Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
28.04.2024 - 01:35
Time of last synchronization with Norwegian Offshore Directorate's internal systems

33/9-14

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.
    33/9-14
    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.
    33/9-14
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    E 86 - 457 SP. 716
    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.
    571-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.
    53
    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,
    17.02.1988
    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.
    09.04.1988
    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.
    09.04.1990
    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.
    10.05.2015
    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.
    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.
    DRAUPNE 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.
    248.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2982.0
    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).
    2979.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    6.1
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    103
    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.
    61° 26' 0.26'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 54' 4.48'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6811719.66
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    441383.29
    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.
    1226

  • Wellbore history
    General
    Well 33/9-14 was drilled on the Statfjord Nord Field on Tampen Spur in the North Sea. The primary objective of the well was to verify the lateral and vertical distribution of sand within a thick Volgian sequence and to prove oil below 2690 m MSL in this sequence (deepest oil in Volgian, well 33/9-8). The Brent Group was a secondary target.
    Operations and results
    Appraisal well 33/9-14 was spudded with the semi-submersible installation Deepsea Bergen and drilled to TD at 2982 m in the Early Jurassic Drake Formation. There were signs of shallow gas from 408 409 m, but the gas bearing sands created no problems. No significant problem was encountered in the operations. The well was drilled with seawater/gel down to 414 m, with gypsum/polymer mud from 414 m to 2670 m, and with gel/lignosulphonate mud from 2670 m to TD.
    The reservoir (interpreted as Kimmeridgian age Intra Draupne Formation Sandstone) came in as prognosed at 2674 m. The oil/water contact was taken from the logs to be at 2747 m, while pressure gradients suggest the contact could be five meter higher up. Intermittent weak shows were described down to 2800 m, else no shows were described in the well.  The reservoir properties were very good with porosities up to 30 %. The Brent Group, Ness Formation came in at 2777 m. It was water wet.
    Six cores were cut in the Intra Draupne Formation Sandstones and the Brent Group in the interval 2680 to 2879 m. The recovery was generally good except for core 3, for which only 0.5 m was recovered. The core-log depth shift was 3.0 to -3.5 m for all cores. FMT fluid samples were taken at 2757 m and at 2798.4 m.
    The well was permanently abandoned on 9 April 1988 as an oil appraisal well.
    Testing
    Two DST tests were performed in the well.
    DST 1 tested the interval 2746.8 - 2759.8 m. It produced 1400 m3 water and 8500 Sm3 gas /day through a 15.9 mm choke. Water production declined to 1287 m3/day at the end of the test. At the end of the test 5%, oil was produced with the water. The DST reservoir temperature was 96 °C.
    DST 2.1 tested the interval 2718 - 2732 m. It produced 1370 Sm3 oil and 74670 Sm3 gas /day through a 14.3 mm choke. The oil production declined to 1310 Sm3/day at the end of the test. The GOR varied accordingly from 55 to 57 Sm3/Sm3, while oil density and gas gravity is reported as 0.837 g/cm3 and 0.704 (air = 1), respectively. The DST reservoir temperature was 95 °C.
    DST 2.2 teste the interval 2718 - 2738 m + 2675 - 2705 m. It produced 1416 Sm3 oil and 58060 Sm3 gas /day through a 14.3 mm choke. The GOR was 41 Sm3/Sm3, the oil density was 0.837 g/cm3, and the gas gravity was 0.703 (air = 1). The DST reservoir temperature was 95 °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]
    420.00
    2981.00

  • 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
    2680.0
    2707.7
    [m ]
    2
    2707.5
    2744.1
    [m ]
    3
    2744.0
    2744.1
    [m ]
    4
    2782.0
    2810.7
    [m ]
    5
    2810.7
    2838.5
    [m ]
    6
    2842.0
    2879.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    157.9
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2680-2685m
    Core photo at depth: 2685-2690m
    Core photo at depth: 2690-2695m
    Core photo at depth: 2695-2700m
    Core photo at depth: 2700-2705m
    2680-2685m
    2685-2690m
    2690-2695m
    2695-2700m
    2700-2705m
    Core photo at depth: 2705-2707m
    Core photo at depth: 2707-2712m
    Core photo at depth: 2712-2717m
    Core photo at depth: 2717-2722m
    Core photo at depth: 2722-2727m
    2705-2707m
    2707-2712m
    2712-2717m
    2717-2722m
    2722-2727m
    Core photo at depth: 2727-2732m
    Core photo at depth: 2732-2737m
    Core photo at depth: 2737-2742m
    Core photo at depth: 2742-2744m
    Core photo at depth: 2744-2744m
    2727-2732m
    2732-2737m
    2737-2742m
    2742-2744m
    2744-2744m
    Core photo at depth: 2782-2787m
    Core photo at depth: 2787-2792m
    Core photo at depth: 2792-2797m
    Core photo at depth: 2797-2802m
    Core photo at depth: 2802-2807m
    2782-2787m
    2787-2792m
    2792-2797m
    2797-2802m
    2802-2807m
    Core photo at depth: 2807-2810m
    Core photo at depth: 2810-2815m
    Core photo at depth: 2815-2810m
    Core photo at depth: 2820-2825m
    Core photo at depth: 2825-2830m
    2807-2810m
    2810-2815m
    2815-2810m
    2820-2825m
    2825-2830m
    Core photo at depth: 2830-2835m
    Core photo at depth: 2835-2838m
    Core photo at depth: 2842-2847m
    Core photo at depth: 2847-2852m
    Core photo at depth: 2852-2857m
    2830-2835m
    2835-2838m
    2842-2847m
    2847-2852m
    2852-2857m
    Core photo at depth: 2857-2862m
    Core photo at depth: 2862-2867m
    Core photo at depth: 2867-2872m
    Core photo at depth: 2872-2877m
    Core photo at depth: 2877-2879m
    2857-2862m
    2862-2867m
    2867-2872m
    2872-2877m
    2877-2879m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2680.6
    [m]
    C
    OD
    2686.3
    [m]
    C
    OD
    2689.7
    [m]
    C
    OD
    2691.2
    [m]
    C
    OD
    2694.5
    [m]
    C
    OD
    2698.6
    [m]
    C
    OD
    2707.5
    [m]
    C
    OD
    2708.1
    [m]
    C
    OD
    2713.5
    [m]
    C
    OD
    2719.3
    [m]
    C
    OD
    2722.7
    [m]
    C
    OD
    2723.4
    [m]
    C
    OD
    2724.8
    [m]
    C
    OD
    2725.9
    [m]
    C
    OD
    2728.3
    [m]
    C
    OD
    2732.3
    [m]
    C
    OD
    2733.5
    [m]
    C
    OD
    2738.5
    [m]
    C
    OD
    2741.1
    [m]
    C
    OD
    2743.0
    [m]
    C
    OD
    2782.1
    [m]
    C
    OD
    2787.9
    [m]
    C
    OD
    2792.5
    [m]
    C
    OD
    2796.5
    [m]
    C
    OD
    2800.8
    [m]
    C
    OD
    2818.3
    [m]
    C
    OD
    2842.8
    [m]
    C
    OD
    2847.3
    [m]
    C
    OD
    2850.2
    [m]
    C
    OD
    2871.7
    [m]
    C
    OD

  • 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
    TEST1
    2746.80
    2759.80
    OIL
    23.03.1988 - 00:00
    YES
    DST
    TEST2,1
    2718.00
    2732.00
    OIL
    28.03.1988 - 00:00
    YES
    DST
    TEST2,2
    2675.00
    2705.00
    OIL
    31.03.1988 - 14:30
    YES

  • 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
    20.97
    pdf
    2.64
    pdf
    20.97

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2745
    2758
    16.0
    2.0
    2718
    2732
    12.7
    2.1
    2718
    2732
    12.7
    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
    14.000
    2.1
    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
    8000
    0.780
    2.0
    1350
    75000
    0.830
    0.720
    55
    2.1
    1164
    43000
    0.837
    0.703
    37

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBLV GR
    268
    2927
    CDL CN SL GR
    2649
    2975
    DIFL ACL GR CAL
    2649
    2975
    DIFL BHC GR CAL
    1278
    2252
    DIPLOG
    2649
    2975
    DLL MLL GR
    2665
    2800
    FMT GR
    2675
    2865
    FMT GR
    2798
    2798
    MWD - EWR GR
    2666
    2879
    MWD - SN GR
    336
    2682
    MWD - SN GR
    2879
    2981
    SWC
    2740
    2966
    VELOCITY
    1000
    2960

  • 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
    330.0
    36
    331.0
    0.00
    LOT
    INTERM.
    20
    404.0
    26
    414.0
    1.29
    LOT
    INTERM.
    13 3/8
    1279.0
    17 1/2
    1292.0
    1.76
    LOT
    INTERM.
    9 5/8
    2654.0
    12 1/4
    2670.0
    1.90
    LOT
    LINER
    7
    2978.0
    8 1/2
    2982.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1295
    1.23
    5.0
    3.5
    WATER BASED
    29.02.1988
    1617
    1.35
    58.0
    5.5
    WATER BASED
    29.02.1988
    1710
    1.45
    27.0
    6.5
    WATER BASED
    29.02.1988
    2050
    1.55
    27.0
    6.5
    WATER BASED
    29.02.1988
    2523
    1.55
    20.0
    11.0
    WATER BASED
    07.03.1988
    2670
    1.55
    25.0
    8.0
    WATER BASED
    08.03.1988
    2673
    1.58
    23.0
    4.0
    WATER BASED
    10.03.1988
    2680
    1.58
    13.0
    8.0
    WATER BASED
    16.03.1988
    2680
    1.58
    13.0
    8.0
    WATER BASED
    17.03.1988

  • 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
    0.21