Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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33/9-18 A

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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.
    33/9-18 A
    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
    Multilateral
    Indicator telling if the parent well is multilateral, meaning it has more than one branch radiating from the main borehole. Example of legal values: YES, NO. See also Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    NO
    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.
    33/9-18
    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.
    Den norske stats oljeselskap a.s
    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.
    800-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.
    35
    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,
    21.12.1994
    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.
    24.01.1995
    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.
    24.01.1997
    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.
    01.07.2004
    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
    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.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    145.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3595.0
    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).
    3195.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    100
    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 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.
    DRAUPNE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 15' 40.78'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 56' 7.73'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6792522.53
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    442897.08
    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.
    2455

  • Wellbore history
    General
    Well 33/9-18 A was drilled to a structure situated east of the Statfjord Field and south-west of the Tordis Field. The main objective of well 33/9-18 A was to test the lithology of a strong seismic amplitude within the same prospect as drilled in well 33/9-18. Well 33/9-18 A is a sidetrack from well 33/9-18.
    Operations and results
    Exploration well 33/9-18 A was spudded on 21 December 1994 with the semi-submersible installation Deepsea Bergen and drilled from kick-off at 1974 m to TD at 3597 m in the Late Jurassic Draupne Formation. The 12 1/4" hole section was drilled with KC1/PAC POLYMER and KCl mud system to prevent bit balling. No shallow gas was recorded.
    Parts of the 12 1/4" section have anomalous resistivity data. The MWD data records from 3070 m to TD are missing, due to washout, lost signal, stuck pipe and MWD tool lost in hole. No wireline logging was performed. 1 core was cut in the Draupne Formation the interval 3397-3404.5 m. No fluid samples were collected. Bit balling was observed several times and a lot of pills were pumped to prevent balling, but minor effects were observed. Dyno-CC-115 (soap) pills showed best results. Drilling from 3145 m to 3397 m had to stop after 49 m due to bad weather. Drilling continued after 7 days stop and the flow rate was increased to maintain a pressure of 280 bar. At TD the actual pressure was nearly 100 bar less than the "theoretical" pressure. This pressure drop was caused by wash out between two drill collars. Got differential stuck at 3512 m when pulling out of the hole. Cut the string at 3382 m to get free. Extra cost related to logistics is estimated to approximately 3.3 mill. NOK. The well was plugged and abandoned after being stuck for 83.5 hrs.
    The well has been interpreted to penetrate large slump/slide blocks consisting of the Brent Group, the Dunlin Group and the Statfjord Formation which are deposited within the Draupne Formation. The strong seismic amplitude within the sidetrack 33/9-18 A was penetrated. The amplitude was represented by occasional water wet sandstone and hard shales. No hydrocarbon shows were observed in the well.
    The well 33/9-18 A was permanently plugged and abandoned as a dry well on 24 January 1995.
    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]
    1980.00
    3595.00

  • 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
    3397.0
    3403.1
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    6.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3397-3402m
    Core photo at depth: 3402-3403m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3397-3402m
    3402-3403m

  • 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
    229.0
    36
    230.0
    0.00
    LOT
    INTERM.
    20
    753.0
    26
    755.0
    1.49
    LOT
    INTERM.
    13 3/8
    1951.0
    17 1/2
    1953.0
    1.96
    LOT
    OPEN HOLE
    3595.0
    12 1/4
    3595.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    MWD - RGD
    1974
    3597

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.10

  • 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
    16.10

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    200
    1.03
    29.0
    18.5
    WATER BASED
    25.01.1995
    500
    1.49
    29.0
    18.5
    WATER BASED
    23.01.1995
    500
    1.49
    29.0
    18.5
    WATER BASED
    23.01.1995
    1900
    1.55
    32.0
    11.5
    WATER BASED
    23.12.1994
    2060
    1.62
    45.0
    20.0
    WATER BASED
    23.12.1994
    2235
    1.62
    45.0
    20.0
    WATER BASED
    28.12.1994
    2285
    1.62
    45.0
    20.0
    WATER BASED
    28.12.1994
    2315
    1.60
    45.0
    20.0
    WATER BASED
    28.12.1994
    2403
    1.60
    45.0
    20.0
    WATER BASED
    28.12.1994
    2549
    1.60
    45.0
    20.0
    WATER BASED
    28.12.1994
    2621
    1.62
    45.0
    20.0
    WATER BASED
    28.12.1994
    2795
    1.63
    45.0
    20.0
    WATER BASED
    29.12.1994
    2992
    1.63
    32.0
    15.0
    WATER BASED
    02.01.1995
    3145
    1.63
    34.0
    16.5
    WATER BASED
    03.01.1995
    3194
    1.63
    30.0
    13.0
    WATER BASED
    05.01.1995
    3194
    1.63
    32.0
    15.0
    WATER BASED
    03.01.1995
    3194
    1.63
    30.0
    13.0
    WATER BASED
    03.01.1995
    3194
    1.63
    30.0
    13.0
    WATER BASED
    03.01.1995
    3194
    1.63
    30.0
    16.0
    WATER BASED
    05.01.1995
    3194
    1.63
    30.0
    15.5
    WATER BASED
    10.01.1995
    3194
    1.63
    31.0
    15.5
    WATER BASED
    10.01.1995
    3194
    1.63
    31.0
    15.5
    WATER BASED
    10.01.1995
    3200
    1.63
    32.0
    15.0
    WATER BASED
    10.01.1995
    3200
    1.63
    30.0
    18.0
    WATER BASED
    10.01.1995
    3200
    1.63
    30.0
    15.5
    WATER BASED
    12.01.1995
    3200
    1.63
    32.0
    17.0
    WATER BASED
    12.01.1995
    3200
    1.63
    31.0
    18.0
    WATER BASED
    13.01.1995
    3200
    1.63
    30.0
    16.0
    WATER BASED
    16.01.1995
    3200
    1.63
    29.0
    18.5
    WATER BASED
    16.01.1995
    3200
    1.63
    29.0
    18.5
    WATER BASED
    23.01.1995
    3200
    1.63
    29.0
    18.0
    WATER BASED
    17.01.1995
    3200
    1.63
    30.0
    19.0
    WATER BASED
    18.01.1995
    3200
    1.63
    29.0
    18.5
    WATER BASED
    20.01.1995
    3200
    1.63
    29.0
    18.5
    WATER BASED
    20.01.1995
    3200
    1.63
    29.0
    18.0
    WATER BASED
    16.01.1995
    3252
    1.63
    32.0
    15.0
    WATER BASED
    10.01.1995
    3397
    1.63
    30.0
    18.0
    WATER BASED
    10.01.1995
    3405
    1.63
    30.0
    15.5
    WATER BASED
    12.01.1995
    3405
    1.63
    32.0
    17.0
    WATER BASED
    12.01.1995
    3457
    1.63
    31.0
    18.0
    WATER BASED
    13.01.1995
    3553
    1.63
    30.0
    16.0
    WATER BASED
    16.01.1995
    3597
    1.63
    29.0
    18.5
    WATER BASED
    16.01.1995
    3597
    1.63
    29.0
    18.0
    WATER BASED
    16.01.1995
    3597
    1.63
    29.0
    18.0
    WATER BASED
    17.01.1995
    3597
    1.63
    29.0
    18.5
    WATER BASED
    23.01.1995
    3597
    1.63
    29.0
    18.5
    WATER BASED
    20.01.1995
    3597
    1.63
    29.0
    18.5
    WATER BASED
    20.01.1995
    3597
    1.63
    30.0
    19.0
    WATER BASED
    18.01.1995

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3200.0
    [m]
    DC
    RRI
    3215.0
    [m]
    DC
    RRI
    3230.0
    [m]
    DC
    RRI
    3248.0
    [m]
    DC
    RRI
    3260.0
    [m]
    DC
    RRI
    3275.0
    [m]
    DC
    RRI
    3290.0
    [m]
    DC
    RRI
    3310.0
    [m]
    DC
    RRI
    3325.0
    [m]
    DC
    RRI
    3340.0
    [m]
    DC
    RRI
    3355.0
    [m]
    DC
    RRI
    3370.0
    [m]
    DC
    RRI
    3380.0
    [m]
    DC
    RRI
    3385.0
    [m]
    DC
    RRI
    3390.0
    [m]
    DC
    RRI
    3395.0
    [m]
    DC
    RRI
    3409.0
    [m]
    DC
    RRI
    3415.0
    [m]
    DC
    RRI
    3421.0
    [m]
    DC
    RRI
    3427.0
    [m]
    DC
    RRI
    3434.0
    [m]
    DC
    RRI
    3442.0
    [m]
    DC
    RRI
    3448.0
    [m]
    DC
    RRI
    3454.0
    [m]
    DC
    RRI
    3460.0
    [m]
    DC
    RRI
    3466.0
    [m]
    DC
    RRI
    3472.0
    [m]
    DC
    RRI
    3475.0
    [m]
    DC
    RRI
    3481.0
    [m]
    DC
    RRI
    3487.0
    [m]
    DC
    RRI
    3493.0
    [m]
    DC
    RRI
    3499.0
    [m]
    DC
    RRI
    3505.0
    [m]
    DC
    RRI
    3511.0
    [m]
    DC
    RRI
    3517.0
    [m]
    DC
    RRI
    3523.0
    [m]
    DC
    RRI
    3529.0
    [m]
    DC
    RRI
    3533.0
    [m]
    DC
    RRI
    3535.0
    [m]
    DC
    RRI
    3541.0
    [m]
    DC
    RRI
    3547.0
    [m]
    DC
    RRI
    3559.0
    [m]
    DC
    RRI
    3565.0
    [m]
    DC
    RRI
    3571.0
    [m]
    DC
    RRI
    3577.0
    [m]
    DC
    RRI
    3583.0
    [m]
    DC
    RRI
    3589.0
    [m]
    DC
    RRI
    3595.0
    [m]
    DC
    RRI

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    3397.10
    [m ]
    3402.02
    [m ]
    3402.85
    [m ]