Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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15/12-1

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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.
    15/12-1
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    15/12-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LINE 511 138- 1975 SP.100
    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.
    132-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.
    62
    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,
    07.07.1975
    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.
    06.09.1975
    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.
    06.09.1977
    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.
    24.09.2004
    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 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.
    24.4
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    95.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3269.0
    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).
    3269.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    113
    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.
    LATE 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.
    58° 10' 32.6'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 44' 23.1'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6449113.79
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    425871.87
    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.
    94

  • Wellbore history
    General
    Well 15/12-1 was drilled in order to evaluate the Paleocene and Jurassic formations on a closed structure 5 km northeast of the Maureen Field which is located just across the UK-Norwegian median line in UK territory. The principle objectives of the 15/12-1 test were the Paleocene and Dogger (Hugin Formation) sandstones where oil accumulations had been proven in the Maureen field 5 km to the southwest on British sector.
    The well is Reference Well for the Sleipner Formation.
    Operations and results
    Wildcat well 15/12-1 was spudded with the semi-submersible installation Ross Rig on 7 July 1975 and drilled to a total depth of 3269 m in Triassic fine-grained sandstone with green and red-brown shale of the Skagerrak Formation. The well was drilled with a lignosulphonate type of mud.
    The Paleocene sandstone at 2633 m to 2643 m in 15/12-1 was encountered 6 m lower than in the Maureen no. 2 well. The sandstone is medium to coarse grained with good porosity (26%), but water wet. The Hugin sandstone was encountered some 50 m higher than in the Maureen no. 2 well. Oil shows were encountered on the cores from the Hugin Formation, but log analysis and FIT proved the sandstone to be water bearing. The logs also indicated shows of hydrocarbon in the Late Cretaceous limestone at 2925 - 2955 m, but log porosity was calculated from 0 to 6%, too tight to obtain a sample. The Late Triassic has good sand development that could be adequate for accumulation of hydrocarbons. During the drilling of the Triassic section, the background gas in mud and cuttings was near zero.
    Eight cores were cut in the well. Paleocene sands (Lista and Maureen Formations) were cored from 2612.1 m to 2651.1 m. One core was cut in the Heather Formation from 3067 m to 3073.3 m; one core was cut from the Hugin Formation into the Sleipner Formation from 3125.7 m to 3143.7 m. The Sleipner Formation was further cored in three cores down to 3183 m. On the basis of log analysis, two points for FIT tests were picked: one point at 3142.5 m (Ï = 23%, SW = 66%) and one point at 3126.5 m (Ï = 11.2%, SW = 31%). Test l at 3142.5 m produced 0.3 litres mud and 9.9 l water with a light skim of oil. The oil skim probably came from the FIT tools hydraulics. Based on the chloride content the water in the sample probably contained a large proportion of mud filtrate. The other sample was a failure due to tight formation. The well was permanently abandoned as a dry well with shows on 6 September 1975.
    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]
    154.53
    3267.46

  • 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
    8570.0
    8578.0
    [ft ]
    2
    8579.0
    8611.0
    [ft ]
    3
    8642.0
    8698.0
    [ft ]
    4
    10063.0
    10083.0
    [ft ]
    5
    10255.0
    10314.0
    [ft ]
    6
    10314.0
    10341.0
    [ft ]
    7
    10350.0
    10409.0
    [ft ]
    8
    10409.0
    10438.0
    [ft ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    88.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2990.0
    [ft]
    DC
    3080.0
    [ft]
    DC
    3170.0
    [ft]
    DC
    3250.0
    [ft]
    DC
    3340.0
    [ft]
    DC
    3430.0
    [ft]
    DC
    3530.0
    [ft]
    DC
    3620.0
    [ft]
    DC
    3710.0
    [ft]
    DC
    3800.0
    [ft]
    DC
    3890.0
    [ft]
    DC
    3980.0
    [ft]
    DC
    4070.0
    [ft]
    DC
    4160.0
    [ft]
    DC
    4250.0
    [ft]
    DC
    4340.0
    [ft]
    DC
    4430.0
    [ft]
    DC
    4520.0
    [ft]
    DC
    4610.0
    [ft]
    DC
    4700.0
    [ft]
    DC
    4790.0
    [ft]
    DC
    4880.0
    [ft]
    DC
    4970.0
    [ft]
    DC
    5060.0
    [ft]
    DC
    5150.0
    [ft]
    DC
    5240.0
    [ft]
    DC
    5330.0
    [ft]
    DC
    5420.0
    [ft]
    DC
    5510.0
    [ft]
    DC
    5600.0
    [ft]
    DC
    5690.0
    [ft]
    DC
    5780.0
    [ft]
    DC
    5840.0
    [ft]
    DC
    RRI
    5870.0
    [ft]
    DC
    5900.0
    [ft]
    DC
    RRI
    5960.0
    [ft]
    DC
    RRI
    5960.0
    [ft]
    DC
    6020.0
    [ft]
    DC
    RRI
    6050.0
    [ft]
    DC
    6080.0
    [ft]
    DC
    RRI
    6140.0
    [ft]
    DC
    RRI
    6140.0
    [ft]
    DC
    6200.0
    [ft]
    DC
    RRI
    6230.0
    [ft]
    DC
    6260.0
    [ft]
    DC
    RRI
    6320.0
    [ft]
    DC
    6330.0
    [ft]
    DC
    RRI
    6380.0
    [ft]
    DC
    RRI
    6410.0
    [ft]
    DC
    6440.0
    [ft]
    DC
    RRI
    6500.0
    [ft]
    DC
    RRI
    6500.0
    [ft]
    DC
    6560.0
    [ft]
    DC
    RRI
    6590.0
    [ft]
    DC
    6620.0
    [ft]
    DC
    RRI
    6680.0
    [ft]
    DC
    RRI
    6680.0
    [ft]
    DC
    6740.0
    [ft]
    DC
    RRI
    6770.0
    [ft]
    DC
    6800.0
    [ft]
    DC
    RRI
    6860.0
    [ft]
    DC
    RRI
    6860.0
    [ft]
    DC
    6920.0
    [ft]
    DC
    RRI
    6950.0
    [ft]
    DC
    6980.0
    [ft]
    DC
    RRI
    7040.0
    [ft]
    DC
    RRI
    7040.0
    [ft]
    DC
    7070.0
    [ft]
    DC
    RRI
    7160.0
    [ft]
    DC
    RRI
    7160.0
    [ft]
    DC
    7220.0
    [ft]
    DC
    RRI
    7250.0
    [ft]
    DC
    7280.0
    [ft]
    DC
    RRI
    7340.0
    [ft]
    DC
    RRI
    7340.0
    [ft]
    DC
    7400.0
    [ft]
    DC
    RRI
    7430.0
    [ft]
    DC
    7460.0
    [ft]
    DC
    RRI
    7520.0
    [ft]
    DC
    RRI
    7530.0
    [ft]
    DC
    7580.0
    [ft]
    DC
    RRI
    7640.0
    [ft]
    DC
    RRI
    7640.0
    [ft]
    DC
    7670.0
    [ft]
    DC
    7700.0
    [ft]
    DC
    RRI
    7760.0
    [ft]
    DC
    RRI
    7760.0
    [ft]
    DC
    7790.0
    [ft]
    DC
    7820.0
    [ft]
    DC
    RRI
    7820.0
    [ft]
    DC
    7850.0
    [ft]
    DC
    7880.0
    [ft]
    DC
    RRI
    7880.0
    [ft]
    DC
    7910.0
    [ft]
    DC
    7940.0
    [ft]
    DC
    RRI
    7940.0
    [ft]
    DC
    8000.0
    [ft]
    DC
    8100.0
    [ft]
    DC
    8190.0
    [ft]
    DC
    8200.0
    [ft]
    DC
    8300.0
    [ft]
    DC
    8320.0
    [ft]
    DC
    8350.0
    [ft]
    DC
    8380.0
    [ft]
    DC
    8400.0
    [ft]
    DC
    8410.0
    [ft]
    DC
    8420.0
    [ft]
    DC
    8440.0
    [ft]
    DC
    8460.0
    [ft]
    DC
    8490.0
    [ft]
    DC
    8520.0
    [ft]
    DC
    8540.0
    [ft]
    DC
    8560.0
    [ft]
    DC
    8576.0
    [ft]
    DC
    8586.0
    [ft]
    DC
    8603.0
    [ft]
    DC
    8660.0
    [ft]
    DC
    8674.0
    [ft]
    DC
    8697.0
    [ft]
    DC
    8790.0
    [ft]
    DC
    8890.0
    [ft]
    DC
    9000.0
    [ft]
    DC
    9100.0
    [ft]
    DC
    9200.0
    [ft]
    DC
    9340.0
    [ft]
    DC
    9360.0
    [ft]
    DC
    9410.0
    [ft]
    DC
    9450.0
    [ft]
    DC
    9490.0
    [ft]
    DC
    9540.0
    [ft]
    DC
    9595.0
    [ft]
    SWC
    9700.0
    [ft]
    DC
    9706.0
    [ft]
    SWC
    9800.0
    [ft]
    DC
    9830.0
    [ft]
    DC
    9850.0
    [ft]
    DC
    9900.0
    [ft]
    DC
    9930.0
    [ft]
    DC
    9950.0
    [ft]
    DC
    9970.0
    [ft]
    DC
    10050.0
    [ft]
    DC
    10063.0
    [ft]
    DC
    10073.0
    [ft]
    DC
    10083.0
    [ft]
    DC
    10100.0
    [ft]
    DC
    10150.0
    [ft]
    DC
    10200.0
    [ft]
    DC
    10250.0
    [ft]
    DC
    10264.0
    [ft]
    DC
    10327.0
    [ft]
    DC
    10331.0
    [ft]
    DC
    10350.0
    [ft]
    C
    10359.0
    [ft]
    C
    10389.0
    [ft]
    C
    10398.0
    [ft]
    C
    10410.0
    [ft]
    DC
    10418.0
    [ft]
    DC
    10426.0
    [ft]
    C
    10437.0
    [ft]
    C
    10710.0
    [ft]
    DC

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.40

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.69

  • 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
    22.22

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BHC GR C
    117
    3269
    CNL FDC GR
    2100
    3269
    DIPMETER
    2150
    3269
    DLL
    2871
    3262
    IES
    399
    3269
    TEMP
    1119
    2845
    VSP
    548
    3266

  • 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
    155.0
    36
    155.0
    0.00
    LOT
    SURF.COND.
    20
    399.0
    26
    413.0
    0.00
    LOT
    INTERM.
    13 3/8
    1533.0
    17 1/2
    1538.0
    0.00
    LOT
    INTERM.
    9 5/8
    2872.0
    12 1/4
    2874.0
    0.00
    LOT
    OPEN HOLE
    3269.0
    8 1/2
    3269.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    399
    1.02
    seawater
    2499
    1.23
    seawater
    3018
    1.37
    seawater
    3048
    1.43
    seawater
    3142
    1.36
    seawater

  • 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