Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
25.12.2024 - 01:26
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30/6-8

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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.
    30/6-8
    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.
    30/6-8
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    703 - 125 SP 205
    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 Hydro Produksjon 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.
    333-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.
    53
    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,
    15.06.1982
    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.
    06.08.1982
    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.
    06.08.1984
    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.
    29.03.2014
    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.
    121.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3600.0
    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).
    3600.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    104
    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 JURASSIC
    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.
    STATFJORD GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 32' 11.92'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 58' 20.59'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6711336.90
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    498484.70
    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.
    77

  • Wellbore history
    General
    Well 30/6-8 was drilled on the Epsilon structure between the Oseberg and Brage discoveries. At the well location seismic mapping indicated structural closure at Brent Group level and below. The primary objectives were to find hydrocarbon accumulations within the Brent Group and the overlying clastic wedge of Bathonian-Callovian age. Other Jurassic sandstones were also considered as prospective targets. The well was planned to reach ca 3500 m total depth, 75m into the Statfjord Group.
    Operations and results
    Wildcat well 30/6-8 was spudded with the semi-submersible installation Treasure Seeker on 15 June 1982 and drilled to TD at 3600 m in the Early Jurassic Statfjord Formation. A 17 1/2" pilot hole was drilled from 232 m to 950 m. No shallow gas was reported. No serious problems occurred while drilling. The well was drilled with seawater and hi-vis pills down to 232 m, with seawater/hi-vis pills and Drispac from 232 m to 955 m, and with KCl/polymer mud from 955 m to TD.
    No hydrocarbon bearing sandstone intervals were encountered in this well. The only hydrocarbon indications were fluorescence and cut fluorescence in sandstone cuttings at 3560 to 3563 m in the Statfjord Group and trace fluorescence, no cut, in sidewall cores at 3147 and 3154 m in the Etive Formation. The well penetrated an Intra Heather Formation Sandstone interval (2445.5 - 2523.5 m) with 10.6 m net with average porosity of 15.7 %. A Callovian wedge (2712.5 - 3024 m) was encountered by the well, but no clastic sediments with reservoir properties were found within the wedge. A total of 147 m of Brent Group (3024 - 3171 m) sediments were encountered. Net sand was 45.9 m with an average porosity of 16.1 %. Net sand within the Cook Formation (3349.5 - 3404.5 m) was 2.8 m with average porosity of 15.8 %. The well stopped 73 m into the Statfjord Formation (3532 -3600 m) of which 21.3 m was sand with an average porosity of 10.6 %.
    The pressure regimes of the four different water saturated reservoirs were calculated from RFT-measurements. The "Intra Heather Sand" shows a normal pressure of approx. 1.03 rd. The Brent, Cook and Statfjord sand intervals have overpressures of respectively 1.08 rd, 1.15 rd and 1.16 rd.
    Four cores were cut. Core 1 was cut in the Late Jurassic Heather Formation from 2768.0 to 2786.0 m. Cores 2 and 3 were cut from 3033 to 3069.1 m in the Tarbert and Ness formations. Core 4 was cut from 3156 to 3169.9 m in the Etive Formation. No wire line fluid samples were taken.
    The well was permanently abandoned on 6 August 1982 as a dry well.
    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]
    240.00
    3593.00

  • 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
    2768.0
    2784.6
    [m ]
    2
    3033.0
    3050.9
    [m ]
    3
    3051.1
    3067.7
    [m ]
    4
    3156.0
    3168.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    63.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2768-2772m
    Core photo at depth: 2772-2776m
    Core photo at depth: 2776-2780m
    Core photo at depth: 2780-2784m
    Core photo at depth: 2784-2785m
    2768-2772m
    2772-2776m
    2776-2780m
    2780-2784m
    2784-2785m
    Core photo at depth: 3033-3037m
    Core photo at depth: 3037-3041m
    Core photo at depth: 3041-3045m
    Core photo at depth: 3045-3049m
    Core photo at depth: 3049-3050m
    3033-3037m
    3037-3041m
    3041-3045m
    3045-3049m
    3049-3050m
    Core photo at depth: 3051-3055m
    Core photo at depth: 3055-3059m
    Core photo at depth: 3059-3063m
    Core photo at depth: 3063-3067m
    Core photo at depth: 3067-3067m
    3051-3055m
    3055-3059m
    3059-3063m
    3063-3067m
    3067-3067m
    Core photo at depth: 3156-3160m
    Core photo at depth: 3160-3164m
    Core photo at depth: 3164-3168m
    Core photo at depth: 3168-3168m
    Core photo at depth: 2035-2941m
    3156-3160m
    3160-3164m
    3164-3168m
    3168-3168m
    2035-2941m
    Core photo at depth: 2931-2933m
    Core photo at depth: 2946-2951m
    Core photo at depth: 2964-2964m
    Core photo at depth:  
    Core photo at depth:  
    2931-2933m
    2946-2951m
    2964-2964m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    250.0
    [m]
    DC
    RRI
    450.0
    [m]
    DC
    RRI
    650.0
    [m]
    DC
    RRI
    1050.0
    [m]
    DC
    RRI
    1250.0
    [m]
    DC
    RRI
    1450.0
    [m]
    DC
    RRI
    1650.0
    [m]
    DC
    RRI
    1850.0
    [m]
    DC
    RRI
    2045.0
    [m]
    DC
    RRI
    2245.0
    [m]
    DC
    RRI
    2300.0
    [m]
    SWC
    RRI
    2312.0
    [m]
    SWC
    RRI
    2370.0
    [m]
    DC
    RRI
    2380.0
    [m]
    DC
    RRI
    2383.0
    [m]
    SWC
    RRI
    2390.0
    [m]
    SWC
    RRI
    2395.0
    [m]
    SWC
    RRI
    2400.0
    [m]
    DC
    RRI
    2404.0
    [m]
    SWC
    RRI
    2410.0
    [m]
    SWC
    RRI
    2416.0
    [m]
    SWC
    RRI
    2420.0
    [m]
    DC
    RRI
    2436.0
    [m]
    SWC
    RRI
    2440.0
    [m]
    DC
    RRI
    2449.5
    [m]
    SWC
    RRI
    2455.0
    [m]
    SWC
    RRI
    2461.5
    [m]
    SWC
    RRI
    2484.0
    [m]
    SWC
    RRI
    2508.5
    [m]
    SWC
    RRI
    2538.0
    [m]
    SWC
    RRI
    2558.0
    [m]
    SWC
    RRI
    2567.5
    [m]
    SWC
    RRI
    2574.0
    [m]
    SWC
    RRI
    2593.0
    [m]
    SWC
    RRI
    2600.0
    [m]
    DC
    RRI
    2629.5
    [m]
    SWC
    RRI
    2645.5
    [m]
    SWC
    RRI
    2664.5
    [m]
    SWC
    RRI
    2678.8
    [m]
    SWC
    RRI
    2691.5
    [m]
    SWC
    RRI
    2700.5
    [m]
    SWC
    RRI
    2710.0
    [m]
    SWC
    RRI
    2719.5
    [m]
    SWC
    RRI
    2768.8
    [m]
    C
    RRI
    2773.6
    [m]
    C
    RRI
    2776.5
    [m]
    C
    RRI
    2784.6
    [m]
    C
    RRI
    2792.0
    [m]
    SWC
    RRI
    2815.5
    [m]
    SWC
    RRI
    2840.0
    [m]
    DC
    RRI
    2860.0
    [m]
    SWC
    RRI
    2880.5
    [m]
    SWC
    RRI
    2940.0
    [m]
    DC
    RRI
    2941.5
    [m]
    SWC
    RRI
    2953.5
    [m]
    SWC
    RRI
    2966.5
    [m]
    SWC
    RRI
    2980.0
    [m]
    SWC
    RRI
    3028.5
    [m]
    SWC
    RRI
    3033.8
    [m]
    C
    RRI
    3033.9
    [m]
    C
    RRI
    3038.1
    [m]
    C
    RRI
    3046.4
    [m]
    C
    RRI
    3056.6
    [m]
    C
    RRI
    3062.2
    [m]
    C
    RRI
    3065.3
    [m]
    C
    RRI
    3072.5
    [m]
    SWC
    RRI
    3079.5
    [m]
    SWC
    RRI
    3099.0
    [m]
    SWC
    RRI
    3114.5
    [m]
    SWC
    RRI
    3120.0
    [m]
    DC
    RRI
    3123.5
    [m]
    SWC
    RRI
    3135.5
    [m]
    SWC
    RRI
    3147.5
    [m]
    SWC
    RRI
    3167.8
    [m]
    C
    RRI
    3168.7
    [m]
    C
    RRI
    3173.0
    [m]
    SWC
    RRI
    3182.0
    [m]
    SWC
    RRI
    3228.5
    [m]
    SWC
    RRI
    3230.0
    [m]
    DC
    RRI
    3249.5
    [m]
    SWC
    RRI
    3263.5
    [m]
    SWC
    RRI
    3309.0
    [m]
    SWC
    RRI
    3330.0
    [m]
    DC
    RRI
    3335.0
    [m]
    SWC
    RRI
    3355.5
    [m]
    SWC
    RRI
    3357.5
    [m]
    SWC
    RRI
    3386.0
    [m]
    SWC
    RRI
    3405.0
    [m]
    SWC
    RRI
    3418.5
    [m]
    SWC
    RRI
    3430.0
    [m]
    DC
    RRI
    3463.0
    [m]
    SWC
    RRI
    3476.0
    [m]
    SWC
    RRI
    3492.0
    [m]
    SWC
    RRI
    3510.0
    [m]
    DC
    RRI
    3515.0
    [m]
    SWC
    RRI
    3585.0
    [m]
    SWC
    RRI

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    787
    2403
    CST
    1150
    1996
    CST
    2012
    2410
    CST
    2395
    2416
    CST
    2414
    2719
    CST
    2428
    3099
    CST
    2750
    2719
    CST
    3135
    3595
    HDT
    941
    3605
    ISF LSS
    120
    3604
    LDT CNL
    941
    3605
    RFT
    2452
    3597
    VELOCITY
    670
    3587

  • 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
    232.0
    36
    232.0
    0.00
    LOT
    SURF.COND.
    20
    941.0
    26
    955.0
    1.59
    LOT
    INTERM.
    13 3/8
    2403.0
    17 1/2
    2414.0
    1.79
    LOT
    OPEN HOLE
    3600.0
    12 1/4
    3600.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    980
    1.25
    55.0
    waterbased
    1350
    1.25
    44.0
    waterbased
    1960
    1.35
    44.0
    waterbased
    2180
    1.45
    22.0
    waterbased
    2420
    1.23
    35.0
    waterbased
    3100
    1.23
    35.0
    waterbased
    3430
    1.27
    12.0
    waterbased
    3560
    1.32
    40.0
    waterbased

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    2769.00
    [m ]
    2772.00
    [m ]
    2778.00
    [m ]
    2783.00
    [m ]

  • 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
    0.23