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

30/9-6

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    30/9-6
    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.
    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.
    30/9-6
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 8502 320 KOL1080
    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.
    539-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.
    44
    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,
    08.03.1987
    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.
    21.04.1987
    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.
    21.04.1989
    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.
    08.01.2015
    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.
    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.
    TARBERT FM
    2nd level with HC, age
    Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    MIDDLE JURASSIC
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd 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.
    NESS FM
    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.
    103.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3034.0
    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).
    3033.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.8
    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.
    STATFJORD GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 23' 3.77'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 49' 55.59'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6694389.17
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    490743.78
    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.
    1027

  • Wellbore history
    General
    Well 30/9-6 was drilled on the C-prospect on the southeast flank of the Oseberg Fault block. The structure is a rotated fault block with overall easterly dips towards the Horda Platform fault. The prospect is further bounded by faults to the west and to the northwest. The primary objective was to prove hydrocarbons in the Brent Group and verify possible pressure communication between the C-structure and the Oseberg Field Alpha structure to the North.
    Operations and results
    Wildcat well 30/9-6 was spudded with the semi-submersible installation Polar Pioneer on 8 March 1987 and drilled to TD at 3034 m in the Early Jurassic Statfjord Group. Drilling proceeded without significant problems. The well was drilled with spud mud down to 970 m and with KCl/polymer mud from 970 m to TD.
    The Brent Group was encountered at 2591 m and had oil in three differently pressured sand bodies, one in the Tarbert Formation and two in the Ness Formation. The lowest seen oil was at 2645 m in the Ness Formation. Four different pressure regimes were found in the Brent group. The Tarbert Formation has 6 m gross with 4.5 m net pay. The average porosity is 19% and the average water saturation is 44%. The Ness Formation has 49 m gross (hydrocarbon-bearing interval) with 13.3 m net pay (combining the two oil bearing sand bodies). The average porosity is 23% and the average water saturation is 39%.
    Weak shows were described in limestones in the interval 2318 m to 2358 m in the top of the Shetland Group. Otherwise, no oil shows were described outside of the oil-bearing Brent reservoirs.
    Five conventional cores were cut in the Brent Group from 2593.5 - 2686 m. RFT fluid samples were taken at 2619 m in both runs 2A and 2B. Run 2B was performed in order to verify the previous run.
    The well was permanently abandoned on 21 April as an oil discovery.
    Testing
    Two drill stem tests were performed.
    DST 1 tested the interval 2637.9 m to 2645.5 m in the lowermost oil bearing section in the Ness Formation. This test produced 185 Sm3 oil and 17175 Sm3 gas /day through a 20/64” choke. The GOR was 92.8 Sm3/Sm3, the oil density was 0.855 G/cm3, and the gas gravity was 0.698 (air = 1) with 1% CO2 and no detectable H2S. The bottom hole temperature was 100 °C.
    DST2 tested the interval 2591.5 m to 2596.5 m in the Tarbert Formation. This test produced 166 Sm3 oil and 16980 Sm3 gas /day through a 20/64” choke. The GOR was 102 Sm3/Sm3, the oil density was 0.856 g/cm3, and the gas gravity was 0.698 with 1% CO2 and no detectable H2S. The bottom hole temperature was 100 °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]
    970.00
    3032.00

  • 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
    2593.5
    2603.3
    [m ]
    2
    2608.0
    2623.5
    [m ]
    3
    2628.0
    2636.0
    [m ]
    4
    2649.0
    2665.2
    [m ]
    5
    2671.0
    2676.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    55.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2593-2597m
    Core photo at depth: 2597-2601m
    Core photo at depth: 2601-2603m
    Core photo at depth: 2604-2608m
    Core photo at depth: 2608-2612m
    2593-2597m
    2597-2601m
    2601-2603m
    2604-2608m
    2608-2612m
    Core photo at depth: 2612-2616m
    Core photo at depth: 2616-2620m
    Core photo at depth: 2620-2623m
    Core photo at depth: 2624-2628m
    Core photo at depth: 2628-2632m
    2612-2616m
    2616-2620m
    2620-2623m
    2624-2628m
    2628-2632m
    Core photo at depth: 2632-2636m
    Core photo at depth: 2645-2649m
    Core photo at depth: 2649-2653m
    Core photo at depth: 2653-2657m
    Core photo at depth: 2657-2661m
    2632-2636m
    2645-2649m
    2649-2653m
    2653-2657m
    2657-2661m
    Core photo at depth: 2661-2665m
    Core photo at depth: 2665-2670m
    Core photo at depth: 2670-2674m
    Core photo at depth: 2674-2676m
    Core photo at depth:  
    2661-2665m
    2665-2670m
    2670-2674m
    2674-2676m

  • 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
    2637.90
    2645.50
    OIL
    08.04.1987 - 00:00
    YES
    DST
    DST2
    2591.50
    2596.50
    OIL
    12.04.1987 - 00:00
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.19
    pdf
    0.24
    pdf
    1.32
    pdf
    1.08

  • 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
    5.83
    pdf
    10.66

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2638
    2646
    7.9
    2.0
    2592
    2597
    7.9
    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
    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
    185
    17175
    0.855
    0.698
    93
    2.0
    166
    16980
    0.856
    0.698
    102

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL CET
    1600
    2962
    CST
    2165
    2570
    CST
    2583
    2999
    DIL LSS LDT CNL GR SP CAL
    950
    3028
    DLL MSFL NGT
    2567
    2800
    MWD GR SON NEU RES
    126
    2587
    RFT
    2591
    3002
    RFT
    2592
    2643
    RFT
    2619
    0
    RLL GR EWR COND
    2565
    2655
    SHDT
    950
    3033
    VSP
    680
    2950

  • 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
    213.0
    36
    214.0
    0.00
    LOT
    INTERM.
    13 3/8
    954.0
    17 1/2
    970.0
    1.71
    LOT
    INTERM.
    9 5/8
    2567.0
    12 1/4
    2587.0
    1.81
    LOT
    LINER
    7
    3031.0
    8 1/2
    3034.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    124
    0.00
    WATER BASED
    21.04.1987
    131
    0.00
    WATER BASED
    21.04.1987
    160
    1.03
    WATER BASED
    09.03.1987
    165
    0.00
    WATER BASED
    21.04.1987
    214
    1.03
    WATER BASED
    10.03.1987
    863
    1.03
    WATER BASED
    11.03.1987
    970
    1.03
    WATER BASED
    12.03.1987
    970
    1.34
    27.0
    11.0
    WATER BASED
    13.03.1987
    1438
    1.34
    28.0
    12.0
    WATER BASED
    16.03.1987
    1527
    1.40
    37.0
    18.0
    WATER BASED
    16.03.1987
    1888
    1.40
    31.0
    12.0
    WATER BASED
    16.03.1987
    2136
    1.40
    30.0
    12.0
    WATER BASED
    17.03.1987
    2267
    1.40
    32.0
    12.0
    WATER BASED
    18.03.1987
    2350
    1.21
    25.0
    9.0
    WATER BASED
    21.04.1987
    2399
    1.40
    34.0
    13.0
    WATER BASED
    19.03.1987
    2465
    1.21
    22.0
    7.0
    WATER BASED
    21.04.1987
    2472
    1.40
    32.0
    10.0
    WATER BASED
    20.03.1987
    2528
    1.40
    33.0
    9.0
    WATER BASED
    2587
    1.40
    31.0
    9.0
    WATER BASED
    2587
    1.21
    17.0
    6.0
    WATER BASED
    24.03.1987
    2593
    1.21
    27.0
    10.0
    WATER BASED
    25.03.1987
    2624
    1.21
    27.0
    10.0
    WATER BASED
    26.03.1987
    2634
    1.21
    26.0
    10.0
    WATER BASED
    13.04.1987
    2634
    1.21
    26.0
    9.0
    WATER BASED
    14.04.1987
    2634
    1.21
    20.0
    7.0
    WATER BASED
    21.04.1987
    2651
    1.21
    26.0
    10.0
    WATER BASED
    30.03.1987
    2686
    1.21
    27.0
    10.0
    WATER BASED
    30.03.1987
    2759
    1.21
    24.0
    9.0
    WATER BASED
    30.03.1987
    2858
    1.21
    24.0
    8.0
    WATER BASED
    30.03.1987
    2965
    1.21
    28.0
    11.0
    WATER BASED
    06.04.1987
    2965
    1.21
    27.0
    11.0
    WATER BASED
    06.04.1987
    2965
    1.21
    27.0
    11.0
    WATER BASED
    07.04.1987
    2965
    1.21
    27.0
    11.0
    WATER BASED
    08.04.1987
    2965
    1.21
    27.0
    11.0
    WATER BASED
    13.04.1987
    2965
    1.21
    25.0
    10.0
    WATER BASED
    13.04.1987
    3034
    1.21
    24.0
    10.0
    WATER BASED
    31.03.1987
    3034
    1.21
    24.0
    10.0
    WATER BASED
    01.04.1987
    3034
    1.21
    24.0
    9.0
    WATER BASED
    02.04.1987
    3034
    1.21
    25.0
    9.0
    WATER BASED
    03.04.1987

  • 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
    0.23