Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
24.11.2024 - 01:27
Time of last synchronization with Norwegian Offshore Directorate's internal systems

15/3-5

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.
    15/3-5
    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
    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.
    15/3-5
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    EL 8206 - 418 A SP 726
    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.
    Elf Petroleum Norge 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.
    397-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.
    138
    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,
    28.12.1983
    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.
    13.05.1984
    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.
    13.05.1986
    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.
    10.08.2013
    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.
    SLEIPNER 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.
    110.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4130.0
    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).
    4130.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    115
    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.
    MIDDLE 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.
    SLEIPNER FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 47' 13.04'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 50' 34.11'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6517057.34
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    433105.22
    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.
    52

  • Wellbore history
    General
    Well 15/3-5 was drilled on the Gudrun Terrace, east of the 15/3-1 S Gudrun Discovery in the North Sea. Well 15/3-5 was drilled in a downdip position of a structure explored by the well 15/3-4, where oil bearing reservoirs of Middle Jurassic age were tested. The main objectives of 15/3-5 were to find the extension of these reservoirs and to define a hydrocarbon/water contact.
    Operations and results
    Appraisal well 15/3-5 was spudded with the semi-submersible installation Byford Dolphin on 28 December 1983 and drilled to TD at 4130 m in the Middle Jurassic Sleipner Formation. Drilling was suspended at 195 m due to bad weather. The well was re-spudded on 6 January 25 m west of the original location. Some technical problems with the BOP occurred after setting of the 20" and 13 3/8" casings. A seat protector got stuck in the riser during drilling of the 17 1/2" hole. Drilling breaks occurred at 3943 m, 3954 m, 4018 m, 4032 m and at 4041 4043 m in the 8 1/2" hole section. The well was drilled using water based mud.
    Top Draupne Formation was encountered at 3808 m, followed by the Heather Formation at 3881 m, and the target Middle Jurassic Sleipner Formation at 3935 m. Several thin reservoir zones were penetrated in the Sleipner Formation. The sands were interpreted as minor fluvial channels (2 to 5m in thickness) deposited in two main sequences. Four of the channels were oil-bearing with an oil gradient of 0.61 bar/10 m based on pressure measurements. An OWC could be established at 4022.6 m. Pressure measurements showed that the upper fluvial channel sequence is over-pressured, and not in contact with the sands encountered in well 15/3-4. The lower fluvial sequence could be connected between the two wells. Petrophysical evaluation of the whole system gave a net pay of 6.7 m.
    In the Quaternary, Tertiary and Cretaceous series no fluorescence due to hydrocarbons were observed. In the Upper Jurassic sequence, a weak yellow colour in direct fluorescence light was observed on sandstone pieces. A pale to clear yellow and orange colour in direct fluorescence light was reported from the Middle Jurassic sequence down to about 4060m. Below 4060 m to TD nil to very weak direct fluorescence was observed.
    Three cores were cut in the Sleipner Formation. Cores 1 and 2 were cut from 3971 to 4003 m (3973.6 to 4005.6 m logger's depth) with 98 % and 84% recovery, respectively. Core 3 was cut from 4020 to 4029 m (4023.9 to 4032.9 m logger's depth) with 94% recovery. RFT wire line fluid samples were taken at 3969.9 m (gas + mud filtrate), 3984 m (gas + mud filtrate), 4022.2 m (minor gas + mud filtrate), and 4028.5 m (trace gas + mud filtrate),
    The well was permanently abandoned on 13 May 1984 as an oil appraisal.
    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]
    200.00
    4130.00

  • Core photos
    Core photos
    Core photo at depth: High: 3971-3975m
    Core photo at depth: Low: 3971-3975m
    Core photo at depth: High: 3975-3979m
    Core photo at depth: Low: 3975-3979m
    Core photo at depth: High: 3979-3983m
    High: 3971-3975m
    Low: 3971-3975m
    High: 3975-3979m
    Low: 3975-3979m
    High: 3979-3983m
    Core photo at depth: Low: 3979-3983m
    Core photo at depth: High: 3983-3987m
    Core photo at depth: Low: 3983-3987m
    Core photo at depth: 3987-3989m
    Core photo at depth: 3989-3991m
    Low: 3979-3983m
    High: 3983-3987m
    Low: 3983-3987m
    3987-3989m
    3989-3991m
    Core photo at depth: High: 3991-3995m
    Core photo at depth: Low: 3991-3995m
    Core photo at depth: High: 3995-3999m
    Core photo at depth: Low: 3995-3999m
    Core photo at depth: 3999-4001m
    High: 3991-3995m
    Low: 3991-3995m
    High: 3995-3999m
    Low: 3995-3999m
    3999-4001m
    Core photo at depth: 4020-4022m
    Core photo at depth: 4022-4026m
    Core photo at depth: 4026-4029m
    Core photo at depth:  
    Core photo at depth:  
    4020-4022m
    4022-4026m
    4026-4029m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3971.4
    [m]
    C
    WESTL
    3973.5
    [m]
    C
    WESTL
    3977.1
    [m]
    C
    WESTL
    3979.6
    [m]
    C
    WESTL
    3980.7
    [m]
    C
    WESTL
    3983.4
    [m]
    C
    WESTL
    3986.4
    [m]
    C
    WESTL
    3987.2
    [m]
    C
    WESTL
    3992.0
    [m]
    C
    WESTL
    3995.8
    [m]
    C
    WESTL
    4000.4
    [m]
    C
    WESTL
    4020.3
    [m]
    C
    WESTL
    4021.4
    [m]
    C
    WESTL
    4023.1
    [m]
    C
    WESTL
    4024.2
    [m]
    C
    WESTL
    4028.3
    [m]
    C
    WESTL

  • 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
    0.00
    0.00
    WATER
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.04
    pdf
    1.67

  • 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
    2.17
    pdf
    11.39

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BGT GR CAL
    962
    2800
    CST
    2817
    3829
    CST
    3210
    3828
    CST
    3830
    3905
    CST
    3938
    4130
    DLL MSFL GR
    3816
    4133
    ISF LSS GR SP
    2797
    3832
    ISF LSS GR SP
    3816
    4005
    ISF LSS GR SP
    3816
    4133
    ISF SON GR
    135
    973
    ISF SON GR SP
    962
    2808
    LDL CAL
    962
    2808
    LDL CNL GR CAL
    3816
    4005
    LDL CNL NGL
    3815
    4135
    LDT GR CAL
    194
    967
    LDT NGT CAL
    2797
    3817
    RFT
    3960
    4135
    RFT
    3984
    4048
    RFT
    4022
    4028
    SHDT
    2797
    3830
    SHDT
    3815
    4135
    SSL
    1000
    4125

  • 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
    196.0
    36
    196.0
    0.00
    LOT
    SURF.COND.
    20
    962.0
    26
    977.0
    1.28
    LOT
    INTERM.
    13 3/8
    2798.0
    17 1/2
    2813.0
    1.72
    LOT
    INTERM.
    9 5/8
    3816.0
    12 1/4
    3832.0
    0.00
    LOT
    OPEN HOLE
    4130.0
    8 1/2
    4130.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    180
    1.03
    26.0
    10.0
    WATER BASED
    210
    1.11
    26.0
    10.0
    WATER BASED
    1040
    1.15
    15.0
    10.0
    WATER BASED
    1170
    1.17
    WATER BASED
    1245
    1.18
    25.0
    20.0
    WATER BASED
    1530
    1.19
    24.0
    14.0
    WATER BASED
    1790
    1.21
    21.0
    13.0
    WATER BASED
    2160
    1.26
    WATER BASED
    2370
    1.26
    32.0
    26.0
    WATER BASED
    2605
    1.28
    21.0
    16.0
    WATER BASED
    3010
    1.29
    35.0
    28.0
    WATER BASED
    3070
    1.30
    35.0
    26.0
    WATER BASED
    3530
    1.33
    36.0
    24.0
    WATER BASED
    3660
    1.37
    36.0
    20.0
    WATER BASED
    3710
    1.41
    48.0
    20.0
    WATER BASED
    3740
    1.43
    48.0
    20.0
    WATER BASED
    3785
    1.45
    40.0
    26.0
    WATER BASED
    3850
    1.60
    WATER BASED
    3930
    1.61
    42.0
    18.0
    WATER BASED
    3970
    1.70
    WATER BASED

  • 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