Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.11.2024 - 09:09
Time of last synchronization with Norwegian Offshore Directorate's internal systems

16/10-2

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.
    16/10-2
    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.
    16/10-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NA85 - 6 & SP. 910
    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.
    685-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.
    43
    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,
    20.06.1991
    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.
    01.08.1991
    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.
    01.08.1993
    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.
    79.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3150.0
    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).
    3148.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    117
    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.
    SKAGERRAK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 8' 26.58'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 2' 14.91'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6444927.85
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    443327.64
    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.
    1767

  • Wellbore history
    General
    Block 16/10 is located in a structurally complex area between the Viking Graben, the Central Graben, the Witch Ground Graben and the Ling Graben.  Well 16/10-2 is the second well drilled in block 16/10 PL 101 operated by Norsk Agip; the first one 16/10-1 was drilled May-July 1986. The purpose of the well was to test the hydrocarbon potential of the "Delta" structure located in the west part of 16/10 block. This structure is a tilted fault block elongated north-south bounded to the west by a north-south trending normal fault, and dip-closing to the north, east and south. It was interpreted as the largest structure in block 16/10 in terms of possible oil reserves. The structure is not salt-induced and being one of the oldest in this area it was also considered prospective for possible early migration. The Upper Jurassic and the Lower Cretaceous shales constituted the seal rocks for the geological model. The main and the secondary targets were respectively the "Oxfordian Sandstones" (Upper Jurassic) and the Triassic sandstones of the Skagerrak Formation that had been found hydrocarbon bearing in the nearby blocks in wells 6/3-1, 15/12-5, 15/12-4, 15/12-8, 15/12-6 and 16/7-4.
    Operations and results
    Exploration well 16/10-2 was spudded with the semi-submersible installation Byford Dolphin on 20 June 1991 and drilled to a total depth of 3150 m in the Triassic sandstones of the Skagerrak Formation. The well was drilled with seawater and gel down to 417 m, with Seawater and gypsum polymer from 417 m to 2798 m and with Bentonite/Anco Temp mud from 2798 m to TD.
    The Quaternary/Tertiary sequence constituted predominantly marine claystones of the Nordland, Hordaland and Rogaland Groups. The Cretaceous sequence was mainly represented by limestones of the Chalk Group and by the reddish claystones and calcareous marls of the Cromer Knoll Group that overlay the Base Cretaceous Unconformity found at 2818 m. The Upper Jurassic sequence consisted of 35 m darkish/brown shales belonging to the Draupne Formation overlying 70 m of the "Oxfordian Sandstones" (Hugin Formation).  This reservoir showed a larger sand development than in 16/10-1 well where only 33 m sand was encountered. The top of the "Oxfordian Sandstones" was encountered at 2853 m. Below the sand, from 2923 m to TD, Triassic continental sandstones of the Skagerrak Formation were encountered. The geological results of 16/10-2 well were in good agreement with the structural and stratigraphic models expected. The targets (i.e. Oxfordian Sandstone and Skagerrak Fm.) were found water bearing and no hydrocarbon bearing level or relevant shows were encountered in the well. Conventional cores were not taken. A RFT segregated sample at 2876 m recovered only water and mud filtrate.
    The well was permanently abandoned as a dry well on 1 August 1991.
    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]
    420.00
    3150.00

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.35

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    2.48

  • 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
    53.73

  • 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
    104
    161
    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
    161.0
    36
    163.0
    0.00
    LOT
    INTERM.
    20
    407.0
    26
    417.0
    1.64
    LOT
    INTERM.
    13 3/8
    1397.0
    17 1/2
    1405.0
    1.80
    LOT
    INTERM.
    9 5/8
    2777.0
    12 1/4
    2798.0
    1.86
    LOT
    OPEN HOLE
    3150.0
    8 1/2
    3150.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    161
    1.05
    WATER BASED
    21.06.1991
    275
    1.05
    WATER BASED
    24.06.1991
    417
    1.04
    WATER BASED
    24.06.1991
    417
    1.09
    WATER BASED
    24.06.1991
    417
    1.05
    13.0
    7.5
    WATER BASED
    27.06.1991
    628
    1.12
    12.0
    5.0
    WATER BASED
    27.06.1991
    896
    1.18
    15.0
    6.0
    WATER BASED
    28.06.1991
    920
    1.19
    15.0
    5.0
    WATER BASED
    01.07.1991
    920
    1.19
    15.0
    5.0
    WATER BASED
    29.06.1993
    1033
    1.22
    15.0
    5.0
    WATER BASED
    29.06.1993
    1033
    1.22
    15.0
    5.0
    WATER BASED
    01.07.1991
    1100
    1.22
    16.0
    4.5
    WATER BASED
    01.07.1991
    1100
    1.22
    16.0
    4.5
    WATER BASED
    29.06.1993
    1277
    1.22
    13.0
    4.0
    WATER BASED
    01.07.1991
    1307
    1.24
    17.0
    5.0
    WATER BASED
    01.07.1991
    1405
    1.25
    17.0
    6.0
    WATER BASED
    01.07.1991
    1405
    1.25
    19.0
    6.0
    WATER BASED
    01.07.1991
    1405
    1.25
    18.0
    4.0
    WATER BASED
    02.07.1991
    1405
    1.25
    16.0
    4.0
    WATER BASED
    03.07.1991
    1498
    1.32
    12.0
    3.0
    DUMMY
    04.07.1991
    1513
    1.40
    17.0
    6.0
    DUMMY
    04.07.1991
    1826
    1.40
    21.0
    8.0
    DUMMY
    05.07.1991
    1850
    1.40
    18.0
    5.5
    DUMMY
    08.07.1991
    2050
    1.40
    17.0
    5.0
    DUMMY
    08.07.1991
    2176
    1.40
    27.0
    6.0
    DUMMY
    08.07.1991
    2430
    1.50
    29.5
    6.5
    DUMMY
    08.07.1991
    2438
    1.50
    22.0
    5.0
    DUMMY
    09.07.1991
    2459
    1.55
    27.0
    7.0
    DUMMY
    10.07.1991
    2459
    1.55
    26.0
    5.0
    DUMMY
    11.07.1991
    2524
    1.55
    22.0
    5.0
    DUMMY
    15.07.1991
    2533
    1.55
    53.0
    4.0
    DUMMY
    15.07.1991
    2585
    1.55
    26.0
    6.0
    DUMMY
    15.07.1991
    2651
    1.55
    27.0
    6.0
    DUMMY
    15.07.1991
    2699
    1.55
    29.0
    7.0
    WATHER BASED
    16.07.1991
    2708
    1.55
    27.0
    6.0
    WATHER BASED
    17.07.1991
    2756
    1.55
    32.0
    8.0
    WATHER BASED
    18.07.1991
    2780
    1.55
    29.0
    6.0
    WATHER BASED
    19.07.1991
    2798
    1.55
    28.0
    6.5
    WATHER BASED
    22.07.1991
    2798
    1.55
    28.0
    6.0
    WATHER BASED
    22.07.1991
    2798
    1.55
    27.0
    7.0
    WATHER BASED
    22.07.1991
    2798
    1.55
    27.0
    7.0
    WATHER BASED
    23.07.1991
    2798
    1.30
    14.0
    3.0
    WATHER BASED
    24.07.1991
    2841
    1.31
    15.0
    6.5
    WATHER BASED
    25.07.1991
    2953
    1.30
    20.0
    6.0
    WATHER BASED
    26.07.1991
    3150
    1.31
    27.0
    7.0
    WATHER BASED
    29.07.1991
    3150
    1.30
    23.0
    6.5
    WATHER BASED
    29.07.1991

  • 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
    0.21