Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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05.11.2024 - 01:27
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15/9-5

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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.
    15/9-5
    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
    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.
    15/9-5
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    510-314 SP.735
    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.
    232-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.
    145
    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,
    19.11.1979
    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.
    11.04.1980
    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.
    11.04.1982
    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.
    08.04.2015
    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.
    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.
    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.
    HUGIN 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.
    108.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3946.0
    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).
    3945.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.25
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    131
    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° 24' 12.47'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 42' 29.2'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6474503.53
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    424497.43
    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.
    326

  • Wellbore history
    General
    Well 15/9-5 was drilled in the Sleipner Vest area in the Central Graben of the North Sea. The objective was to test hydrocarbons in Middle Jurassic sandstones in the Beta structure of Sleipner Vest. The well is Reference Well for the Heimdal and Våle formations.
    Operations and results
    Appraisal well 15/9-5 was spudded with the semi-submersible installation Norskald on 19 November 1979 and drilled to TD at 3946 m in the Triassic Skagerrak Formation. Operations met with many problems, but the well objectives were fulfilled in the end. Excessive drag when pulling core barrel out of reservoir was a severe problem, and consequently frequent reaming and circulating trips was needed. Having finished logging in the 8 1/2” section, and just started testing the BOP stack, one of the riser tension sheaves broke and fell down. Also several problems with the hydraulic BOP control system and the ball joint made nearly 12 days rig repair necessary. After this delay the hole required extensive reaming before the 7” liner could be ran and the final 6” section could be drilled. Testing operations were hampered and delayed by bad weather and test equipment breakdown. The well was drilled with spud mud down to 426 m and with seawater/lignosulphonate mud from 426 m to TD.
    The well proved gas in sandstones of Middle Jurassic age from top Hugin Formation at 3526 m down to a true gas/water contact at 3662 m, based on logs and RFT samples. The Sleipner Formation was encountered at 3693 m. Logs and RFT pressure gradient proved Sleipner water filled, and ca 3 bar overpressured compared to the Hugin Formation. Shows were described on cores all through the hydrocarbon bearing reservoir. Abundant spots of fluorescence described on cuttings below ca 2000 m are described as “no shows”. According to other comments in the cuttings descriptions the fluorescence may be related to diesel addition to the mud.
    Nine cores were cut in the interval 3525 to 3663.6 m. A total of 133 m core (96.8%) was recovered. A FIT fluid sample at 3536 m recovered gas, condensate and mud. An RFT fluid sample was taken at 3540 m.
    The well was permanently abandoned on 11 April 1980 as a gas/condensate appraisal well.
    Testing
    Three Drill Stem Tests were conducted.
    DST1 tested the interval 3642 m to 3646.6 m. The final flow was controlled by using two variable chokes mounted in parallel. On the smallest choke size, 2x25/64”, the well produced 583000 Sm3 gas and 181 Sm3 condensate /day. The GOR was ca 3200 Sm3/Sm3, the oil density was 45.3 °API, and the gas gravity was 0.774 (air = 1).
    DST2 tested the interval 3605 to 3610 m plus 3613 to 3618 m. The final flow was controlled by using two variable chokes mounted in parallel. On the smallest choke size, 2x28.75/64”, the well produced 699400 Sm3 gas and 189 Sm3 condensate /day. The GOR was ca 3700 Sm3/Sm3, the oil density was 45.4°API, and the gas gravity was 0.773 (air = 1). The CO2 content was 9.2%. Maximum temperature during this test was 122.8 °C.
    DST3 tested the interval 3536 to 3546 m. The final flow was controlled by using two variable chokes mounted in parallel. The choke size was kept at 2x45.5/64” throughout the whole flow. The well produced 815500 Sm3 gas and 212 Sm3 condensate /day. The GOR was ca 3850 Sm3/Sm3, the oil density was 40 °API, and the gas gravity was 0.771 (air = 1). The CO2 content was 7.7 %.  Maximum temperature during this test was 117.8 °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]
    190.00
    3946.00

  • 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
    3525.0
    3543.4
    [m ]
    2
    3543.4
    3547.0
    [m ]
    3
    3547.0
    3565.4
    [m ]
    4
    3565.4
    3583.8
    [m ]
    5
    3584.1
    3600.4
    [m ]
    6
    3600.7
    3618.9
    [m ]
    7
    3619.2
    3634.9
    [m ]
    8
    3635.4
    3643.8
    [m ]
    9
    3645.3
    3662.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    134.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3525-3527m
    Core photo at depth: 3527-3530m
    Core photo at depth: 3530-3533m
    Core photo at depth: 3533-3535m
    Core photo at depth: 3535-3538m
    3525-3527m
    3527-3530m
    3530-3533m
    3533-3535m
    3535-3538m
    Core photo at depth: 3538-3541m
    Core photo at depth: 3541-3543m
    Core photo at depth: 3543-3546m
    Core photo at depth: 3546-3547m
    Core photo at depth: 3547-3549m
    3538-3541m
    3541-3543m
    3543-3546m
    3546-3547m
    3547-3549m
    Core photo at depth: 3549-3552m
    Core photo at depth: 3552-3555m
    Core photo at depth: 3555-3557m
    Core photo at depth: 3557-3560m
    Core photo at depth: 3560-3563m
    3549-3552m
    3552-3555m
    3555-3557m
    3557-3560m
    3560-3563m
    Core photo at depth: 3563-3565m
    Core photo at depth: 3565-3568m
    Core photo at depth: 3568-3570m
    Core photo at depth: 3570-3573m
    Core photo at depth: 3573-3576m
    3563-3565m
    3565-3568m
    3568-3570m
    3570-3573m
    3573-3576m
    Core photo at depth: 3576-3578m
    Core photo at depth: 3578-3581m
    Core photo at depth: 3581-3583m
    Core photo at depth: 3584-3586m
    Core photo at depth: 3586-3589m
    3576-3578m
    3578-3581m
    3581-3583m
    3584-3586m
    3586-3589m
    Core photo at depth: 3589-3592m
    Core photo at depth: 3592-3594m
    Core photo at depth: 3594-3597m
    Core photo at depth: 3597-3600m
    Core photo at depth: 3600-3603m
    3589-3592m
    3592-3594m
    3594-3597m
    3597-3600m
    3600-3603m
    Core photo at depth: 3603-3606m
    Core photo at depth: 3606-3608m
    Core photo at depth: 3608-3611m
    Core photo at depth: 3611-3614m
    Core photo at depth: 3614-3615m
    3603-3606m
    3606-3608m
    3608-3611m
    3611-3614m
    3614-3615m
    Core photo at depth: 3616-3618m
    Core photo at depth: 3619-3621m
    Core photo at depth: 3621-3624m
    Core photo at depth: 3624-3627m
    Core photo at depth: 3627-3630m
    3616-3618m
    3619-3621m
    3621-3624m
    3624-3627m
    3627-3630m
    Core photo at depth: 3630-3632m
    Core photo at depth: 3632-3634m
    Core photo at depth: 3635-3638m
    Core photo at depth: 3638-3640m
    Core photo at depth: 3640-3643m
    3630-3632m
    3632-3634m
    3635-3638m
    3638-3640m
    3640-3643m
    Core photo at depth: 3643-3644m
    Core photo at depth: 3645-3648m
    Core photo at depth: 3648-3650m
    Core photo at depth: 3650-3653m
    Core photo at depth: 3653-3656m
    3643-3644m
    3645-3648m
    3648-3650m
    3650-3653m
    3653-3656m
    Core photo at depth: 3656-3658m
    Core photo at depth: 3658-3661m
    Core photo at depth: 3661-3662m
    Core photo at depth:  
    Core photo at depth:  
    3656-3658m
    3658-3661m
    3661-3662m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3430.0
    [m]
    DC
    3435.0
    [m]
    DC
    3439.0
    [m]
    DC
    3469.0
    [m]
    DC
    3499.0
    [m]
    DC
    3520.0
    [m]
    DC
    3528.8
    [m]
    C
    3555.1
    [m]
    C
    3573.2
    [m]
    C
    3577.3
    [m]
    C
    3596.6
    [m]
    C
    3598.1
    [m]
    C
    3607.4
    [m]
    C
    3615.9
    [m]
    C
    3623.6
    [m]
    C
    3634.0
    [m]
    C
    3636.0
    [m]
    C
    3643.5
    [m]
    C
    3650.8
    [m]
    C
    3691.0
    [m]
    DC
    3721.0
    [m]
    DC
    3751.0
    [m]
    DC
    3781.0
    [m]
    DC

  • 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
    3588.00
    3593.00
    21.03.1980 - 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
    21.58

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3617
    3647
    25.0
    2.0
    3588
    3593
    0.0
    3.0
    3511
    3521
    0.0
    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
    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
    218
    768
    0.799
    0.768
    3
    2.0
    229
    865
    0.811
    0.886
    4
    3.0
    206
    813
    4

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    ARROW PLOT
    2827
    3951
    CBL
    400
    2825
    FDC CNL GR
    2827
    3949
    FDC GR
    447
    2833
    GR CCL
    182
    2850
    HDT
    2826
    3950
    ISF SON GR
    182
    3949
    VELOCITY
    475
    3940

  • 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
    158.0
    0.00
    LOT
    SURF.COND.
    20
    422.0
    26
    437.0
    1.37
    LOT
    INTERM.
    13 3/8
    1232.0
    17 1/2
    1243.0
    1.95
    LOT
    INTERM.
    9 5/8
    2792.0
    12 1/4
    2807.0
    1.72
    LOT
    LINER
    7
    3663.0
    8 1/2
    3664.0
    1.96
    LOT
    OPEN HOLE
    3921.0
    6
    3921.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    204
    1.04
    100.0
    waterbased
    436
    1.09
    38.0
    waterbased
    795
    1.09
    36.0
    waterbased
    1300
    1.20
    100.0
    waterbased
    3325
    1.38
    45.0
    waterbased
    3580
    1.40
    50.0
    waterbased
    3778
    1.35
    44.0
    waterbased

  • 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