Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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21.11.2024 - 01:28
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15/6-11 A

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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.
    15/6-11 A
    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
    Press release
    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.
    15/6-11
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    3D LINE st0730z09 INLINE 1460 & TRACE 1480
    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.
    Statoil Petroleum 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.
    1336-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.
    78
    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,
    26.12.2010
    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.
    13.03.2011
    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.
    13.03.2013
    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.
    13.03.2013
    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.
    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.
    22.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    116.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4305.0
    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).
    3853.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    42
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    121
    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.
    58° 34' 8.62'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 42' 10.61'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6492945.84
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    424551.53
    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.
    6526

  • Wellbore history
    General
    Well 15/6-11 A was drilled to appraise the 15/5-1 Dagny Discovery in the South-eastern end of the Viking Graben. The north-eastern extension of this structure, the Ermintrude Segment, was tested in 2007 by well 15/6-9 S and side tracks 15/6-9 A&B, which proved oil and gas in a down-to situation in the Hugin Formation, and in communication with the Dagny Discovery. Well 15/6-11-A was drilled on the western part of the Ermintrude structure, on the saddle point between the main Dagny segment and the Ermintrude Segment. The main objective was thus to delimit and test the extension of the hydrocarbon-bearings sands in Hugin Formation of the Dagny Discovery. If hydrocarbons were confirmed a drill stem test would be conducted.
    Operations and results
    Appraisal well 15/6-11 A was sidetracked from the primary well 15/6-11 S on 26 December 2010. Kick-off point was 1981 m. The well was drilled with the semi-submersible installation Ocean Vanguard to TD at 4305 m (3853 m TVD) in the Early Jurassic Statfjord Formation. No significant problems were encountered in the operations. The sidetrack well was drilled with XP-07 14A oil based mud from kick-off to TD.
    The target reservoir sandstones of the Hugin Formation were encountered at 4121 m (3708.5 m TVD), 12.5 m deeper than prognosis. The Hugin Formation was found to be heterolithic siltstone/sandstone at the top but grading to better sand quality with depth. Good sandstones with high gas values and hydrocarbon shows were encountered 4138 m. Both the core and the logs showed presence of hydrocarbons in the Hugin Formation with OWC at 4167 m (3745 m TVD). There were shows indications also in sands in the Sleipner Formation and in the Statfjord Formation towards TD of the well.
    A core was cut from 4148 m to 4179 m. The core shift relative to the logs was found to be close to + 2.3 m for the whole core. MDT wire line fluid samples were taken at 4148 m (oil and gas), and at 2597.7 m (water).
    The well was permanently abandoned on 13 March 2011 as a gas/condensate appraisal well.
    Testing
    A drill stem test was conducted from perforations at 4137.8 m to 4158.5 m in the gas/condensate bearing zone of the Hugin Formation. The test produced 120 Sm3 oil and 220000 Sm3 gas /day through a 32/64" choke. The GOR was 1830 Sm3/Sm3. The bottom hole temperature at reference depth was 118 deg 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]
    1990.00
    4305.20

  • 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
    4148.0
    4181.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    33.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3965.0
    [m]
    DC
    3970.0
    [m]
    DC
    3975.0
    [m]
    DC
    3980.0
    [m]
    DC
    3985.0
    [m]
    DC
    3990.0
    [m]
    DC
    3995.0
    [m]
    DC
    4000.0
    [m]
    DC
    4006.0
    [m]
    DC
    4012.0
    [m]
    DC
    4018.0
    [m]
    DC
    4024.0
    [m]
    DC
    4030.0
    [m]
    DC
    4036.0
    [m]
    DC
    4042.0
    [m]
    DC
    4048.0
    [m]
    DC
    4054.0
    [m]
    DC
    4060.0
    [m]
    DC
    4066.0
    [m]
    DC
    4072.0
    [m]
    DC
    4078.0
    [m]
    DC
    4084.0
    [m]
    DC
    4090.0
    [m]
    DC
    4096.0
    [m]
    DC
    4102.0
    [m]
    DC
    4105.0
    [m]
    DC
    4108.0
    [m]
    DC
    4114.0
    [m]
    DC
    4117.0
    [m]
    DC
    4120.0
    [m]
    DC
    4123.0
    [m]
    DC
    4126.0
    [m]
    DC
    4129.0
    [m]
    DC
    4132.0
    [m]
    DC
    4135.0
    [m]
    DC
    4138.0
    [m]
    DC
    4141.0
    [m]
    DC
    4144.0
    [m]
    DC
    4147.0
    [m]
    DC
    4148.0
    [m]
    C
    4150.0
    [m]
    DC
    4151.7
    [m]
    C
    4153.0
    [m]
    DC
    4156.0
    [m]
    DC
    4156.2
    [m]
    C
    4159.0
    [m]
    DC
    4159.5
    [m]
    C
    4162.0
    [m]
    DC
    4163.1
    [m]
    C
    4163.9
    [m]
    C
    4165.0
    [m]
    DC
    4165.6
    [m]
    C
    4168.0
    [m]
    DC
    4171.0
    [m]
    DC
    4171.7
    [m]
    C
    4174.0
    [m]
    DC
    4174.6
    [m]
    C
    4177.0
    [m]
    DC
    4178.0
    [m]
    C
    4179.1
    [m]
    C
    4180.0
    [m]
    DC
    4183.0
    [m]
    DC
    4186.0
    [m]
    DC
    4189.0
    [m]
    DC
    4192.0
    [m]
    DC
    4195.0
    [m]
    DC
    4198.0
    [m]
    DC
    4207.0
    [m]
    DC
    4213.0
    [m]
    DC
    4219.0
    [m]
    DC
    4225.0
    [m]
    DC
    4231.0
    [m]
    DC
    4237.0
    [m]
    DC
    4243.0
    [m]
    DC
    4249.0
    [m]
    DC
    4255.0
    [m]
    DC
    4261.0
    [m]
    DC
    4267.0
    [m]
    DC
    4273.0
    [m]
    DC
    4279.0
    [m]
    DC
    4285.0
    [m]
    DC
    4291.0
    [m]
    DC
    4297.0
    [m]
    DC
    4303.0
    [m]
    DC
    4305.2
    [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
    4158.00
    4139.58
    OIL
    25.02.2011 - 19:40
    YES

  • Lithostratigraphy

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    4148
    4180
    12.7
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    22.000
    118
    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
    120
    220000

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    MWD LWD - ARCRES8 TELE
    4010
    4148
    MWD LWD - ARCVRES8 TELE
    1989
    4003
    MWD LWD - GVR ARC6 TELE
    4010
    4305

  • 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
    LINER
    9 5/8
    4002.0
    12 1/4
    4006.0
    2.13
    LOT
    LINER
    7
    4304.0
    8 1/2
    4305.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    420
    1.39
    28.0
    Spud Mud
    1950
    1.49
    13.0
    XP-07 - #14
    2244
    1.39
    28.0
    XP-07 - #14
    2631
    1.40
    23.0
    XP-07 - #14
    2902
    1.39
    25.0
    XP-07 - #14
    3042
    1.40
    28.0
    XP-07 - #14
    3117
    1.40
    24.0
    XP-07 - #14
    3390
    1.42
    27.0
    XP-07 - #14
    3430
    1.43
    23.0
    XP-07 - #14
    3477
    1.45
    24.0
    XP-07 - #14
    3549
    1.48
    26.0
    XP-07 - #14
    4003
    1.50
    29.0
    XP-07 - #14
    4003
    1.50
    25.0
    XP-07 - #14
    4028
    1.50
    28.0
    XP-07 - #14
    4076
    1.50
    30.0
    XP-07 - #14
    4174
    1.50
    34.0
    XP-07 - #14
    4180
    1.51
    31.0
    XP-07 - #14
    4305
    1.52
    30.0
    XP-07 - #14
    4305
    1.50
    27.0
    XP-07 - #14
    4305
    1.50
    26.0
    XP-07 - #14
    4305
    1.52
    31.0
    XP-07 - #14
    4305
    1.50
    32.0
    XP-07 - #14

  • 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
    0.23