Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.11.2024 - 09:09
Time of last synchronization with Norwegian Offshore Directorate's internal systems

15/9-15

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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.
    15/9-15
    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
    Multilateral
    Indicator telling if the parent well is multilateral, meaning it has more than one branch radiating from the main borehole. Example of legal values: YES, NO. See also Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    NO
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    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.
    15/9-15
    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.
    330-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.
    66
    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,
    28.05.1982
    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.
    01.08.1982
    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.
    01.08.1984
    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.
    21.05.2015
    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.
    WILDCAT
    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.
    TRIASSIC
    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.
    SKAGERRAK 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).
    3200.0
    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).
    3199.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    116
    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.
    TRIASSIC
    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.
    SKAGERRAK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 18' 7.45'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 55' 19.67'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6462994.43
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    436823.95
    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.
    74

  • Wellbore history
    General
    Well 15/9-15 was drilled south of the Sleipner Øst Field in the Viking Graben of the North Sea. The objectives were to test possible hydrocarbon accumulations in Paleocene and Mesozoic sandstones in the 15/9 My structure.
    Operations and results
    Wildcat well 15/9-15 was spudded with the semi-submersible installation Ross Rig on 28 May 1982 and drilled to TD at 3200 m in the Triassic Skagerrak Formation. During drilling the 12 1/4" section, a significant volume of mud was lost at 2200 m. The thief zone was most probably in the Frigg sand. 3 days were spent locating the zone and pumping LCM pills. Otherwise no significant problem was encountered in the operations, which proceeded with little downtime. The well was drilled with spud mud down to 515 m and with gypsum/lignosulphonate mud from 515 m to TD.
    The Paleocene sandstones were missing in this well. The Mesozoic sandstones were encountered at 2806. The upper part  consisted of  tight Melke Formation sandstones without shows. From 2821 m (top Skagerrak Formation) they were gas bearing down to a true gas/water contact at 2923 m. No oil shows were recorded outside of the hydrocarbon-bearing reservoir in this well.
    Four cores were cut across the reservoir from 2805 m in the Heather Formation to 2878.2 m in the Skagerrak Formation. The core-to-log depth shift was 2.8 m for all four cores. RFT fluid samples were taken at 282.5 m (gas, condensate and mud filtrate), 2838.5 m (gas, condensate and mud filtrate), and at 2907 m (gas, condensate and mud filtrate) fluid samples were taken.
    The well was permanently abandoned on 1 August 1982 as a gas and condensate discovery.
    Testing
    Two Drill Stem Tests were performed.
    DST 1 tested the interval 2880 m to 2890 m. It produced 298000 Sm3 gas and 155 Sm3 condensate through a 32/64” choke. The GOR was 1922 Sm3/Sm3, the condensate density was 0.760 g/cm3, and the gas gravity was 0.718 with 0.2% CO2. The maximum temperature was 106.8 °C.
    DST 2 tested the interval 2830 m to 2850 m. It produced 293900 Sm3 gas and 124 Sm3 condensate through a 28/64” choke. The GOR was 2478 Sm3/Sm3, the condensate density was 0.757 g/cm3, and the gas gravity was 0.710 with 0.5% CO2. The maximum temperature was 105.7 °C.
    Both Drill Stem Tests included a flow period with a three-step multirate drawdown test. Check the well completion report and well test report for further details, such as flow parameters for other choke sizes.

  • 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]
    170.00
    2769.00

  • 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
    2805.0
    2823.4
    [m ]
    2
    2823.4
    2841.6
    [m ]
    3
    2841.6
    2859.9
    [m ]
    4
    2859.9
    2878.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    73.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2805-2810m
    Core photo at depth: 2810-2815m
    Core photo at depth: 2815-2820m
    Core photo at depth: 2820-2823m
    Core photo at depth: 2820-2923m
    2805-2810m
    2810-2815m
    2815-2820m
    2820-2823m
    2820-2923m
    Core photo at depth: 2823-2828m
    Core photo at depth: 2828-2833m
    Core photo at depth: 2833-2838m
    Core photo at depth: 2833-2838m
    Core photo at depth: 2838-2841m
    2823-2828m
    2828-2833m
    2833-2838m
    2833-2838m
    2838-2841m
    Core photo at depth: 2838-2841m
    Core photo at depth: 2841-2846m
    Core photo at depth: 2841-2846m
    Core photo at depth: 2846-2851m
    Core photo at depth: 2846-2851m
    2838-2841m
    2841-2846m
    2841-2846m
    2846-2851m
    2846-2851m
    Core photo at depth: 2851-2856m
    Core photo at depth: 2851-2856m
    Core photo at depth: 2856-2859m
    Core photo at depth: 2856-2859m
    Core photo at depth: 2859-2864m
    2851-2856m
    2851-2856m
    2856-2859m
    2856-2859m
    2859-2864m
    Core photo at depth: 2859-2864m
    Core photo at depth: 2864-2869m
    Core photo at depth: 2864-2869m
    Core photo at depth: 2869-2874m
    Core photo at depth: 2869-2874m
    2859-2864m
    2864-2869m
    2864-2869m
    2869-2874m
    2869-2874m
    Core photo at depth: 2874-2878m
    Core photo at depth: 2874-2878m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2874-2878m
    2874-2878m

  • 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
    2880.00
    2890.00
    20.07.1982 - 00:00
    YES
    DST
    TEST2
    2830.00
    2850.00
    25.07.1982 - 00:00
    YES

  • 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
    171.5
    36
    171.5
    0.00
    LOT
    SURF.COND.
    20
    498.0
    26
    515.0
    1.65
    LOT
    INTERM.
    13 3/8
    1178.0
    17 1/2
    1192.0
    1.68
    LOT
    INTERM.
    9 5/8
    2463.0
    12 1/4
    2478.0
    1.87
    LOT
    LINER
    7
    3199.0
    8 1/2
    3200.0
    0.00
    LOT

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2880
    2890
    25.0
    2.0
    2830
    2850
    22.0
    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
    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
    188
    467000
    0.770
    0.736
    2551
    2.0
    202
    510000
    0.767
    0.740
    2507

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    100
    1172
    CBL VDL GR
    1050
    2463
    CBL VDL GR
    2300
    3139
    CST
    1287
    2464
    CST
    2670
    3189
    CST
    2701
    3194
    CST
    2734
    3189
    DLL MSFL GR
    2800
    2950
    GEODIP
    2800
    2950
    HDT
    2463
    3202
    ISF BHC GR
    172
    1191
    ISF BHC MSFL GR
    1178
    3201
    LDT CNL GR
    1178
    2470
    LDT GR
    498
    1191
    RFT
    2823
    3090

  • 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
    0.39
    pdf
    5.35
    pdf
    1.04
    pdf
    1.18
    pdf
    0.59
    pdf
    19.09
    pdf
    1.95
    pdf
    19.09

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    350
    1.11
    waterbased
    515
    1.09
    waterbased
    1190
    1.13
    waterbased
    1920
    1.20
    waterbased
    2435
    1.21
    waterbased
    2630
    1.40
    waterbased
    2680
    1.50
    waterbased

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2752.5
    [m]
    SWC
    RRI
    2768.0
    [m]
    SWC
    RRI
    2777.0
    [m]
    SWC
    RRI
    2793.0
    [m]
    SWC
    RRI
    2818.6
    [m]
    C
    APT
    2821.0
    [m]
    C
    APT
    2821.8
    [m]
    C
    APT
    2822.4
    [m]
    C
    APT
    2828.4
    [m]
    C
    APT
    2829.4
    [m]
    C
    APT
    2830.6
    [m]
    C
    APT
    2831.4
    [m]
    C
    APT
    2832.0
    [m]
    C
    APT
    2832.3
    [m]
    C
    APT
    2836.8
    [m]
    C
    APT
    2849.2
    [m]
    C
    APT
    2849.8
    [m]
    C
    APT
    2851.5
    [m]
    C
    APT
    2851.7
    [m]
    C
    APT
    2853.6
    [m]
    C
    APT
    2853.8
    [m]
    C
    APT
    2857.7
    [m]
    C
    APT
    2862.8
    [m]
    C
    APT
    2866.9
    [m]
    C
    APT
    2868.7
    [m]
    C
    APT
    2872.1
    [m]
    C
    APT
    2874.9
    [m]
    C
    APT
    2876.5
    [m]
    C
    APT