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

30/6-19

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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.
    30/6-19
    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).
    WILDCAT
    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
    Multilateral
    Indicator telling if the parent well is multilateral, meaning it has more than one branch radiating from the main borehole. Example of legal values: YES, NO. See also Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    NO
    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.
    30/6-19
    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.
    Norsk Hydro Produksjon AS
    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.
    511-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.
    74
    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,
    09.04.1986
    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.
    21.06.1986
    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.
    21.06.1988
    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.
    29.03.2014
    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
    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.
    YES
    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.
    BRENT GP
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    159.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3301.0
    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).
    3299.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    137
    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.
    EARLY JURASSIC
    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.
    EIRIKSSON FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 42' 58.03'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 54' 54.18'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6731330.07
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    495364.23
    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.
    489

  • Wellbore history
    General
    Well 30/6-19 was drilled on the Beta Saddle prospect between the Veslefrikk field and the 30/6-5 Oseberg East (Beta South) discovery. The objectives of the well were to prove hydrocarbons in the Brent Group, the Cook Formation, and the Statfjord Group. Planned TD was ca 3400 m or ca 100 m into the Statfjord Formation.
    Operations and results
    Well 30/6-19 was spudded with the semi-submersible installation Polar Pioneer on 9 April 1986 and drilled to TD at 3301 m in the Early Jurassic Statfjord Group, Eirikson Formation. Drilling proceeded without significant problems down to 1589 m where the string got stuck and the well was sidetracked at 1179 m. At 3117 m the string got stuck and a cement plug was set at 2847 m. The well was sidetracked again at 2822 m and drilled to TD.
    The Brent Group (2857 - 2989 m) contained oil down to the OWC at 2956.5 m (Free water level from RFT). Net pay in the oil zone is 58.1 m with an average porosity of 18.8% and an average water saturation of 48.3%. No additional hydrocarbon reservoirs were encountered by the well and only occasional weak shows were seen on sandstone stringers in the Drake Formation and single grains in the Statfjord Group. RFT pressures showed the Cook Formation to be overpressured and the Statfjord Group to be underpressured relative to the Brent Group. This assumes same water density as in the Brent Group water zone.
    Four conventional cores were cut in the Brent reservoir from 2858 - 2970 m. Core depths are ca 1.5 m shallower than logger's depth. RFT pressure recordings were performed throughout the Brent Group and in the Cook and Statfjord Formations. Segregated RFT samples were taken in the final sidetrack in the Ness Formation (2869 m; water and a little oil), the Etive Formation (2909 m; oil), and in the Oseberg Formation (2954.8 m water and a little oil).
    The well was suspended 21 June 1986 for further testing at a later time. It is classified as an oil and gas discovery.
    Testing
    Three drill stem tests were performed.
    DST 1 tested the interval 2945-2954.0 in the Lower Oseberg Formation. It produced 564 Sm3 oil and 26000 Sm3 gas through a 40/64" choke. GOR was 46 Sm3/Sm3. Oil density was 0.864 g/cm3 and associated gas was 0.85 (air = 1) with 5% CO2 and 3.5 ppm H2S. Bottom hole temperature in the test was 124 deg C.
    DST 2 tested the interval 2907 - 2932.3 m in the Upper Oseberg, Rannoch and Etive Formations. It produced 797 Sm3 oil and 34000 Sm3 gas through a 36/64" choke. GOR was 43 Sm3/Sm3. Oil density was 0.833 g/cm3 and associated gas was 0.78 (air = 1) with 5% CO2 and 4 ppm H2S. Bottom hole temperature in the test was 122 deg C.
    DST 3 tested the interval 2876-2884 m in the Ness Formation. It produced 668 Sm3 oil and 25000 Sm3 gas through a 52/64" choke. GOR was 50 Sm3/Sm3. Oil density was 0.831 g/cm3 and associated gas was 0.86 (air = 1) with 4.5% CO2 and 5 ppm H2S. Bottom hole temperature in the test was 123 deg 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]
    620.00
    3300.00

  • 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
    2858.0
    2886.0
    [m ]
    2
    2886.0
    2913.7
    [m ]
    3
    2914.0
    2942.0
    [m ]
    4
    2942.0
    2954.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    95.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2858-2862m
    Core photo at depth: 2862-2866m
    Core photo at depth: 2866-2870m
    Core photo at depth: 2870-2874m
    Core photo at depth: 2874-2878m
    2858-2862m
    2862-2866m
    2866-2870m
    2870-2874m
    2874-2878m
    Core photo at depth: 2878-2882m
    Core photo at depth: 2882-2886m
    Core photo at depth: 2886-2890m
    Core photo at depth: 2890-2894m
    Core photo at depth: 2894-2898m
    2878-2882m
    2882-2886m
    2886-2890m
    2890-2894m
    2894-2898m
    Core photo at depth: 2898-2902m
    Core photo at depth: 2902-2906m
    Core photo at depth: 2906-2910m
    Core photo at depth: 2910-2913m
    Core photo at depth: 2914-2918m
    2898-2902m
    2902-2906m
    2906-2910m
    2910-2913m
    2914-2918m
    Core photo at depth: 2918-2922m
    Core photo at depth: 2922-2926m
    Core photo at depth: 2926-2930m
    Core photo at depth: 2930-2934m
    Core photo at depth: 2934-2938m
    2918-2922m
    2922-2926m
    2926-2930m
    2930-2934m
    2934-2938m
    Core photo at depth: 2938-2942m
    Core photo at depth: 2942-2046m
    Core photo at depth: 2946-2950m
    Core photo at depth: 2950-2954m
    Core photo at depth: 2954-2958m
    2938-2942m
    2942-2046m
    2946-2950m
    2950-2954m
    2954-2958m
    Core photo at depth: 2958-2962m
    Core photo at depth: 2962-2966m
    Core photo at depth: 2966-2970m
    Core photo at depth:  
    Core photo at depth:  
    2958-2962m
    2962-2966m
    2966-2970m

  • 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
    2945.00
    2954.00
    OIL
    06.06.1986 - 00:00
    YES
    DST
    DST2
    2907.00
    2932.30
    OIL
    11.06.1986 - 00:00
    YES
    DST
    DST3
    2876.00
    2784.00
    15.06.1986 - 00:00
    YES

  • 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
    SURF.COND.
    20
    602.0
    26
    729.0
    1.39
    LOT
    INTERM.
    13 3/8
    1495.0
    17 1/2
    1589.0
    1.76
    LOT
    INTERM.
    9 5/8
    2790.0
    12 1/4
    2804.0
    1.68
    LOT
    LINER
    7
    3273.0
    8 1/2
    3301.0
    0.00
    LOT

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2945
    2954
    15.9
    2.0
    2907
    2932
    14.3
    3.0
    2876
    2884
    20.6
    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
    3.0
    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
    564
    26000
    0.861
    0.850
    46
    2.0
    797
    34000
    0.833
    0.780
    52
    3.0
    668
    25000
    0.831
    0.860
    50

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL CET
    335
    1493
    CBL VDL CET
    1327
    3004
    CST
    2215
    2795
    CST
    2242
    2751
    CST
    2812
    3299
    DIL LSS GR SP
    550
    3302
    DLL MSFL LSS GR
    2790
    3065
    LDL CNL NGT CAL GR
    602
    3302
    RFT
    2858
    2926
    RFT
    2858
    3283
    SHDT
    1493
    3302

  • Lithostratigraphy

  • 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
    15.95

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    267
    1.03
    WATER BASED
    09.04.1986
    563
    1.05
    10.0
    8.0
    WATER BASED
    10.04.1986
    614
    1.15
    9.0
    27.0
    WATER BASED
    13.04.1986
    614
    1.05
    14.0
    31.0
    WATER BASED
    13.04.1986
    614
    1.05
    16.0
    41.0
    WATER BASED
    13.04.1986
    614
    1.09
    15.0
    9.0
    WATER BASED
    14.04.1986
    619
    1.09
    15.0
    9.0
    WATER BASED
    15.04.1986
    729
    1.09
    12.0
    9.0
    WATER BASED
    16.04.1986
    1153
    1.15
    20.0
    12.0
    WATER BASED
    20.04.1986
    1202
    1.13
    20.0
    11.0
    WATER BASED
    21.04.1986
    1271
    1.11
    21.0
    15.0
    WATER BASED
    17.04.1986
    1359
    1.15
    22.0
    13.0
    WATER BASED
    22.04.1986
    1539
    1.25
    27.0
    16.0
    WATER BASED
    23.04.1986
    1539
    1.25
    27.0
    16.0
    WATER BASED
    24.04.1986
    1539
    1.40
    27.0
    20.0
    WATER BASED
    27.04.1986
    1589
    1.11
    20.0
    13.0
    WATER BASED
    20.04.1986
    1718
    1.40
    23.0
    15.0
    WATER BASED
    27.04.1986
    2073
    1.40
    25.0
    15.0
    WATER BASED
    27.04.1986
    2230
    1.40
    21.0
    14.0
    WATER BASED
    29.04.1986
    2388
    1.40
    17.0
    8.0
    WATER BASED
    29.04.1986
    2453
    1.40
    21.0
    11.0
    WATER BASED
    01.05.1986
    2496
    1.40
    17.0
    8.0
    WATER BASED
    01.05.1986
    2590
    1.40
    19.0
    10.0
    WATER BASED
    04.05.1986
    2681
    1.40
    17.0
    9.0
    WATER BASED
    04.05.1986
    2800
    1.22
    15.0
    8.0
    WATER BASED
    20.05.1986
    2803
    1.40
    15.0
    9.0
    WATER BASED
    04.05.1986
    2803
    1.40
    14.0
    8.0
    WATER BASED
    05.05.1986
    2804
    1.40
    18.0
    9.0
    WATER BASED
    06.05.1986
    2804
    1.40
    18.0
    8.0
    WATER BASED
    08.05.1986
    2804
    1.40
    18.0
    9.0
    WATER BASED
    08.05.1986
    2840
    1.21
    10.0
    6.0
    WATER BASED
    11.05.1986
    2846
    1.25
    21.0
    8.0
    WATER BASED
    21.05.1986
    2886
    1.21
    9.0
    5.0
    WATER BASED
    11.05.1986
    2900
    1.19
    14.0
    8.0
    WATER BASED
    15.06.1986
    2900
    1.19
    14.0
    8.0
    WATER BASED
    16.06.1986
    2900
    1.19
    14.0
    8.0
    WATER-BASED
    17.06.1986
    2900
    1.19
    13.0
    7.0
    WATER-BASED
    18.06.1986
    2900
    1.19
    13.0
    7.0
    WATER-BASED
    19.06.1986
    2900
    1.19
    22.0
    13.0
    WATER-BASED
    22.06.1986
    2914
    1.21
    16.0
    8.0
    WATER BASED
    11.05.1986
    2939
    1.18
    12.0
    5.0
    WATER BASED
    10.06.1986
    2939
    1.18
    12.0
    5.0
    WATER BASED
    11.06.1986
    2939
    1.19
    12.0
    5.0
    WATER BASED
    12.06.1986
    2939
    1.19
    18.0
    8.0
    WATER BASED
    09.06.1986
    2939
    1.19
    14.0
    8.0
    WATER BASED
    15.06.1986
    2963
    1.22
    13.0
    8.0
    WATER BASED
    12.05.1986
    2976
    1.25
    23.0
    11.0
    WATER BASED
    25.05.1986
    3000
    1.25
    20.0
    8.0
    WATER BASED
    25.05.1986
    3002
    1.21
    11.0
    7.0
    WATER BASED
    13.05.1986
    3038
    1.21
    14.0
    8.0
    WATER BASED
    14.05.1986
    3043
    1.19
    18.0
    8.0
    WATER BASED
    05.06.1986
    3043
    1.19
    16.0
    7.0
    WATER BASED
    01.06.1986
    3043
    1.19
    14.0
    6.0
    WATER BASED
    02.06.1986
    3043
    1.19
    13.0
    6.0
    WATER BASED
    03.06.1986
    3043
    1.19
    18.0
    8.0
    WATER BASED
    04.06.1986
    3043
    1.19
    18.0
    8.0
    WATER BASED
    08.06.1986
    3088
    1.22
    14.0
    9.0
    WATER BASED
    15.05.1986
    3110
    1.25
    19.0
    8.0
    WATER BASED
    25.05.1986
    3117
    1.21
    20.0
    10.0
    WATER BASED
    19.05.1986
    3117
    1.22
    17.0
    9.0
    WATER BASED
    19.05.1986
    3117
    1.22
    16.0
    9.0
    WATER BASED
    19.05.1986
    3117
    1.22
    14.0
    7.0
    WATER BASED
    19.05.1986
    3161
    1.25
    18.0
    8.0
    WATER BASED
    26.05.1986
    3264
    1.25
    18.0
    8.0
    WATER BASED
    27.05.1986
    3301
    1.25
    20.0
    10.0
    WATER BASED
    28.05.1986
    3301
    1.25
    20.0
    10.0
    WATER BASED
    29.05.1986
    3301
    1.19
    16.0
    8.0
    WATER BASED
    01.06.1986