Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
11.11.2024 - 01:26
Time of last synchronization with Norwegian Offshore Directorate's internal systems

6706/6-1

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.
    6706/6-1
    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
    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.
    6706/6-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    inline 1689-xline 6688 on ES00-01 3D
    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.
    Esso Exploration and Production Norway 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.
    1050-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.
    45
    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,
    04.05.2003
    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.
    17.06.2003
    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.
    17.06.2005
    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.
    17.06.2005
    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.
    PALEOCENE
    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.
    NO FORMAL NAME
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    36.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    1298.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3451.0
    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).
    3450.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    84
    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.
    PALEOCENE
    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.
    NO FORMAL NAME
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    67° 33' 34.79'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    6° 41' 18.38'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7495801.60
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    401546.00
    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.
    4705

  • Wellbore history
    General
    Wildcat well 6706/6-1 is a true frontier well. It was drilled to test the hydrocarbon potential of the Cretaceous Hvitveis prospect at the Naglfar Dome in the Vøring Basin. The objective for Well 6706/6-1 was to test a seismically defined reservoir interval, interpreted to be a Nise Formation Equivalent.
    Operations and results
    Wildcat well 6706/6-1 was spudded with the dynamically positioned vessel West Navigator in 1298 m water depth on 2 May 2003 and drilled to TD at 3451 m in Paleocene sediments. Drilling started with a 9 7/8" pilot hole to 2050 m with MWD logging. High-risk shallow gas anomaly had been mapped 490 m east of the location. No shallow gas or boulder problems were encountered in the pilot hole. The main hole was drilled from a location ca 100 m south of the pilot hole. A hard crust about 1.5 m below the sea floor caused the bit to skid ca 40 m from the planned position in the first spud. In the second attempt the bit skidded 6 m before it entered the crust. This was within acceptable limits and drilling of the main hole could commence without significant problems. The well was drilled with seawater and hi-vis pills down to 2050 m and with KCl/Glydril mud from 2050 m to TD. First returns were at 2060 m.
    Biostratigraphic analyses showed that the entire section from 2060 m (first returns) to 3451 m (TD) was deposited during the Alisocysta margarita dinoflagellate zone, representing approximately 4 million years of sedimentation in the late Danian and early Selandian. The two uppermost cuttings samples (2060 m  and 2080 m) show well-preserved Alisocysta margarita and Palaeocystodinium bulliforme , together with reworked Late Cretaceous dinoflagellates. The conventional core and sidewall cores in the lowermost 170 metres of the well contain sparse and very poorly preserved A. margarita, P. bulliforme, Deflandrea spp., and Senoniasphaera inornata . The contrast in preservation quality of these Danian - Selandian dinoflagellates in the lower part of the well compared to those at the level of first returns indicate that the lowermost occurrences are in situ , since caved specimens would show pristine preservation. Microplankton assemblages in the conventional core and sidewall cores are totally dominated by reworking, mainly Late Cretaceous with some Early Cretaceous and older sources. Mixing of Late Cretaceous bioevents and absence of certain regional Late Cretaceous bioevents is further indication that this well penetrates approximately 1400 metres of a Danian - Selandian mass transport deposit sourced from Late and Early Cretaceous sediments.
    Four intervals in the well had higher gas readings ("gas shows") than the general background of 0.7- 1 %: 2340 m to 2360 m (maximum 6 %), 3014 m to 3020 m (maximum 6 %), 3260 m to 3280 m (maximum 8 %), and 3360 m to 3450 m (maximum 2.5 %). A weak oil show was described in a single cuttings sample from 2368 m. A second, weak oil show was described on the core at 3283.55 m. The well discovered a close to normally pressured dry gas accumulation in a reservoir section picked at 3239 m, beginning with thin sandstone stringers interbedded with shale, overlying more massive sandstones at 3251 m. Gas was found down to a free water level at 3266 m.
    Geochemical analyses showed that much of the shaley sequences penetrated by the well had good TOC, but with low potential for petroleum generation, probably only gas prone at best. Thermal maturity reaches beginning of the oil window %Ro = 0.5) at around 2700 m which is quite shallow considering the 1298 m water depth. At TD vitrinite reflectance is ca 0.75%. Headspace gas analyses largely confirmed the interval with gas shows recorded on the rig. In addition, some possibly migrated condensate-range hydrocarbons were found in cuttings in the interval 3100 m to 3250 m.
    One conventional core was cut with 82 % recovery in the interval 3277 m to 3285.5 m. Fluid sampling was done at 3265.5 m with the RCI wire line tool. The samples contained gas and mud filtrate with a thin film of condensate. All samples had dew points higher than the reservoir pressure and were thus not representative for the formation fluid. The reason for this was probably pressure draw down due to a relatively tight formation.
    The well was permanently abandoned on 18 June 2003 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]
    2060.00
    3450.00

  • 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
    3277.0
    3283.6
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    6.6
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    NO

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2060.0
    [m]
    DC
    RRI
    2060.0
    [m]
    DC
    OD
    2070.0
    [m]
    DC
    OD
    2080.0
    [m]
    DC
    OD
    2080.0
    [m]
    DC
    RRI
    2110.0
    [m]
    DC
    RRI
    2120.0
    [m]
    DC
    RRI
    2140.0
    [m]
    DC
    OD
    2150.0
    [m]
    DC
    RRI
    2180.0
    [m]
    DC
    RRI
    2200.0
    [m]
    DC
    OD
    2230.0
    [m]
    DC
    RRI
    2240.0
    [m]
    DC
    RRI
    2260.0
    [m]
    DC
    OD
    2300.0
    [m]
    DC
    RRI
    2321.0
    [m]
    DC
    OD
    2330.0
    [m]
    DC
    RRI
    2360.0
    [m]
    DC
    RRI
    2360.0
    [m]
    DC
    OD
    2405.0
    [m]
    DC
    RRI
    2447.0
    [m]
    DC
    RRI
    2500.0
    [m]
    DC
    RRI
    2560.0
    [m]
    DC
    RRI
    2630.0
    [m]
    DC
    RRI
    2650.0
    [m]
    DC
    RRI
    2720.0
    [m]
    DC
    RRI
    2790.0
    [m]
    DC
    RRI
    2810.0
    [m]
    DC
    RRI
    2820.0
    [m]
    DC
    RRI
    2890.0
    [m]
    DC
    RRI
    2900.0
    [m]
    DC
    RRI
    2906.0
    [m]
    DC
    RRI
    3016.0
    [m]
    DC
    RRI
    3060.0
    [m]
    DC
    RRI
    3110.0
    [m]
    DC
    RRI
    3160.0
    [m]
    DC
    RRI
    3170.0
    [m]
    DC
    RRI
    3210.0
    [m]
    DC
    RRI
    3237.5
    [m]
    SWC
    RRI
    3238.0
    [m]
    DC
    RRI
    3243.2
    [m]
    SWC
    RRI
    3253.0
    [m]
    DC
    RRI
    3254.2
    [m]
    SWC
    RRI
    3262.0
    [m]
    DC
    RRI
    3262.2
    [m]
    SWC
    RRI
    3278.0
    [m]
    C
    OD
    3279.7
    [m]
    C
    OD
    3279.7
    [m]
    C
    RRI
    3279.8
    [m]
    C
    OD
    3279.8
    [m]
    C
    OD
    3279.8
    [m]
    C
    RRI
    3279.9
    [m]
    C
    OD
    3280.5
    [m]
    C
    OD
    3280.8
    [m]
    C
    OD
    3280.9
    [m]
    C
    OD
    3280.9
    [m]
    C
    RRI
    3281.0
    [m]
    C
    OD
    3281.2
    [m]
    C
    RRI
    3281.2
    [m]
    C
    OD
    3281.3
    [m]
    C
    OD
    3282.4
    [m]
    C
    RRI
    3282.4
    [m]
    C
    OD
    3282.7
    [m]
    C
    RRI
    3282.8
    [m]
    SWC
    RRI
    3283.0
    [m]
    C
    OD
    3286.0
    [m]
    DC
    OD
    3304.0
    [m]
    DC
    RRI
    3308.5
    [m]
    SWC
    RRI
    3309.2
    [m]
    SWC
    RRI
    3328.0
    [m]
    DC
    OD
    3367.7
    [m]
    SWC
    RRI
    3390.0
    [m]
    DC
    OD
    3390.5
    [m]
    SWC
    RRI
    3407.5
    [m]
    SWC
    RRI
    3420.0
    [m]
    DC
    RRI
    3450.0
    [m]
    DC
    RRI
    3450.0
    [m]
    DC
    OD
    3450.0
    [m]
    DC
    OD

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    1334
    1334
    1385
    1543
    1543
    1875
    1875
    3239

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.29

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.95

  • 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
    8.54
    .PDF
    2.80

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    GR CHECKSHOT
    2770
    3220
    GR CN ZDL XMAC ELITE DLL MLL
    2042
    2770
    GR CN ZDL XMAC ELITE DLL MLL
    2631
    3216
    GR MLR XMAC ELITE CHECKSHOT
    2500
    3445
    GR RCI
    3243
    3430
    GR SWC
    3231
    3435
    LWD - CDR ARC APWD DIR
    1329
    2050
    LWD - CDR ARC DIR
    2050
    2770
    LWD - DIR
    1331
    2050
    LWD - PWD CDR ARC DIR
    2770
    3220
    LWD -L PWD CDR ARC RAB ADN CDN D
    3220
    3450

  • 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
    36
    1422.0
    42
    1428.0
    0.00
    LOT
    SURF.COND.
    20
    2042.0
    28
    2050.0
    1.27
    LOT
    INTERM.
    13 3/8
    3211.0
    17
    3220.0
    1.49
    LOT
    OPEN HOLE
    3451.0
    12 1/4
    3451.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1428
    1.05
    DUMMY
    2050
    0.00
    DUMMY
    2770
    1.18
    15.0
    DUMMY
    3220
    0.00
    DUMMY
    3349
    1.28
    15.0
    DUMMY

  • 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
    0.26