Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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15.04.2026 - 00:57
Time of last synchronization with Norwegian Offshore Directorate's internal systems

15/3-12 A

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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.
    15/3-12 A
    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 top-hole drilling campaign covering several wellbores.
    RE-CLASS TO DEV: Exploration wellbore that is reclassified to a development wellbore and given a new name.
    RE-CLASS TO TEST: Exploration wellbore that is reclassified to test production and given a new name.
    SUSPENDED: The drilling operation in the wellbore has been temporarily stopped. The current plan is to continue drilling later on.
    WILL NEVER BE DRILLED: Wellbore registered with a name and WellID by the Norwegian Offshore Directorate, but which for various reasons will not be drilled.
    ONLINE/OPERATIONAL: The wellbore is ongoing, but not completed, may be operations such as drilling, batch-drilling, logging, testing, plugging, preparation for production/injection or temporarily stopped in connection with the operations.
    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.
    15/3-12
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    PGS16M04-PGS16910VIK
    Drilling operator
    Name of the licensee starting the drilling operation on behalf of the active production license. This is usually the operator of the production license.
    Equinor Energy 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.
    1798-L
    Production licence at wellhead
    Official designation of the production licence the wellbore was drilled or planned to be drilled from (wellhead posistion).
    Prod. licence for drilling target
    The active production licence of the planned drilling target of the wellbore. This can differ from the production licence the wellbore was drilled from.
    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.
    43
    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.
    21.01.2020
    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.
    03.03.2020
    Plugged and abondon date
    Date when the P&A-operations of the wellbore was finished, as reported by the operator to the Norwegian Offshore Directorate throught DDRS (Daily Drilling Reporting System). Only applied once pr. wellhead/surface location.
    03.03.2020
    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.
    03.03.2022
    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.
    08.08.2022
    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.
    38.6
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    109.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4037.0
    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).
    3833.0
    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.
    58° 46' 53.25'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 54' 13.44'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6516386.03
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    436616.94
    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.
    8948
    Legend +

  • Wellbore history
    General
    Well 15/3-12 A is a geological side-track to well 15/3-12 S, which discovered oil in the Sigrun East Hugin prospect on the Gudrun Terrace in the North Sea. Side-track 15/3-12 A was drilled to the Sigrun East Draupne prospect located west of the primary well and south of the Sigrun Field. The primary objective of 15/3-12 A was to verify down-flank continuation of the Hugin Formation reservoir and find the related hydrocarbon contacts. The secondary objective was to verify presence of Intra-Draupne Formation reservoir and hydrocarbons in same.
    Operations and results
    Wildcat well 15/3-12 A was kicked off on 19 January 2020 from the main well at 2100 m in Lower Hordaland Group. It was drilled with the semi-submersible installation West Phoenix to 3593 m (3428 m TVD) in the Cromer Knoll Group. While POOH with 12 ¼” drilling BHA, the drill string got stuck at 2756 m in Ty sand. The BHA could not be freed and a technical side-track 15/3-12 A T2 was initiated with kick-off at 2215 m. Large amounts of caved cuttings was produced during kick-off. Drilling proceeded to final TD at 4038 m (3834 m TVD) in the Middle Jurassic Sleipner Formation. Both 15/3-12 A and 15/3-12 A T2 were drilled using Exploradrill oil-based mud from kick-off to TD.
    The Hugin reservoir was water filled and only cemented sand stringers were penetrated in the Draupne Formation. No oil shows were described in the well. Combined pressure data from the 15/12-3 S and 15/12-3 A T2 well indicated the following hydrocarbon contacts in the Hugin Formation: Free Water Level at 3614.6 m TVD in the upper reservoir unit, OWC at 3570 m TVD in the middle unit, and Free Water Level at 3605.4 m TVD in the lower unit. The contacts are based on pressure data and oil sample densities and are not penetrated by the wellbores.
    No cores were cut. MDT water samples were taken at 3898 m in the Hugin Formation in the 15/3-12 A T2 side-track
    The well was permanently abandoned on 2 March 2020 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]
    2120.00
    3593.00

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3612.0
    [m]
    DC
    PETROSTR
    3621.0
    [m]
    DC
    PETROSTR
    3630.0
    [m]
    DC
    PETROSTR
    3639.0
    [m]
    DC
    PETROSTR
    3648.0
    [m]
    DC
    PETROSTR
    3657.0
    [m]
    DC
    PETROSTR
    3657.0
    [m]
    DC
    PETROSTR
    3666.0
    [m]
    DC
    PETROSTR
    3684.0
    [m]
    DC
    PETROSTR
    3690.0
    [m]
    DC
    PETROSTR
    3696.0
    [m]
    DC
    PETROSTR
    3702.0
    [m]
    DC
    PETROSTR
    3708.0
    [m]
    DC
    PETROSTR
    3714.0
    [m]
    DC
    PETROSTR
    3720.0
    [m]
    DC
    PETROSTR
    3726.0
    [m]
    DC
    PETROSTR
    3732.0
    [m]
    DC
    PETROSTR
    3738.0
    [m]
    DC
    PETROSTR
    3744.0
    [m]
    DC
    PETROSTR
    3750.0
    [m]
    DC
    PETROSTR
    3756.0
    [m]
    DC
    PETROSTR
    3762.0
    [m]
    DC
    PETROSTR
    3768.0
    [m]
    DC
    PETROSTR
    3774.0
    [m]
    DC
    PETROSTR
    3783.0
    [m]
    DC
    PETROSTR
    3792.0
    [m]
    DC
    PETROSTR
    3801.0
    [m]
    DC
    PETROSTR
    3810.0
    [m]
    DC
    PETROSTR
    3819.0
    [m]
    DC
    PETROSTR
    3828.0
    [m]
    DC
    PETROSTR
    3837.0
    [m]
    DC
    PETROSTR
    3846.0
    [m]
    DC
    PETROSTR
    3855.0
    [m]
    DC
    PETROSTR
    3864.0
    [m]
    DC
    PETROSTR
    3873.0
    [m]
    DC
    PETROSTR
    3882.0
    [m]
    DC
    PETROSTR
    3888.0
    [m]
    DC
    PETROSTR
    3894.0
    [m]
    DC
    PETROSTR
    3900.0
    [m]
    DC
    PETROSTR
    3906.0
    [m]
    DC
    PETROSTR
    3912.0
    [m]
    DC
    PETROSTR
    3918.0
    [m]
    DC
    PETROSTR
    3924.0
    [m]
    DC
    PETROSTR
    3930.0
    [m]
    DC
    PETROSTR
    3936.0
    [m]
    DC
    PETROSTR
    3942.0
    [m]
    DC
    PETROSTR
    3948.0
    [m]
    DC
    PETROSTR
    3954.0
    [m]
    DC
    PETROSTR
    3960.0
    [m]
    DC
    PETROSTR
    3966.0
    [m]
    DC
    PETROSTR
    3972.0
    [m]
    DC
    PETROSTR
    3978.0
    [m]
    DC
    PETROSTR
    3984.0
    [m]
    DC
    PETROSTR
    3990.0
    [m]
    DC
    PETROSTR
    3996.0
    [m]
    DC
    PETROSTR
    4002.0
    [m]
    DC
    PETROSTR
    4008.0
    [m]
    DC
    PETROSTR
    4014.0
    [m]
    DC
    PETROSTR
    4020.0
    [m]
    DC
    PETROSTR
    4026.0
    [m]
    DC
    PETROSTR
    4032.0
    [m]
    DC
    PETROSTR
    4037.7
    [m]
    DC
    PETROSTR

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    MWD LWD - PD OARCVIS TELES
    2110
    3593

  • 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
    LINER
    9 7/8
    3605.0
    12 1/4
    3605.0
    1.89
    FIT