Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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16/7-3

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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.
    16/7-3
    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.
    16/7-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 8122 - 563 SP 738
    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.
    Esso Exploration and Production Norway 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.
    331-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.
    47
    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,
    11.06.1982
    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.
    27.07.1982
    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.
    27.07.1984
    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.
    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.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    85.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3141.0
    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).
    3141.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    94
    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.
    EARLY PERMIAN
    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.
    ROTLIEGEND GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 24' 21.96'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 8' 8.06'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6474396.59
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    449482.48
    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.
    75

  • Wellbore history
    General
    Exploration well 16/7-3 is located on the Utsira High, about ten km east of the Sleipner East field. The objective of the well was to test potential Jurassic sands on the large structure in the centre of the block.
    The well would also test the Zechstein carbonate and Rotliegendes sandstone plays in a small fault block structure.
    Operations and results
    The well was spudded with the semi-submersible installation Glomar Biscay II and drilled without incident to TD at 3141 m in the Rotliegendes Group. The well was drilled with seawater gel, adding lignite from 2150 m.
    The Cretaceous sequence consisted of the Late Cretaceous Tor and Hod chalk formations resting unconformably on a very thin Late Jurassic Draupne shale. Thirty-seven net m of good quality sand was encountered in the Jurassic Hugin Formation. The Triassic consisted of red beds with no major sand development. The Zechstein contained tight anhydritic dolomite, some vuggy dolomite, and shales, while the Rotliegendes Group had poor reservoir quality dolomite cemented sandstones, siltstones and shales. A shows on a core was recorded in the interval 2345 m to 2350.7 m in the upper part of the Jurassic Hugin Formation. Otherwise no hydrocarbons were encountered in the well. Two cores were taken in the 8 1/2" section, in the interval 2342 m to 2365.5 m in the Jurassic Hugin Formation. Forty sidewall cores were taken in the interval 2296 m to 3130 m. No fluid samples were taken. The well was permanently abandoned as dry on 28 August 1982.
    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]
    180.00
    3140.00

  • 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
    2342.0
    2350.7
    [m ]
    2
    2351.0
    2365.6
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    23.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2342-2348m
    Core photo at depth: 2348-2450m
    Core photo at depth: 2351-2357m
    Core photo at depth: 2357-2363m
    Core photo at depth: 2363-2365m
    2342-2348m
    2348-2450m
    2351-2357m
    2357-2363m
    2363-2365m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    520.0
    [m]
    DC
    550.0
    [m]
    DC
    580.0
    [m]
    DC
    610.0
    [m]
    DC
    640.0
    [m]
    DC
    670.0
    [m]
    DC
    700.0
    [m]
    DC
    730.0
    [m]
    DC
    760.0
    [m]
    DC
    790.0
    [m]
    DC
    820.0
    [m]
    DC
    850.0
    [m]
    DC
    880.0
    [m]
    DC
    910.0
    [m]
    DC
    940.0
    [m]
    DC
    970.0
    [m]
    DC
    1000.0
    [m]
    DC
    1030.0
    [m]
    DC
    1060.0
    [m]
    DC
    1090.0
    [m]
    DC
    1120.0
    [m]
    DC
    1150.0
    [m]
    DC
    1180.0
    [m]
    DC
    1210.0
    [m]
    DC
    1240.0
    [m]
    DC
    1270.0
    [m]
    DC
    1300.0
    [m]
    DC
    1330.0
    [m]
    DC
    1360.0
    [m]
    DC
    1390.0
    [m]
    DC
    1420.0
    [m]
    DC
    1450.0
    [m]
    DC
    1480.0
    [m]
    DC
    1510.0
    [m]
    DC
    1540.0
    [m]
    DC
    1570.0
    [m]
    DC
    1600.0
    [m]
    DC
    1630.0
    [m]
    DC
    1660.0
    [m]
    DC
    1690.0
    [m]
    DC
    1720.0
    [m]
    DC
    1750.0
    [m]
    DC
    1780.0
    [m]
    DC
    1810.0
    [m]
    DC
    1840.0
    [m]
    DC
    1870.0
    [m]
    DC
    1900.0
    [m]
    DC
    1930.0
    [m]
    DC
    1960.0
    [m]
    DC
    1990.0
    [m]
    DC
    2021.0
    [m]
    DC
    2039.0
    [m]
    DC
    2051.0
    [m]
    DC
    2060.0
    [m]
    DC
    2069.0
    [m]
    DC
    2081.0
    [m]
    DC
    2090.0
    [m]
    DC
    2099.0
    [m]
    DC
    2111.0
    [m]
    DC
    2120.0
    [m]
    DC
    2129.0
    [m]
    DC
    2141.0
    [m]
    DC
    2171.0
    [m]
    DC
    2180.0
    [m]
    DC
    2189.0
    [m]
    DC
    2201.0
    [m]
    DC
    2210.0
    [m]
    DC
    2219.0
    [m]
    DC
    2231.0
    [m]
    DC
    2240.0
    [m]
    DC
    2249.0
    [m]
    DC
    2252.0
    [m]
    DC
    2261.0
    [m]
    DC
    2273.0
    [m]
    DC
    2282.0
    [m]
    DC
    2312.0
    [m]
    DC
    2334.5
    [m]
    SWC
    2335.0
    [m]
    SWC
    2336.5
    [m]
    SWC
    2337.5
    [m]
    SWC
    2337.5
    [m]
    SWC
    2340.0
    [m]
    SWC
    2341.0
    [m]
    SWC
    2342.0
    [m]
    C
    2342.0
    [m]
    DC
    2342.1
    [m]
    C
    2342.5
    [m]
    C
    2342.8
    [m]
    C
    2343.0
    [m]
    C
    2343.3
    [m]
    C
    2343.8
    [m]
    C
    2344.0
    [m]
    C
    2345.5
    [m]
    C
    2346.3
    [m]
    C
    2347.0
    [m]
    C
    2351.0
    [m]
    C
    2351.2
    [m]
    C
    2354.1
    [m]
    C
    2355.0
    [m]
    C
    2356.8
    [m]
    C
    2359.0
    [m]
    C
    2361.3
    [m]
    C
    2363.0
    [m]
    C
    2364.0
    [m]
    C
    2365.0
    [m]
    C
    2365.5
    [m]
    C
    2372.0
    [m]
    DC
    2372.0
    [m]
    SWC
    2376.0
    [m]
    SWC
    2386.0
    [m]
    SWC
    2391.0
    [m]
    SWC
    2402.0
    [m]
    DC
    2432.0
    [m]
    DC
    2462.0
    [m]
    DC
    2492.0
    [m]
    DC
    2522.0
    [m]
    DC
    2543.0
    [m]
    DC
    2573.0
    [m]
    DC
    2581.0
    [m]
    SWC
    2603.0
    [m]
    DC
    2635.0
    [m]
    DC
    2666.0
    [m]
    DC
    2696.0
    [m]
    DC
    2726.0
    [m]
    DC
    2756.0
    [m]
    DC
    2786.0
    [m]
    DC
    2816.0
    [m]
    DC
    2840.2
    [m]
    SWC
    2846.0
    [m]
    DC
    2876.0
    [m]
    DC
    2906.0
    [m]
    DC
    2936.0
    [m]
    DC
    2966.0
    [m]
    DC
    2996.0
    [m]
    DC
    3026.0
    [m]
    DC
    3056.0
    [m]
    DC
    3086.0
    [m]
    DC
    3116.0
    [m]
    DC
    3140.0
    [m]
    DC

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.39

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    2.31

  • 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
    2.31

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    4ARM-CAL
    110
    460
    4ARM-CAL
    440
    1223
    CBL GR
    171
    255
    CDL CNL GR SP CAL
    2287
    2851
    CDL CNL GR SP CAL
    2500
    3134
    DIPLOG
    2282
    3133
    IEL AC GR SP CAL
    105
    463
    IEL AC GR SP CAL
    440
    1223
    IEL AC GR SP CAL
    1882
    2297
    IEL AC GR SP CAL
    2274
    2848
    IEL AC GR SP CAL
    2500
    3134
    MFT
    2346
    2841
    SWC
    2296
    3130
    TEMP
    10
    1183
    TEMP CCL
    1200
    1775
    VSP
    175
    3128

  • 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
    171.3
    36
    173.0
    0.00
    LOT
    SURF.COND.
    20
    449.5
    26
    469.0
    1.78
    LOT
    INTERM.
    13 3/8
    1212.0
    17 1/2
    1228.0
    1.74
    LOT
    INTERM.
    9 5/8
    2287.0
    12 1/4
    2303.0
    1.80
    LOT
    OPEN HOLE
    3141.0
    8 1/2
    3141.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    340
    1.07
    55.0
    water
    460
    1.10
    40.0
    water
    640
    1.14
    50.0
    water
    980
    1.19
    40.0
    water
    1620
    1.20
    47.0
    water
    1990
    1.19
    43.0
    water
    2140
    1.17
    46.0
    water
    2230
    1.27
    60.0
    water
    2880
    1.21
    54.0
    water
    2940
    1.20
    56.0
    water

  • 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