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

30/6-14

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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.
    30/6-14
    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
    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
    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.
    30/6-14
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 8006 - 402 SP 202
    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.
    Norsk Hydro Produksjon 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.
    398-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.
    54
    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,
    17.12.1983
    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.
    08.02.1984
    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.
    08.02.1986
    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.
    29.03.2014
    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.
    EARLY 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.
    STATFJORD GP
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    148.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2900.0
    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).
    2900.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    114
    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.
    EARLY 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.
    STATFJORD GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 38' 7.69'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 59' 21.76'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6722344.00
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    499418.89
    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.
    53

  • Wellbore history
    General
    Well 30/6-14 was drilled on the Zeta structure on the Brage Horst, east of the main Oseberg Alpha structure and south of the Oseberg Beta structure. The primary objectives for the well were to find hydrocarbons in the Brent Group, and to find additional hydrocarbon accumulations within possible Early and Late Jurassic sandstone deposits. Planned TD of the well was ca 3100 m or 75 m into the Statfjord Formation.
    Operations and results
    Wildcat well 30/6-14 was spudded with the semi-submersible installation Treasure Scout on 17 December 1983 and drilled to TD at 2900 m in the Early Jurassic Statfjord Group. No significant problems occurred in the operations. The well was drilled using water based mud. The well was drilled with spud mud down to 618 m, with KCl/polymer mud from 618 m to 1675 m,
    Top Brent Group was penetrated at 2650 m and top Drake Formation at 2589 with an Intra Drake Sand at 2605 to 2621 m. Both Brent and Drake were found water bearing. Hydrocarbons were encountered in the top of the Early Jurassic Statfjord Group from 2783.5 m down to a depth of 2789 m. RFT pressures indicated the free water level to be at 2790 m. No additional hydrocarbon bearing reservoirs were encountered. Apart from spots of cut fluorescence on claystones in the Drake Formation no oil shows were recorded outside of the Statfjord Group hydrocarbon bearing reservoir.
    Three cores were cut in the Jurassic sequence, one from 2561 to 2567.6 m in the Etive Formation, one from 2608 to 2621.2 m in the Drake Formation, and one from 2785 to 2800 m in the upper part of the Statfjord Group. No wire line fluid samples were taken.
    The well was permanently abandoned on 8 February 1984 as an oil discovery.
    Testing
    Two DST's were performed in the oil zone in the Statfjord Formation.
    DST no 1 (2783 - 2787 m) produced no formation fluid to the surface, but 12.7 m3 /day of diesel cushion was produced through a 128/64" choke. Oil samples were recovered when reversing out the test tubing content. The oil gravity was 36 deg API. The bottom hole temperature was 103.3 deg C.
    DST no 1A was a re-perforation of the same interval as in DST no 1, with one additional meter (2783 - 2788 m). The purpose was to improve the poor results from DST no 1. Again only small amounts of oil were produced: 19.8 m3 diesel cushion /day through a 128/64" choke. No crude oil was produced to surface. Oil samples from reversing out the test tubing had a gravity of 38 deg API. The bottom hole temperature was 110 deg C.

  • 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]
    270.00
    2900.00

  • 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
    2566.1
    2567.6
    [m ]
    2
    2608.0
    2621.2
    [m ]
    3
    2785.0
    2798.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    28.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2561-2567m
    Core photo at depth: 2567-2612m
    Core photo at depth: 2612-2617m
    Core photo at depth: 2617-2621m
    Core photo at depth: 2785-2789m
    2561-2567m
    2567-2612m
    2612-2617m
    2617-2621m
    2785-2789m
    Core photo at depth: 2789-2794m
    Core photo at depth: 2794-2798m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2789-2794m
    2794-2798m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2265.0
    [m]
    DC
    PETROSTR
    2270.0
    [m]
    DC
    PETROS
    2275.0
    [m]
    DC
    PETROS
    2280.0
    [m]
    DC
    PETROS
    2285.0
    [m]
    DC
    PETROS
    2290.0
    [m]
    DC
    PETROS
    2295.0
    [m]
    DC
    PETROS
    2300.0
    [m]
    DC
    PETROS
    2305.0
    [m]
    DC
    PETROS
    2310.0
    [m]
    DC
    PETROS
    2315.0
    [m]
    DC
    PETROS
    2320.0
    [m]
    DC
    PETROS
    2325.0
    [m]
    DC
    PETROS
    2330.0
    [m]
    DC
    PETROS
    2335.0
    [m]
    DC
    PETROS
    2340.0
    [m]
    DC
    PETROS
    2345.0
    [m]
    DC
    PETROS
    2350.0
    [m]
    DC
    PETROS
    2355.0
    [m]
    DC
    PETROS
    2360.0
    [m]
    DC
    PETROS
    2365.0
    [m]
    DC
    PETROS
    2370.0
    [m]
    DC
    PETROS
    2375.0
    [m]
    DC
    PETROS
    2380.0
    [m]
    DC
    PETROS
    2385.0
    [m]
    DC
    PETROS
    2395.0
    [m]
    DC
    PETROS
    2405.0
    [m]
    DC
    PETROS
    2415.0
    [m]
    DC
    PETROS

  • 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
    DST1A
    2783.00
    2788.00
    29.01.1984 - 00:00
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.27
    pdf
    0.55

  • 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
    1.96
    pdf
    9.59

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2783
    2787
    50.8
    1.1
    2783
    2788
    50.8
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    1.1
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    1.0
    13
    0.845
    1.1
    20
    0.835

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    295
    1640
    CBL VDL
    1295
    2824
    CST
    2429
    2075
    CST
    2905
    2440
    DLL MSFL CAL GR
    2600
    2900
    ISF SON
    601
    1647
    ISF SON
    618
    258
    ISF SON
    1649
    2905
    LDT
    601
    1648
    LDT CNL
    1649
    2905
    NGT
    2225
    2905
    RFT
    2421
    2851
    SHDT
    1800
    2903
    VELOCITY
    354
    2905

  • 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
    258.0
    36
    260.0
    0.00
    LOT
    SURF.COND.
    20
    601.0
    26
    618.0
    1.79
    LOT
    INTERM.
    13 3/8
    1648.0
    17 1/2
    1675.0
    1.74
    LOT
    INTERM.
    9 5/8
    2885.0
    12 1/4
    2900.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    495
    1.10
    53.0
    WATER BASED
    1365
    1.12
    50.0
    WATER BASED
    1650
    1.13
    45.0
    WATER BASED
    1710
    1.25
    45.0
    WATER BASED
    2195
    1.24
    45.0
    WATER BASED
    2280
    1.25
    54.0
    WATER BASED
    2360
    1.24
    50.0
    WATER BASED

  • 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
    0.24