Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
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24/12-6 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.
    24/12-6 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.
    24/12-6
    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.
    Det norske oljeselskap ASA
    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.
    1297-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.
    127
    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,
    16.08.2010
    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.
    20.12.2010
    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.
    01.04.2012
    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.
    01.04.2012
    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.
    DRY
    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.
    29.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    116.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    5207.0
    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).
    5076.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    21.7
    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.
    MIDDLE JURASSIC
    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.
    SLEIPNER FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 3' 54.14'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 45' 15.24'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6548111.45
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    428561.94
    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.
    6328

  • Wellbore history
    General
    Well 24/12-6 S was drilled on the Stirby prospect in the Vana Sub-basin of the Viking Graben in the North Sea. Stirby was a potential multipay structure and the main target was the Late Jurassic Intra Draupne Formation Sandstones ("Stirby Upper"). The secondary target was the Middle Jurassic Hugin/Sleipner Formation sandstones ("Stirby Deep"). Additional targets was possible in the Heather Formation with potential for reservoir sands deposited from the east as encountered in the Gudrun Field south of the Stirby location.
    Operations and results
    Wildcat well 24/12-6 S was spudded with the semi-submersible installation Songa Delta on 16 August 2010 and drilled to TD at 5207 m (5076 m TVD)in the Middle Jurassic Sleipner Formation. Severe hole problems with excessive cavings and tight hole was experienced in the 17 1/2" section from 1279 m to 2771 m. The reason for this was believed to be too high concentrations of KCl, drying out the claystone. Due to these problems the well was plugged back and sidetracked from 1300 m. The well was drilled with Spud mud down to 1279 m, and with KCl brine from 1279 m to 2771 m. After sidetracking the well was drilled with Carbotech oil based mud from 1300 m to 4330, and with Magmatech oil based mud from 4330 m to TD.
    The Draupne Formation was encountered at from 4417 m (4286 m TVD ), the Heather Formation at 4788 m (4657 m TVD), and top Vestland Group, Hugin Formation at 5029 m (4898 m TVD). Only rare traces of sand were seen at the expected primary target, the Late Jurassic Intra Draupne Sand (Stirby Upper). This part of the well contained organic rich shale with thin beds of limestone. These limestone beds correspond to the strong amplitudes which defined the main target as a basin floor fan in the prognosis. The secondary target, the Middle Jurassic Vestland Group (Stirby Deep), came in 7.8 m deeper than prognosed. An upper sandstone, probably belonging to the Hugin Formation, was described as silica cemented. Only one stable pressure point was collected here and thereby no gradient defining hydrocarbon or water was obtained. In the lower sandstone just above TD of the well another pressure point reading was obtained, 33 bar lower than the one in "Upper sandstone". Scanning evaluation with the RCI tool in the lower sandstone gave the conclusion that this sand was water filled. No oil shows were reported above BCU. Direct and cut fluorescence was observed on traces of sandstone grains/aggregates from top Hugin Formation and downwards. The fluorescence on the aggregates was however difficult to interpret due to possible interference from mineral fluorescence, oil base and rock flour.
    No cores were cut and no wire line fluid samples were taken.
    The well was permanently abandoned on 20 December 2010 as a dry 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]
    1290.00
    2770.00

  • 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
    225.0
    36
    229.0
    0.00
    LOT
    SURF.COND.
    20
    1273.0
    26
    1279.0
    0.00
    LOT
    PILOT HOLE
    1279.0
    9 7/8
    1279.0
    0.00
    LOT
    INTERM.
    13 5/8
    2812.0
    17 1/2
    2828.0
    2.20
    LOT
    INTERM.
    9 5/8
    4321.0
    12 1/4
    4330.0
    0.00
    LOT
    OPEN HOLE
    5207.0
    8 1/2
    5207.0
    1.77
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CALI MRCH GR CCL MFC
    100
    4268
    CBL MRCH GR CCL SBT MFC
    3778
    4263
    DEN NEU MRCH JAR TTRM GR ZDL CN
    4317
    5204
    LWD - GR REMP AC
    196
    2770
    MWD - GR REMP AC
    196
    4326
    MWD - GR REMP DEN NEU AC
    4300
    4767
    MWD - GR REMP DEN NEU AC FMP
    4738
    5204
    PRES MRCH JAR TTRM GR RCI PVT
    5030
    5207
    RES MRCH JAR TTRM DSL HDIL MREX
    4300
    5187
    VSP GR GEOWAVE
    205
    4135

  • Lithostratigraphy

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    174
    1.05
    SPUD MUD
    226
    1.05
    SPUD MUD
    990
    1.05
    SPUD MUD
    1120
    1.05
    SPUD MUD
    1223
    1.36
    39.0
    CARBO TECH
    1279
    1.45
    SPUD MUD
    1445
    1.45
    13.0
    KCL BRINE
    1720
    1.25
    16.0
    KCL BRINE
    2500
    1.39
    42.0
    CARBO TECH
    2653
    1.32
    14.0
    KCL BRINE
    2711
    1.32
    18.0
    KCL BRINE
    2746
    1.39
    41.0
    CARBO TECH
    2828
    1.39
    39.0
    CARBO TECH
    3051
    1.60
    37.0
    CARBO TECH
    3800
    1.60
    37.0
    CARBO TECH
    4150
    1.60
    45.0
    CARBO TECH
    4276
    1.65
    53.0
    CARBO TECH
    4276
    1.65
    42.0
    CARBO TECH
    4330
    1.65
    41.0
    CARBO TECH
    4772
    2.00
    47.0
    MAGMA TECH
    5101
    2.00
    50.0
    MAGMA TECH
    5207
    2.02
    51.0
    MAGMA TECH