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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33/9-13 S

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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.
    33/9-13 S
    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.
    33/9-13
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    E 86-543 & CMP 946
    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.
    565-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.
    72
    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,
    14.10.1987
    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.
    24.12.1987
    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.
    24.12.1989
    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.
    10.04.2015
    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.
    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.
    22.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    291.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3077.0
    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).
    3001.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    34.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    102
    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.
    61° 27' 4.45'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 58' 3'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6813648.01
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    444949.13
    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.
    1028

  • Wellbore history
    General
    Well 33/9-13 S was drilled on the Statfjord Nord Field on the Tampen Spur area in the North Sea. The primary objective was to prove oil in the Brent Group to the northeast of the 33/9-8 discovery well. Secondary objective was to test the Statfjord Group in a position up-dip of the 33/9-8 location.
    Operations and results
    Well 33/9-13 S was spudded with the semi-submersible installation Ross Isle on 14 October 1987 and drilled to TD at 3077 m in the Early Jurassic Statfjord Group. The well location was moved ca 300 m to the south-southwest to avoid a potential shallow gas zone at 381 m. The well was deviated back to the original target position with maximum deviation 34.3° at 1739 m. Shallow gas was encountered at 399.5 m, 399.9m, 404.5 m, and 547 m. No significant problem was encountered in the operations. The well was drilled with seawater and hi-vis bentonite down to 398 m, with gypsum/polymer mud from 398 m to 2378 m, and with lignosulphonate/bentonite mud from 2378 m to TD.
    The Brent Group, Rannoch Formation was encountered at 2726 m and was completely oil filled down-to 2795 m (2720 m TVD) with shows on claystones and siltstones down to top Dunlin Group. The Statfjord Group was encountered at 3003 m and was water filled. Shows were described only within the Brent Group.
    Four cores were cut in the Brent and uppermost Dunlin Groups within the interval 2732 - 2828.3 m. No fluid samples were taken on wire line.
    The well was permanently abandoned on 24 December 1987 as an oil appraisal well.
    Testing
    Two Drill Stem Tests were conducted
    DST 1.1 tested the interval 2778 to 2787 m (2703 to 2712 TVD). The test produced 122 Sm3 oil and 6960 Sm3 gas /day through a 9.53 mm choke. The GOR was 57 Sm3/Sm3, the oil density was 0.850 g/cm3, and the gas gravity was 0.890 (air = 1). The DST reservoir temperature was 93.1 °C.
    DST 1.2 tested the interval 2758 to 2775.2 m + 2778 to 2787 m (2683 to 2700.2 m + 2703 to 2712 TVD). The test produced 642 Sm3 oil and 33139 Sm3 gas /day through a 9.53 mm choke. The GOR was 51.6 Sm3/Sm3, the oil density was 0.838 g/cm3, and the gas gravity was 0.830 (air = 1). The DST reservoir temperature was 93.1 °C.
    DST 2 tested the interval 2727 to 2740.7 m (2652 to 2665.7 m TVD). The test produced 815 Sm3 oil and 41640 Sm3 gas /day through a 9.53 mm choke. The GOR was 51 Sm3/Sm3, the oil density was 0.839 g/cm3, and the gas gravity was 0.805 (air = 1). The DST reservoir temperature was 93.0 °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]
    410.00
    3075.00

  • 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
    2732.0
    2754.3
    [m ]
    2
    2756.0
    2783.4
    [m ]
    3
    2783.4
    2799.9
    [m ]
    4
    2801.0
    2828.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    93.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2732-2736m
    Core photo at depth: 2736-2740m
    Core photo at depth: 2740-2743m
    Core photo at depth: 2744-2748m
    Core photo at depth: 2748-2752m
    2732-2736m
    2736-2740m
    2740-2743m
    2744-2748m
    2748-2752m
    Core photo at depth: 2752-2754m
    Core photo at depth: 2756-2760m
    Core photo at depth: 2760-2764m
    Core photo at depth: 2764-2768m
    Core photo at depth: 2768-2772m
    2752-2754m
    2756-2760m
    2760-2764m
    2764-2768m
    2768-2772m
    Core photo at depth: 2772-2776m
    Core photo at depth: 2776-2780m
    Core photo at depth: 2780-2783m
    Core photo at depth: 2787-2791m
    Core photo at depth: 2791-2795m
    2772-2776m
    2776-2780m
    2780-2783m
    2787-2791m
    2791-2795m
    Core photo at depth: 2795-2799m
    Core photo at depth: 2799-2800m
    Core photo at depth: 2801-2805m
    Core photo at depth: 2805-2809m
    Core photo at depth: 2809-2813m
    2795-2799m
    2799-2800m
    2801-2805m
    2805-2809m
    2809-2813m
    Core photo at depth: 2813-2817m
    Core photo at depth: 2817-2821m
    Core photo at depth: 2821-2825m
    Core photo at depth: 2825-2828m
    Core photo at depth: 2783-2787m
    2813-2817m
    2817-2821m
    2821-2825m
    2825-2828m
    2783-2787m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2649.0
    [m]
    DC
    OD
    2670.0
    [m]
    DC
    OD
    2691.0
    [m]
    DC
    OD
    2697.0
    [m]
    DC
    OD
    2703.0
    [m]
    DC
    OD
    2706.0
    [m]
    DC
    OD
    2709.0
    [m]
    DC
    OD
    2712.0
    [m]
    DC
    OD
    2715.0
    [m]
    DC
    OD
    2718.0
    [m]
    DC
    OD
    2724.0
    [m]
    DC
    OD
    2730.0
    [m]
    DC
    OD
    2732.5
    [m]
    C
    OD
    2733.2
    [m]
    C
    OD
    2734.2
    [m]
    C
    OD
    2734.6
    [m]
    C
    OD
    2735.6
    [m]
    C
    OD
    2735.8
    [m]
    C
    OD
    2736.0
    [m]
    DC
    OD
    2737.5
    [m]
    C
    OD
    2747.4
    [m]
    C
    OD
    2748.9
    [m]
    C
    OD
    2749.6
    [m]
    C
    OD
    2753.9
    [m]
    C
    OD
    2759.1
    [m]
    C
    OD
    2763.2
    [m]
    C
    OD
    2766.6
    [m]
    C
    OD
    2767.3
    [m]
    C
    OD
    2767.3
    [m]
    C
    OD
    2772.5
    [m]
    C
    OD
    2775.5
    [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
    TEST1,1
    2758.00
    2787.00
    26.11.1987 - 02:30
    YES
    DST
    TEST1,2
    2758.00
    2787.00
    OIL
    28.11.1987 - 04:30
    YES
    DST
    TEST2
    2727.00
    2740.70
    13.12.1987 - 00:00
    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
    22.54

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2703
    2712
    9.5
    1.1
    2758
    2787
    14.3
    1.2
    2683
    2700
    9.5
    2.0
    2652
    2666
    18.6
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    93
    1.1
    19.000
    8.000
    1.2
    8.000
    93
    2.0
    93
    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
    122
    6960
    0.850
    0.890
    57
    1.1
    1100
    0.800
    0.810
    45
    1.2
    642
    33139
    0.838
    0.830
    52
    2.0
    1602
    68755
    0.842
    0.785
    43

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBLV GRS
    310
    3020
    CDL CN SPL GRS
    2680
    3072
    DIFL AC GRS CAL
    2361
    3074
    DIPS GRS
    2710
    3069
    DLL MLL GRS CAL
    2729
    2820
    FMT GRS
    2710
    3069
    MWD - SN GR
    379
    3077
    VELOCITY
    700
    3060

  • 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
    375.0
    36
    375.0
    0.00
    LOT
    SURF.COND.
    20
    394.0
    26
    422.0
    1.27
    LOT
    INTERM.
    13 3/8
    1300.0
    17 1/2
    1315.0
    1.79
    LOT
    INTERM.
    9 5/8
    2363.0
    12 1/4
    2378.0
    1.84
    LOT
    LINER
    7
    3075.0
    8 1/2
    3077.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    374
    1.20
    13.0
    18.5
    WATER BASED
    19.10.1987
    374
    1.20
    13.0
    18.5
    WATER BASED
    19.10.1987
    394
    1.22
    17.0
    5.0
    WATER BASED
    19.10.1987
    394
    1.22
    17.0
    5.0
    WATER BASED
    19.10.1987
    398
    1.20
    12.0
    11.5
    WATER BASED
    19.10.1987
    398
    1.20
    12.0
    11.5
    WATER BASED
    19.10.1987
    515
    1.22
    20.0
    5.3
    WATER BASED
    26.10.1987
    515
    1.22
    20.0
    5.3
    WATER BASED
    26.10.1987
    1230
    1.22
    23.0
    7.0
    WATER BASED
    26.10.1987
    1230
    1.22
    23.0
    7.0
    WATER BASED
    26.10.1987
    1315
    1.22
    21.0
    6.0
    WATER BASED
    26.10.1987
    1315
    1.22
    21.0
    6.0
    WATER BASED
    26.10.1987
    1460
    1.30
    18.0
    5.0
    WATER BASED
    29.10.1987
    1460
    1.30
    18.0
    5.0
    WATER BASED
    28.10.1987
    1781
    1.54
    19.0
    6.0
    WATER BASED
    30.10.1987
    1781
    1.54
    19.0
    6.0
    WATER BASED
    29.10.1987
    2096
    1.54
    24.0
    14.0
    WATER BASED
    02.11.1987
    2096
    1.54
    24.0
    14.0
    WATER BASED
    01.11.1987
    2097
    1.60
    23.0
    10.0
    WATER BASED
    18.12.1987
    2097
    1.60
    23.0
    10.0
    WATER BASED
    18.12.1987
    2246
    1.58
    22.0
    16.0
    WATER BASED
    01.11.1987
    2246
    1.58
    22.0
    16.0
    WATER BASED
    02.11.1987
    2378
    1.58
    30.0
    14.0
    WATER BASED
    02.11.1987
    2378
    1.58
    24.0
    6.5
    WATER BASED
    03.11.1987
    2378
    1.58
    30.0
    14.0
    WATER BASED
    01.11.1987
    2378
    1.58
    24.0
    6.5
    WATER BASED
    02.11.1987
    2378
    1.58
    27.0
    7.0
    WATER BASED
    05.11.1987
    2378
    1.58
    27.0
    7.0
    WATER BASED
    05.11.1987
    2416
    1.52
    33.0
    8.0
    WATER BASED
    06.11.1987
    2416
    1.52
    33.0
    8.0
    WATER BASED
    06.11.1987
    2536
    1.51
    31.0
    6.0
    WATER BASED
    09.11.1987
    2536
    1.51
    31.0
    6.0
    WATER BASED
    09.11.1987
    2675
    1.56
    38.0
    7.0
    WATER BASED
    09.11.1987
    2675
    1.56
    38.0
    7.0
    WATER BASED
    09.11.1987
    2720
    1.60
    35.0
    6.0
    WATER BASED
    09.11.1987
    2720
    1.60
    35.0
    6.0
    WATER BASED
    09.11.1987
    2740
    1.60
    33.0
    5.0
    WATER BASED
    10.11.1987
    2740
    1.60
    33.0
    5.0
    WATER BASED
    10.11.1987
    2753
    1.60
    23.0
    7.0
    WATER BASED
    15.12.1987
    2753
    1.60
    23.0
    7.0
    WATER BASED
    15.12.1987
    2753
    1.60
    23.0
    9.0
    WATER BASED
    16.12.1987
    2753
    1.60
    23.0
    9.0
    WATER BASED
    16.12.1987
    2785
    1.60
    34.0
    5.0
    WATER BASED
    11.11.1987
    2785
    1.60
    34.0
    5.0
    WATER BASED
    11.11.1987
    2820
    1.60
    33.0
    5.0
    WATER BASED
    12.11.1987
    2820
    1.60
    33.0
    5.0
    WATER BASED
    12.11.1987
    2828
    1.60
    37.0
    6.6
    WATER BASED
    13.11.1987
    2828
    1.60
    37.0
    6.6
    WATER BASED
    13.11.1987
    2867
    1.60
    32.0
    12.0
    WATER BASED
    16.11.1987
    2867
    1.60
    32.0
    12.0
    WATER BASED
    16.11.1987
    2983
    1.60
    30.0
    11.0
    WATER BASED
    16.11.1987
    2983
    1.60
    30.0
    11.0
    WATER BASED
    16.11.1987
    3077
    1.60
    23.0
    8.0
    WATER BASED
    19.11.1987
    3077
    1.60
    23.0
    8.0
    WATER BASED
    19.11.1987
    3077
    1.60
    26.0
    7.0
    WATER BASED
    20.11.1987
    3077
    1.60
    30.0
    12.0
    WATER BASED
    16.11.1987
    3077
    1.60
    24.0
    7.0
    WATER BASED
    17.11.1987
    3077
    1.60
    30.0
    12.0
    WATER BASED
    16.11.1987
    3077
    1.60
    24.0
    7.0
    WATER BASED
    17.11.1987
    3077
    1.60
    26.0
    7.0
    WATER BASED
    20.11.1987

  • 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
    0.22