Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
27.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

34/7-21 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.
    34/7-21 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.
    34/7-21
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    SG 8431 R 211 C 1241
    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.
    752-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.
    60
    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,
    15.12.1992
    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.
    12.02.1993
    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.
    12.02.1995
    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.
    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
    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.
    LATE 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.
    INTRA DRAUPNE FM SS
    2nd level with HC, age
    Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    LATE JURASSIC
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd 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.
    INTRA HEATHER FM SS
    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.
    192.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3360.0
    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).
    2874.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    59
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    102
    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.
    TARBERT FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 17' 36.84'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 4' 21.14'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6796001.43
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    450299.76
    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.
    2068

  • Wellbore history
    General
    Exploration well 34/7-21 A is a sidetrack to well 34/7-21 which found oil in three different sands in the Late Jurassic - Early Cretaceous succession. No OWC was found. The primary purpose of the sidetrack was to test the extension of these discoveries and to prove possible OWC(s). A secondary objective was to test the presence of sandstones, and possible hydrocarbons, within the Late Cretaceous in which a thin sandstone interval was proved oil-bearing in well 34/7-21.
    Operations and results
    Well 34/7-21A was kicked off from 1798 m in the vertical well on 16 December 1992. The well was deviated and penetrated the top reservoir 585 m west of the vertical well. It was drilled with the semi-submersible installation Treasure Saga to TD at 3360 m (2874 m TVD), 37 metres TVD into the Brent Group. Initial problems with steering the drill string resulted in a kick-off in the wrong direction. The well was turned around and lined up to the correct azimuth. The drill string got mechanically stuck three times in the interval 2465 m to 2571 m, but came free within short time. The string also got stuck at 2998 m when running in the hole after waiting on weather. The hole apparently deteriorated with time. The TD caliper log showed severe washouts of the hole, up to a maximum of 22". Waiting on weather for about 17 days was seen to be a major cause of the severe washouts. The washouts and hence increased amounts of cuttings, possibly explain the problems with the hole packing off and the string becoming stuck. Due to the hole angle and the bad hole condition logging operations were troublesome and time consuming, with many of the logs being run on drill pipe. The sidetrack was drilled with a KCl mud all through. The KCl levels were high and in addition glycol was introduced to inhibit the formation, but without the wanted effect as proved by the severe washout.
    The Base Cretaceous Unconformity was penetrated at 2870 m. A 3 m thick sandstone interval just below the Base Cretaceous Unconformity, an Intra-Draupne Sand, 25 m thick TVD, was interpreted from logs to contain movable hydrocarbons. Good oil shows were observed in the more silty/shaly laminated part of the unit below. This sandstone was found in pressure communication with the upper Intra-Draupne Sand tested in well 34/7-21. Deeper down in the Draupne Formation at 2960 m a second Intra-Draupne Sand thin sandstone interval was found hydrocarbon-bearing. Hydrocarbons were in addition proved in a 2 m thick sandstone interval at the top of the Heather Formation. The three hydrocarbon intervals were separated and not in pressure communication. No OWC could be established from the pressure measurements, but both formation water and oil were sampled in the main reservoir sand (2870.0-2875.0 m, 2575.0-2578.0 m TVD), indicating proximity to an OWC. In addition to live oil in the Late Jurassic shows were reported in siltstone/sandstone laminae intermittently in the interval 2335 - 2811, as well as in siltstone/sandstone laminae in the Heather Formation below the oil bearing sands. The Brent Formation proved to be water-bearing.
    Four cores were cut within the interval 2847-2911 m from the Late Cretaceous Rødby Formation and 6 m into the Draupne Formation A fifth core was cut in a shaly part of the Draupne Formation in the interval 2943-2954 m. A total of 75 metres were cut, of which 69.5 metres were recovered (93%). A total of 8 runs were made with the FMT of which 4 were regarded as successful. Fluid samples were taken at 3035.5 m / 2670.4 m TVD (oil and gas), 2872.5 m / 2577 m TVD (water), 2874 m / 2577.7 m TVD (gas and filtrate), and at 2873.5 m / 2577.3 m TVD (oil, gas, and filtrate) The well was permanently abandoned on 12 February 1993 as an oil appraisal.
    Testing
    The sidetrack well 34/7-21 A was not tested.

  • 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]
    1820.00
    3360.00

  • 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
    2847.0
    2873.5
    [m ]
    2
    2874.0
    2885.3
    [m ]
    3
    2890.0
    2900.8
    [m ]
    4
    2901.0
    2910.1
    [m ]
    5
    2943.0
    2953.9
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    68.6
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2847-2851m
    Core photo at depth: 2851-2855m
    Core photo at depth: 2855-2859m
    Core photo at depth: 2859-2863m
    Core photo at depth: 2863-2867m
    2847-2851m
    2851-2855m
    2855-2859m
    2859-2863m
    2863-2867m
    Core photo at depth: 2867-2871m
    Core photo at depth: 2871-2873m
    Core photo at depth: 2874-2878m
    Core photo at depth: 2878-2882m
    Core photo at depth: 2882-2885m
    2867-2871m
    2871-2873m
    2874-2878m
    2878-2882m
    2882-2885m
    Core photo at depth: 2890-2894m
    Core photo at depth: 2894-2898m
    Core photo at depth: 2898-2900m
    Core photo at depth: 2901-2905m
    Core photo at depth: 2905-2909m
    2890-2894m
    2894-2898m
    2898-2900m
    2901-2905m
    2905-2909m
    Core photo at depth: 2909-2920m
    Core photo at depth: 2943-2947m
    Core photo at depth: 2947-2951m
    Core photo at depth: 2951-2953m
    Core photo at depth:  
    2909-2920m
    2943-2947m
    2947-2951m
    2951-2953m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2868.0
    [m]
    C
    RRI
    2871.0
    [m]
    C
    RRI
    2872.0
    [m]
    C
    RRI
    2874.0
    [m]
    C
    RRI
    2876.0
    [m]
    C
    RRI
    2878.0
    [m]
    C
    RRI
    2879.0
    [m]
    C
    RRI
    2880.0
    [m]
    C
    RRI

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.30
    pdf
    8.56

  • 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
    12.15

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CDL CN SL
    1795
    3344
    DPIL MAC GR
    1795
    3353
    FMT GR
    2844
    3035
    HEXDIP GR
    2830
    3060
    MWD FLS - GR RES DIR TEMP
    1795
    3319
    VELOCITY
    1330
    3350

  • 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.
    13 3/8
    1795.0
    17 1/2
    1810.0
    1.85
    LOT
    OPEN HOLE
    3360.0
    12 1/4
    3360.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1800
    1.55
    29.0
    12.0
    WATER BASED
    16.12.1992
    1873
    1.52
    30.0
    17.0
    WATER BASED
    17.12.1992
    2155
    1.54
    36.0
    28.0
    WATER BASED
    21.12.1992
    2155
    1.54
    32.0
    22.0
    WATER BASED
    21.12.1992
    2260
    1.56
    44.0
    38.0
    WATER BASED
    21.12.1992
    2309
    1.56
    42.0
    36.0
    WATER BASED
    21.12.1992
    2465
    1.60
    58.0
    44.0
    WATER BASED
    23.12.1992
    2510
    1.61
    43.0
    28.0
    WATER BASED
    14.12.1992
    2510
    1.61
    43.0
    28.0
    WATER BASED
    14.12.1992
    2510
    1.61
    38.0
    24.0
    WATER BASED
    16.12.1992
    2580
    1.60
    46.0
    35.0
    WATER BASED
    28.12.1992
    2580
    1.60
    48.0
    37.0
    WATER BASED
    28.12.1992
    2774
    1.60
    46.0
    30.0
    WATER BASED
    28.12.1992
    2847
    1.60
    51.0
    31.0
    WATER BASED
    28.12.1992
    2864
    1.60
    44.0
    31.0
    WATER BASED
    28.12.1992
    2878
    1.60
    42.0
    30.0
    WATER BASED
    28.12.1992
    2899
    1.60
    41.0
    31.0
    WATER BASED
    04.01.1993
    2899
    1.60
    41.0
    31.0
    WATER BASED
    04.01.1993
    2934
    1.60
    43.0
    29.0
    WATER BASED
    04.01.1993
    2934
    1.60
    42.0
    34.0
    WATER BASED
    04.01.1993
    2973
    1.60
    43.0
    33.0
    WATER BASED
    04.01.1993
    2998
    1.60
    39.0
    28.0
    WATER BASED
    04.01.1993
    3033
    1.60
    39.0
    28.0
    WATER BASED
    05.01.1993
    3033
    1.60
    39.0
    28.0
    WATER BASED
    07.01.1993
    3033
    1.60
    39.0
    28.0
    WATER BASED
    07.01.1993
    3033
    1.60
    39.0
    28.0
    WATER BASED
    08.01.1993
    3033
    1.60
    39.0
    28.0
    WATER BASED
    12.01.1993
    3033
    1.60
    39.0
    28.0
    WATER BASED
    12.01.1993
    3033
    1.60
    39.0
    28.0
    WATER BASED
    12.01.1993
    3033
    1.60
    39.0
    28.0
    WATER BASED
    14.01.1993
    3033
    1.60
    42.0
    28.0
    WATER BASED
    15.01.1993
    3033
    1.60
    39.0
    28.0
    WATER BASED
    04.01.1993
    3033
    1.60
    39.0
    28.0
    WATER BASED
    12.01.1993
    3056
    1.60
    54.0
    40.0
    WATER BASED
    15.01.1993
    3122
    1.60
    54.0
    32.0
    WATER BASED
    20.01.1993
    3122
    1.60
    42.0
    33.0
    WATER BASED
    20.01.1993
    3122
    1.60
    42.0
    33.0
    WATER BASED
    20.01.1993
    3137
    1.60
    45.0
    31.0
    WATER BASED
    20.01.1993
    3228
    1.60
    49.0
    35.0
    WATER BASED
    22.01.1993
    3241
    1.63
    46.0
    34.0
    WATER BASED
    25.01.1993
    3302
    1.60
    44.0
    36.0
    WATER BASED
    25.01.1993
    3360
    1.60
    39.0
    34.0
    WATER BASED
    26.01.1993
    3360
    1.60
    37.0
    23.0
    WATER BASED
    28.01.1993
    3360
    1.60
    35.0
    23.0
    WATER BASED
    29.01.1993
    3360
    1.60
    35.0
    25.0
    WATER BASED
    01.02.1993
    3360
    1.60
    36.0
    26.0
    WATER BASED
    01.02.1993
    3360
    1.60
    35.0
    25.0
    WATER BASED
    02.02.1993
    3360
    1.60
    35.0
    23.0
    WATER BASED
    03.02.1993
    3360
    1.60
    35.0
    26.0
    WATER BASED
    08.02.1993
    3360
    1.60
    35.0
    26.0
    WATER BASED
    08.02.1993
    3360
    1.60
    35.0
    26.0
    WATER BASED
    08.02.1993
    3360
    1.60
    35.0
    28.0
    WATER BASED
    09.02.1993
    3360
    1.60
    43.0
    39.0
    WATER BASED
    10.02.1993
    3360
    1.60
    43.0
    39.0
    WATER BASED
    11.02.1993
    3360
    1.60
    43.0
    39.0
    WATER BASED
    12.02.1993
    3360
    1.60
    43.0
    39.0
    WATER BASED
    15.02.1993
    3360
    1.60
    43.0
    39.0
    WATER BASED
    15.02.1993
    3360
    1.60
    46.0
    36.0
    WATER BASED
    25.01.1993
    3360
    1.60
    40.0
    35.0
    WATER BASED
    27.01.1993
    3360
    1.60
    33.0
    20.0
    WATER BASED
    01.02.1993
    3360
    1.60
    35.0
    23.0
    WATER BASED
    04.02.1993
    3360
    1.60
    35.0
    28.0
    WATER BASED
    08.02.1993

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    2704.12
    [m ]
    2876.60
    [m ]
    2879.27
    [m ]
    2881.30
    [m ]
    2884.40
    [m ]
    2890.90
    [m ]
    2893.85
    [m ]
    2899.64
    [m ]
    2903.73
    [m ]
    2906.70
    [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
    0.22