Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
24.11.2024 - 01:27
Time of last synchronization with Norwegian Offshore Directorate's internal systems

16/2-12

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    16/2-12
    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.
    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
    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.
    16/2-12
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    inline 4258 & xline 3757 - ST11313
    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.
    Statoil 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.
    1400-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.
    44
    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,
    25.07.2012
    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.
    06.09.2012
    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.
    06.09.2014
    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.
    06.01.2015
    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.
    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.
    LATE 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.
    INTRA DRAUPNE FM SS
    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.
    PRE-DEVONIAN
    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.
    BASEMENT
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    22.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    115.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2067.0
    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).
    2067.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    0.6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    87
    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.
    PRE-DEVONIAN
    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.
    BASEMENT
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 53' 4.27'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 29' 18.11'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6527456.29
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    470505.67
    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.
    6952

  • Wellbore history
    General
    Well 16/2-12 was drilled on the Geitungen Prospect on the Utsira High in the North Sea. The prospect is situated on a basement terrace north-west of the Johan Sverdrup Field. The main objectives were to investigate the hydrocarbon potential, reservoir quality, and lateral distribution of Intra-Draupne Formation sandstones, and the underlying sandstones of the Hugin and Sleipner Formations. The secondary objectives were to explore the hydrocarbon potential and reservoir properties in the fractured granitic Basement.
    Operations and results
    Well 16/2-12 was spudded with the semi-submersible installation Ocean Vanguard on 25 July 2012 and drilled to TD at 2067 m in granite Basement. There was a pre-drill shallow gas warning at 707 m, ca 100 m below 20” casing shoe, but no gas was observed when drilling. The well was drilled with seawater down to 211 m and with PerformaDril water based mud from 211 m to TD.
    The well penetrated rocks of Quaternary, Neogene, Paleogene, Cretaceous and Jurassic age. No indication of hydrocarbons were recorded above top Intra Draupne Formation sandstone, which was picked at 1894 m, 12 m deeper than prognosed. The reservoir had excellent reservoir properties and contained oil. The top of the Basement was picked at 1938 m, 5 m deeper than prognosed. The fractures in the uppermost part of Basement were oil-filled. The oil/water contact was not encountered, but pressure measurements indicate a connection between this segment and the rest of the Johan Sverdrup discovery. Extensive data acquisition and sampling was carried out. The gas/oil ratio is 51.8 Sm3/Sm3 and the oil density is estimated at 0.81 g/cm3 in the Intra-Draupne reservoir.
    Four cores were cut in the interval 1893 m to 1951.7 m, covering the whole Jurassic interval and 13.7 m of the Basement. The difference between the cores depth and wireline logs depth is less than 50 cm. Core 1 was dripping with oil and had excellent shows. The same type of shows continued on core 2 down to 1930 m. From 1930 – 1940 m, the shows disappeared. From 1940 m, oil was observed in fractures in the granitic Basement. Due to less fractures in core 4 shows disappeared. The deepest indication of weak shows were seen at 1950 m.
    Reservoir fluid samples were obtained at four depths, with three MDT runs in the well. Large diameter probe was used on MDT wireline runs 5 and 7, and dual straddle packer was used on MDT wireline Run 8. In Run 5, samples were taken in Intra-Draupne Formation sandstone at 1901.3 m (oil) and in the Basement at 1940.0 m (oil with water and filtrate). In Run 7 samples were taken in Intra-Draupne Formation sandstone at 1928.3 m (oil), In Run 8 samples were taken in the Basement at 1940.1 m (oil with water and filtrate) and at 1945 m (water).
    The well was permanently abandoned on 6 September 2010. It was planned and drilled as a wildcat well. However, after performing data acquisition, and acquiring formation pressure testing data in the reservoir section, the well was reclassified as an appraisal of the Johan Sverdrup field.
    Testing
    Formation tests (mini-DST) were conducted in the bedrock, revealing stable flow rates of both oil and water in different levels in the fractured and weathered bedrocks.

  • 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]
    615.00
    2067.00

  • 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
    1893.0
    1919.4
    [m ]
    2
    1920.0
    1942.8
    [m ]
    3
    1942.8
    1947.1
    [m ]
    4
    1947.1
    1951.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    58.1
    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
    615.0
    [m]
    DC
    FUGRO
    630.0
    [m]
    DC
    FUGRO
    650.0
    [m]
    DC
    FUGRO
    670.0
    [m]
    DC
    FUGRO
    690.0
    [m]
    DC
    FUGRO
    710.0
    [m]
    DC
    FUGRO
    730.0
    [m]
    DC
    FUGRO
    750.0
    [m]
    DC
    FUGRO
    770.0
    [m]
    DC
    FUGRO
    790.0
    [m]
    DC
    FUGRO
    810.0
    [m]
    DC
    FUGRO
    830.0
    [m]
    DC
    FUGRO
    850.0
    [m]
    DC
    FUGRO
    870.0
    [m]
    DC
    FUGRO
    890.0
    [m]
    DC
    FUGRO
    910.0
    [m]
    DC
    FUGRO
    930.0
    [m]
    DC
    FUGRO
    950.0
    [m]
    DC
    FUGRO
    970.0
    [m]
    DC
    FUGRO
    990.0
    [m]
    DC
    FUGRO
    1010.0
    [m]
    DC
    FUGRO
    1030.0
    [m]
    DC
    FUGRO
    1050.0
    [m]
    DC
    FUGRO
    1100.0
    [m]
    DC
    FUGRO
    1120.0
    [m]
    DC
    FUGRO
    1140.0
    [m]
    DC
    FUGRO
    1160.0
    [m]
    DC
    FUGRO
    1180.0
    [m]
    DC
    FUGRO
    1200.0
    [m]
    DC
    FUGRO
    1220.0
    [m]
    DC
    FUGRO
    1240.0
    [m]
    DC
    FUGRO
    1260.0
    [m]
    DC
    FUGRO
    1280.0
    [m]
    DC
    FUGRO
    1300.0
    [m]
    DC
    FUGRO
    1320.0
    [m]
    DC
    FUGRO
    1340.0
    [m]
    DC
    FUGRO
    1360.0
    [m]
    DC
    FUGRO
    1380.0
    [m]
    DC
    FUGRO
    1400.0
    [m]
    DC
    FUGRO
    1420.0
    [m]
    DC
    FUGRO
    1440.0
    [m]
    DC
    FUGRO
    1460.0
    [m]
    DC
    FUGRO
    1480.0
    [m]
    DC
    FUGRO
    1500.0
    [m]
    DC
    FUGRO
    1520.0
    [m]
    DC
    FUGRO
    1540.0
    [m]
    DC
    FUGRO
    1560.0
    [m]
    DC
    FUGRO
    1580.0
    [m]
    DC
    FUGRO
    1600.0
    [m]
    DC
    FUGRO
    1620.0
    [m]
    DC
    FUGRO
    1640.0
    [m]
    DC
    FUGRO
    1660.0
    [m]
    DC
    FUGRO
    1670.0
    [m]
    DC
    FUGRO
    1676.0
    [m]
    DC
    FUGRO
    1680.0
    [m]
    DC
    FUGRO
    1686.0
    [m]
    DC
    FUGRO
    1692.0
    [m]
    DC
    FUGRO
    1695.0
    [m]
    DC
    FUGRO
    1704.0
    [m]
    DC
    FUGRO
    1713.0
    [m]
    DC
    FUGRO
    1722.0
    [m]
    DC
    FUGRO
    1800.0
    [m]
    DC
    FUGRO
    1806.0
    [m]
    DC
    FUGRO
    1815.0
    [m]
    DC
    FUGRO
    1821.0
    [m]
    DC
    FUGRO
    1830.0
    [m]
    DC
    FUGRO
    1836.0
    [m]
    DC
    FUGRO
    1842.0
    [m]
    DC
    FUGRO
    1848.0
    [m]
    DC
    FUGRO
    1854.0
    [m]
    DC
    FUGRO
    1860.0
    [m]
    DC
    FUGRO
    1866.0
    [m]
    DC
    FUGRO
    1869.0
    [m]
    DC
    FUGRO
    1875.0
    [m]
    DC
    FUGRO
    1881.0
    [m]
    DC
    FUGRO
    1887.0
    [m]
    DC
    FUGRO
    1890.0
    [m]
    DC
    FUGRO
    1893.0
    [m]
    C
    FUGRO
    1895.8
    [m]
    C
    FUGRO
    1897.0
    [m]
    C
    FUGRO
    1899.7
    [m]
    C
    FUGRO
    1928.9
    [m]
    C
    FUGRO
    1929.0
    [m]
    C
    FUGRO
    1929.9
    [m]
    C
    FUGRO
    1939.6
    [m]
    C
    FUGRO

  • 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
    MDT
    1901.30
    0.00
    OIL
    YES
    MDT
    1928.30
    0.00
    OIL
    YES
    MDT
    1940.00
    0.00
    OIL
    YES

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CMR ECS GR
    1673
    2064
    FMI HNGS HRLA
    1673
    2067
    LWD - ARCVRES6 GVR6 TELE
    1676
    1893
    LWD - ARCVRES6 TELE
    1893
    2067
    MDT
    1895
    1940
    MSIP GPIT PEX
    1231
    2056
    MWD - ARCVRES8 PDX5 TELE
    1213
    1676
    MWD - ARCVRES9 TELE
    211
    1223
    PEX DSI
    525
    1215
    VSP
    600
    2067

  • 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
    211.0
    36
    215.0
    0.00
    SURF.COND.
    20
    602.0
    26
    610.0
    1.56
    LOT
    INTERM.
    13 3/8
    1213.0
    17 1/2
    1223.0
    1.69
    LOT
    INTERM.
    9 5/8
    1673.0
    12 1/4
    1676.0
    1.56
    LOT
    OPEN HOLE
    2067.0
    8 1/2
    2067.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    149
    1.35
    10.0
    Spud Mud
    610
    1.30
    36.0
    Performadril
    973
    1.30
    33.0
    Performadril
    1242
    1.35
    33.0
    Performadril
    1394
    1.24
    33.0
    Performadril
    1676
    1.35
    35.0
    Performadril
    1893
    1.20
    29.0
    Performadril
    1947
    1.21
    34.0
    Performadril
    1952
    1.22
    34.0
    Performadril
    2067
    1.20
    31.0
    Performadril

  • 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
    0.20