Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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03.11.2024 - 01:26
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16/10-3

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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.
    16/10-3
    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.
    16/10-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ES 9401- INLINE 1782 & CROSSLINE 5320
    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.
    Norsk Agip 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.
    856-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.
    41
    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,
    22.10.1996
    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.
    01.12.1996
    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.
    01.12.1998
    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.
    31.10.2003
    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.
    40.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    75.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2850.0
    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).
    2849.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    103
    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.
    TRIASSIC
    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.
    SMITH BANK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 13' 18.54'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 19' 34.3'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6453751.14
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    460416.92
    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.
    2703

  • Wellbore history
    General
    Well 16/10-3 was drilled as an exploration well on the "Tyr Central prospect" located near the block boundary in the northeast part of the Block in Production License 101. The licence was awarded in 1985, after the 9th concession round.
    The purpose of drilling well 16/10-3 was to test the hydrocarbon potential of the Middle Jurassic/Triassic reservoir (Hugin and Skagerrak Formations) in the Tyr structure. The tested structure consisted in several culminations with a common dip closure. The well location was set on the largest of these, called "Tyr Central". The well was drilled by Norsk Agip as operator and was a joint well with the licence holders of PL 072.
    Operations and results
    Exploration well 16/10-3 was spudded with the jack-up installation "Transocean Nordic" on 22 October 1996 and drilled to a total depth of 2850 m in the Triassic Smith Bank Formation shales. The well was drilled/cased/logged and abandoned in 40 days but due to WOW (wait on weather) the rig was not released from its contract and moved off location until the 6 December 1996 after a total of almost 51 days. The well was drilled with spud mud down to 196 m, with Seawater and PAC hi-vis sweeps from 196 m to 431, and with KCl / PAC glycol mud from 431 m to TD.
    All the expected formations were encountered. The Jurassic/Triassic sands were found with fair reservoir quality. The expected reservoir was encountered at 2521 m, 31 m deeper than prognosis. The Hugin-Skagerrak sands were found water bearing and no hydrocarbon shows were detected. No relevant gas amounts were recorded in the well and no hydrocarbon shows were identified on cuttings in the reservoir section. Two FMT fluid samples were collected at two different depths: the recovery was mud filtrate in the first sample at 2522 m and mud in the second one at 2544.3 m. No conventional cores were cut in this well. The well was permanently abandoned as a dry well on 1 December 1996.
    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]
    210.00
    2849.00

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2300.0
    [m]
    DC
    MILLENNI
    2310.0
    [m]
    DC
    MILLEN
    2320.0
    [m]
    DC
    MILLEN
    2330.0
    [m]
    DC
    MILLEN
    2340.0
    [m]
    DC
    MILLEN
    2350.0
    [m]
    DC
    MILLEN
    2360.0
    [m]
    DC
    MILLEN
    2370.0
    [m]
    DC
    MILLEN
    2382.2
    [m]
    SWC
    MILLEN
    2390.0
    [m]
    DC
    MILLEN
    2400.0
    [m]
    DC
    MILLEN
    2410.0
    [m]
    DC
    MILLEN
    2420.0
    [m]
    DC
    MILLEN
    2430.0
    [m]
    DC
    MILLEN
    2440.0
    [m]
    DC
    MILLEN
    2450.0
    [m]
    DC
    MILLEN
    2457.4
    [m]
    SWC
    MILLEN
    2470.0
    [m]
    DC
    MILLEN
    2480.0
    [m]
    DC
    MILLEN
    2490.0
    [m]
    DC
    MILLEN
    2500.0
    [m]
    DC
    MILLEN
    2505.0
    [m]
    DC
    MILLEN
    2510.0
    [m]
    DC
    MILLEN
    2513.0
    [m]
    DC
    MILLEN
    2516.0
    [m]
    DC
    MILLEN
    2519.5
    [m]
    SWC
    MILLEN
    2522.5
    [m]
    SWC
    MILLEN
    2524.0
    [m]
    SWC
    MILLEN
    2528.5
    [m]
    SWC
    MILLEN
    2532.4
    [m]
    SWC
    MILLEN
    2542.4
    [m]
    SWC
    MILLEN
    2546.0
    [m]
    DC
    MILLEN
    2555.0
    [m]
    DC
    MILLEN
    2568.3
    [m]
    SWC
    MILLEN
    2573.0
    [m]
    DC
    MILLEN
    2579.0
    [m]
    SWC
    MILLEN
    2594.0
    [m]
    DC
    MILLEN
    2609.0
    [m]
    DC
    MILLEN
    2622.5
    [m]
    SWC
    MILLEN
    2633.0
    [m]
    DC
    MILLEN
    2642.0
    [m]
    DC
    MILLEN
    2654.0
    [m]
    DC
    MILLEN
    2663.0
    [m]
    DC
    MILLEN
    2675.0
    [m]
    DC
    MILLEN
    2684.0
    [m]
    DC
    MILLEN
    2693.0
    [m]
    DC
    MILLEN
    2705.0
    [m]
    DC
    MILLEN
    2714.0
    [m]
    DC
    MILLEN
    2723.0
    [m]
    DC
    MILLEN
    2732.0
    [m]
    DC
    MILLEN
    2744.0
    [m]
    DC
    MILLEN
    2753.0
    [m]
    DC
    MILLEN
    2765.0
    [m]
    DC
    MILLEN
    2780.0
    [m]
    DC
    MILLEN
    2794.7
    [m]
    SWC
    MILLEN
    2794.8
    [m]
    SWC
    MILLEN
    2813.0
    [m]
    DC
    MILLEN
    2825.0
    [m]
    DC
    MILLEN
    2837.0
    [m]
    DC
    MILLEN
    2849.0
    [m]
    DC
    MILLEN

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.43

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.93
    pdf
    1.38

  • 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
    77.56

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DLL ACL GR CAL
    421
    1232
    DLL ACL GR CAL
    2138
    2849
    DLL ACL ZDEN GR
    1225
    2147
    FMT GR
    2522
    2620
    FMT GR
    2522
    2527
    FMT GR
    2522
    2621
    HEXDIP GR
    2138
    2849
    MWD - DPR DIR
    431
    2850
    MWD - GR DPR DIR
    196
    431
    SWC GR
    2346
    2795
    VSP GR
    900
    2845
    ZDEN CN SL
    2138
    2849

  • 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
    187.0
    36
    190.0
    0.00
    LOT
    SURF.COND.
    20
    421.0
    26
    422.0
    1.49
    LOT
    INTERM.
    13 3/8
    1225.0
    17 1/2
    1226.0
    1.77
    LOT
    INTERM.
    9 5/8
    2138.0
    12 1/4
    2140.0
    1.75
    LOT
    OPEN HOLE
    2850.0
    8 1/2
    2850.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    160
    1.38
    29.0
    KCL/PAC/GLYCOL
    195
    1.08
    SPUD MUD
    196
    1.05
    13.0
    SEAWATER
    431
    1.18
    14.0
    SW/PAC
    431
    1.17
    17.0
    SEAWATER
    508
    1.25
    20.0
    KCL/PAC/GLYCOL
    925
    1.30
    19.0
    KCL/PAC/GLYCOL
    1235
    1.37
    16.0
    KCL/PAC/GLYCOL
    1598
    1.39
    25.0
    KCL/PAC/GLYCOL
    2054
    1.38
    28.0
    KCL/PAC/GLYCOL
    2150
    1.45
    30.0
    KCL/PAC/GLYCOL
    2527
    1.39
    31.0
    KCL/PAC/GLYCOL
    2545
    1.40
    29.0
    KCL/PAC/GLYCOL
    2850
    1.39
    28.0
    KCL/PAC/GLYCOL

  • 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