Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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26.12.2024 - 01:26
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16/2-19 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.
    16/2-19 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).
    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.
    16/2-19
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    3D survey:LN0902STR11 inline 3526 & xline 3631
    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.
    1517-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.
    32
    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,
    03.04.2014
    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.
    03.05.2014
    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.
    03.05.2016
    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.
    03.05.2016
    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
    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.
    TRIASSIC
    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.
    SKAGERRAK FM
    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.
    116.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2347.5
    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).
    1979.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    42.6
    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° 54' 12.28'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 29' 37.71'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6529557.51
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    470835.44
    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.
    7456

  • Wellbore history
    General
    Well 16/2-19 A is a geological sidetrack to the 16/2-19 Geitungen well. The well is drilled on the northern part of the Johan Sverdrup Field on the Utsira High in the North Sea.  The sidetrack 16/2-19 A targeted Intra Draupne Formation Sandstones in an assumed depocentre in a more distal position than the 16/2-12 but in a more proximal position than 16/2-19. The objectives were to investigate the reservoir distribution, facies and quality of the Draupne sandstone, and to find the oil-water contact.
    Operations and results
    Appraisal well 16/2-19 A was kicked off through 13 3/8" casing at 625.5 m in the primary well on 3 April 2014. It was drilled with the semi-submersible installation Ocean Vanguard to TD at 2347 m (1979 m TVD) in granitic basement rock. No significant problem was encountered in the operations. The well was drilled with XP-07 oil based mud from kick-off to TD.
    Draupne Formation claystone was penetrated at 2265 m, while Intra Draupne Formation Sandstone came in at 2271 m. A 13 m gross oil column was encountered in Intra Draupne Formation sandstone and Triassic Skagerrak Formation sandstone, the upper 3 m of which were in sandstone with very good reservoir quality. An oil-down-to situation was encountered. Oil shows described in in the reservoir section from 2270 m to 2289 m; otherwise, no shows are reported from the well.
    Two cores were cut across the reservoir section. Core 1 was cut from 2256.5 m in the Åsgard Formation, through Draupne formation claystone and Intra Draupne Formation Sandstone to 2283.2 m in the uppermost Hegre Group with 100% recovery.  Core 2 was cut from 2283.2 m to 2305.1 m in the Skagerrak Formation with 99% recovery.  MDT fluid samples were taken at 2281.04 m (oil with trace OBM contamination) and 2291.74 m (oil with ca 30% OBM contamination).
    The well was permanently abandoned on 3 May 2014 as an oil appraisal well. A CATS system was installed for long term monitoring of pressure and temperature.
    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]
    630.00
    2348.00

  • 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
    2256.5
    2283.2
    [m ]
    2
    2283.2
    2304.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    48.2
    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
    650.0
    [m]
    DC
    ROBERTSO
    660.0
    [m]
    DC
    ROBERT
    670.0
    [m]
    DC
    ROBERT
    680.0
    [m]
    DC
    ROBERT
    690.0
    [m]
    DC
    ROBERT
    700.0
    [m]
    DC
    ROBERT
    710.0
    [m]
    DC
    ROBERT
    720.0
    [m]
    DC
    ROBERT
    730.0
    [m]
    DC
    ROBERT
    740.0
    [m]
    DC
    ROBERT
    750.0
    [m]
    DC
    ROBERT
    760.0
    [m]
    DC
    ROBERT
    770.0
    [m]
    DC
    ROBERT
    780.0
    [m]
    DC
    ROBERT
    790.0
    [m]
    DC
    ROBERT
    800.0
    [m]
    DC
    ROBERT
    810.0
    [m]
    DC
    ROBERT
    820.0
    [m]
    DC
    ROBERT
    830.0
    [m]
    DC
    ROBERT
    840.0
    [m]
    DC
    ROBERT
    850.0
    [m]
    DC
    ROBERT
    870.0
    [m]
    DC
    ROBERT
    880.0
    [m]
    DC
    ROBERT
    890.0
    [m]
    DC
    ROBERT
    900.0
    [m]
    DC
    ROBERT
    910.0
    [m]
    DC
    ROBERT
    920.0
    [m]
    DC
    ROBERT
    930.0
    [m]
    DC
    ROBERT
    940.0
    [m]
    DC
    ROBERT
    950.0
    [m]
    DC
    ROBERT
    960.0
    [m]
    DC
    ROBERT
    970.0
    [m]
    DC
    ROBERT
    980.0
    [m]
    DC
    ROBERT
    990.0
    [m]
    DC
    ROBERT
    1000.0
    [m]
    DC
    ROBERT
    1010.0
    [m]
    DC
    ROBERT
    1020.0
    [m]
    DC
    ROBERT
    1030.0
    [m]
    DC
    ROBERT
    1040.0
    [m]
    DC
    ROBERT
    1050.0
    [m]
    DC
    ROBERT
    1070.0
    [m]
    DC
    ROBERT
    1080.0
    [m]
    DC
    ROBERT
    1090.0
    [m]
    DC
    ROBERT
    1100.0
    [m]
    DC
    ROBERT
    1110.0
    [m]
    DC
    ROBERT
    1120.0
    [m]
    DC
    ROBERT
    1130.0
    [m]
    DC
    ROBERT
    1140.0
    [m]
    DC
    ROBERT
    1150.0
    [m]
    DC
    ROBERT
    1160.0
    [m]
    DC
    ROBERT
    1170.0
    [m]
    DC
    ROBERT
    1180.0
    [m]
    DC
    ROBERT
    1190.0
    [m]
    DC
    ROBERT
    1200.0
    [m]
    DC
    ROBERT
    1220.0
    [m]
    DC
    ROBERT
    1240.0
    [m]
    DC
    ROBERT
    1260.0
    [m]
    DC
    ROBERT
    1280.0
    [m]
    DC
    ROBERT
    1300.0
    [m]
    DC
    ROBERT
    1320.0
    [m]
    DC
    ROBERT
    1340.0
    [m]
    DC
    ROBERT
    1360.0
    [m]
    DC
    ROBERT
    1380.0
    [m]
    DC
    ROBERT
    1400.0
    [m]
    DC
    ROBERT
    1420.0
    [m]
    DC
    ROBERT
    1440.0
    [m]
    DC
    ROBERT
    1460.0
    [m]
    DC
    ROBERT
    1480.0
    [m]
    DC
    ROBERT
    1500.0
    [m]
    DC
    ROBERT
    1520.0
    [m]
    DC
    ROBERT
    1540.0
    [m]
    DC
    ROBERT
    1560.0
    [m]
    DC
    ROBERT
    1580.0
    [m]
    DC
    ROBERT
    1600.0
    [m]
    DC
    ROBERT
    1620.0
    [m]
    DC
    ROBERT
    1640.0
    [m]
    DC
    ROBERT
    1680.0
    [m]
    DC
    ROBERT
    1700.0
    [m]
    DC
    ROBERT
    1720.0
    [m]
    DC
    ROBERT
    1740.0
    [m]
    DC
    ROBERT
    1760.0
    [m]
    DC
    ROBERT
    1780.0
    [m]
    DC
    ROBERT
    1800.0
    [m]
    DC
    ROBERT
    1820.0
    [m]
    DC
    ROBERT
    1840.0
    [m]
    DC
    ROBERT
    1880.0
    [m]
    DC
    ROBERT
    1900.0
    [m]
    DC
    ROBERT
    1920.0
    [m]
    DC
    ROBERT
    1940.0
    [m]
    DC
    ROBERT
    1960.0
    [m]
    DC
    ROBERT
    1980.0
    [m]
    DC
    ROBERT
    2000.0
    [m]
    DC
    ROBERT
    2020.0
    [m]
    DC
    ROBERT
    2060.0
    [m]
    DC
    ROBERT
    2080.0
    [m]
    DC
    ROBERT
    2100.0
    [m]
    DC
    ROBERT
    2120.0
    [m]
    DC
    ROBERT
    2126.5
    [m]
    C
    ROBERT
    2133.0
    [m]
    DC
    ROBERT
    2139.0
    [m]
    DC
    ROBERT
    2145.0
    [m]
    DC
    ROBERT
    2169.0
    [m]
    DC
    ROBERT
    2175.0
    [m]
    DC
    ROBERT
    2181.0
    [m]
    DC
    ROBERT
    2187.0
    [m]
    DC
    ROBERT
    2196.0
    [m]
    DC
    ROBERT
    2208.0
    [m]
    DC
    ROBERT
    2214.0
    [m]
    DC
    ROBERT
    2226.0
    [m]
    DC
    ROBERT
    2232.0
    [m]
    DC
    ROBERT
    2238.0
    [m]
    DC
    ROBERT
    2244.0
    [m]
    DC
    ROBERT
    2250.0
    [m]
    DC
    ROBERT
    2263.7
    [m]
    C
    ROBERT
    2267.5
    [m]
    C
    ROBERT
    2269.5
    [m]
    C
    ROBERT
    2272.1
    [m]
    C
    ROBERT
    2272.9
    [m]
    C
    ROBERT
    2274.9
    [m]
    C
    ROBERT
    2275.9
    [m]
    C
    ROBERT
    2280.6
    [m]
    C
    ROBERT
    2283.2
    [m]
    C
    ROBERT
    2285.9
    [m]
    C
    ROBERT
    2307.0
    [m]
    DC
    ROBERT
    2313.0
    [m]
    DC
    ROBERT
    2319.0
    [m]
    DC
    ROBERT
    2325.0
    [m]
    DC
    ROBERT

  • 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
    2291.70
    0.00
    OIL
    18.09.2014 - 00:00
    YES
    MDT
    2281.00
    0.00
    OIL
    18.09.2014 - 00:00
    YES

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT PEX HNGS
    2120
    2345
    DUAL OBMI PPC MSIP PPC
    2120
    2345
    EXPRO CPST
    1005
    1005
    MDT MINIDST
    2270
    2292
    MWD LWD - ARCVIS
    202
    902
    MWD LWD - ARCVRES6 TELE675
    2120
    2131
    MWD LWD - ARCVRES6 TELE675
    2262
    2347
    MWD LWD - PD ARC TELE
    625
    2126
    PERFO
    2277
    2283
    USIT CBL GR
    1610
    2120
    XPT ECS CMR
    2120
    2345

  • 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
    INTERM.
    9 5/8
    2120.0
    12 1/4
    2126.0
    1.40
    FIT
    LINER
    7
    2335.0
    8 1/2
    2347.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    715
    1.23
    17.0
    XP-07 - Yellow
    1494
    1.39
    24.0
    XP-07 - Yellow
    2126
    1.39
    23.0
    XP-07 - Yellow
    2126
    1.41
    23.0
    XP-07 - Yellow
    2127
    1.22
    18.0
    XP-07 - Yellow
    2305
    1.24
    18.0
    XP-07 - Yellow
    2322
    1.21
    16.0
    XP-07 - Yellow
    2347
    1.17
    17.0
    XP-07 - Yellow
    2348
    1.21
    17.0
    XP-07 - Yellow