Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

34/10-21

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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.
    34/10-21
    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.
    34/10-21
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 8134 - 173 SP. 160
    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.
    Den norske stats oljeselskap a.s
    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.
    426-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.
    89
    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,
    26.07.1984
    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.
    22.10.1984
    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.
    22.10.1986
    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.
    02.12.2014
    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.
    GAS
    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.
    TARBERT FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    29.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    136.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4005.0
    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).
    4003.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.7
    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.
    STATFJORD GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 7' 33.04'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 8' 54.53'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6777264.06
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    454125.77
    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.
    221

  • Wellbore history
    General
    Well 34/10-21 was the third well drilled on the Gullfaks South structure in the Tampen Spur area in the northern North Sea. The objective was to test for possible hydrocarbon accumulations and for a possible extension of reserves in the Gullfaks South field. Targets included the Brent, Cook and Statfjord Sandstones and possible sand accumulations in the Early Cretaceous.
    Operations and results
    Appraisal well 34/10-21 was spudded with the semi-submersible installation Dyvi Delta on 26 July 1984 and drilled to TD at 4005 m in Late Triassic sediments of the Raude Formation. The well was drilled with gel/seawater down to 615 m, with gypsum/CMC/lignosulphonate from 615 m 3196 m, and with gel/lignosulphonate from 3196 m to TD.
    No sandstones were encountered in the Early Cretaceous. Hydrocarbon bearing Brent sandstone was encountered at 3287 m, with the hydrocarbon/water contact established at 3333 m+/-3 m. No hydrocarbons were identified in the Cook sandstones. The logs indicated hydrocarbons in the Statfjord Group, but drill stem test gave no flow from these sandstones. No shows were described above the Tarbert reservoir. Below the OWC, shows on sandstone were described down to 3359 m.
    Six cores were cut; four from 3289 m to 3383 in the Brent Group and two from 3970 m to 3985.5 in the Raude Formation. Core recoveries were from 90 % to 100 %. RFT fluid samples were taken in the Brent Group oil zone at 3298.5 m, 3317.3 m, and 3325.0 m.
    The well was permanently abandoned on 22 October 1984 as a gas appraisal well.
    Testing
    Two drill stem tests were performed.
    DST 1 tested the interval 3905.2 m to 3922.2 m in the Statfjord Group. This test gave no flow.
    DST 2 tested the interval 3290.7 - 3312.7 m in the Tarbert Formation. This test produced 130 Sm3 condensate and 837800 Sm3 gas /day through a 14.29 mm choke. The GOR was 6424 SM3/Sm3, the condensate density was 0.80 g/cm3, the gas gravity was 0.65 (air=1). The downhole temperature reading in the test was 119.3 °C.

  • 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]
    228.00
    4002.00

  • 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
    3289.0
    3306.3
    [m ]
    2
    3307.0
    3331.4
    [m ]
    3
    3333.9
    3359.0
    [m ]
    4
    3361.5
    3383.2
    [m ]
    5
    3970.0
    3973.6
    [m ]
    6
    3973.5
    3985.4
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    104.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3289-3295m
    Core photo at depth: 3295-3301m
    Core photo at depth: 3301-3306m
    Core photo at depth: 3307-3313m
    Core photo at depth: 3313-3319m
    3289-3295m
    3295-3301m
    3301-3306m
    3307-3313m
    3313-3319m
    Core photo at depth: 3319-3325m
    Core photo at depth: 3325-3331m
    Core photo at depth: 3331-3331m
    Core photo at depth: 3333-3339m
    Core photo at depth: 3339-3345m
    3319-3325m
    3325-3331m
    3331-3331m
    3333-3339m
    3339-3345m
    Core photo at depth: 3345-3351m
    Core photo at depth: 3351-3357m
    Core photo at depth: 3357-3359m
    Core photo at depth: 3361-3367m
    Core photo at depth: 3367-3373m
    3345-3351m
    3351-3357m
    3357-3359m
    3361-3367m
    3367-3373m
    Core photo at depth: 3373-3379m
    Core photo at depth: 3379-3383m
    Core photo at depth: 3970-3973m
    Core photo at depth: 3973-3979m
    Core photo at depth: 3979-3985m
    3373-3379m
    3379-3383m
    3970-3973m
    3973-3979m
    3979-3985m
    Core photo at depth: 3985-3985m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3985-3985m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3045.0
    [m]
    SWC
    GEOCH
    3063.0
    [m]
    SWC
    GEOCH
    3077.0
    [m]
    SWC
    GEOCH
    3089.0
    [m]
    SWC
    GEOCH
    3102.0
    [m]
    DC
    GEOCH
    3103.0
    [m]
    SWC
    GEOCH
    3111.0
    [m]
    DC
    GEOCH
    3120.0
    [m]
    DC
    GEOCH
    3132.0
    [m]
    DC
    GEOCH
    3141.0
    [m]
    DC
    GEOCH
    3153.0
    [m]
    DC
    GEOCH
    3162.0
    [m]
    DC
    GEOCH
    3171.0
    [m]
    DC
    GEOCH
    3180.0
    [m]
    DC
    GEOCH
    3195.0
    [m]
    DC
    GEOCH
    3210.0
    [m]
    DC
    GEOCH
    3219.0
    [m]
    DC
    GEOCH
    3231.0
    [m]
    DC
    GEOCH
    3243.0
    [m]
    DC
    GEOCH
    3258.0
    [m]
    DC
    GEOCH
    3270.0
    [m]
    DC
    GEOCH
    3282.0
    [m]
    DC
    GEOCH
    3288.0
    [m]
    DC
    GEOCH

  • 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
    TEST2
    3290.00
    3312.00
    CONDENSATE
    13.10.1984 - 00:00
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.87
    pdf
    2.69
    pdf
    3.55
    pdf
    3.16
    pdf
    11.90

  • Documents – reported by the production licence (period for duty of secrecy expired)

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3905
    3922
    0.0
    2.0
    3290
    3313
    25.4
    2.1
    3290
    3312
    25.4
    2.2
    3290
    3312
    25.4
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.0
    21.000
    2.1
    13.000
    45.000
    2.2
    27.000
    14.000
    45.000
    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
    2.0
    194
    1132000
    0.804
    5840
    2.1
    197
    1131000
    0.804
    5732
    2.2
    1130000
    0.800
    5700

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    750
    3954
    CEQL
    3035
    3954
    CET GR
    3035
    3966
    CST GR
    2855
    3103
    DLL MSFL GR
    3181
    4006
    ISF LSS MSFL GR
    600
    4005
    LDL CNL GR
    600
    4006
    MWD
    226
    600
    NGS
    3193
    3611
    RFT GR
    3290
    3512
    RFT GR
    3293
    3498
    SHDT GR
    1896
    3961
    WSS VSP
    240
    4005

  • 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
    226.0
    36
    228.0
    0.00
    LOT
    SURF.COND.
    20
    600.0
    26
    745.0
    1.81
    LOT
    INTERM.
    13 3/8
    1896.0
    17 1/2
    1990.0
    1.56
    LOT
    INTERM.
    9 5/8
    3181.0
    12 1/4
    3196.0
    1.99
    LOT
    LINER
    7
    4000.0
    8 1/2
    4005.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    228
    1.03
    WATER BASED
    30.07.1984
    495
    1.06
    8.0
    20.0
    WATER BASED
    30.07.1984
    629
    1.22
    7.0
    20.0
    WATER BASED
    31.07.1984
    745
    1.10
    5.0
    8.0
    WATER BASED
    03.08.1984
    1237
    1.11
    5.0
    7.1
    WATER BASED
    07.08.1984
    1755
    1.10
    6.8
    6.8
    WATER BASED
    07.08.1984
    1760
    1.17
    6.8
    7.7
    WATER BASED
    07.08.1984
    1915
    1.17
    8.0
    4.8
    WATER BASED
    07.08.1984
    1915
    1.20
    10.0
    5.7
    WATER BASED
    07.08.1984
    1915
    1.22
    10.0
    7.7
    WATER BASED
    07.08.1984
    1915
    1.20
    10.0
    5.7
    WATER BASED
    07.08.1984
    1915
    1.22
    10.0
    7.7
    WATER BASED
    07.08.1984
    1918
    1.29
    9.0
    4.2
    WATER BASED
    10.08.1984
    1990
    1.29
    13.0
    4.8
    WATER BASED
    14.08.1984
    2134
    1.28
    14.0
    4.9
    WATER BASED
    14.08.1984
    2851
    1.26
    15.0
    5.8
    WATER BASED
    20.08.1984
    2948
    1.27
    15.0
    5.0
    WATER BASED
    20.08.1984
    2949
    1.33
    14.0
    7.7
    WATER BASED
    20.08.1984
    3027
    1.33
    17.0
    6.6
    WATER BASED
    20.08.1984
    3046
    1.33
    WATER BASED
    21.08.1984
    3047
    1.39
    16.0
    7.3
    WATER BASED
    21.08.1984
    3135
    1.39
    18.0
    7.3
    WATER BASED
    22.08.1984
    3185
    1.44
    19.0
    8.0
    WATER BASED
    23.08.1984
    3196
    1.44
    18.0
    8.0
    WATER BASED
    24.08.1984
    3220
    1.44
    17.0
    7.7
    WATER BASED
    28.08.1984
    3361
    1.44
    14.0
    6.0
    WATER BASED
    03.09.1984
    3586
    1.44
    16.0
    7.9
    WATER BASED
    06.09.1984
    3612
    1.44
    15.0
    6.9
    WATER BASED
    10.09.1984
    3700
    1.44
    15.0
    6.0
    WATER BASED
    11.09.1984
    3760
    1.44
    17.0
    5.2
    WATER BASED
    13.09.1984
    3846
    1.44
    17.0
    5.0
    WATER BASED
    17.09.1984
    3962
    1.44
    16.0
    5.0
    WATER BASED
    19.09.1984

  • 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