Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
25.11.2024 - 01:30
Time of last synchronization with Norwegian Offshore Directorate's internal systems

34/7-17 A

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.
    34/7-17 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).
    APPRAISAL
    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
    Field
    Name of the field the wellbore is related to.
    Discovery
    Name of the discovery the wellbore is related to.
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    34/7-17
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    GE-83 ROW 341 COL 1025
    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.
    Saga Petroleum ASA
    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.
    677-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.
    28
    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,
    07.04.1991
    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.
    04.05.1991
    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.
    04.05.1993
    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.
    28.02.2008
    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.
    APPRAISAL
    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.
    OIL/GAS
    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
    1st level with HC, age
    Age of lithostratigraphic unit, 1st level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE. See also Norwegian Offshore Directorate bulletins.
    MIDDLE JURASSIC
    1st level with HC, formation
    Name of lithostartigraphic unit, 1st level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP. See also Norwegian Offshore Directorate bulletins.
    TARBERT FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    26.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    259.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2650.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    43
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    96
    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.
    MIDDLE 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.
    ETIVE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 20' 50.69'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 5' 42.31'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6801982.38
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    451591.07
    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.
    1536

  • Wellbore history
    General
    Well 34/7-17 A is a sidetrack to well 34/7-17 on the Vigdis Field on Tampen Spur in the Northern North Sea. In well 34/7-17 the primary target Brent reservoir was encountered 38 m deeper than prognosed and dry with only scattered oil shows. The 34/7-17 A sidetracked well thus aimed primarily at the Brent reservoir in an up-dip position above a possible OWC. According to prognosis Brent should be truncated in this direction. A secondary objective was to test the pressure regimes in the Jurassic sequence, including possible depletion associated with pressure communication, previously identified in the nearby Tordis Field.
    Operations and results
    Well 34/7-17 A was spudded with the semi-submersible installation Treasure Saga on 7 April 1991. Kick off point was at 1994 m below the 13 3/8? casing shoe in well 34/7-17, in the top of the Shetland Group. The target was located up-dip in a south-easterly direction and the sidetrack was drilled deviated from its beginning. The well was drilled without significant technical problems to TD at 2650 m (2557 m TVD) in the Middle Jurassic Etive Formation of the Brent Group. It was drilled with KCl mud from kick off to TD.
    Top Brent Group, Tarbert Formation, was penetrated at 2494.5 m (2439.5 m TVD). Truncation was confirmed by the absence of the Viking Group and erosion into the top of the Brent Group. The Brent Group proved to be oil bearing only in the uppermost 6.5 m TVD with a possible OWC at 2502.5 m (2446 m TVD / 2420 m MSL TVD). Above the reservoir ditch cuttings recorded a continuous sequence with good traces of oil shows between 2235 and Top Brent Group. The interval 2310 to 2370 m also had oil staining and a strong odour of hydrocarbons. No shows were reported below 2506 m.
    One core was cut in the top of the reservoir between 2597 and 2617. Totally 21 m was cut, of which 20 m was recovered.
    Two RFT runs were conducted over the Brent Group. The resulting pressure gradients showed the Tarbert Formation to be under-pressured by 5.1 bar compared to the underlying Formations of the Brent Group with transitional pressures in the Ness Formation. Two RFT segregated samples were recovered from 2495.5 and 2495.7 m in the top of the Tarbert Formation. Both contained mud and water with a film of oil.
    The well was permanently abandoned on 4 May 1991 as an oil appraisal.
    Testing
    One well test was carried out in the top of the Brent Group over the interval 2495 to 2499 m. The test was performed with variable, increasing choke sizes and it produced fluids with increasing water cut. At the end of the test a total liquid flow rate of 700 Sm3/day through a 15.9 mm choke was recorded at a well head pressure of 49 bar. The water cut at this end was 70%, the separator GOR was 115 Sm3/Sm3, the dead oil density was 0.850 g/cm3, and the gas gravity was 0.8 (air = 1). The maximum bottom hole

  • 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]
    1995.00
    2649.00

  • 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
    2497.0
    2517.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    20.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Oil samples at the Norwegian Offshore Directorate
    Oil samples at the Norwegian Offshore Directorate
    Test type
    Bottle number
    Top depth
    MD [m]
    Bottom depth
    MD [m]
    Fluid type
    Test time
    Samples available
    DST
    DST1
    2495.00
    2499.00
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.39
    pdf
    5.66

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2495
    2499
    15.6
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    5.000
    25.000
    91
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    1.0
    719
    36000
    0.850
    0.800
    50

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DITE MSFL SDT GR SP
    1953
    2647
    LDL CNL GR
    1953
    2650
    MWD GRD - GR RES DIR
    1994
    2650
    RFT GR
    2495
    2614
    SHDT GR
    1953
    2651

  • 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
    INTERM.
    9 5/8
    2633.0
    12 1/4
    2650.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    2460
    1.65
    27.0
    15.0
    WATER BASED
    10.04.1991
    2460
    1.65
    28.0
    19.0
    WATER BASED
    10.04.1991
    2460
    1.65
    28.0
    19.0
    WATER BASED
    11.04.1991
    2460
    1.65
    28.0
    19.0
    WATER BASED
    15.04.1991
    2460
    1.65
    28.0
    19.0
    WATER BASED
    17.04.1991
    2460
    1.65
    28.0
    19.0
    WATER BASED
    12.04.1991
    2493
    1.70
    33.0
    21.0
    WATER BASED
    17.04.1991
    2493
    1.70
    35.0
    22.0
    WATER BASED
    23.04.1991
    2493
    1.70
    33.0
    19.0
    WATER BASED
    29.04.1991
    2493
    1.70
    34.0
    18.0
    WATER BASED
    30.04.1991
    2493
    1.70
    34.0
    18.0
    WATER BASED
    03.05.1991
    2493
    1.70
    33.0
    19.0
    WATER BASED
    06.05.1991
    2493
    1.70
    36.0
    18.0
    WATER BASED
    17.04.1991
    2493
    1.70
    32.0
    21.0
    WATER BASED
    17.04.1991
    2493
    1.70
    33.0
    21.0
    WATER BASED
    18.04.1991
    2493
    1.70
    33.0
    21.0
    WATER BASED
    19.04.1991
    2493
    1.70
    32.0
    21.0
    WATER BASED
    23.04.1991
    2493
    1.70
    33.0
    21.0
    WATER BASED
    23.04.1991
    2493
    1.70
    35.0
    19.0
    WATER BASED
    25.04.1991
    2493
    1.70
    36.0
    19.0
    WATER BASED
    25.04.1991
    2493
    1.70
    36.0
    19.0
    WATER BASED
    26.04.1991
    2493
    1.70
    36.0
    15.0
    WATER BASED
    30.04.1991
    2493
    1.70
    33.0
    19.0
    WATER BASED
    30.04.1991
    2493
    1.70
    33.0
    19.0
    WATER BASED
    02.05.1991
    2493
    1.70
    WATER BASED
    03.05.1991
    2493
    1.70
    WATER BASED
    03.05.1991
    2493
    1.70
    36.0
    15.0
    WATER BASED
    03.05.1991
    2493
    1.70
    36.0
    15.0
    WATER BASED
    03.05.1991
    2493
    1.70
    34.0
    18.0
    WATER BASED
    03.05.1991
    2493
    1.70
    34.0
    18.0
    WATER BASED
    03.05.1991
    2493
    1.70
    33.0
    19.0
    WATER BASED
    03.05.1991
    2493
    1.70
    34.0
    18.0
    WATER BASED
    06.05.1991

  • 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