Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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25.11.2024 - 01:30
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30/9-12 A

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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.
    30/9-12 A
    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.
    SUSPENDED
    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.
    30/9-12
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 8831- ROW 143 & COLUMN 520
    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.
    683-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.
    27
    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,
    09.05.1991
    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.
    04.06.1991
    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.
    04.06.1993
    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.
    29.06.2004
    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 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.
    INTRA HEATHER FM SS
    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.
    104.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3061.0
    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).
    2927.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    24.5
    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.
    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° 25' 57.09'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 51' 34.9'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6699747.91
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    492276.08
    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.
    1770

  • Wellbore history
    General
    Well 30/9-12 A was designed as a sidetrack from well 30/9-12 on the Alpha South structure on the southern extension of the Oseberg Field. Well 30/9-12 proved a 10 m column of oil in the Tarbert Formation, but as no oil/water contact was established there remained uncertainty as to the amount of hydrocarbon resources within the southern part of the Alpha South structure. The objectives of well 30/9-12A were to sidetrack approximately 700 m down dip south-eastwards in order to establish the water pressure and oil/water contact in the Tarbert Formation in the area as well as to verify the structural mapping and geological model of the area. No drilling hazards were anticipated.
    Operations and results
    Appraisal well 30/9-12 A was with kicked off with the semi-submersible rig Vildkat Explorer on 9 May 1991. Kick-off point was at 1033 m, below the 13 3/8" casing shoe in well 30/9-12. The well bore was drilled to a total depth of 3061 m (2927 m TVD RKB) in the Drake Formation of the Dunlin Group. It was drilled with KCl polymer mud from kick-off to TD.
    The well encountered an unexpected Heather Formation sandstone development that proved to be hydrocarbon bearing. A total of 2.63 m net pay sand was calculated, with an average porosity of 23.3% and average water saturation of
    31.4%. Sandstones of the Brent Group were penetrated below the regional oil/water contact and were found to be totally water bearing. A total of six conventional cores were cut in this well in the interval 2874 m to 2919 m in the Tarbert and Ness Formations. A total of 30 sidewall cores were attempted and 28 were recovered. Drilling went on without any significant problems to TD. Oil was recovered from RFT samples taken at 2776.3 m and 2776.6 m. Geochemical analyses showed the Heather oil in 30/9-12 A correlate very well with Tarbert oils from 30/9-12 and 30/9-10, indicating a common source and identical maturity.
    The well was suspended on 4 June 1991 as a minor oil discovery.
    Testing
    No drill stem test was performed

  • 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]
    1040.00
    3060.00

  • 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
    2874.0
    2876.0
    [m ]
    2
    2877.0
    2887.0
    [m ]
    3
    2888.0
    2899.0
    [m ]
    4
    2901.0
    2904.0
    [m ]
    5
    2906.0
    2912.0
    [m ]
    6
    2914.0
    2920.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    38.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2874-2880m
    Core photo at depth: 2880-2885m
    Core photo at depth: 2885-2891m
    Core photo at depth: 2891-2896m
    Core photo at depth: 2896-2903m
    2874-2880m
    2880-2885m
    2885-2891m
    2891-2896m
    2896-2903m
    Core photo at depth: 2903-2910m
    Core photo at depth: 2911-2917m
    Core photo at depth: 2917-2919m
    Core photo at depth:  
    Core photo at depth:  
    2903-2910m
    2911-2917m
    2917-2919m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1070.0
    [m]
    DC
    STRAT
    1100.0
    [m]
    DC
    STRAT
    1130.0
    [m]
    DC
    STRAT
    1150.0
    [m]
    DC
    STRAT
    1170.0
    [m]
    DC
    STRAT
    1200.0
    [m]
    DC
    STRAT
    1230.0
    [m]
    DC
    STRAT
    1250.0
    [m]
    DC
    STRAT
    1290.0
    [m]
    DC
    STRAT
    1310.0
    [m]
    DC
    STRAT
    1340.0
    [m]
    DC
    STRAT
    1360.0
    [m]
    DC
    STRAT
    1390.0
    [m]
    DC
    STRAT
    1420.0
    [m]
    DC
    STRAT
    1450.0
    [m]
    DC
    STRAT
    1480.0
    [m]
    DC
    STRAT
    1500.0
    [m]
    DC
    STRAT
    1530.0
    [m]
    DC
    STRAT
    1560.0
    [m]
    DC
    STRAT
    1590.0
    [m]
    DC
    STRAT
    1620.0
    [m]
    DC
    STRAT
    1650.0
    [m]
    DC
    STRAT
    1710.0
    [m]
    DC
    STRAT
    1810.0
    [m]
    DC
    STRAT
    1900.0
    [m]
    DC
    STRAT
    1920.0
    [m]
    DC
    STRAT
    1950.0
    [m]
    DC
    STRAT
    1980.0
    [m]
    DC
    STRAT
    2000.0
    [m]
    DC
    STRAT
    2030.0
    [m]
    DC
    STRAT
    2060.0
    [m]
    DC
    STRAT
    2090.0
    [m]
    DC
    STRAT
    2120.0
    [m]
    DC
    STRAT
    2150.0
    [m]
    DC
    STRAT
    2180.0
    [m]
    DC
    STRAT
    2210.0
    [m]
    DC
    STRAT
    2240.0
    [m]
    DC
    STRAT
    2270.0
    [m]
    DC
    STRAT
    2300.0
    [m]
    DC
    STRAT
    2330.0
    [m]
    DC
    STRAT
    2360.0
    [m]
    DC
    STRAT
    2390.0
    [m]
    DC
    STRAT
    2565.0
    [m]
    DC
    HYDRO
    2620.0
    [m]
    DC
    STRAT
    2650.0
    [m]
    DC
    STRAT
    2675.0
    [m]
    DC
    HYDRO
    2680.0
    [m]
    DC
    STRAT
    2690.0
    [m]
    DC
    STRAT
    2695.0
    [m]
    DC
    STRAT
    2700.0
    [m]
    DC
    STRAT
    2715.0
    [m]
    DC
    STRAT
    2721.0
    [m]
    SWC
    HYDRO
    2724.0
    [m]
    SWC
    HYDRO
    2728.5
    [m]
    SWC
    HYDRO
    2735.8
    [m]
    SWC
    HYDRO
    2738.5
    [m]
    SWC
    HYDRO
    2745.0
    [m]
    SWC
    HYDRO
    2760.0
    [m]
    DC
    STRAT
    2763.2
    [m]
    SWC
    HYDRO
    2772.0
    [m]
    SWC
    HYDRO
    2777.8
    [m]
    SWC
    HYDRO
    2780.9
    [m]
    SWC
    HYDRO
    2784.0
    [m]
    SWC
    HYDRO
    2795.0
    [m]
    SWC
    HYDRO
    2805.2
    [m]
    SWC
    HYDRO
    2812.0
    [m]
    DC
    STRAT
    2822.5
    [m]
    SWC
    HYDRO
    2827.8
    [m]
    SWC
    HYDRO
    2835.3
    [m]
    SWC
    HYDRO
    2848.0
    [m]
    SWC
    HYDRO
    2857.0
    [m]
    SWC
    HYDRO
    2865.0
    [m]
    DC
    STRAT
    2865.5
    [m]
    SWC
    HYDRO
    2868.2
    [m]
    SWC
    HYDRO
    2871.0
    [m]
    SWC
    HYDRO
    2877.8
    [m]
    C
    HYDRO
    2879.5
    [m]
    C
    HYDRO
    2882.0
    [m]
    C
    HYDRO
    2882.4
    [m]
    C
    HYDRO
    2883.2
    [m]
    C
    HYDRO
    2883.9
    [m]
    C
    HYDRO
    2885.2
    [m]
    C
    HYDRO
    2888.5
    [m]
    C
    HYDRO
    2897.0
    [m]
    C
    HYDRO
    2901.4
    [m]
    C
    HYDRO
    2901.6
    [m]
    C
    HYDRO
    2907.7
    [m]
    C
    HYDRO
    2915.4
    [m]
    C
    HYDRO
    2917.1
    [m]
    C
    HYDRO
    2917.8
    [m]
    C
    HYDRO
    2927.0
    [m]
    DC
    STRAT
    2937.0
    [m]
    DC
    STRAT
    2947.4
    [m]
    SWC
    HYDRO
    2955.0
    [m]
    DC
    STRAT
    2975.0
    [m]
    DC
    STRAT
    2985.0
    [m]
    DC
    STRAT
    2995.0
    [m]
    DC
    STRAT
    3005.5
    [m]
    SWC
    HYDRO
    3007.5
    [m]
    SWC
    HYDRO
    3020.0
    [m]
    SWC
    HYDRO
    3030.0
    [m]
    DC
    STRAT
    3040.0
    [m]
    DC
    STRAT
    3050.0
    [m]
    SWC
    HYDRO
    3060.0
    [m]
    DC
    STRAT

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.41

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.53

  • 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
    8.61

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CST GR
    2721
    3050
    DIL LSS LDL CNL NGL SP CAL
    2718
    3062
    DIL LSS LDL GR SP AMS
    1040
    2800
    DLL MSFL LDL CNL GR CAL
    2718
    2918
    FMS4 GR
    2718
    3060
    MWD GR RES DIR
    1033
    3058
    RFT HP GR
    2776
    2903
    RFT HP GR
    2776
    2776
    RFT HP GR
    2874
    2979
    VSP
    930
    3050

  • 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
    214.0
    36
    216.0
    0.00
    LOT
    CONDUCTOR
    13 3/8
    1002.0
    17 1/2
    1019.0
    0.00
    LOT
    INTERM.
    9 5/8
    2717.0
    12 1/4
    2824.0
    1.61
    LOT
    OPEN HOLE
    3061.0
    8 1/2
    3061.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    300
    1.20
    13.0
    7.0
    WATER BASED
    04.06.1991
    1017
    1.26
    20.0
    12.0
    WATER BASED
    10.05.1991
    1474
    1.39
    19.0
    12.0
    WATER BASED
    14.05.1991
    2100
    1.40
    20.0
    11.0
    WATER BASED
    14.05.1991
    2372
    1.40
    22.0
    10.0
    WATER BASED
    14.05.1991
    2419
    1.42
    21.0
    10.0
    WATER BASED
    14.05.1991
    2482
    1.40
    20.0
    14.0
    WATER BASED
    15.05.1991
    2549
    1.40
    20.0
    13.0
    WATER BASED
    16.05.1991
    2600
    1.20
    13.0
    7.0
    WATER BASED
    04.06.1991
    2617
    1.40
    20.0
    8.0
    WATER BASED
    21.05.1991
    2658
    1.40
    19.0
    11.0
    WATER BASED
    21.05.1991
    2658
    1.40
    22.0
    10.0
    WATER BASED
    21.05.1991
    2681
    1.41
    12.0
    13.0
    WATER BASED
    21.05.1991
    2709
    1.40
    19.0
    7.0
    WATER BASED
    21.05.1991
    2750
    1.39
    18.0
    9.0
    WATER BASED
    22.05.1991
    2750
    1.40
    18.0
    6.0
    WATER BASED
    23.05.1991
    2750
    1.40
    21.0
    8.0
    WATER BASED
    24.05.1991
    2824
    1.20
    12.0
    6.0
    WATER BASED
    28.05.1991
    2877
    1.20
    12.0
    7.0
    WATER BASED
    28.05.1991
    2894
    1.20
    12.0
    6.0
    WATER BASED
    28.05.1991
    2907
    1.20
    12.0
    6.0
    WATER BASED
    28.05.1991
    2919
    1.20
    13.0
    6.0
    WATER BASED
    29.05.1991
    2919
    1.20
    13.0
    6.0
    WATER BASED
    30.05.1991
    3001
    1.20
    13.0
    6.0
    WATER BASED
    31.05.1991
    3061
    1.20
    13.0
    7.0
    WATER BASED
    04.06.1991
    3061
    1.20
    13.0
    7.0
    WATER BASED
    04.06.1991

  • 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