Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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16.07.2024 - 01:28
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34/7-5

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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.
    34/7-5
    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.
    34/7-5
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    SG 82 31 - 113 SP. 485
    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.
    448-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,
    17.01.1985
    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.
    16.03.1985
    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.
    16.03.1987
    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.
    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.
    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.
    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.
    NESS 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.
    244.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3146.0
    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).
    3145.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    98
    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° 21' 54.95'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 1' 23.67'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6804026.01
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    447777.65
    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.
    458
  • Wellbore history

    General
    Well 34/7-5 is located in the Statfjord Øst area of the Northern North Sea. The primary objectives of the well were to test the reservoir potential of the Brent Group, and to determine if the oil/water contact is the same as that found in the 33/9-7 Statfjord Øst discovery well drilled to the south southwest of this well in the neighbouring block, but on the assumed same structure. A secondary objective was to test the reservoir potential of the Statfjord Formation.
    Operations and results
    Wildcat well 34/7-5 was spudded with the semi-submersible installation Treasure Saga on 17 January 1985 and drilled to TD at 3146 m in the Late Triassic Lunde Formation. Drilling proceeded without significant problems. The well was drilled with spud mud down to 930 m and with gypsum/polymer mud from 930 m to TD.
    Trace oil shows appeared in sandstone lamina in the Cretaceous from about 2380, limestones had shows from about 2488 m. The Brent Group reservoir came in at 2502 m, approximately 60 m deeper than prognosed. Hydrocarbons were encountered in the upper section belonging to the Ness Formation. The oil/water contact could not be defined from pressure data. From shows on cores and the well logs an OWC could be placed at approximately 2521 m, in accordance with the results from well 33/9-7. Below the OWC oil shows on sandstone decreased gradually from 2523 m until they vanished at 2616 m. The Statfjord Formation was dry.
    Eleven cores were cut. Cores 1 to 10 were cut from 2508 m to 2633 m in the Brent Group and the uppermost part of the Drake Formation. Core 1, from 2508 to 2510 gave no recovery. The core depths for Cores 2 to 10 were from 0.5 m to 2.2 m short of logger's depth. Core 11 was cut from 2869 m to 2883.5 m in the calcareous Amundsen Formation. For this core there was no difference between core depth and logger's depth. No wire line fluid samples were taken.
    The well was permanently abandoned on 16 March 1985 as an oil appraisal.
    Testing
    Two drill stem tests were performed from the interval 2502.5 - 2512.5 m.
    The first test, DST 1, produced oil with a water cut of 50%, strongly suggesting water channelling behind casing from the underlying water zone.
    Cement was squeezed behind casing to isolate the perforated zone and a second repeat test, DST 1A was initiated. This test produced clean oil at a rate of 260 Sm3 /day through a 9.5 mm choke. The wellhead pressure was 72 bar. The highest recorded bottom hole temperature was 88 deg C in both DST 1 and in DST 1A.
  • 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]
    390.00
    3147.00
  • 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
    2
    2510.0
    2520.7
    [m ]
    3
    2521.0
    2527.3
    [m ]
    4
    2529.5
    2541.2
    [m ]
    5
    2542.0
    2555.1
    [m ]
    6
    2555.1
    2571.9
    [m ]
    7
    2573.0
    2590.7
    [m ]
    8
    2591.0
    2607.5
    [m ]
    9
    2609.0
    2622.2
    [m ]
    10
    2624.0
    2631.6
    [m ]
    11
    2869.0
    2883.4
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    127.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 2510-2515m
    Core photo at depth: 2515-2520m
    Core photo at depth: 2520-2521m
    Core photo at depth: 2521-2526m
    Core photo at depth: 2526-2527m
    2510-2515m
    2515-2520m
    2520-2521m
    2521-2526m
    2526-2527m
    Core photo at depth: 2529-2534m
    Core photo at depth: 2534-2539m
    Core photo at depth: 2539-2541m
    Core photo at depth: 2542-2547m
    Core photo at depth: 2547-2552m
    2529-2534m
    2534-2539m
    2539-2541m
    2542-2547m
    2547-2552m
    Core photo at depth: 2552-2555m
    Core photo at depth: 2555-2560m
    Core photo at depth: 2560-2565m
    Core photo at depth: 2565-2570m
    Core photo at depth: 2570-2571m
    2552-2555m
    2555-2560m
    2560-2565m
    2565-2570m
    2570-2571m
    Core photo at depth: 2573-2578m
    Core photo at depth: 2578-2583m
    Core photo at depth: 2583-2588m
    Core photo at depth: 2588-2590m
    Core photo at depth: 2591-2596m
    2573-2578m
    2578-2583m
    2583-2588m
    2588-2590m
    2591-2596m
    Core photo at depth: 2596-2601m
    Core photo at depth: 2601-2606m
    Core photo at depth: 2606-2607m
    Core photo at depth: 2609-2614m
    Core photo at depth: 2614-2619m
    2596-2601m
    2601-2606m
    2606-2607m
    2609-2614m
    2614-2619m
    Core photo at depth: 2619-2622m
    Core photo at depth: 2624-2629m
    Core photo at depth: 2629-2631m
    Core photo at depth: 2869-2874m
    Core photo at depth: 2874-2879m
    2619-2622m
    2624-2629m
    2629-2631m
    2869-2874m
    2874-2879m
    Core photo at depth: 2819-2883m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2819-2883m
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2148.0
    [m]
    DC
    RRI
    2166.0
    [m]
    DC
    RRI
    2196.0
    [m]
    DC
    RRI
    2211.0
    [m]
    DC
    RRI
    2241.0
    [m]
    DC
    RRI
    2256.0
    [m]
    DC
    RRI
    2271.0
    [m]
    DC
    RRI
    2320.0
    [m]
    DC
    RRI
    2510.5
    [m]
    C
    RRI
    2535.0
    [m]
    DC
    RRI
    2556.0
    [m]
    DC
    RRI
    2565.0
    [m]
    DC
    RRI
    2577.0
    [m]
    DC
    RRI
    2598.0
    [m]
    DC
    RRI
    2610.0
    [m]
    DC
    RRI
    2621.4
    [m]
    C
    RRI
    2624.3
    [m]
    C
    RRI
    2626.0
    [m]
    C
    RRI
    2628.7
    [m]
    C
    RRI
    2631.3
    [m]
    C
    RRI
    2709.0
    [m]
    DC
    RRI
    2727.0
    [m]
    DC
    RRI
    2739.0
    [m]
    DC
    RRI
    2781.0
    [m]
    DC
    RRI
    2796.0
    [m]
    DC
    RRI
    2811.0
    [m]
    DC
    RRI
    2826.0
    [m]
    DC
    RRI
    2895.0
    [m]
    DC
    RRI
    2910.0
    [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
    DST1A
    2502.50
    2512.50
    08.03.1985 - 01:00
    YES
  • Lithostratigraphy

  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.55
    pdf
    1.91
    pdf
    0.72
    pdf
    8.71
  • 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
    1.94
    pdf
    41.54
  • Drill stem tests (DST)

    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2503
    2512
    9.5
    2.0
    2502
    2512
    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
    13.000
    9.000
    36.000
    2.0
    11.000
    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
    318
    46000
    0.085
    0.760
    145
    2.0
    262
    4000
    0.845
    151
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    ACBL
    680
    1840
    CDL CNL GR
    1843
    2746
    CDL CNL GR
    2470
    3143
    CDL GR
    379
    929
    CDL GR
    912
    1860
    DIFL LSBHC GR
    379
    929
    DIFL LSBHC GR
    912
    1863
    DIFL LSBHC GR
    1840
    3143
    DIPLOG
    1840
    3143
    DLL MLL GR
    2450
    2746
    FMT
    1840
    3143
    FMT
    1843
    2746
    GR
    120
    384
    SIGNATURE
    2440
    2610
    SIGNATURE
    2891
    3115
    SWC
    0
    0
    VSP
    380
    3131
  • 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
    380.0
    36
    790.0
    0.00
    LOT
    SURF.COND.
    20
    913.0
    26
    930.0
    1.52
    LOT
    INTERM.
    13 3/8
    1844.0
    17 1/2
    1865.0
    1.79
    LOT
    INTERM.
    9 5/8
    2636.0
    12 1/4
    3146.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    384
    1.03
    WATER BASED
    18.01.1985
    790
    1.10
    WATER BASED
    25.01.1985
    930
    1.12
    WATER BASED
    25.01.1985
    1164
    1.10
    10.0
    17.0
    WATER BASED
    29.01.1985
    1489
    1.22
    10.0
    13.0
    WATER BASED
    29.01.1985
    1785
    1.40
    20.0
    22.0
    WATER BASED
    29.01.1985
    1865
    1.43
    19.0
    18.0
    WATER BASED
    29.01.1985
    1865
    1.43
    50.0
    18.0
    WATER BASED
    29.01.1985
    1865
    1.43
    50.0
    18.0
    WATER BASED
    29.01.1985
    1985
    1.52
    55.0
    18.0
    WATER BASED
    31.01.1985
    2138
    1.62
    55.0
    16.0
    WATER BASED
    01.02.1985
    2325
    1.66
    55.0
    20.0
    WATER BASED
    04.02.1985
    2434
    1.69
    50.0
    15.0
    WATER BASED
    04.02.1985
    2454
    1.69
    52.0
    15.0
    WATER BASED
    04.02.1985
    2672
    1.68
    55.0
    16.0
    WATER BASED
    12.02.1985
    2750
    1.68
    64.0
    17.0
    WATER BASED
    13.02.1985
    2750
    1.68
    54.0
    13.0
    WATER BASED
    14.02.1985
    2750
    1.68
    54.0
    13.0
    WATER BASED
    14.02.1985
    2794
    1.63
    51.0
    18.0
    WATER BASED
    15.02.1985
    2836
    1.64
    51.0
    18.0
    WATER BASED
    18.02.1985
  • 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
    0.22