Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.11.2024 - 09:09
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34/4-7

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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.
    34/4-7
    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.
    34/4-7
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    SG 8420 - 084 SP. 595
    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.
    535-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.
    85
    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,
    17.02.1987
    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.
    12.05.1987
    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.
    12.05.1989
    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.
    26.10.2009
    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 TRIASSIC
    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.
    LUNDE 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.
    354.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2950.0
    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).
    2950.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    110
    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° 31' 9.83'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 15' 15.45'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6821032.19
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    460326.58
    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.
    943

  • Wellbore history
    General
    Well 34/4-7 was drilled in the north-eastern margin of the Snorre Field. The Late Triassic - Early Jurassic reservoirs of the Snorre Field are made up of a complete series of rotated fault blocks dipping between 5 and 12 degrees towards west and northwest. The primary purpose of the well was to assess the upper part of the Lunde Formation. The well was located to provide data on the reservoir quality of both oil and water bearing parts of upper Lunde, and to investigate potential changes in porosity and permeability across the oil/water contact. Further objectives were to verify a revised velocity model for the 34/4 part of the Snorre Field and reduce structural uncertainty.
    Operations and results
    Wildcat well 34/4-7 was spudded with the semi-submersible installation Treasure Saga on 17 February 1987 and drilled to TD at 2950 m in the Late Triassic Lunde Formation. Drilling proceeded without significant problems. The 26" section was drilled first as a 17 1/2" pilot hole down to 915 m as a precaution against shallow gas, then opened up to 26" with an underreamer. The well was drilled with seawater and bentonite down to 470 m, with gel mud from 470 m to 915 m, with gypsum/polymer mud from 915 m to 2407 m, and with KCl mud from 2407 m to TD.
    Apart from the Pliocene Utsira Formation at 1062 m and some minor sandy intervals in Middle Oligocene to Late Miocene, the upper section down to Triassic consists mainly of claystones. No Jurassic sediments were encountered in the well. The Triassic Lunde Formation was encountered at 2502 m, 35 m deeper than expected and is composed of sandstones with minor siltstones in the upper part. From 2736 m the Lunde Formation consists of interbedded sandstone, claystone and limestone and from about 2872 m to TD the lithology is mainly sandstones with minor claystone and limestone. Hydrocarbons were encountered in the section belonging to the upper member of the Lunde Formation, from 2502 m down to an OWC, defined from FMT pressure gradients and PLT logging during DST, at 2586 m. The cores from the oil bearing part reservoir shows light brown oil stain with good odour, strong bright yellow fluorescence, instant blue white cut and pale yellow residue upon evaporation. Below 2586 m both shows and cut become poorer, and from 2610 m there were no shows.
    Apart from in the reservoir as described above traces of shows were seen first at 2080 m in silty/sandy laminas of the Shetland Group. These are described as yellow fluorescence with slowly to very slowly streaming white yellow cut. From 2270 m the shows are slightly decreasing to a dull yellow fluorescence with very slow streaming light yellow cut, occasionally no cut.
    Ten cores were cut in the Lunde Formation in the interval 2506 - 2711.5 m with a total recovery of 199.4 m. Segregated FMT samples were taken at 2509 m, 2581.5 m, 2584.4 m, and at 2592.5 m. The sample from 2509 m was sent to the laboratory for PVT analyses. It contained ca 2 l oil and 1.1 l of mud filtrate.
    The well was permanently abandoned on 12 May 1987 as an oil appraisal
    Testing
    Two production tests were performed in the upper member of the Lunde Formation.
    Test No 1 was carried out from the intervals 2579 - 2587 m and 2590 - 2596 m, straddling the oil/water contact. The main flow produced 190 Sm3 oil and 215 m3 water/day through a 7.9 mm choke. The GOR was 105 Sm3/Sm3, the dead oil density was 0.833 g/cm3 and the gas gravity was 0.81 (air = 1). A Production Logging Test (PLT)-flow followed. The PLT flow confirmed the OWC at exactly 2586 m. The temperature recorded by the Production Logging tool was 99.4 deg C, close to the maximum 99.6 deg C measured in the preceding more unstable clean-up flow. After the PLT flow an injection test was performed as the final part of Test No 1.
    Test No 2 was carried out from the intervals 2506 - 2512.5 m, 2517 - 2529 m, 2532.5 - 2535.5 m, 2544 - 2550.5, and 2560 - 2566 m in the oil zone. The well produced oil without water continuously for 18 days. During the last 17 days the test produced initially 1550 Sm3/day declining to a fairly constant rate around 1390 Sm3/day through a 14.3 mm choke. The GOR stabilised at 85 Sm3/Sm3 while the temperature stabilized at 96.9 deg C. The dead oil density was 0.835 g/cm3 and the gas gravity was 0.73 (air = 1). The wellhead pressure dropped from 184 to 161 bar through the test.
    The down-hole test temperatures are significantly higher than the wire line temperatures from similar depths. The bottom hole temperature at final TD in the well are based on the temperature gradient given by the DST temperatures.

  • 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]
    480.00
    2950.00

  • 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
    2506.0
    2511.0
    [m ]
    2
    2512.0
    2531.2
    [m ]
    3
    2536.0
    2563.5
    [m ]
    4
    2563.5
    2591.3
    [m ]
    5
    2591.3
    2603.0
    [m ]
    6
    2619.3
    2647.0
    [m ]
    7
    2647.0
    2656.5
    [m ]
    8
    2656.5
    2675.0
    [m ]
    9
    2675.0
    2692.7
    [m ]
    10
    2693.0
    2711.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    183.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • 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
    DST1
    2579.00
    2596.00
    02.04.1987 - 04:00
    YES
    DST
    DST2
    2506.00
    2566.00
    19.04.1987 - 16:00
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.79
    pdf
    2.14

  • 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
    2.83
    pdf
    10.00

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2596
    2579
    7.9
    2.0
    2506
    2566
    14.3
    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
    38.000
    99
    2.0
    96
    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
    190
    19950
    0.833
    0.870
    105
    2.0
    1378
    118000
    0.835
    0.730
    85

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL GR
    640
    1872
    CDL CNL GR
    1872
    2647
    CDL CNL GR
    2472
    2940
    CDL GR
    902
    1863
    COREGUN
    918
    1867
    COREGUN
    1984
    2925
    DIFL LSBHC GR
    902
    1882
    DIFL LSBHC GR
    1872
    2939
    DIPLOG
    1872
    2941
    DLL MLL GR
    2450
    2646
    FMT HP
    2509
    2632
    FMT HP
    2509
    2874
    MWD
    0
    915
    MWD
    915
    1887
    MWD
    1887
    2950
    VELOCITY
    907
    2926

  • 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
    465.0
    36
    470.0
    1.16
    LOT
    SURF.COND.
    20
    902.0
    26
    915.0
    1.59
    LOT
    INTERM.
    13 3/8
    1872.0
    17 1/2
    2145.0
    1.83
    LOT
    INTERM.
    9 5/8
    2921.0
    12 1/4
    2950.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    422
    1.06
    WATER BASED
    18.02.1987
    470
    1.06
    WATER BASED
    20.02.1987
    470
    1.06
    WATER BASED
    23.02.1987
    680
    1.12
    4.0
    12.0
    WATER BASED
    23.02.1987
    915
    1.14
    4.0
    12.5
    WATER BASED
    23.02.1987
    915
    1.14
    7.0
    16.3
    WATER BASED
    23.02.1987
    915
    1.16
    6.0
    14.9
    WATER BASED
    24.02.1987
    915
    1.03
    WATER BASED
    27.02.1987
    1113
    1.16
    20.0
    10.6
    WATER BASED
    27.02.1987
    1480
    1.20
    20.0
    10.1
    WATER BASED
    02.03.1987
    1644
    1.30
    25.0
    11.1
    WATER BASED
    02.03.1987
    1863
    1.47
    21.0
    8.2
    WATER BASED
    05.03.1987
    1887
    1.47
    21.0
    7.2
    WATER BASED
    05.03.1987
    1887
    1.47
    24.0
    9.6
    WATER BASED
    05.03.1987
    1887
    1.47
    24.0
    10.6
    WATER BASED
    05.03.1987
    2145
    1.58
    23.0
    10.1
    WATER BASED
    10.03.1987
    2298
    1.68
    26.0
    11.5
    WATER BASED
    10.03.1987
    2407
    1.70
    26.0
    13.0
    WATER BASED
    10.03.1987
    2471
    1.70
    23.0
    7.7
    WATER BASED
    10.03.1987
    2513
    1.70
    23.0
    8.7
    WATER BASED
    10.03.1987
    2563
    1.70
    26.0
    8.7
    WATER BASED
    12.03.1987
    2591
    1.70
    24.0
    7.7
    WATER BASED
    12.03.1987
    2647
    1.70
    25.0
    8.7
    WATER BASED
    13.03.1987
    2647
    1.70
    27.0
    8.2
    WATER BASED
    23.03.1987
    2647
    1.70
    25.0
    8.7
    WATER BASED
    23.03.1987
    2675
    1.70
    25.0
    8.2
    WATER BASED
    23.03.1987
    2712
    1.70
    25.0
    8.2
    WATER BASED
    23.03.1987
    2792
    1.70
    25.0
    7.2
    WATER BASED
    23.03.1987
    2869
    1.70
    13.0
    4.4
    WATER BASED
    27.03.1987
    2869
    1.70
    14.0
    4.4
    WATER BASED
    27.03.1987
    2869
    1.70
    12.0
    5.3
    WATER BASED
    31.03.1987
    2869
    1.03
    WATER BASED
    13.04.1987
    2869
    1.70
    20.0
    4.8
    WATER BASED
    27.03.1987
    2950
    1.70
    22.0
    4.4
    WATER BASED
    27.03.1987
    2950
    1.70
    25.0
    8.2
    WATER BASED
    23.03.1987
    2950
    1.70
    22.0
    5.3
    WATER BASED
    2950
    1.70
    23.0
    6.3
    WATER BASED
    23.03.1987
    2950
    1.70
    24.0
    6.8
    WATER BASED
    23.03.1987
    2950
    1.70
    22.0
    4.4
    WATER BASED
    24.03.1987

  • 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