Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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9/2-5

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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.
    9/2-5
    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).
    APPRAISAL
    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.
    RE-CLASS TO DEV
    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
    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.
    9/2-5
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 9413- INLINE 760 & CROSSLINE 655
    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.
    Den norske stats oljeselskap a.s
    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.
    816-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.
    29
    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,
    23.06.1995
    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.
    21.07.1995
    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.
    21.07.1997
    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.
    24.09.2002
    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
    Reclassified to wellbore
    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.
    NO
    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.
    MIDDLE 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.
    SANDNES 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.
    MIDDLE JURASSIC
    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.
    BRYNE FM
    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.
    77.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3355.0
    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).
    3354.6
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    118
    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° 45' 15.3'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    4° 21' 21.16'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6402303.16
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    580693.95
    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.
    2599

  • Wellbore history
    General
    The objective for the well 9/2-5 was to appraise the extension of the oil-bearing sequence in the Beta East structure on the Yme field.
    Operations and results
    Appraisal well 9/2-5 was spudded with the semi-submersible installation "DeepSea Bergen" on 23 June 1995 and drilled to a total depth of 3355 m in the Middle Jurassic Bryne Formation. The well was drilled with very small target tolerances, hence a directional assembly with motor was utilized in order to steer. The well had a final inclination of 2.1° and hit target according to tolerances. The well was drilled 13 days faster than planned; especially the drilling operations went faster than expected. The well was planned and drilled without the use of 20" casing, which gave substantial time saving. The well was drilled with seawater and hi-vis pills down to 1750 m and KCl mud with glycol from 1750 m to TD. The Sandnes and the Bryne Formations were penetrated slightly deeper than prognosed. Both proved better reservoir quality than expected based on information from the well 9/2-3. FMT sampling proved that the Beta East structure has the same oil gradient and water gradient as the Gamma structure. The oil/water contact was recorded at 3270 m TVD (3247 m TVD MSL). Two cores were cut in the interval 3154 to 3193 m in the Sandnes Formation. Several FMT runs were initiated to obtain representative formation fluid samples from the Sandnes Formation. The content of the first segregated sample, Run 2A, confirmed considerable invasion of mud filtrate and made it necessary to increase the volume of the pre-flush chamber. This change in tool configuration led to several misruns due to operational tool failures. Finally, in Run 2F, indications of a successful segregated sample were obtained and the 4-liter PVT chamber was transferred to standard PVT bottles for onshore PVT analysis. One more attempt, Run 2G, was performed
    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]
    1590.00
    3355.00

  • 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
    3154.0
    3163.6
    [m ]
    2
    3164.5
    3192.9
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    38.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3154-3159m
    Core photo at depth: 3159-3163m
    Core photo at depth: 3164-3169m
    Core photo at depth: 3169-3174m
    Core photo at depth: 3174-3179m
    3154-3159m
    3159-3163m
    3164-3169m
    3169-3174m
    3174-3179m
    Core photo at depth: 3179-3184m
    Core photo at depth: 3184-3189m
    Core photo at depth: 3189-3193m
    Core photo at depth:  
    Core photo at depth:  
    3179-3184m
    3184-3189m
    3189-3193m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2990.0
    [m]
    DC
    GEOSTR
    3006.0
    [m]
    DC
    GEOSTR
    3018.0
    [m]
    DC
    GEOSTR
    3030.0
    [m]
    DC
    GEOSTR
    3042.0
    [m]
    DC
    GEOSTR
    3054.0
    [m]
    DC
    GEOSTR
    3066.0
    [m]
    DC
    GEOSTR
    3078.0
    [m]
    DC
    GEOSTR
    3080.0
    [m]
    DC
    GEOSTR
    3090.0
    [m]
    DC
    GEOSTR
    3100.0
    [m]
    DC
    GEOSTR
    3102.0
    [m]
    DC
    GEOSTR
    3110.0
    [m]
    DC
    GEOSTR
    3114.0
    [m]
    DC
    GEOSTR
    3125.3
    [m]
    DC
    GEOSTR
    3138.0
    [m]
    DC
    GEOSTR
    3144.0
    [m]
    DC
    GEOSTR
    3150.0
    [m]
    DC
    GEOSTR
    3154.0
    [m]
    DC
    GEOSTR
    3156.0
    [m]
    DC
    GEOSTR
    3158.5
    [m]
    C
    GEOSTR
    3159.0
    [m]
    DC
    GEOSTR
    3167.8
    [m]
    C
    GEOSTR
    3171.5
    [m]
    C
    GEOSTR
    3172.9
    [m]
    C
    GEOSTR
    3173.2
    [m]
    C
    GEOSTR
    3181.9
    [m]
    C
    GEOSTR
    3183.5
    [m]
    C
    GEOSTR
    3184.7
    [m]
    C
    GEOSTR
    3191.4
    [m]
    C
    GEOSTR
    3195.0
    [m]
    DC
    GEOSTR
    3201.0
    [m]
    DC
    GEOSTR
    3207.0
    [m]
    DC
    GEOSTR
    3213.0
    [m]
    DC
    GEOSTR
    3222.0
    [m]
    DC
    GEOSTR
    3228.0
    [m]
    DC
    GEOSTR
    3234.0
    [m]
    DC
    GEOSTR
    3240.0
    [m]
    DC
    GEOSTR
    3246.0
    [m]
    DC
    GEOSTR
    3252.0
    [m]
    DC
    GEOSTR
    3261.0
    [m]
    DC
    GEOSTR
    3267.0
    [m]
    DC
    GEOSTR
    3273.0
    [m]
    DC
    GEOSTR
    3279.0
    [m]
    DC
    GEOSTR
    3285.0
    [m]
    DC
    GEOSTR
    3291.0
    [m]
    DC
    GEOSTR
    3297.0
    [m]
    DC
    GEOSTR
    3303.0
    [m]
    DC
    GEOSTR
    3309.0
    [m]
    DC
    GEOSTR
    3315.0
    [m]
    DC
    GEOSTR
    3321.0
    [m]
    DC
    GEOSTR
    3327.0
    [m]
    DC
    GEOSTR
    3333.0
    [m]
    DC
    GEOSTR
    3339.0
    [m]
    DC
    GEOSTR
    3345.0
    [m]
    DC
    GEOSTR
    3351.0
    [m]
    DC
    GEOSTR
    3355.0
    [m]
    DC
    GEOSTR

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.36

  • 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
    8.03

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DIFL ACL GR
    1572
    3124
    DIFL ACL ZDL CN GR
    3095
    3354
    DIPLOG GR
    2400
    3115
    DLL MLL DSL
    3312
    2253
    DPR
    3125
    3355
    DPR TF4-5A
    144
    3125
    FMT CHT OD GR
    3152
    3322
    ZOVSP
    500
    3105

  • 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
    SURF.COND.
    30
    159.0
    36
    160.0
    0.00
    LOT
    CONDUCTOR
    13 3/8
    1572.0
    17 1/2
    1573.0
    1.81
    LOT
    INTERM.
    9 5/8
    3115.0
    12 1/4
    3117.0
    1.80
    LOT
    LINER
    7
    3355.0
    8 1/2
    3355.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    240
    1.03
    WATER BASED
    26.06.1995
    1218
    1.03
    26.0
    26.0
    WATER BASED
    26.06.1995
    1586
    1.40
    19.0
    21.5
    WATER BASED
    28.06.1995
    1586
    1.03
    18.0
    39.0
    WATER BASED
    29.06.1995
    1660
    1.04
    18.0
    39.0
    WATER BASED
    30.06.1995
    1825
    1.45
    27.0
    15.5
    WATER BASED
    03.07.1995
    2230
    1.42
    26.0
    17.5
    WATER BASED
    03.07.1995
    2710
    1.50
    32.0
    15.5
    WATER BASED
    04.07.1995
    2819
    1.42
    25.0
    16.0
    WATER BASED
    03.07.1995
    2975
    1.50
    32.0
    15.5
    WATER BASED
    04.07.1995
    3115
    1.40
    25.0
    16.5
    WATER BASED
    17.07.1995
    3115
    1.40
    24.0
    18.0
    WATER BASED
    18.07.1995
    3115
    1.40
    25.0
    17.0
    WATER BASED
    12.07.1995
    3125
    1.40
    20.0
    16.0
    WATER BASED
    11.07.1995
    3154
    1.40
    20.0
    16.0
    WATER BASED
    11.07.1995
    3166
    1.40
    25.0
    17.0
    WATER BASED
    11.07.1995
    3234
    1.40
    25.0
    17.0
    WATER BASED
    12.07.1995
    3284
    1.40
    23.0
    15.5
    WATER BASED
    14.07.1995
    3329
    1.40
    23.0
    17.0
    WATER BASED
    14.07.1995
    3355
    1.40
    25.0
    16.5
    WATER BASED
    17.07.1995

  • 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
    0.22