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

15/6-7

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.
    15/6-7
    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.
    15/6-7
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    DX91-156-112 & SP259/DX 91-156-004- SP24
    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.
    Deminex Norge 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.
    758-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.
    46
    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,
    24.04.1993
    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.
    08.06.1993
    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.
    08.06.1995
    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.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    107.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3540.0
    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).
    3539.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    120
    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° 35' 21.41'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 52' 19.06'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6495019.48
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    434420.13
    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.
    2084

  • Wellbore history
    General
    Well 15/6-7 was the first well in licence 166. The primary objective of the well was to test the hydrocarbon potential of the Middle Jurassic, Hugin Formation of Callovian age within a seismically defined structural trap. There were no secondary objectives for the well, however, other potential reservoir horizons, albeit outside closure, were anticipated within the early Tertiary succession. The well programme was designed to maximize the evaluation of these sections as
    required.
    Operations and results
    Exploration well 15/6-7 was spudded on 24 April 1993 with the semi-submersible installation "Vildkat Explorer" and drilled to TD at 3540 m in the Triassic Smith Bank Formation. The well was drilled with gel and seawater down to 505 m, with PHPA/KCl mud from 505 m to 1173 m, with PHPA/KCl/Glycol mud from 1173 m to 2788 m, and with PHPA/KCl mud from 2788 m to TD.
    The Quaternary and Tertiary sequence represented by the Nordland, Hordaland and Rogaland Group is dominated by mudstone lithologies with occasional thick sandstone developments in the Utsira, Grid, and Heimdal Formations. Background gas values ranged from less than 0.1% to 0.5% with rare isolated gas peaks. The Late Cretaceous succession in the well, 493 m thick, is dominated by carbonate lithologies of the Shetland Group; below 3150 m these become increasingly and atypically sandy. A number of gas peaks were recorded over the interval 3025 m to 3157 m with a maximum gas peak of 5.42% recorded at 3154 m. The Early Cretaceous, 14.5 m thick, represented by the Cromer Knoll Group is substantially thinner than anticipated and consists of arenaceous limestones interbedded with thin calcareous sandstones. The Upper Jurassic Draupne Formation was penetrated at 3233 m, 36 m low to prognosis. Intra Draupne Formation Sandstone was encountered at 3292 m. A formation fluid influx of 3.9 m3 equivalent to a calculated pore pressure of 1.5 sg (RFT) occurred at 3327 m (3331 m loggers depth), a gas peak of 0.74% was associated with this influx. The mud weight was increased from 1.30 sg to 1.52 sg during well control operations. The top Heather Formation was penetrated at 3352.5 m, 75.5 m deeper than anticipated. Background gas values within the Draupne and Heather Formations gradually decreased with depth from 4% to 0.18% at the base of the Heather Formation. The primary objective, the Hugin Formation, was penetrated at 3390.5 m, 4.5 m shallower than anticipated. The Hugin Formation consists of interbedded mudstones and sandstones with the sandstone beds increasing in thickness with depth. The well failed to penetrate any hydrocarbon bearing horizons. The primary objective Hugin Formation was water bearing. This was confirmed by RFT and petrophysical evaluation of the logs.
    One conventional core was cut over the interval 3414 m to 3432 m (15.7 m recovered) in the Triassic Skagerrak Formation. Three RFT runs, 3/1,3/2 and 3/3, were performed in the 8.5" hole section in the Draupne, Hugin and Skagerrak Formations, over the interval 3433-3331 m. A segregated sample was taken on run 3/3. The sample recovered 5 l of muddy water in the 6-gallon chamber. The 1-gallon chamber was plugged.
    The well was permanently plugged and abandoned as a dry hole on 8 June 1993.
    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
    3540.00

  • 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
    3414.0
    3429.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    15.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3414-3419m
    Core photo at depth: 3419-3424m
    Core photo at depth: 3424-3429m
    Core photo at depth: 3429-3430m
    Core photo at depth:  
    3414-3419m
    3419-3424m
    3424-3429m
    3429-3430m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1700.0
    [m]
    SWC
    RRI
    1715.0
    [m]
    DC
    RRI
    1725.0
    [m]
    DC
    RRI
    1735.0
    [m]
    SWC
    RRI
    1750.0
    [m]
    SWC
    RRI
    1766.0
    [m]
    SWC
    RRI
    1780.0
    [m]
    DC
    RRI
    1795.0
    [m]
    DC
    RRI
    1805.0
    [m]
    DC
    RRI
    1822.0
    [m]
    SWC
    RRI
    1832.0
    [m]
    SWC
    RRI
    1862.0
    [m]
    SWC
    RRI
    1870.0
    [m]
    SWC
    RRI
    1880.0
    [m]
    DC
    RRI
    1889.0
    [m]
    SWC
    RRI
    1950.0
    [m]
    DC
    RRI
    1957.0
    [m]
    SWC
    RRI
    1965.0
    [m]
    DC
    RRI
    2022.0
    [m]
    SWC
    RRI
    2030.0
    [m]
    DC
    RRI
    2050.0
    [m]
    DC
    RRI
    2069.0
    [m]
    SWC
    RRI
    2109.0
    [m]
    SWC
    RRI
    2125.0
    [m]
    DC
    RRI
    2140.0
    [m]
    DC
    RRI
    2155.0
    [m]
    DC
    RRI
    2167.0
    [m]
    SWC
    RRI
    2183.0
    [m]
    SWC
    RRI
    2197.0
    [m]
    SWC
    RRI
    2215.0
    [m]
    DC
    RRI
    2230.0
    [m]
    DC
    RRI
    2269.0
    [m]
    SWC
    RRI
    2277.0
    [m]
    SWC
    RRI
    2290.0
    [m]
    DC
    RRI
    2297.0
    [m]
    SWC
    RRI
    2310.0
    [m]
    DC
    RRI
    2325.0
    [m]
    DC
    RRI
    2336.0
    [m]
    SWC
    RRI
    2350.0
    [m]
    DC
    RRI
    2360.0
    [m]
    DC
    RRI
    2370.0
    [m]
    SWC
    RRI
    2385.0
    [m]
    DC
    RRI
    2394.0
    [m]
    SWC
    RRI
    2425.0
    [m]
    DC
    RRI
    2440.0
    [m]
    DC
    RRI
    2463.0
    [m]
    SWC
    RRI
    2473.0
    [m]
    SWC
    RRI
    2490.0
    [m]
    DC
    RRI
    2505.0
    [m]
    DC
    RRI
    2530.0
    [m]
    DC
    RRI
    2537.0
    [m]
    SWC
    RRI
    2555.0
    [m]
    DC
    RRI
    2570.0
    [m]
    DC
    RRI
    2585.0
    [m]
    DC
    RRI
    2597.0
    [m]
    SWC
    RRI
    2607.0
    [m]
    SWC
    RRI
    2613.0
    [m]
    SWC
    RRI
    2625.0
    [m]
    DC
    RRI
    2640.0
    [m]
    DC
    RRI
    2650.0
    [m]
    DC
    RRI
    2660.0
    [m]
    SWC
    RRI
    2675.0
    [m]
    DC
    RRI
    3163.0
    [m]
    SWC
    RRI
    3175.0
    [m]
    SWC
    RRI
    3195.0
    [m]
    SWC
    RRI
    3209.5
    [m]
    SWC
    RRI
    3215.5
    [m]
    SWC
    RRI
    3236.0
    [m]
    SWC
    RRI
    3244.5
    [m]
    SWC
    RRI
    3257.0
    [m]
    SWC
    RRI
    3261.0
    [m]
    DC
    RRI
    3281.0
    [m]
    SWC
    RRI
    3291.5
    [m]
    SWC
    RRI
    3306.0
    [m]
    DC
    RRI
    3318.0
    [m]
    DC
    RRI
    3336.0
    [m]
    SWC
    RRI
    3354.0
    [m]
    DC
    RRI
    3374.0
    [m]
    SWC
    RRI
    3408.0
    [m]
    DC
    RRI
    3411.0
    [m]
    DC
    RRI
    3414.0
    [m]
    DC
    RRI
    3418.0
    [m]
    C
    RRI
    3420.7
    [m]
    C
    RRI
    3423.1
    [m]
    C
    RRI
    3429.7
    [m]
    C
    RRI

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.66

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.99
    pdf
    0.45

  • 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
    35.51

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR CCL
    2282
    2765
    CST GR
    1350
    2602
    CST GR
    1372
    2732
    CST GR
    3019
    3525
    CST GR
    3156
    3524
    DLL MSFL SDT AS AMS
    2775
    3540
    DLL MSFL SDT AS GR
    492
    1152
    DLL MSFL SDT AS GR SP
    1157
    2768
    LDL CNL NGS AMS
    1157
    2764
    LDL CNL NGS AMS
    2775
    3543
    MWD - BGD
    132
    505
    MWD - BGD GR
    505
    1173
    MWD - DPR
    2800
    3146
    MWD - DPR
    3409
    3536
    MWD - RDG
    3246
    3410
    MWD - RGD
    1173
    2788
    RFT
    3331
    3433
    SHDT FMS GR AMS
    3098
    3544
    SHDT GR AMS
    1700
    2715
    VSP AMS
    1085
    3515

  • 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
    217.0
    36
    220.0
    0.00
    LOT
    INTERM.
    20
    492.0
    26
    505.0
    1.36
    LOT
    INTERM.
    13 3/8
    1157.0
    17 1/2
    1173.0
    1.84
    LOT
    INTERM.
    9 5/8
    2773.0
    12 1/4
    2788.0
    1.74
    LOT
    OPEN HOLE
    3540.0
    8 1/2
    3540.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    180
    1.03
    WATER BASED
    220
    1.05
    WATER BASED
    505
    1.20
    WATER BASED
    1173
    1.14
    190.0
    WATER BASED
    2067
    1.30
    170.0
    WATER BASED
    2100
    1.30
    180.0
    WATER BASED
    2213
    1.30
    220.0
    WATER BASED
    2440
    1.30
    180.0
    WATER BASED
    2614
    1.30
    180.0
    WATER BASED
    2690
    1.30
    190.0
    WATER BASED
    2700
    1.30
    130.0
    WATER BASED
    2700
    1.54
    230.0
    WATER BASED
    2788
    1.30
    290.0
    WATER BASED
    3120
    1.30
    180.0
    WATER BASED
    3226
    1.50
    260.0
    WATER BASED
    3414
    1.52
    200.0
    WATER BASED
    3540
    1.52
    230.0
    WATER BASED

  • 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