Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
27.12.2024 - 01:25
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15/9-9

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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.
    15/9-9
    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.
    15/9-9
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    line no 510 - 157 SP: 160
    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.
    285-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,
    04.05.1981
    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.
    14.07.1981
    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.
    14.07.1983
    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.
    24.09.2015
    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.
    GAS/CONDENSATE
    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.
    PALEOCENE
    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.
    HEIMDAL 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.
    PALEOCENE
    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.
    TY FM
    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.
    83.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3044.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    79
    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 PERMIAN
    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.
    ROTLIEGEND GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 20' 47.81'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 53' 24.98'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6467984.08
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    435038.52
    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.
    328

  • Wellbore history
    General
    Well 15/9-9, was drilled on the Sleipner Terrace in the North Sea. The primary objective was to test possible hydrocarbons in Jurassic sandstones on the 15/9-Gamma structure and to get more information about the sand distribution in the area.
    Operations and results
    Wildcat well 15/9-9 was spudded with the semi-submersible installation Nordraug on 4 May 1981 and drilled to TD at 3044 m in the Early-Middle Permian Rotliegendes Group. No significant problems were experienced in operation, logging or testing of the well. The well was drilled with seawater and pre-hydrated gel down to 501 m, with gel/lignosulphonate from 501 to 1155 m, with gypsum/polymer mud from 1155 m to 2540 m, and with gel/lignosulphonate from 2540 m to TD.
    The primary objective, the Jurassic, was thinner than expected and consisted of Late Jurassic Viking Group shales only. The well, however, proved gas and condensate in the Heimdal Formation. The Heimdal Formation was reached at 2322 m. It consisted of sand of fairly good reservoir properties interbedded with some thin shale beds. The whole sand interval was hydrocarbon bearing and no water contact was located. In addition, the well proved residual hydrocarbons over the interval 2648 to 2738 m on cores from the Triassic Skagerrak Formation.
    Seven cores were cut. The interval 2648 to 2756 m was cored in six cores with 98 - 100% recovery. A seventh core was cut from 3032 to 3043.5 m with 96% recovery at TD. RFT segregated samples were taken at 2323 m (condensate and mud filtrate) and 2648 m (water and mud filtrate, no gas or condensate). Repeated attempts to sample in the interval 2401 to 2414 all failed due to plugging of probe by unconsolidated sand.
    The well was permanently abandoned on 14 July as a gas/condensate discovery.
    Testing
    Three drill stem tests were performed.
    DST 1 tested the interval 2414 to 2421 m. This test gave no flow to surface and it was aborted due to malfunctioning downhole valves. The maximum downhole temperature measured by the gauges was 85.6 °C
    DST 2 tested the interval 2386 to 2392 m. This test produced 286 Sm3 condensate and 586200 Sm3 gas /day through a 1.0" choke (max flow).  No H2S and only traces of CO2 was measured. The GOR was 2050 Sm3/Sm3, the condensate gravity was 57.7 °API and the gas gravity was 0.734. The bottom hole temperature measured by the Flopetrol gauge was 87.8 °C.
    DST 3 tested the interval 2323 to 2333 m. This test produced 272 Sm3 condensate and 587000 Sm3 gas /day through a 1.0" choke (max flow).  No H2S and only traces of CO2 was measured. The GOR was 2160 Sm3/Sm3, the condensate gravity was 60.7 °API and the gas gravity was 0.740. The maximum down hole temperature measured by the gauges was 93.9 °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]
    160.00
    3040.00

  • 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
    2648.0
    2665.7
    [m ]
    2
    2666.0
    2684.0
    [m ]
    3
    2684.0
    2701.9
    [m ]
    4
    2702.0
    2719.9
    [m ]
    5
    2720.0
    2738.4
    [m ]
    6
    2738.4
    2755.6
    [m ]
    7
    3032.0
    3043.1
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    118.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2648-2651m
    Core photo at depth: 2651-2654m
    Core photo at depth: 2654-2657m
    Core photo at depth: 2657-2660m
    Core photo at depth: 2660-2663m
    2648-2651m
    2651-2654m
    2654-2657m
    2657-2660m
    2660-2663m
    Core photo at depth: 2663-2665m
    Core photo at depth: 2665-2669m
    Core photo at depth: 2669-2672m
    Core photo at depth: 2672-2675m
    Core photo at depth: 2675-2678m
    2663-2665m
    2665-2669m
    2669-2672m
    2672-2675m
    2675-2678m
    Core photo at depth: 2678-2681m
    Core photo at depth: 2681-2684m
    Core photo at depth: 2684-2687m
    Core photo at depth: 2687-2690m
    Core photo at depth: 2690-2693m
    2678-2681m
    2681-2684m
    2684-2687m
    2687-2690m
    2690-2693m
    Core photo at depth: 2693-2696m
    Core photo at depth: 2696-2699m
    Core photo at depth: 2699-2701m
    Core photo at depth: 2702-2705m
    Core photo at depth: 2705-2708m
    2693-2696m
    2696-2699m
    2699-2701m
    2702-2705m
    2705-2708m
    Core photo at depth: 2708-2711m
    Core photo at depth: 2711-2714m
    Core photo at depth: 2714-2717m
    Core photo at depth: 2717-2719m
    Core photo at depth: 2720-2723m
    2708-2711m
    2711-2714m
    2714-2717m
    2717-2719m
    2720-2723m
    Core photo at depth: 2723-2726m
    Core photo at depth: 2726-2729m
    Core photo at depth: 2729-2732m
    Core photo at depth: 2732-2735m
    Core photo at depth: 2735-2738m
    2723-2726m
    2726-2729m
    2729-2732m
    2732-2735m
    2735-2738m
    Core photo at depth: 2738-2738m
    Core photo at depth: 2738-2741m
    Core photo at depth: 2741-2744m
    Core photo at depth: 2744-2747m
    Core photo at depth: 2747-2750m
    2738-2738m
    2738-2741m
    2741-2744m
    2744-2747m
    2747-2750m
    Core photo at depth: 2750-2753m
    Core photo at depth: 2753-2755m
    Core photo at depth: 3032-3035m
    Core photo at depth: 3035-3038m
    Core photo at depth: 3038-3041m
    2750-2753m
    2753-2755m
    3032-3035m
    3035-3038m
    3038-3041m
    Core photo at depth: 3041-3043m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3041-3043m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2105.0
    [m]
    DC
    2130.0
    [m]
    DC
    2160.0
    [m]
    DC
    2191.0
    [m]
    DC
    2221.0
    [m]
    DC
    2251.0
    [m]
    DC
    2281.0
    [m]
    DC
    2311.0
    [m]
    DC
    2341.0
    [m]
    DC
    2371.0
    [m]
    DC
    2401.0
    [m]
    DC
    2431.0
    [m]
    DC
    2452.0
    [m]
    DC
    2482.0
    [m]
    DC
    2512.0
    [m]
    DC
    2542.0
    [m]
    DC
    2551.0
    [m]
    DC
    2572.0
    [m]
    DC
    2602.0
    [m]
    DC
    2605.0
    [m]
    DC
    2605.0
    [m]
    DC
    2611.0
    [m]
    DC
    2623.0
    [m]
    DC
    2623.0
    [m]
    DC
    2626.0
    [m]
    DC
    2626.0
    [m]
    DC
    2629.0
    [m]
    DC
    2632.0
    [m]
    DC
    2635.0
    [m]
    DC
    2648.2
    [m]
    C
    STATOIL
    2650.5
    [m]
    C
    STATOIL
    2650.7
    [m]
    C
    STATOIL
    2650.9
    [m]
    C
    2655.1
    [m]
    C
    STATOIL
    2659.7
    [m]
    C
    STATOI
    2667.0
    [m]
    C
    2667.4
    [m]
    C
    STATOIL
    2668.4
    [m]
    C
    STATOI
    2668.7
    [m]
    C
    STATOI
    2686.0
    [m]
    C
    STATOI
    2686.0
    [m]
    C
    2691.8
    [m]
    C
    STATOIL
    2701.8
    [m]
    C
    STATOIL
    2703.7
    [m]
    C
    2704.7
    [m]
    C
    STATOIL
    2705.6
    [m]
    C
    STATOI
    2708.5
    [m]
    C
    STATOI
    2715.3
    [m]
    C
    STATOI
    2715.7
    [m]
    C
    STATOI
    2716.6
    [m]
    C
    STATOI
    2716.7
    [m]
    C
    STATOI
    2717.4
    [m]
    C
    STATOI
    2717.5
    [m]
    C
    STATOI
    2725.6
    [m]
    C
    2730.5
    [m]
    C
    STATOIL
    2736.5
    [m]
    C
    STATOI
    2737.6
    [m]
    C
    STATOI
    2740.1
    [m]
    C
    2744.5
    [m]
    C
    STATOIL
    2744.6
    [m]
    C
    STATOI
    2763.6
    [m]
    C
    STATOI
    2975.7
    [m]
    C
    STATOI
    3033.0
    [m]
    C

  • 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
    TEST2
    2386.00
    2392.00
    02.07.1981 - 05:00
    YES
    DST
    TEST3
    2323.00
    2333.00
    06.07.1981 - 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
    1.85
    pdf
    20.29

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2414
    2421
    0.0
    2.0
    2386
    2392
    25.4
    3.0
    2323
    2332
    25.4
    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
    295
    580000
    0.740
    0.740
    3.0
    271
    590000
    0.740
    0.740

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    388
    2526
    CST
    2579
    3028
    CYBERDIP ADT
    1141
    3043
    DLL MSFL GR
    2300
    2539
    FDC CNL GR
    487
    3043
    ISF SON GR
    81
    3043
    RFT
    2322
    3043
    VELOCITY
    700
    3040

  • 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
    158.0
    36
    159.0
    0.00
    LOT
    SURF.COND.
    20
    487.0
    26
    501.0
    1.78
    LOT
    INTERM.
    13 3/8
    1142.0
    17 1/2
    1155.0
    1.79
    LOT
    INTERM.
    9 5/8
    2527.0
    12 1/4
    2540.0
    1.82
    LOT
    OPEN HOLE
    3044.0
    8 1/2
    3044.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    390
    1.06
    waterbased
    960
    1.14
    waterbased
    1410
    1.13
    waterbased
    2430
    1.20
    waterbased
    2530
    1.29
    waterbased
    2535
    1.50
    waterbased

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    3032.56
    [m ]
    3035.03
    [m ]
    3036.03
    [m ]
    3041.02
    [m ]

  • 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
    0.27