3/8
    2077.0
    16
    2416.0
    1.95
    LOT
    INTERM.
    9 7/8
    4142.0
    12 1/4
    4149.0
    2.24
    LOT
    OPEN HOLE
    4435.0
    8 1/2
    4435.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    MWD LWD - DIR
    214
    620
    MWD LWD - GR
    110
    214
    MWD LWD - GR RES DIR
    214
    620
    MWD LWD - GR RES DIR PWD DDS
    620
    2416

  • Lithostratigraphy

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    41
    1.49
    15.0
    Kill
    214
    1.05
    3.0
    Bentonite / SW
    617
    1.19
    10.0
    PHB/Sea water
    620
    1.14
    11.0
    PHB/Sea water
    1150
    1.74
    46.0
    OB Versatec
    1323
    1.49
    33.0
    Versatec
    2177
    1.54
    39.0
    Versatec
    2416
    1.56
    32.0
    Versatec
    2416
    1.56
    32.0
    Versatec
    2764
    1.69
    48.0
    Versatec OBM
    4000
    1.70
    48.0
    Versatec OBM
    4149
    1.72
    48.0
    Versatec OBM
    4150
    2.04
    50.0
    OB WARP
    4274
    2.01
    45.0
    OB WARP
    4435
    2.01
    48.0
    OB WARP

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    4183.0
    [m]
    DC
    APT
    4195.0
    [m]
    DC
    APT
    4204.0
    [m]
    DC
    APT
    4213.0
    [m]
    DC
    APT
    4222.0
    [m]
    DC
    APT
    4231.0
    [m]
    DC
    APT
    4240.0
    [m]
    DC
    APT
    4249.0
    [m]
    DC
    APT
    4258.0
    [m]
    DC
    APT
    4274.0
    [m]
    DC
    APT
    4435.0
    [m]
    DC
    APT