Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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21.11.2024 - 01:28
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30/9-1

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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.
    30/9-1
    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.
    30/9-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    705 118 SP 332
    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.
    351-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.
    98
    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,
    24.10.1982
    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.
    29.01.1983
    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.
    29.01.1985
    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.
    07.01.2015
    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.
    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.
    BRENT GP
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    106.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2895.0
    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).
    2895.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    112
    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.
    DRAKE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 28' 25.09'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 52' 45.38'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6704324.73
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    493362.24
    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.
    65

  • Wellbore history
    General
    Well 30/9-1 was drilled on the southeast part of the Oseberg fault block (Alpha structure) in the North Sea. The Alpha structure is an eastward tilted fault block that contains proven reserves of oil and gas in the Middle Jurassic Brent Group sandstone reservoir. The primary objective of the well was to establish the oil/water contact in this part of the structure. The well was planned to be drilled to a total depth of 2850 m, approximately 100 m into the Dunlin Group.
    Operations and results
    Appraisal well 30/9-1 was spudded with the semi-submersible installation Treasure Seeker on 24 October 1982 and drilled to TD at 2895 m in the Early Jurassic Drake Formation. No significant problem was encountered in the operations. The well was drilled with seawater/hi-vis pills and pre-hydrated bentonite down to 969 m, with KCl/Drispac mud from 969 m to 2515 m, and with KCl/polysal mud from 2515 m to TD.
    The Brent Group was found hydrocarbon bearing from 2685 m down to 2738 m where the free water level was established. This interval comprises the whole of the Ness Formation and the uppermost 3 m of the Etive Formation. Net pay in the interval was 10.5 m. Poor oil shows were recorded on limestone cuttings in the interval 2281 to 2232 m in the uppermost Shetland Group. Good oil shows were recorded through the oil column of the reservoir. Below the contact at 2738 m, shows became weaker and patchy down to 2778 m. Below this depth only some weak shows on claystone from three sidewall cores in the interval 2872 m to 2895 m were reported.
    Seven conventional cores were cut from 2682 m at the top of the Ness formation to 2784.9 m, into the Dunlin Group shales. RFT fluid samples were taken at 2690.5 m (oil, gas, water, and filtrate), 2732.2 m (water and filtrate with small amounts of oil and gas), 2737.5 m (water and filtrate with trace oil and gas), and at 3782.2 m (water and filtrate with small amounts of oil and gas).
    The well was permanently abandoned on 29 January 1983 as an oil appraisal well.
    Testing
    Three drill stem tests were performed in the Brent Group.
    DST l (2743-2761 m) in the upper part of the Etive Formation is a combined water production/injection test. It produced 200 m3/day of water through a 44/64" choke. The first injection rate was 134 m3/day of water and the second injection rate amounted to 1170.4 m3/day) of water. Maximum temperature measured at 2740.5 m was 105.1 °C.
    DST 2 (2727 -2733 m) at the very base of the Ness Formation flowed 325 Sm3/day oil with 36507 Sm3/day of associated gas with a gravity of 0.780 (air = 1). Choke size was 28/64". The GOR was 112 Sm3/Sm3, the oil gravity was 32.2° API, and the gas gravity was 0.780 (air = 1). Maximum temperature measured at 2714.3 m was 106.6 °C.
    DST 3 (2689 – 2692 m) in the uppermost part of the Ness Formation tested 375 Sm3/day of oil and 39620 Sm3/day of gas through a 28/64" choke. The GOR was 106 Sm3/Sm3, the oil gravity was 34.9°API and the gas gravity 0.724 (air = 1). Maximum temperature measured at 2678.9 m was 105.7 °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]
    250.00
    2895.00

  • 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
    2681.8
    2699.0
    [m ]
    2
    2700.0
    2707.0
    [m ]
    3
    2708.5
    2713.2
    [m ]
    4
    2714.0
    2730.5
    [m ]
    5
    2737.3
    2749.9
    [m ]
    6
    2750.0
    2768.0
    [m ]
    7
    2768.0
    2784.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    92.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    330.0
    [m]
    DC
    RRI
    530.0
    [m]
    DC
    RRI
    730.0
    [m]
    DC
    RRI
    930.0
    [m]
    DC
    RRI
    1130.0
    [m]
    DC
    RRI
    1330.0
    [m]
    DC
    RRI
    1510.0
    [m]
    DC
    GEOCH
    1530.0
    [m]
    DC
    RRI
    1540.0
    [m]
    DC
    GEOCH
    1570.0
    [m]
    DC
    GEOCH
    1600.0
    [m]
    DC
    GEOCH
    1630.0
    [m]
    DC
    GEOCH
    1666.0
    [m]
    DC
    GEOCH
    1690.0
    [m]
    DC
    GEOCH
    1720.0
    [m]
    DC
    GEOCH
    1730.0
    [m]
    DC
    RRI
    1750.0
    [m]
    DC
    GEOCH
    1780.0
    [m]
    DC
    GEOCH
    1810.0
    [m]
    DC
    GEOCH
    1840.0
    [m]
    DC
    GEOCH
    1870.0
    [m]
    DC
    GEOCH
    1900.0
    [m]
    DC
    GEOCH
    1915.0
    [m]
    DC
    RRI
    1930.0
    [m]
    DC
    GEOCH
    1960.0
    [m]
    DC
    GEOCH
    1990.0
    [m]
    DC
    GEOCH
    2020.0
    [m]
    DC
    GEOCH
    2050.0
    [m]
    DC
    GEOCH
    2080.0
    [m]
    DC
    GEOCH
    2110.0
    [m]
    DC
    GEOCH
    2115.0
    [m]
    DC
    RRI
    2140.0
    [m]
    DC
    GEOCH
    2170.0
    [m]
    DC
    GEOCH
    2200.0
    [m]
    DC
    GEOCH
    2215.0
    [m]
    DC
    RRI
    2230.0
    [m]
    DC
    GEOCH
    2260.0
    [m]
    DC
    GEOCH
    2280.0
    [m]
    DC
    GEOCH
    2290.0
    [m]
    DC
    GEOCH
    2320.0
    [m]
    DC
    GEOCH
    2406.0
    [m]
    SWC
    RRI
    2415.0
    [m]
    SWC
    RRI
    2422.5
    [m]
    SWC
    RRI
    2433.0
    [m]
    SWC
    RRI
    2452.0
    [m]
    SWC
    RRI
    2465.0
    [m]
    SWC
    RRI
    2477.0
    [m]
    SWC
    RRI
    2485.0
    [m]
    SWC
    RRI
    2494.0
    [m]
    SWC
    RRI
    2505.0
    [m]
    SWC
    RRI
    2514.0
    [m]
    SWC
    RRI
    2528.0
    [m]
    SWC
    RRI
    2540.0
    [m]
    SWC
    RRI
    2560.0
    [m]
    SWC
    RRI
    2569.0
    [m]
    SWC
    RRI
    2580.0
    [m]
    SWC
    RRI
    2592.0
    [m]
    SWC
    RRI
    2605.0
    [m]
    SWC
    RRI
    2615.0
    [m]
    SWC
    RRI
    2624.0
    [m]
    SWC
    RRI
    2635.0
    [m]
    SWC
    RRI
    2649.0
    [m]
    SWC
    RRI
    2659.0
    [m]
    SWC
    RRI
    2672.5
    [m]
    SWC
    RRI
    2682.0
    [m]
    SWC
    RRI
    2693.1
    [m]
    C
    RRI
    2706.8
    [m]
    C
    RRI
    2739.7
    [m]
    C
    RRI
    2786.6
    [m]
    C
    RRI
    2790.0
    [m]
    DC
    RRI
    2795.0
    [m]
    SWC
    RRI
    2811.0
    [m]
    SWC
    RRI
    2837.0
    [m]
    SWC
    RRI
    2850.0
    [m]
    SWC
    RRI
    2860.0
    [m]
    SWC
    RRI
    2872.0
    [m]
    SWC
    RRI
    2880.0
    [m]
    DC
    RRI
    2885.0
    [m]
    SWC
    RRI
    2895.0
    [m]
    SWC
    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
    DST2A
    2727.00
    2733.00
    15.01.1983 - 00:00
    YES
    DST
    DST3
    2689.00
    2692.00
    21.01.1983 - 00:00
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.08
    pdf
    3.15

  • 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
    4.45
    pdf
    23.78

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2743
    2761
    17.4
    2.0
    2727
    2733
    11.1
    3.0
    2689
    2692
    11.1
    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
    2.0
    325
    37000
    0.864
    0.780
    112
    3.0
    375
    40000
    0.850
    0.724
    105

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL
    1300
    2485
    CST
    1720
    2514
    CST
    2505
    2895
    CST
    2520
    2885
    DLL MSFL MLL
    2495
    2870
    HDT
    1900
    2514
    HDT SHDT
    2495
    2897
    ISF LSS
    219
    965
    ISF LSS MSFL
    951
    2512
    ISF LSS MSFL EPT
    2495
    2895
    ISF LSS NGT
    2495
    2897
    LDT CNL
    951
    2507
    LDT CNL NGT EPT
    2495
    2893
    RFT
    2570
    2881
    RFT
    2729
    0
    RFT
    2732
    2737
    RFT
    2737
    0
    VELOCITY
    648
    2893

  • 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
    217.0
    36
    220.0
    0.00
    LOT
    SURF.COND.
    20
    951.0
    26
    969.0
    1.64
    LOT
    INTERM.
    13 3/8
    2498.0
    17 1/2
    2515.0
    1.70
    LOT
    INTERM.
    9 5/8
    2878.0
    12 1/4
    2895.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    260
    1.05
    waterbased
    560
    1.10
    waterbased
    1300
    1.32
    waterbased
    1730
    1.44
    waterbased
    2080
    1.46
    waterbased
    2260
    1.48
    waterbased
    2560
    1.24
    waterbased

  • 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