Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

16/10-1

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.
    16/10-1
    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.
    16/10-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 8315 - 303 SP. 946
    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.
    515-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.
    51
    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,
    25.05.1986
    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.
    14.07.1986
    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.
    14.07.1988
    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.
    27.02.2004
    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.
    84.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3151.0
    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).
    3151.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    123
    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.
    LATE 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.
    ZECHSTEIN GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 3' 23.68'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 3' 14.05'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6435546.75
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    444163.52
    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.
    901

  • Wellbore history
    General
    Well 16/10-1 was the first well drilled in block 16/10 operated by Norsk Agip. Among the various structures defined within block 16/10, the one called "Alpha", located in the southwestern area, was selected as the first one to be drill. Main reason for this choice was the presence of a deep basin (Witch Ground Graben) to the south west of the block, where the Viking Group shales was believed to have generated hydrocarbons since Cretaceous time. The tectonic evolution of the structure is probably of pre-Cretaceous age, well before hydrocarbon generation started.
    The purpose of the well was to explore all main reservoirs down to Triassic. The primary targets were the Jurassic and Triassic sandstone units, expected at 2850 m and 2980 m, respectively. Prognosed TD was at 3175 m.
    Operations and results
    Wildcat well 16/10-1 was spudded 25 May 1986 by Dyvi Offshore A/S semi-submersible rig Dyvi Stena and drilled to TD at 3151 m in the Late Permian Zechstein Group. The well was drilled with Seawater and hi-vis pills down to 514 m, with KCl/Polymer mud from 524 m to 2565 m, and with lignosulphonate mud from 2565 m t TD. Drilling proceeded without any significant problems. Electrical logs were run already in the 26" section from 195 m. No shallow gas was encountered.
    The Quaternary/Tertiary sequence, 2280.5 m thick, is represented by Nordland, Hordaland and Rogaland groups and is predominantly constituted by marine claystones. A 513.5 m Cretaceous section represented by the limestones of the Chalk Group and by the reddish marl and calcareous shales of the Cromer Knoll Group was penetrated. It was nearly a complete sequence except for two possible hiatus: the first in the Late Santonian and the second between the Cenomanian and the Aptian-Albian. The base Cretaceous Unconformity overlies the Late Jurassic shales of the Viking Group (top at 2794 m), which proved to have a thickness of 211 m. The top of the Jurassic sandstones of the Vestland Group was encountered at 3005 m. The "Oxfordian Sandstone Unit" (Hugin Formation) was 33m thick with very good reservoir properties. Below this was a 15 m thick "coal unit" of the Sleipner Formation, containing a major coal sequence with interbedded carbonaceous claystone/shale. Below the Mid Kimmerian Unconformity, a 58 m thick sequence of arenaceous sediments of the Triassic Skagerrak Formation was drilled. The interval was a monotonous sequence of clastics, with the typical continental red iron colour. At 3116 m the top of the Permian evaporites of the Zechstein Group was touched and penetrated until the depth of 3151 m (TD). Two cores were cut in the Heather Formation, the first from 2855 m to 2873 m, and the second from 2925 m to 2934 m. No fluid samples were taken. The well was permanently abandoned on 14 July 1986 as a dry hole.
    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]
    510.00
    3147.00

  • 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
    2855.0
    2873.0
    [m ]
    2
    2925.0
    2934.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    27.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2855-2859m
    Core photo at depth: 2860-2864m
    Core photo at depth: 2865-2869m
    Core photo at depth: 2870-2872m
    Core photo at depth: 2925-2929m
    2855-2859m
    2860-2864m
    2865-2869m
    2870-2872m
    2925-2929m
    Core photo at depth: 2930-2933m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2930-2933m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2760.2
    [m]
    SWC
    RRI
    2793.0
    [m]
    DC
    RRI
    2798.4
    [m]
    SWC
    RRI
    2799.0
    [m]
    DC
    RRI
    2811.5
    [m]
    SWC
    RRI
    2814.0
    [m]
    DC
    RRI
    2826.0
    [m]
    DC
    RRI
    2841.0
    [m]
    DC
    RRI
    2844.0
    [m]
    DC
    RRI
    2855.0
    [m]
    C
    RRI
    2860.0
    [m]
    C
    RRI
    2864.0
    [m]
    C
    RRI
    2867.0
    [m]
    C
    RRI
    2873.0
    [m]
    C
    RRI
    2874.0
    [m]
    DC
    RRI
    2877.0
    [m]
    DC
    RRI
    2889.0
    [m]
    DC
    RRI
    2892.0
    [m]
    DC
    RRI
    2903.0
    [m]
    SWC
    RRI
    2907.0
    [m]
    DC
    RRI
    2910.0
    [m]
    DC
    RRI
    2924.0
    [m]
    DC
    RRI
    2926.0
    [m]
    C
    RRI
    2929.0
    [m]
    C
    RRI
    2932.0
    [m]
    C
    RRI
    2934.0
    [m]
    C
    RRI
    2949.0
    [m]
    DC
    RRI
    2953.5
    [m]
    DC
    RRI
    2964.0
    [m]
    DC
    RRI
    2975.0
    [m]
    SWC
    RRI
    2979.0
    [m]
    DC
    RRI
    2994.0
    [m]
    DC
    RRI
    3007.6
    [m]
    SWC
    RRI
    3009.0
    [m]
    DC
    RRI
    3018.5
    [m]
    SWC
    RRI
    3024.0
    [m]
    DC
    RRI
    3028.1
    [m]
    SWC
    RRI
    3036.0
    [m]
    DC
    RRI
    3042.0
    [m]
    DC
    RRI
    3063.0
    [m]
    DC
    RRI
    3066.0
    [m]
    DC
    RRI
    3081.0
    [m]
    DC
    RRI
    3100.0
    [m]
    DC
    RRI
    3108.0
    [m]
    SWC
    RRI
    3114.0
    [m]
    DC
    RRI
    3129.0
    [m]
    DC
    RRI
    3144.0
    [m]
    DC
    RRI
    3151.0
    [m]
    DC
    RRI

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.53

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    4.38

  • 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
    61.92

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    100
    1396
    CBL VDL GR
    950
    2777
    CST
    2780
    3142
    DIL BHC GR
    161
    392
    DIL SLS GR
    407
    1315
    DITE SLS GR
    1396
    2798
    DITE SLS GR
    2777
    3150
    GR
    104
    161
    LDT CNL NGS
    2777
    3150
    MWD - GR RES DIR
    407
    1405
    MWD - GR RES DIR
    1396
    2798
    MWD - GR RES DIR
    2777
    3150
    RFT
    2803
    3120
    SHDT GR
    1396
    2798
    SHDT GR
    2777
    3150
    VSP
    400
    3150

  • 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
    195.0
    36
    195.0
    0.00
    LOT
    SURF.COND.
    20
    505.0
    26
    522.0
    1.61
    LOT
    INTERM.
    13 3/8
    1409.0
    17 1/2
    1424.0
    1.82
    LOT
    INTERM.
    9 5/8
    2540.0
    12 1/4
    2565.0
    1.82
    LOT
    OPEN HOLE
    3151.0
    8 1/2
    3151.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    109
    1.10
    WATER BASED
    23.05.1986
    146
    1.10
    WATER BASED
    23.05.1986
    196
    1.10
    WATER BASED
    05.06.1986
    218
    1.05
    WATER BASED
    05.06.1986
    329
    1.05
    WATER BASED
    05.06.1986
    400
    1.05
    WATER BASED
    05.06.1986
    515
    1.05
    WATERBASED
    05.06.1986
    515
    1.15
    15.0
    3.0
    WATER BASED
    05.06.1986
    536
    1.15
    15.0
    3.0
    WATER BASED
    05.06.1986
    619
    1.16
    17.0
    6.0
    WATER BASED
    05.06.1986
    715
    1.16
    17.0
    6.0
    WATER BASED
    05.06.1986
    811
    1.18
    18.0
    7.0
    WATER BASED
    05.06.1986
    831
    1.20
    19.0
    7.5
    WATERBASED
    05.06.1986
    918
    1.22
    19.0
    7.5
    WATER BASED
    05.06.1986
    1054
    1.22
    19.0
    7.5
    WATER BASED
    05.06.1986
    1121
    1.21
    20.0
    9.0
    WATER BASED
    08.06.1986
    1207
    1.24
    23.0
    6.0
    WATER BASED
    08.06.1986
    1419
    1.24
    28.5
    6.5
    WATER BASED
    08.06.1986
    1424
    1.23
    21.0
    8.0
    WATER BASED
    11.06.1986
    1515
    1.27
    23.0
    6.0
    WATER BASED
    11.06.1986
    1582
    1.27
    23.0
    6.0
    WATER BASED
    11.06.1986
    1621
    1.27
    24.0
    8.0
    WATER BASED
    15.06.1986
    1718
    1.27
    24.0
    8.0
    WATER BASED
    15.06.1986
    1734
    1.27
    24.0
    8.0
    WATER BASED
    15.06.1986
    1740
    1.32
    23.0
    6.5
    WATER BASED
    15.06.1986
    1824
    1.32
    19.0
    6.0
    WATER BASED
    15.06.1986
    1873
    1.32
    16.0
    4.0
    WATER BASED
    15.06.1986
    1923
    1.32
    16.0
    4.5
    WATER BASED
    15.06.1986
    1970
    1.37
    23.0
    6.0
    WATER BASED
    15.06.1986
    1988
    1.37
    23.0
    6.0
    WATER BASED
    15.06.1986
    2027
    1.42
    23.0
    6.0
    WATER BASED
    15.06.1986
    2080
    1.42
    32.0
    9.0
    WATER BASED
    15.06.1986
    2125
    1.42
    30.0
    10.5
    WATER BASED
    16.06.1986
    2229
    1.42
    27.0
    7.0
    WATER BASED
    17.06.1986
    2243
    1.42
    27.0
    7.0
    WATER BASED
    17.06.1986
    2257
    1.42
    34.0
    15.0
    WATER BASED
    17.06.1986
    2349
    1.42
    39.0
    18.0
    WATER BASED
    18.06.1986
    2422
    1.42
    38.0
    16.0
    WATER BASED
    19.06.1986
    2604
    1.25
    15.0
    7.0
    WATER BASED
    26.06.1986
    2639
    1.30
    18.0
    7.5
    WATER BASED
    29.06.1986
    2695
    1.30
    20.0
    6.0
    WATER BASED
    29.06.1986
    2759
    1.30
    20.0
    5.5
    WATER BASED
    29.06.1986
    2782
    1.30
    20.0
    6.5
    WATER BASED
    30.06.1986
    2824
    1.35
    21.0
    6.0
    WATER BASED
    30.06.1986
    2857
    1.35
    24.0
    6.5
    WATER BASED
    01.07.1986
    2873
    1.35
    21.0
    6.5
    WATER BASED
    02.07.1986
    2908
    1.35
    20.0
    6.0
    WATER BASED
    03.07.1986
    2983
    1.35
    25.0
    7.5
    WATER BASED
    06.07.1986
    3083
    1.35
    24.0
    6.5
    WATER BASED
    06.07.1986
    3151
    1.35
    21.0
    6.5
    WATER BASED
    08.07.1986