Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
24.11.2024 - 01:27
Time of last synchronization with Norwegian Offshore Directorate's internal systems

34/7-17

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
    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.
    668-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.
    42
    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,
    25.02.1991
    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.
    07.04.1991
    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.
    07.04.1993
    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.
    SHOWS
    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.
    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).
    3115.0
    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).
    3111.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    6.6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    103
    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 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.
    LUNDE 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.
    1713

  • Wellbore history
    General
    Well 34/7-17 is located on the Vigdis Field on Tampen Spur in the Northern North Sea. It was drilled on the southern extension of the C-Plus prospect, on the eastern margin of a complete or non-truncated Brent Group sequence. Furthermore, the location is defined by the down dipping geometry to the northwest, and the proximity to a major fault zone to the south. The primary purpose of the well was to test the reservoir quality and fluid contacts in the prospect. The sequence was drilled in a structural position where a large range of oil-water contacts could be tested. 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 was spudded with the semi-submersible installation Treasure Saga on 25 February 1991 and drilled to TD at 3115 m in the Late Triassic Lunde Formation. Due to leaks in the riser the 26? section was drilled riserless while the riser was sent onshore for repairs. First returns to the rig floor was at 897 m. From the MWD logs possible shallow gas was interpreted at 519 - 520, 576 - 576.5 and 692 -693 m, but flow checks performed proved negative. The well was drilled with spud mud down to 897 m, and with KCl mud from 897 m to TD.
    In the Nordland, Hordaland, Rogaland and Shetland Groups, the well penetrated mainly claystones with minor sandstone intervals. Top of the Brent Group reservoir was reached at 2461 m (2458 m TVD), which was 38 m deeper than prognosed. The Jurassic section comprised a minor interval of the Viking Group, and a complete section of the Middle Jurassic Brent Group, the Early Jurassic Dunlin Group and the Statfjord Formation. Both main reservoir targets, the Brent Group and the Statfjord Formation, proved to be water bearing. Scattered oil shows were noted in sandstones in drill cuttings from the Lista Formation (at 1855 to 1900 m). A continuous section with traces of both direct and predominantly crush cut fluorescence was recorded in side wall cores between 2235 and 2405 m. Only scattered shows were recorded on the cores taken in the primary target Brent Group reservoir (at 2467 m and at 2472 to 2481 m). Shows were again noted in sandstone side wall cores from the Amundsen and Statfjord Formations in the interval 2920 to 3080 m.
    A total of 8 cores were cut in the Brent Group between 2460.0 and 2586.0 m (driller's depth). This makes a total of 126 m, of which 117.05 m were recovered (93%). Two RFT runs were conducted, one in the Lista Formation and one in the Early - Middle Jurasic. The resulting pressure gradients showed three different pressure regimes in the Middle - Early Jurassic, each separated by ca 5 bar pressure. Highest pressure was seen in the Statfjord Formation, medium pressure was seen in the Lower Brent Group and the lowest pressure in the upper Brent Group (Tarbert Formation). Only one (at 1881.5 m) of the pressure measurements taken in the Rogaland Group was reliable, indicating an equivalent pressure gradient of 1.40-1.41 g/cc subsea. One segregated RFT fluid sample was taken at 1881.5 m. The content was reported to be water and mud.
    The open hole was plugged back to 2408 m and prepared for sidetracking to a new reservoir target. The well is classified as dry with shows.
    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]
    900.00
    3114.00

  • 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
    2460.0
    2478.5
    [m ]
    2
    2478.5
    2496.9
    [m ]
    3
    2498.0
    2507.5
    [m ]
    4
    2508.0
    2531.6
    [m ]
    5
    2534.0
    2542.0
    [m ]
    6
    2545.0
    2552.5
    [m ]
    7
    2554.0
    2570.2
    [m ]
    8
    2571.0
    2586.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    116.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2460-2465m
    Core photo at depth: 2465-2470m
    Core photo at depth: 2470-2475m
    Core photo at depth: 2475-2478m
    Core photo at depth: 2478-2483m
    2460-2465m
    2465-2470m
    2470-2475m
    2475-2478m
    2478-2483m
    Core photo at depth: 2483-2488m
    Core photo at depth: 2488-2493m
    Core photo at depth: 2493-2496m
    Core photo at depth: 2498-2503m
    Core photo at depth: 2503-2507m
    2483-2488m
    2488-2493m
    2493-2496m
    2498-2503m
    2503-2507m
    Core photo at depth: 2508-2513m
    Core photo at depth: 2513-2518m
    Core photo at depth: 2518-2523m
    Core photo at depth: 2523-2528m
    Core photo at depth: 2528-2531m
    2508-2513m
    2513-2518m
    2518-2523m
    2523-2528m
    2528-2531m
    Core photo at depth: 2534-2539m
    Core photo at depth: 2539-2542m
    Core photo at depth: 2545-2550m
    Core photo at depth: 2550-2552m
    Core photo at depth: 2554-2559m
    2534-2539m
    2539-2542m
    2545-2550m
    2550-2552m
    2554-2559m
    Core photo at depth: 2559-2564m
    Core photo at depth: 2564-2569m
    Core photo at depth: 2569-2570m
    Core photo at depth: 2571-2576m
    Core photo at depth: 2576-2581m
    2559-2564m
    2564-2569m
    2569-2570m
    2571-2576m
    2576-2581m
    Core photo at depth: 2581-2586m
    Core photo at depth: 2497-2502m
    Core photo at depth: 2502-2507m
    Core photo at depth: 2507-2512m
    Core photo at depth: 2512-2517m
    2581-2586m
    2497-2502m
    2502-2507m
    2507-2512m
    2512-2517m

  • Lithostratigraphy

  • 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
    25.94

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    780
    1942
    DIL LSS LDL GR SP
    879
    1948
    DITE MSFL LDL CNL GR
    1953
    3116
    DSI GR
    1953
    3113
    MWD DPR RGD - GR RES DIR
    285
    3115
    RFT GR
    1879
    1914
    RFT GR
    2462
    3074
    SHDT GR
    1953
    3119
    VELOCITY
    1000
    3115

  • 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
    371.0
    36
    372.0
    0.00
    LOT
    INTERM.
    20
    881.0
    26
    902.0
    1.83
    LOT
    INTERM.
    13 3/8
    1955.0
    17 1/2
    1974.0
    1.80
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    390
    1.20
    WATER BASED
    01.03.1991
    390
    1.20
    WATER BASED
    04.03.1991
    390
    1.20
    WATER BASED
    27.02.1991
    390
    1.04
    WATER BASED
    05.03.1991
    815
    1.04
    WATER BASED
    05.03.1991
    897
    1.04
    WATER BASED
    05.03.1991
    897
    1.04
    WATER BASED
    05.03.1991
    897
    1.04
    WATER BASED
    07.03.1991
    897
    1.30
    20.0
    16.0
    WATER BASED
    11.03.1991
    1268
    1.30
    25.0
    23.0
    WATER BASED
    12.03.1991
    1509
    1.40
    31.0
    25.0
    WATER BASED
    12.03.1991
    1807
    1.49
    36.0
    24.0
    WATER BASED
    12.03.1991
    1879
    1.49
    33.0
    18.0
    WATER BASED
    14.03.1991
    1879
    1.49
    33.0
    15.0
    WATER BASED
    19.03.1991
    1879
    1.49
    32.0
    16.0
    WATER BASED
    19.03.1991
    1969
    1.49
    32.0
    17.0
    WATER BASED
    13.03.1991
    1969
    1.49
    34.0
    18.0
    WATER BASED
    13.03.1991
    1974
    1.49
    27.0
    16.0
    WATER BASED
    19.03.1991
    2036
    1.51
    31.0
    14.0
    WATER BASED
    19.03.1991
    2272
    1.60
    34.0
    15.0
    WATER BASED
    20.03.1991
    2460
    1.65
    40.0
    15.0
    WATER BASED
    22.03.1991
    2460
    1.65
    40.0
    15.0
    WATER BASED
    25.03.1991
    2460
    1.65
    37.0
    15.0
    WATER BASED
    25.03.1991
    2460
    1.65
    39.0
    16.0
    WATER BASED
    25.03.1991
    2460
    1.65
    42.0
    20.0
    WATER BASED
    25.03.1991
    2460
    1.65
    43.0
    22.0
    WATER BASED
    27.03.1991
    2460
    1.65
    25.0
    13.0
    WATER BASED
    05.04.1991
    2460
    1.65
    27.0
    15.0
    WATER BASED
    09.04.1991
    2460
    1.65
    25.0
    18.0
    WATER BASED
    09.04.1991
    2460
    1.65
    36.0
    16.0
    WATER BASED
    21.03.1991
    2460
    1.65
    25.0
    14.0
    WATER BASED
    08.04.1991
    2460
    1.65
    26.0
    16.0
    WATER BASED
    09.04.1991

  • 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
    0.22