Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
11.11.2024 - 01:26
Time of last synchronization with Norwegian Offshore Directorate's internal systems

16/2-17 B

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.
    16/2-17 B
    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.
    16/2-17
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    inline 4273 & crossline 3224(On 3D cube LN0902STR11)
    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.
    1448-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.
    28
    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,
    20.05.2013
    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.
    16.06.2013
    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.
    16.06.2015
    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.
    16.06.2015
    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.
    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.
    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
    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.
    PRE-DEVONIAN
    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.
    111.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2200.0
    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).
    1937.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    36
    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° 48' 15.92'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 31' 46.03'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6518520.01
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    472811.62
    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.
    7175

  • Wellbore history
    General
    Well 16/2-17 B is a geological sidetrack to well 16/2-17 S. The sidetrack targeted the Cliffhanger South prospect on the western side of the main western bounding fault on the Johan Sverdrup Discovery. The primary objective of 16/2-17 B was to investigate whether the Intra-Draupne Formation sandstone is present west of the main bounding fault. A secondary objective was to investigate the hydrocarbon potential of the Basement, which is expected to be directly beneath the Jurassic reservoir.
    Operations and results
    Appraisal sidetrack well 16/2-17 B was drilled with the semi-submersible installation Ocean Vanguard. It was kicked off from 600 m in the primary well bore on 20 May 2013 and drilled to TD at 2200 m (1937 m TVD) in pre-Devonian granitic basement. No significant problem was encountered in the operations. The well was drilled with XP-07 oil based mud.
    This well did not encounter any Jurassic strata, nor any sands with potential reservoir properties. The top of the Basement was encountered at 2133 m, which was 23 m TVD deeper than prognosed. The granitic Basement contained hydrocabons; however, the fractured top was disappointing concerning reservoir properties. Apart from the shows in top of the granitic basement, no oil shows above the oil-based mud were recorded in the well.
    Three cores were cut through the target prospect, from 2087 in the Rødby Formation to 2144.5 m in the Basement. The basement core recovered 70.5% (including ca 7.6 m of the basement); the two others had 100% recovery. MDT pressure evaluation was attempted at four depths in the top of the basement without success due to tight rock. No fluid samples were taken.
    The well was permanently abandoned on 16 May 2013 as a dry well with shows.
    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]
    620.00
    2200.00

  • 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
    2087.0
    2114.5
    [m ]
    2
    2114.5
    2130.5
    [m ]
    3
    2130.5
    2140.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    53.5
    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
    FUGRO
    660.0
    [m]
    DC
    FUGRO
    670.0
    [m]
    DC
    FUGRO
    680.0
    [m]
    DC
    FUGRO
    690.0
    [m]
    DC
    FUGRO
    700.0
    [m]
    DC
    FUGRO
    710.0
    [m]
    DC
    FUGRO
    720.0
    [m]
    DC
    FUGRO
    730.0
    [m]
    DC
    FUGRO
    740.0
    [m]
    DC
    FUGRO
    750.0
    [m]
    DC
    FUGRO
    760.0
    [m]
    DC
    FUGRO
    770.0
    [m]
    DC
    FUGRO
    780.0
    [m]
    DC
    FUGRO
    790.0
    [m]
    DC
    FUGRO
    800.0
    [m]
    DC
    FUGRO
    810.0
    [m]
    DC
    FUGRO
    820.0
    [m]
    DC
    FUGRO
    830.0
    [m]
    DC
    FUGRO
    840.0
    [m]
    DC
    FUGRO
    850.0
    [m]
    DC
    FUGRO
    860.0
    [m]
    DC
    FUGRO
    870.0
    [m]
    DC
    FUGRO
    880.0
    [m]
    DC
    FUGRO
    890.0
    [m]
    DC
    FUGRO
    900.0
    [m]
    DC
    FUGRO
    910.0
    [m]
    DC
    FUGRO
    920.0
    [m]
    DC
    FUGRO
    930.0
    [m]
    DC
    FUGRO
    940.0
    [m]
    DC
    FUGRO
    950.0
    [m]
    DC
    FUGRO
    960.0
    [m]
    DC
    FUGRO
    970.0
    [m]
    DC
    FUGRO
    980.0
    [m]
    DC
    FUGRO
    990.0
    [m]
    DC
    FUGRO
    1000.0
    [m]
    DC
    FUGRO
    1010.0
    [m]
    DC
    FUGRO
    1020.0
    [m]
    DC
    FUGRO
    1030.0
    [m]
    DC
    FUGRO
    1040.0
    [m]
    DC
    FUGRO
    1050.0
    [m]
    DC
    FUGRO
    1060.0
    [m]
    DC
    FUGRO
    1070.0
    [m]
    DC
    FUGRO
    1080.0
    [m]
    DC
    FUGRO
    1090.0
    [m]
    DC
    FUGRO
    1100.0
    [m]
    DC
    FUGRO
    1110.0
    [m]
    DC
    FUGRO
    1120.0
    [m]
    DC
    FUGRO
    1130.0
    [m]
    DC
    FUGRO
    1140.0
    [m]
    DC
    FUGRO
    1150.0
    [m]
    DC
    FUGRO
    1160.0
    [m]
    DC
    FUGRO
    1170.0
    [m]
    DC
    FUGRO
    1190.0
    [m]
    DC
    FUGRO
    1210.0
    [m]
    DC
    FUGRO
    1230.0
    [m]
    DC
    FUGRO
    1250.0
    [m]
    DC
    FUGRO
    1270.0
    [m]
    DC
    FUGRO
    1290.0
    [m]
    DC
    FUGRO
    1310.0
    [m]
    DC
    FUGRO
    1330.0
    [m]
    DC
    FUGRO
    1350.0
    [m]
    DC
    FUGRO
    1370.0
    [m]
    DC
    FUGRO
    1390.0
    [m]
    DC
    FUGRO
    1410.0
    [m]
    DC
    FUGRO
    1430.0
    [m]
    DC
    FUGRO
    1450.0
    [m]
    DC
    FUGRO
    1470.0
    [m]
    DC
    FUGRO
    1490.0
    [m]
    DC
    FUGRO
    1510.0
    [m]
    DC
    FUGRO
    1530.0
    [m]
    DC
    FUGRO
    1550.0
    [m]
    DC
    FUGRO
    1570.0
    [m]
    DC
    FUGRO
    1590.0
    [m]
    DC
    FUGRO
    1610.0
    [m]
    DC
    FUGRO
    1630.0
    [m]
    DC
    FUGRO
    1650.0
    [m]
    DC
    FUGRO
    1670.0
    [m]
    DC
    FUGRO
    1690.0
    [m]
    DC
    FUGRO
    1710.0
    [m]
    DC
    FUGRO
    1730.0
    [m]
    DC
    FUGRO
    1750.0
    [m]
    DC
    FUGRO
    1770.0
    [m]
    DC
    FUGRO
    1870.0
    [m]
    DC
    FUGRO
    2087.0
    [m]
    C
    FUGRO
    2091.5
    [m]
    C
    FUGRO
    2095.8
    [m]
    C
    FUGRO
    2100.0
    [m]
    C
    FUGRO
    2103.8
    [m]
    C
    FUGRO
    2106.1
    [m]
    C
    FUGRO
    2106.2
    [m]
    C
    FUGRO
    2111.0
    [m]
    C
    FUGRO
    2114.5
    [m]
    C
    FUGRO
    2118.0
    [m]
    C
    FUGRO
    2124.0
    [m]
    C
    FUGRO
    2125.3
    [m]
    C
    FUGRO

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    HNGS PEX ONMI2 UBI
    1780
    2196
    MDT PR MINIDST
    2133
    2140
    MSIP AIT
    1321
    2205
    MWD - PD ARCVRES6
    2087
    2200
    MWD - PD GVR6 ARCVRES6
    1784
    2087
    MWD - PD X6 GR RES ECD DIR
    616
    1784

  • 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.
    13 3/8
    600.0
    0.0
    0.00
    INTERM.
    9 5/8
    1780.0
    12 1/4
    1784.0
    0.00
    OPEN HOLE
    2200.0
    8 1/2
    2200.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    613
    1.35
    20.0
    XP-07 - Yellow
    1208
    1.45
    40.0
    XP-07 - Yellow
    1761
    1.22
    16.0
    XP-07 - Yellow
    1787
    1.20
    14.0
    XP-07 - Yellow
    1800
    1.22
    17.0
    XP-07 - Yellow
    2136
    1.21
    20.0
    XP-07 - Yellow
    2200
    1.20
    23.0
    XP-07 - Yellow