Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
21.11.2024 - 01:28
Time of last synchronization with Norwegian Offshore Directorate's internal systems

6407/6-7 S

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.
    6407/6-7 S
    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
    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.
    NORWEGIAN 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.
    6407/6-7
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST04m8-inline 2154 and crossline 2680
    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.
    StatoilHydro 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.
    1243-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.
    46
    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,
    12.04.2009
    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.
    27.05.2009
    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.
    27.05.2011
    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.
    27.05.2011
    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
    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.
    LATE 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.
    ROGN 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.
    MIDDLE JURASSIC
    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.
    GARN 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.
    247.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3227.0
    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).
    3184.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    15.8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    127
    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.
    ÅRE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    64° 33' 53'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 40' 26.7'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7160787.20
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    436458.94
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    32
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    6100

  • Wellbore history
    General
    The 6407/6-7 S Harepus well was drilled on the eastern limits of the Halten Terrace, adjacent to the Trøndelag Platform offshore Mid Norway. The main objective was to prove hydrocarbon bearing sands in the Middle Jurassic Garn and Ile Formations (Fangst Group). Secondary objectives were to test the hydrocarbon potential of the Ror, Tilje and Åre Formations.
    Operations and results
    Well 6407/6-U-2 (pilot hole) was spudded and drilled to a total depth of 437 m. A drill break and a drop in gamma measurements indicated a sand layer from 436 - 437 m. Shallow gas was observed at seabed surface by ROV sonar during the connection at 437 m. The well was killed with 1.60 SG kill mud and plugged back to surface with three cement plugs.
    Wildcat well 6407/6-7 S was spudded with the semi-submersible installation Ocean Vanguard on 12 April 2009 and drilled to TD at 3227 m (3184 m TVD) in the Early Jurassic Åre Formation. The well was designed as a vertical well down to ca 1710 m in the 12 1/4" hole section and directionally drilled from the 12 1/4" section to hit the geological target at a 15 deg angle, holding this inclination to TD. No shallow gas was observed while drilling the 36" and 17 1/2" hole sections. The well was drilled with Seawater and hi-vis sweeps down to 422 m, with 1.15 SG WB spud mud from 422 m to 1149 m, with Performadril HPWBM mud from 1149 m to 2701 m, and with Performadril mud from 2701 m to TD.
    The well penetrated rocks of Quaternary, Tertiary, Cretaceous, and Jurassic age. TD of the well was in the Åre Formation. Base Cretaceous/Top Spekk Formation was encountered at 2685 m with Late Jurassic Rogn Formation sandstone coming in at 2747 m (2716.2 m TVD) and a second Spekk Formation interval at 2765.7 m (2734.3 m TVD). Eroded Middle Jurassic Garn formation was encountered at 2777.3 m (2745.6 m TVD, 40 m deeper than predicted. Gas with condensate was proved in the Rogn and Garn Formations with a gas down to (GDT) proven in the Garn formation. The Garn formation pressure was 28 bar depleted and the pressure plots could not be used to determine gas-water-contact (GWC). From pressure points and logs gas is seen down to 2813.4 m (2780.6 m TVD) and water up to 2827.2 m (2794.0 m TVD). No hydrocarbons were seen in the Early Jurassic Båt Group.
    No oil shows were seen in the well apart from some weak cloudy bluish white cut fluorescence, and in parts, a greenish yellow residual in core chips from the reservoir section.
    One core was cut from 2756.5 to 2778.8 m in the Rogn and Garn Formations. Good quality gas samples were collected with the MDT single probe equipment in the Rogn Formation at 2764 m, 2764.7 m, and 2770.8 m and in the Garn Formation at 2784.1 m. No water samples were collected due to hole conditions.
    The well was permanently abandoned on 27 May 2009 as a gas discovery.
    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]
    430.00
    3222.00

  • 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
    2756.5
    2778.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    22.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    FMI MSIP
    2700
    3220
    MDT PRETEST
    2751
    3139
    MDT PS PA MINI-DST
    0
    0
    MDT PS SAMPLING
    2764
    2784
    MWD - PP ARCVRES6 GR RES PWD DIR
    1149
    3227
    MWD - PP ARCVRES9 GR RES PW
    321
    1149
    MWD - PP DIR
    269
    321
    PEX HRLA ECS CMR
    2700
    3227
    VSP
    328
    3220

  • 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
    317.0
    36
    317.0
    0.00
    LOT
    SURF.COND.
    20
    418.0
    26
    422.0
    1.27
    LOT
    PILOT HOLE
    437.0
    9 7/8
    437.0
    0.00
    LOT
    INTERM.
    13 3/8
    1144.0
    17 1/2
    1149.0
    1.76
    LOT
    INTERM.
    9 5/8
    2700.0
    12 1/4
    2701.0
    1.86
    LOT
    OPEN HOLE
    3227.0
    8 1/2
    3227.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    547
    1.15
    10.0
    Spud Mud
    649
    1.17
    9.0
    Spud Mud
    850
    1.17
    9.0
    Spud Mud
    965
    1.14
    9.0
    Spud Mud
    1149
    1.24
    8.0
    HPWBM
    1310
    1.45
    27.0
    HPWBM
    1884
    1.52
    38.0
    HPWBM
    2052
    1.51
    37.0
    HPWBM
    2192
    1.51
    34.0
    HPWBM
    2626
    1.51
    43.0
    HPWBM
    2698
    1.27
    19.0
    HPWBM
    2756
    1.26
    24.0
    HPWBM
    3215
    1.25
    25.0
    HPWBM
    3227
    1.25
    25.0
    HPWBM

  • 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