Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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34/7-16 R

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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.
    34/7-16 R
    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.
    SUSPENDED
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    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.
    34/7-16
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    G/E 83 (RP) RAD 253& KOL 933.
    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.
    640-L2
    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,
    04.09.1990
    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.
    15.10.1990
    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.
    15.10.1992
    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.
    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.
    YES
    Reentry activity
    Reason for reentry of the wellbore. Only relevant for exploration wellbores. Example of legal values: DRILLING, DRILLING/PLUGGING, LOGGING, PLUGGING, TESTING, TESTING/PLUGGING.
    DRILLING
    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.
    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.
    ETIVE FM
    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.
    MIDDLE 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.
    RANNOCH 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.
    286.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2980.0
    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).
    2978.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    106
    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° 23' 13.06'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 6' 59.12'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6806371.84
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    452792.04
    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.
    1677

  • Wellbore history
    <
    General
    Well 34/7-16 R is a re-entry of well 34/7-16, which was suspended due to time schedule for the rig. The well is located between the Statfjord and Snorre Fields on Tampen Spur in the Northern North Sea. The purpose of the re-entry was to test the hydrocarbon-bearing Brent Group reservoir and also to drill through and test the Statfjord Formation.
    Operations and results
    Well 34/7-16 was re-entered (34/7-16 R) on 4 September 1990 by the semi-submersible rig Treasure Saga and drilled through the Statfjord formation to TD at 2980 m, 35 m into the Late Triassic Lunde Formation. The well was drilled with KCl mud.
    Both the Statfjord formation and the Lunde Formation proved to be water bearing. The Statfjord Formation (2821 - 2945 m) had an estimated average log porosity of 21.7% and a net to gross ratio of 0.56.
    The well suspended on 15 October 1990 as an oil appraisal.
    Testing
    Three DST tests were performed in well 34/7-16 R.
    DST 1 tested the interval 2821 - 2837 m in the Statfjord Formation. The test was mainly designed to get representative samples of Statfjord Formation water. The initial pressure and temperature at the top perforation was 406 bar and 102 deg C. Clean water with very little gas was produced. The gas gravity was 0.64 (air = 1). It was not possible to maintain stable flowing conditions due to plugging at the choke manifold, but a flow-rate of 1450 m3/day at a wellhead pressure of 105 bar was measured at the end of the 12 hrs flow period.
    DST 2 tested a four metres zone from 2454 - 2458 m in the Rannoch Formation. The main objective was to evaluate the lateral extension of the two calcite cemented layers (2451 - 2453 and 2459 - 2461 m). The initial pressure and temperature at the top perforation was 366 bar and 90 deg C. Oil with a GOR of 55 Sm3/Sm3 was produced. The gas gravity was 0.75 (air = 1) and the CO2 content was 0.27%. After a clean-up period, the well was flowed for 26 hours followed by a 25 hours build-up. At the end of the flow, the measured flow rate was 950 Sm3/day through an 11.1 mm choke at a wellhead pressure of 132 bar.
    DST 3 tested the interval 2401 - 2414 m in the Etive Formation in order to investigate reservoir heterogeneities. The initial pressure and temperature at the top perforation was 362 bar and 89 deg C. Oil with a GOR of 47 Sm3/Sm3 was produced. The gas gravity was 0.71 (air = 1) and the CO2 content was 0.28%. After a clean-up period, the well was flowed for 25 hours followed by a 24 hours build-up period. At the end of the flow, the measured flow rate was 1310 Sm3/day through a 12.7 mm choke at a wellhead pressure of 159 bar.

  • 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
    DST2
    2454.00
    2458.00
    OIL
    30.09.1990 - 09:25
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.29
    pdf
    5.75

  • 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
    13.67

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2454
    2458
    111.0
    2.0
    2401
    2414
    12.7
    3.0
    2821
    2837
    0.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    13.200
    36.600
    90
    2.0
    15.900
    36.200
    89
    3.0
    102
    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
    950
    52250
    0.860
    0.710
    55
    2.0
    1310
    62040
    0.860
    0.710
    47
    3.0

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    1900
    2684
    CDL CNL GR
    2684
    2977
    DIFL ACL GR
    2684
    2977
    DIPLOG
    2686
    2978
    FMT
    2832
    2943
    MWD - GR RES DIR TEMP
    2701
    2980
    VELOCITY
    850
    3000

  • 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
    LINER
    7
    2976.0
    8 1/2
    2980.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    362
    1.55
    21.0
    9.0
    WATER BASED
    07.09.1990
    2400
    1.68
    16.0
    22.0
    DUMMY
    30.06.1994
    2400
    1.68
    17.0
    22.0
    DUMMY
    01.07.1994
    2400
    1.45
    20.0
    13.0
    DUMMY
    04.07.1994
    2400
    1.68
    27.0
    23.0
    DUMMY
    04.07.1994
    2400
    1.53
    17.0
    17.0
    DUMMY
    04.07.1994
    2686
    1.65
    37.0
    14.0
    WATER BASED
    14.09.1990
    2686
    1.65
    34.0
    13.0
    WATER BASED
    18.09.1990
    2686
    1.65
    28.0
    15.0
    WATER BASED
    08.10.1990
    2686
    1.67
    29.0
    15.0
    WATER BASED
    15.10.1990
    2686
    1.65
    39.0
    18.0
    WATER BASED
    18.09.1990
    2686
    1.65
    39.0
    20.0
    WATER BASED
    18.09.1990
    2686
    1.65
    36.0
    17.0
    WATER BASED
    21.09.1990
    2686
    1.65
    39.0
    18.0
    WATER BASED
    21.09.1990
    2686
    1.65
    39.0
    20.0
    WATER BASED
    21.09.1990
    2686
    1.65
    34.0
    12.0
    WATER BASED
    25.09.1990
    2686
    1.65
    33.0
    13.0
    WATER BASED
    25.09.1990
    2686
    1.65
    42.0
    22.0
    WATER BASED
    25.09.1990
    2686
    1.65
    33.0
    18.0
    WATER BASED
    25.09.1990
    2686
    1.65
    33.0
    18.0
    WATER BASED
    26.09.1990
    2686
    1.65
    36.0
    21.0
    WATER BASED
    28.09.1990
    2686
    1.65
    36.0
    19.0
    WATER BASED
    02.10.1990
    2686
    1.65
    36.0
    21.0
    WATER BASED
    02.10.1990
    2686
    1.65
    36.0
    21.0
    WATER BASED
    02.10.1990
    2686
    1.65
    36.0
    17.0
    WATER BASED
    03.10.1990
    2686
    1.65
    29.0
    14.0
    WATER BASED
    05.10.1990
    2686
    1.65
    28.0
    16.0
    WATER BASED
    05.10.1990
    2686
    1.65
    29.0
    14.0
    WATER BASED
    08.10.1990
    2686
    1.65
    28.0
    15.0
    WATER BASED
    08.10.1990
    2686
    1.65
    28.0
    14.0
    WATER BASED
    10.10.1990
    2686
    1.65
    28.0
    14.0
    WATER BASED
    11.10.1990
    2686
    1.65
    28.0
    14.0
    WATER BASED
    11.10.1990
    2686
    1.67
    WATER BASED
    16.10.1990
    2686
    1.67
    WATER BASED
    16.10.1990
    2686
    1.65
    26.0
    20.0
    WATER BASED
    16.10.1990
    2885
    1.65
    54.0
    14.0
    WATER BASED
    14.09.1990
    2885
    1.65
    54.0
    14.0
    WATER BASED
    13.09.1990

  • 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