Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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6406/2-1 R

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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.
    6406/2-1 R
    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
    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.
    6406/2-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    SG 9312 3D- ROW 1396 & COLUMN 1975
    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.
    Saga Petroleum ASA
    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.
    798-L2
    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.
    140
    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,
    21.08.1995
    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.
    07.01.1996
    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.
    07.01.1998
    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.
    29.05.2002
    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.
    YES
    Reentry activity
    Reason for reentry of the wellbore. Only relevant for exploration wellbores. Example of legal values: DRILLING, DRILLING/PLUGGING, LOGGING, PLUGGING, TESTING, TESTING/PLUGGING.
    TESTING
    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.
    FANGST GP
    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.
    EARLY 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.
    BÅT GP
    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.
    278.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    5892.0
    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).
    5790.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    38.1
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    194
    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.
    LATE 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.
    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° 52' 15.19'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    6° 36' 21.35'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7196390.67
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    386574.36
    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.
    2642

  • Wellbore history
    General
    Exploration well 6406/2-1 was drilled on the B-prospect east in the block 6406/2, south of the Smørbukk Field and west of the Trestakk Field on Haltenbanken. The main purpose was to test the B-prospect sandstones of Middle to Early Jurassic age and the presence of hydrocarbons. Further, the reservoir quality at great depth (prognosed TD 5200 m) was to be tested. The main reservoir zones were prognosed to be the Ile and Tilje Formations, both prognosed to consist of mica-bearing sandstones with thin shale layers. The Garn and Tofte Formations, expected to be purer quartz-sandstones and more susceptible to diagenetic quartz cementation, were considered as additional potential.
    Possible sandstones were also prognosed at three different levels within the Cromer Knoll Group (in the Lysing and Lange Formations, of Turonian and Cenomanian age), and the well 6406/2-1 was aimed to test these levels within structural closure.
    Operations and results
    Well 6406/2-1 was spudded on 31 October 1994 with the semi-submersible "Ross Rig" . Due to environmental restrictions in the area, the drilling operations was stopped on 1 April 1995, and the well was temporarily plugged and abandoned on 9 April 1995 at a preliminary TD of 5295 m. Total non-productive time (NPT) for the well was 49,3 days. The reasons for lost time were mainly:
    - Core barrel stuck when attempting to pull out of hole with core no. 7
    - Leakages on hose between yellow pod and shuttle valve for MPR
    - Stuck with 2 radioactive logging tools
    - Unsuccessful attempts to log with RCI / FMT tools

    The well 6406/2-1 R was reentered 21 August 1995 and reached TD 20 September at 5892 m (5790 mTVD). The production testing of seven Jurassic reservoir levels was started 28 September 1995, and was completed 1 January 1996. The planned TD for the reentry was changed during drilling to 5800 m or 100 m below the Intra Åre Coal Sequence, in order to investigate the reservoir potential of the underlying sandstones.

    Well 6406/2-1 was drilled with a spud mud down to 1236 m and KCl mud with ANCO 208 glycols to 5295 m. The 6406/2-1 Re-entry (5295 m - 5892 m) was drilled water based without ANCO 208.

    The combined well bore 6406/2-1 + 6406/2-1 R was a record well on the Norwegian sector both as the deepest TD to date and with the longest cored section to date (692.5 m gross, 625 m recovered).

    In the Nordland and Hordaland Groups, the well penetrated mainly clay/claystones with some thin sand beds, predominantly non-calcareous. The Rogaland Group comprised tuffaceous claystones with local carbonate cement in the upper part (Tare Formation), and claystones with thin limestone beds in the lower part (Tang Formation). In the Shetland Group, silty claystones with occasional thin beds of sandstone and limestone were drilled in the Springar Formation, whereas the Nise and Kvitnos Formations consisted of silty and sandy claystones with thin beds of sandstone and limestone.
    In the Cromer Knoll Group, two of the prognosed sandy intervals were identified; the Lysing Formation of Late Turonian age and an Intra Lange Sandstone close to the Cenomanian - Albian boundary. Weak oil stain as well as hydrocarbon fluorescence and cut reactions could be traced in cuttings and sidewall cores within these two sandstone intervals. However, the individual sand beds are too thin to constitute any significant reservoir. In addition a sandy interval (Intra Lange Sandstone) was identified in Upper Cenomanian - Lower Turonian sediments. No shows were observed in this interval.
    The Upper Jurassic Viking Group was penetrated at 4371 m. It consisted of dark shales, rich in organic content typical for the Spekk Formation, and paler gray mudstones of the Melke Formation
    The well proved good reservoir quality in mica-bearing sandstones of the Ile, Tofte, Tilje and the upper part of the Åre Formations, and marginal porosities in the Garn Formation which contained more quartz rich, mature sand. Hydrocarbons were discovered in all reservoir units, and no hydrocarbon contacts were encountered.
    Pressure points were measured in the Garn, Ile and Tofte Formations. The formation pressures were slightly higher than hydrostatic. An FMT fluid sample was collected from 4435 m in the Garn Formation. It contained only filtrate and some gas. Two FMT- fluid samples were collected at 4687 m and 4700 m in the Ile Formation. Both contained gas and oil in addition to filtrate. No FMT results were obtained from the Tilje and Åre Formations.

    In well 6406/2-1 684.5 m was cored (616.6 m recovered) in the Middle and Lower Jurassic. One core was sampled in well 6406/2-1 R in the lower part of the Åre Formation at 5643-5651,65 m (later log-shifted 11 m downwards). The well was suspended at TD as a gas/condensate discovery.
    Testing
    Seven drill stem tests were performed.
    The test intervals 4,5 and 6 in the Tilje, Tofte and Ile Formations produced gas and condensate. The test intervals 3 and 7 in the middle of the Tilje Formation and the Garn Formation, respectively, produced both gas/condensate and formation water, indicating hydrocarbon contacts within interval 3 (5024-5041 m) and interval 7 (4427-4495 m). The test interval 1 in the upper Åre Formation and test interval 2 in the lower Tilje Formation produced water.

  • 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
    5643.0
    5651.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    8.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 5643-5648m
    Core photo at depth: 5648-5652m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    5643-5648m
    5648-5652m

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.77

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.70
    pdf
    1.96
    pdf
    0.50

  • 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
    40.87

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    5227
    5201
    6.4
    2.0
    5170
    5099
    20.6
    3.0
    5041
    5021
    12.7
    4.0
    4924
    4910
    12.7
    5.0
    4858
    4816
    28.6
    6.0
    4704
    4645
    28.6
    7.0
    4495
    4427
    25.4
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    51.000
    45.000
    51.000
    175
    2.0
    51.000
    49.000
    51.000
    173
    3.0
    48.000
    13.000
    53.000
    157
    4.0
    48.000
    28.000
    52.000
    169
    5.0
    50.000
    26.000
    52.000
    167
    6.0
    38.000
    22.000
    51.000
    158
    7.0
    38.000
    19.000
    157
    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
    2.0
    3.0
    22
    88000
    0.796
    0.770
    4000
    4.0
    69
    289000
    0.783
    0.770
    4200
    5.0
    273
    788000
    0.803
    0.770
    2700
    6.0
    247
    716300
    0.798
    0.730
    2900
    7.0
    4
    0.800
    0.730

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DLL ZDL CN DGR
    5248
    5820
    DPIL MAC DSL
    5250
    5880
    FMT
    5300
    5641
    VSP
    3060
    3400
    VSP
    5170
    5755

  • 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
    INTERM.
    7
    5892.0
    5 7/8
    5892.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    5295
    1.25
    13.0
    10.0
    WATER BASED
    28.08.1995
    5295
    1.25
    13.0
    11.0
    WATER BASED
    29.08.1995
    5298
    1.25
    12.0
    10.0
    WATER BASED
    30.08.1995
    5324
    1.25
    26.0
    12.0
    WATER BASED
    01.09.1995
    5374
    1.25
    15.0
    9.0
    WATER BASED
    04.09.1995
    5393
    1.25
    16.0
    7.0
    WATER BASED
    06.09.1995
    5431
    1.25
    18.0
    10.0
    WATER BASED
    06.09.1995
    5440
    1.25
    17.0
    10.0
    WATER BASED
    06.09.1995
    5461
    1.25
    19.0
    13.0
    WATER BASED
    06.09.1995
    5461
    1.25
    18.0
    13.0
    WATER BASED
    06.09.1995
    5521
    1.25
    22.0
    20.0
    WATER BASED
    07.09.1995
    5580
    1.25
    23.0
    13.0
    WATER BASED
    08.09.1995
    5637
    1.25
    23.0
    13.0
    WATER BASED
    11.09.1995
    5637
    1.25
    23.0
    13.0
    WATER BASED
    11.09.1995
    5653
    1.25
    21.0
    10.0
    WATER BASED
    11.09.1995
    5654
    1.25
    19.0
    7.0
    WATER BASED
    12.09.1995
    5682
    1.30
    19.0
    7.0
    WATER BASED
    13.09.1995
    5684
    1.30
    24.0
    10.0
    WATER BASED
    14.09.1995

  • 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
    0.28