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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7/1-2 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.
    7/1-2 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
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    7/1-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    Crossline 2525- NH 0201
    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.
    StatoilHydro Petroleum 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.
    1174-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.
    50
    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,
    20.03.2008
    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.
    08.05.2008
    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.
    08.05.2010
    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.
    08.05.2010
    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.
    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.
    44.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    87.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3175.0
    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).
    3158.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    16
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    126
    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.
    BRYNE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    57° 55' 57.09'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 4' 10.82'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6421722.87
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    444903.98
    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.
    5793

  • Wellbore history
    General
    The 7/1-2 S Yoda well is located on the north-western margin of the Jæren High, 18 km southeast of the Varg field and 5.5 km northeast of the closest well 6/3-2. The well is located on a 4-way dip closure over a salt wall similar to the Rev discovery 13 km northwest of Yoda. The primary objective of the well was to prove commercial hydrocarbons in the Late Jurassic Ula Formation sandstones. The secondary objective was to test the Triassic prospectivity.
    Operations and results
    Well was spudded with the jack-up installation Mærsk Giant on 20 March 2008 and drilled to TD at 3175 m in the Middle Jurassic Bryne Formation. It was drilled slightly deviated in an S-shaped track, vertical down to ca 1600 m and below ca 2400 m with maximum deviation of 16 deg from vertical at 1893 m. Whilst drilling the 17 1/2" section from 592 to 1320 m the hole produced significant amounts of large, blocky cavings, but there were no real problems encountered during operations. The well was drilled with seawater down to 201 m, with Aquadril glycol/KCl mud from 201 to 1320 m, and with Carbo-Sea oil based mud from 1320 m to TD.
    The Mandal Formation was encountered at 2848 m and was 71 m thick with very high gamma ray responses varying between 150 and 300 API. The top of the reservoir, Ula Formation, was encountered at 2945 m, 16 m shallower than prognosed, and 14 m thicker than prognosed. No shows were observed in cuttings and gas and the resistivity remained low throughout the Ula Formation indicating a water wet reservoir. The rock below the Ula Formation reservoir was prognosed to be the Triassic Skagerrak Formation. However, it turned out to be the Middle Jurassic Bryne Formation. As a result the well was TD?ed in the Bryne Formation and not as planned in the Skagerrak Formation. This was first discovered after receiving the post well biostratigraphy results.
    No cores were cut and no wire line pressure or fluid samples were taken.
    The well was permanently abandoned on 8 May 2008 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]
    210.00
    3175.00

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    610.0
    [m]
    DC
    APT
    810.0
    [m]
    DC
    APT
    910.0
    [m]
    DC
    APT
    1020.0
    [m]
    DC
    APT
    1110.0
    [m]
    DC
    APT
    1160.0
    [m]
    DC
    APT
    1180.0
    [m]
    DC
    APT
    1200.0
    [m]
    DC
    APT
    1220.0
    [m]
    DC
    APT
    1240.0
    [m]
    DC
    APT
    1260.0
    [m]
    DC
    APT
    1280.0
    [m]
    DC
    APT
    1300.0
    [m]
    DC
    APT
    1320.0
    [m]
    DC
    APT
    1340.0
    [m]
    DC
    APT
    1360.0
    [m]
    DC
    APT
    1380.0
    [m]
    DC
    APT
    1400.0
    [m]
    DC
    APT
    1420.0
    [m]
    DC
    APT
    1440.0
    [m]
    DC
    APT
    1460.0
    [m]
    DC
    APT
    1480.0
    [m]
    DC
    APT
    1500.0
    [m]
    DC
    APT
    1520.0
    [m]
    DC
    APT
    1540.0
    [m]
    DC
    APT
    1560.0
    [m]
    DC
    APT
    1580.0
    [m]
    DC
    APT
    1600.0
    [m]
    DC
    APT
    1620.0
    [m]
    DC
    APT
    1640.0
    [m]
    DC
    APT
    1660.0
    [m]
    DC
    APT
    1680.0
    [m]
    DC
    APT
    1700.0
    [m]
    DC
    APT
    1720.0
    [m]
    DC
    APT
    1740.0
    [m]
    DC
    APT
    1760.0
    [m]
    DC
    APT
    1780.0
    [m]
    DC
    APT
    1820.0
    [m]
    DC
    APT
    1840.0
    [m]
    DC
    APT
    1860.0
    [m]
    DC
    APT
    1880.0
    [m]
    DC
    APT
    1900.0
    [m]
    DC
    APT
    1920.0
    [m]
    DC
    APT
    1940.0
    [m]
    DC
    APT
    1960.0
    [m]
    DC
    APT
    1980.0
    [m]
    DC
    APT
    2000.0
    [m]
    DC
    APT
    2020.0
    [m]
    DC
    APT
    2040.0
    [m]
    DC
    APT
    2060.0
    [m]
    DC
    APT
    2080.0
    [m]
    DC
    APT
    2100.0
    [m]
    DC
    APT
    2120.0
    [m]
    DC
    APT
    2140.0
    [m]
    DC
    APT
    2160.0
    [m]
    DC
    APT
    2180.0
    [m]
    DC
    APT
    2200.0
    [m]
    DC
    APT
    2220.0
    [m]
    DC
    APT
    2240.0
    [m]
    DC
    APT
    2260.0
    [m]
    DC
    APT
    2280.0
    [m]
    DC
    APT
    2300.0
    [m]
    DC
    APT
    2320.0
    [m]
    DC
    APT
    2340.0
    [m]
    DC
    APT
    2360.0
    [m]
    DC
    APT
    2380.0
    [m]
    DC
    APT
    2420.0
    [m]
    DC
    APT
    2440.0
    [m]
    DC
    APT
    2460.0
    [m]
    DC
    APT
    2840.0
    [m]
    DC
    APT
    2850.0
    [m]
    DC
    APT
    2860.0
    [m]
    DC
    APT
    2870.0
    [m]
    DC
    APT
    2880.0
    [m]
    DC
    APT
    2890.0
    [m]
    DC
    APT
    2900.0
    [m]
    DC
    APT
    2910.0
    [m]
    DC
    APT
    2920.0
    [m]
    DC
    APT
    2930.0
    [m]
    DC
    APT
    2937.0
    [m]
    DC
    APT
    2949.0
    [m]
    DC
    APT
    2955.0
    [m]
    DC
    APT
    3126.0
    [m]
    DC
    APT
    3132.0
    [m]
    DC
    APT
    3138.0
    [m]
    DC
    APT
    3144.0
    [m]
    DC
    APT
    3150.0
    [m]
    DC
    APT
    3156.0
    [m]
    DC
    APT
    3162.0
    [m]
    DC
    APT
    3168.0
    [m]
    DC
    APT
    3175.0
    [m]
    DC
    APT

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    HDIL XMAC DSL GR
    2400
    3172
    MWD - DIR
    130
    201
    MWD - DIR GR RES PWD
    201
    3173
    ZDL CN GR
    2870
    3172
    ZDL CN GR
    2870
    3172

  • 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
    198.0
    36
    201.0
    0.00
    LOT
    SURF.COND.
    20
    583.0
    26
    592.0
    1.85
    LOT
    INTERM.
    13 3/8
    1313.0
    17 1/2
    1320.0
    1.80
    LOT
    INTERM.
    9 5/8
    2931.0
    12 1/4
    2937.0
    2.12
    LOT
    OPEN HOLE
    3175.0
    8 1/2
    3175.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    205
    1.03
    Water Based
    206
    1.30
    13.0
    Water Based
    224
    1.30
    13.0
    Water Based
    440
    1.09
    10.0
    Water Based
    592
    1.25
    20.0
    Water Based
    1038
    1.39
    19.0
    Water Based
    1320
    1.39
    18.0
    Water Based