Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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05.11.2024 - 01:27
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34/7-4

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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.
    34/7-4
    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.
    34/7-4
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    G/E-035 SP. 430
    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.
    445-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.
    59
    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,
    19.11.1984
    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.
    16.01.1985
    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.
    16.01.1987
    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.
    01.04.2012
    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.
    EARLY 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.
    STATFJORD GP
    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.
    319.0
    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).
    3114.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    75
    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° 29' 4.44'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 8' 0.26'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6817231.93
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    453843.83
    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.
    455

  • Wellbore history
    General
    Well 34/7-4 was drilled on the Snorre E structure in the northern part of block 34/7. The primary objectives were to further appraise the reservoir potential of the Statfjord Formation in the E-structure extension of the Snorre Discovery, to test the oil/water contact found in wells 34/7-1, and to test the reservoir quality in this area. A secondary objective was to test the reservoir potential in the upper Lunde Formation, which contain oil in an up-dip location.
    Operations and results
    Appraisal well 34/7-4 was spudded with the semi-submersible installation Treasure Saga on 19 November 1984 and drilled to TD at 3115 m in the Late Triassic Lunde Formation. No significant problems occurred during drilling of the well. The well was drilled with spud mud down to 963 m, with gypsum/polymer mud from 963 m to 2759 m, and with lignosulphonate mud from 2759 m to TD.
    Except for the sandy Utsira Formation (Late Miocene/Pliocene) and an Early Eocene sandstone unit (1625-1664 m) in the lower part of the Hordaland Group, the well proved mainly claystones down to the Early Jurassic Statfjord Formation at 2535.5 m. The Statfjord Formation was 92 m thick and was oil bearing down to claystones in top Lunde Formation at 2627.5 m. No definite oil-water contact was seen. The N/G ratio in the Statfjord Formation was 0.26. The average porosity was 20 % and the average water saturation was 44%. The Lunde Formation proved mainly a claystone/siltstone sequence in the upper part, while the lowermost 265 m proved a sequence of alternating sandstones and claystones with limestone stringers. Of this sequence some 123 m can be considered as net. The Lunde Formation reservoir was water bearing.
    Three cores totalling 24.6 m (recovered 22.3 m. 91% recovery) were cut in the Statfjord Formation from 2533 m to 2557.5 m. Core depths were from 2.0 to 4.0 m short of logger's depth. Another two cores were attempted at 2558.5 m and 2559 m, but these gave no recovery. Two FMT-chambers containing reservoir fluid were collected in the Statfjord Formation at 2537 m and 2555 m. These samples proved not to be representative, since the bubble point pressures were too low.
    The well was permanently abandoned on 16 January 1985 as an oil appraisal.
    Testing
    One drill stem test was carried out in the interval 2547.0 - 2563.0 m in the Statfjord Formation. The zone produced clean oil at a rate of 865 Sm3 /day through a 9.5 mm choke with a wellhead pressure of 130 bar. The reservoir pressure was 386.5 bar and the temperature 91deg C at 2555.0 m. The formation permeability was estimated to 1330 mD and no heterogeneities were observed during the test.
    The separator GOR was 34 Sm3/Sm3 and the dead oil density was 0.843 g/cc with a Formation Volume Factor of 1.27.
    >

  • 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]
    490.00
    3116.00

  • 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
    2533.0
    2536.7
    [m ]
    2
    2537.5
    2552.5
    [m ]
    3
    2552.5
    2557.6
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    23.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2533-2536m
    Core photo at depth: 2537-2541m
    Core photo at depth: 2541-2545m
    Core photo at depth: 2545-2549m
    Core photo at depth: 2549-2552m
    2533-2536m
    2537-2541m
    2541-2545m
    2545-2549m
    2549-2552m
    Core photo at depth: 2552-2556m
    Core photo at depth: 2556-2557m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2552-2556m
    2556-2557m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1190.0
    [m]
    DC
    RRI
    1210.0
    [m]
    DC
    RRI
    1220.0
    [m]
    DC
    RRI
    1240.0
    [m]
    DC
    RRI
    1260.0
    [m]
    DC
    RRI
    1270.0
    [m]
    DC
    RRI
    1280.0
    [m]
    DC
    RRI
    1290.0
    [m]
    DC
    RRI
    1310.0
    [m]
    DC
    RRI
    1330.0
    [m]
    DC
    RRI
    1850.0
    [m]
    DC
    RRI
    1865.0
    [m]
    DC
    RRI
    1880.0
    [m]
    DC
    RRI
    1895.0
    [m]
    DC
    RRI
    1910.0
    [m]
    DC
    RRI

  • 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
    2563.00
    2547.00
    YES
    DST
    DST1
    0.00
    0.00
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.61
    pdf
    5.16
    pdf
    0.93
    pdf
    0.38

  • 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
    1.78
    pdf
    37.52

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2547
    2563
    9.5
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    192.000
    131.000
    385.000
    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
    865
    35000
    0.833
    0.740
    33

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CALIPER
    953
    1229
    CDL CN GR
    1915
    2755
    CDL CN GR
    2744
    3073
    COREGUN
    0
    0
    COREGUN
    0
    0
    DIELECTRIC
    2450
    2748
    DIFL LSBHC
    953
    1930
    DIFL LSBHC GR
    469
    970
    DIFL LSBHC GR
    1915
    2758
    DIFL LSBHC GR
    2744
    3118
    DIPLOG
    1915
    2750
    DIPLOG
    2744
    3117
    DLL MLL GR
    2450
    2757
    FMT
    1915
    2750
    FMT
    2744
    3117
    GR
    120
    473
    SPECTRALOG
    1915
    2750
    SPECTRALOG
    2744
    3068
    VSP
    318
    3118

  • 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
    469.0
    36
    473.0
    0.00
    LOT
    SURF.COND.
    20
    953.0
    26
    971.0
    1.51
    LOT
    INTERM.
    13 3/8
    1015.0
    17 1/2
    1930.0
    1.78
    LOT
    INTERM.
    13 3/8
    1915.0
    17 1/2
    1930.0
    1.90
    LOT
    INTERM.
    13 3/8
    1915.0
    17 1/2
    1930.0
    1.78
    LOT
    INTERM.
    9 5/8
    2745.0
    12 1/4
    2756.0
    1.90
    LOT
    INTERM.
    9 5/8
    2745.0
    12 1/4
    2756.0
    0.00
    LOT
    OPEN HOLE
    3115.0
    8 1/2
    3115.0
    0.00
    LOT
    OPEN HOLE
    3115.0
    8 1/2
    3115.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    408
    1.03
    100.0
    WATER BASED
    21.11.1984
    473
    1.03
    100.0
    WATER BASED
    21.11.1984
    702
    1.10
    62.0
    57.0
    WATER BASED
    23.11.1984
    971
    1.15
    56.0
    49.0
    WATER BASED
    26.11.1984
    971
    1.22
    56.0
    56.0
    WATER BASED
    26.11.1984
    971
    1.22
    59.0
    56.0
    WATER BASED
    26.11.1984
    971
    1.22
    53.0
    50.0
    WATER BASED
    27.11.1984
    971
    1.22
    52.0
    48.0
    WATER BASED
    27.11.1984
    971
    1.07
    54.0
    16.0
    WATER BASED
    30.11.1984
    971
    1.07
    54.0
    16.0
    WATER BASED
    03.12.1984
    971
    1.22
    56.0
    56.0
    WATER BASED
    26.11.1984
    971
    1.22
    59.0
    56.0
    WATER BASED
    26.11.1984
    971
    1.22
    53.0
    50.0
    WATER BASED
    27.11.1984
    971
    1.22
    52.0
    48.0
    WATER BASED
    27.11.1984
    971
    1.07
    54.0
    16.0
    WATER BASED
    30.11.1984
    971
    1.07
    54.0
    16.0
    WATER BASED
    03.12.1984
    1117
    1.14
    48.0
    18.0
    WATER BASED
    11.12.1984
    1552
    1.27
    48.0
    18.0
    WATER BASED
    11.12.1984
    1652
    1.32
    48.0
    18.0
    WATER BASED
    11.12.1984
    1903
    1.37
    48.0
    18.0
    WATER BASED
    12.12.1984
    1930
    1.44
    26.0
    19.0
    WATER BASED
    13.12.1984
    1930
    1.44
    22.0
    20.0
    WATER BASED
    17.12.1984
    1930
    1.44
    22.0
    20.0
    WATER BASED
    17.12.1984
    2072
    1.44
    33.0
    17.0
    WATER BASED
    17.12.1984
    2286
    1.56
    22.0
    15.0
    WATER BASED
    17.12.1984
    2381
    1.60
    24.0
    18.0
    WATER BASED
    18.12.1984
    2498
    1.69
    50.0
    18.0
    WATER BASED
    20.12.1984
    2537
    1.69
    50.0
    16.0
    WATER BASED
    20.12.1984
    2559
    1.69
    47.0
    13.0
    WATER BASED
    27.12.1984
    2559
    1.69
    49.0
    14.0
    WATER BASED
    27.12.1984
    2559
    1.69
    49.0
    14.0
    WATER BASED
    27.12.1984
    2583
    1.69
    51.0
    15.0
    WATER BASED
    06.01.1985
    2630
    1.69
    48.0
    14.0
    WATER BASED
    27.12.1984
    2688
    1.69
    49.0
    15.0
    WATER BASED
    27.12.1984
    2749
    1.69
    50.0
    16.0
    WATER BASED
    27.12.1984
    2810
    1.60
    50.0
    18.0
    WATER BASED
    01.01.1985
    2997
    1.60
    50.0
    18.0
    WATER BASED
    01.01.1985
    3115
    1.60
    48.0
    13.0
    WATER BASED
    06.01.1985
    3115
    1.60
    49.0
    18.0
    WATER BASED
    01.01.1985
    3115
    1.60
    48.0
    13.0
    WATER BASED
    06.01.1985

  • 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