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

6406/2-6

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.
    6406/2-6
    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.
    SUSPENDED
    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.
    6406/2-6
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    HWM94- INLINE 940 & CROSSLINE 1630
    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.
    934-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.
    75
    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,
    25.08.1998
    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.
    07.11.1998
    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.
    07.11.2000
    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.
    18.12.2002
    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.
    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.
    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.
    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.
    ILE 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.
    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.
    TOFTE FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    302.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    5263.0
    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).
    5256.8
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    11.2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    177
    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° 45' 31.34'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    6° 22' 54.69'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7184316.92
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    375445.84
    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.
    3407

  • Wellbore history
    General
    Well 6406/2-6 was the third wildcat drilled in the PL 199 licence. The well was drilled on the southern part of the "C structure" in the southwestern part of block 6406/2, south of the Kristin Field and southwest of the 6406/2-1 Lavrans discovery on Haltenbanken. The C structure is an easterly dipping, rotated fault block, down faulted relative to the Lavrans structure and with structural similarities. The main objective of well 6406/2-6 was to test the hydrocarbon potential of the C structure within the Early and Middle Jurassic Fangst and Båt Group sandstones. Late Cretaceous Lysing and Lange sandstones were secondary targets for the well.
    Operations and results
    Wildcat well 6406/2-6 was spudded by the semi-submersible installation "Deepsea Bergen" on 25 August 1998 and drilled to 5263 m, 58 m into the Early Jurassic Åre Formation. The well was a "High Pressure High Temperature" well with max down hole temperature of 177 deg C and max pressure gradient of 1.95 g/cc in top Garn Formation (4479 m TVD RKB). Shallow gas was not encountered and operations went without major problems. The well was drilled with seawater and hi-vis pills down to 1413 m, KCl mud with glycol additive (3 - 5 % Glydril MC) from 1413 m to 2760 m, and oil based mud from 2760 m to TD. Hydrocarbons were proven in Ile and Tofte Formations, and there where good hydrocarbon indications in the Garn and Lange Formations. The main result of well 6406/2-6 was the Ragnfrid discovery with gas/condensate in Ile and Tofte Formations as proven by fluid samples and good indications of hydrocarbons in upper part of Garn Formation and in Lower Lange sandstones. No hydrocarbon fluid samples were obtained from the latter units due to poor reservoir quality. The Tilje and Åre Formations appeared to be water bearing in the well position. The Tofte Formation has good to excellent reservoir properties, Ile properties are fair to good, Garn has poor to moderate reservoir properties except for a good zone in the middle part, and the Lange sandy intervals seem to have low permeabilities. One core (27m) was cut in the Garn Formation. Four MDT samples were taken in the hydrocarbon bearing Ile and Tofte Formations. One of these was recovered from 4737.4 m in the Tofte Formation; the other three were recovered from 4622.2 m in the Ile Formation. All four samples were heavily contaminated with oil-based mud. In addition to these, MDT water samples were collected from the Garn, Ile, and Tofte Formations. The well was suspended as a gas and condensate discovery on 7 November 1998.
    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]
    1420.00
    5263.00

  • 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
    4504.0
    4530.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    26.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 4504-4509m
    Core photo at depth: 4509-4514m
    Core photo at depth: 4514-4519m
    Core photo at depth: 4519-4524m
    Core photo at depth: 4524-4529m
    4504-4509m
    4509-4514m
    4514-4519m
    4519-4524m
    4524-4529m
    Core photo at depth: 4529-4531m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    4529-4531m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1470.0
    [m]
    DC
    STRAT
    1490.0
    [m]
    DC
    STRAT
    1510.0
    [m]
    DC
    STRAT
    1530.0
    [m]
    DC
    STRAT
    1550.0
    [m]
    DC
    STRAT
    1570.0
    [m]
    DC
    STRAT
    1590.0
    [m]
    DC
    STRAT
    1630.0
    [m]
    DC
    STRAT
    1650.0
    [m]
    DC
    STRAT
    1670.0
    [m]
    DC
    STRAT
    1700.0
    [m]
    DC
    STRAT
    1710.0
    [m]
    DC
    STRAT
    1730.0
    [m]
    DC
    STRAT
    1740.0
    [m]
    DC
    STRAT
    1780.0
    [m]
    DC
    STRAT
    1800.0
    [m]
    DC
    STRAT
    1820.0
    [m]
    DC
    STRAT
    1840.0
    [m]
    DC
    STRAT
    1860.0
    [m]
    DC
    STRAT
    1870.0
    [m]
    DC
    STRAT
    1890.0
    [m]
    DC
    STRAT
    1900.0
    [m]
    DC
    STRAT
    1920.0
    [m]
    DC
    STRAT
    1940.0
    [m]
    DC
    STRAT
    1950.0
    [m]
    DC
    STRAT
    1970.0
    [m]
    DC
    STRAT
    1990.0
    [m]
    DC
    STRAT
    2010.0
    [m]
    DC
    STRAT
    2030.0
    [m]
    DC
    STRAT
    2050.0
    [m]
    DC
    STRAT
    2070.0
    [m]
    DC
    STRAT
    2080.0
    [m]
    DC
    STRAT
    2110.0
    [m]
    DC
    STRAT
    2130.0
    [m]
    DC
    STRAT
    2150.0
    [m]
    DC
    STRAT
    2170.0
    [m]
    DC
    STRAT
    2190.0
    [m]
    DC
    STRAT
    2210.0
    [m]
    DC
    STRAT
    2230.0
    [m]
    DC
    STRAT
    2250.0
    [m]
    DC
    STRAT
    2270.0
    [m]
    DC
    STRAT
    2290.0
    [m]
    DC
    STRAT
    2310.0
    [m]
    DC
    STRAT
    2330.0
    [m]
    DC
    STRAT
    2350.0
    [m]
    DC
    STRAT
    2370.0
    [m]
    DC
    STRAT
    2390.0
    [m]
    DC
    STRAT
    2410.0
    [m]
    DC
    STRAT
    2430.0
    [m]
    DC
    STRAT
    2450.0
    [m]
    DC
    STRAT
    2470.0
    [m]
    DC
    STRAT
    2490.0
    [m]
    DC
    STRAT
    2510.0
    [m]
    DC
    STRAT
    2530.0
    [m]
    DC
    STRAT
    2550.0
    [m]
    DC
    STRAT
    2570.0
    [m]
    DC
    STRAT
    2590.0
    [m]
    DC
    STRAT
    2620.0
    [m]
    DC
    STRAT
    2630.0
    [m]
    DC
    STRAT
    2650.0
    [m]
    DC
    STRAT
    2675.0
    [m]
    DC
    STRAT
    2690.0
    [m]
    DC
    STRAT
    2710.0
    [m]
    DC
    STRAT
    2730.0
    [m]
    DC
    STRAT
    2750.0
    [m]
    DC
    STRAT
    2770.0
    [m]
    DC
    STRAT
    2785.0
    [m]
    DC
    STRAT
    2810.0
    [m]
    DC
    STRAT
    2830.0
    [m]
    DC
    STRAT
    2850.0
    [m]
    DC
    STRAT
    2865.0
    [m]
    DC
    STRAT
    2880.0
    [m]
    DC
    STRAT
    2900.0
    [m]
    DC
    STRAT
    2920.0
    [m]
    DC
    STRAT
    2940.0
    [m]
    DC
    STRAT
    2960.0
    [m]
    DC
    STRAT
    2980.0
    [m]
    DC
    STRAT
    3000.0
    [m]
    DC
    STRAT
    3060.0
    [m]
    DC
    STRAT
    3080.0
    [m]
    DC
    STRAT
    3100.0
    [m]
    DC
    STRAT
    3160.0
    [m]
    DC
    STRAT
    3180.0
    [m]
    DC
    STRAT
    3200.0
    [m]
    DC
    STRAT
    3220.0
    [m]
    DC
    STRAT
    3260.0
    [m]
    DC
    STRAT
    3275.0
    [m]
    DC
    STRAT
    3300.0
    [m]
    DC
    STRAT
    3320.0
    [m]
    DC
    STRAT
    3345.0
    [m]
    DC
    STRAT
    3365.0
    [m]
    DC
    STRAT
    3375.0
    [m]
    DC
    STRAT
    3395.0
    [m]
    DC
    STRAT
    3415.0
    [m]
    DC
    STRAT
    3435.0
    [m]
    DC
    STRAT
    3455.0
    [m]
    DC
    STRAT
    3475.0
    [m]
    DC
    STRAT
    3495.0
    [m]
    DC
    STRAT
    3515.0
    [m]
    DC
    STRAT
    3535.0
    [m]
    DC
    STRAT
    3555.0
    [m]
    DC
    STRAT
    3575.0
    [m]
    DC
    STRAT
    3595.0
    [m]
    DC
    STRAT
    3615.0
    [m]
    DC
    STRAT
    3635.0
    [m]
    DC
    STRAT
    3655.0
    [m]
    DC
    STRAT
    3675.0
    [m]
    DC
    STRAT
    3695.0
    [m]
    DC
    STRAT
    3715.0
    [m]
    DC
    STRAT
    3735.0
    [m]
    DC
    STRAT
    3755.0
    [m]
    DC
    STRAT
    3775.0
    [m]
    DC
    STRAT
    3795.0
    [m]
    DC
    STRAT
    3815.0
    [m]
    DC
    STRAT
    3835.0
    [m]
    DC
    STRAT
    3855.0
    [m]
    DC
    STRAT
    3875.0
    [m]
    DC
    STRAT
    3895.0
    [m]
    DC
    STRAT
    3915.0
    [m]
    DC
    STRAT
    3935.0
    [m]
    DC
    STRAT
    3955.0
    [m]
    DC
    STRAT
    3975.0
    [m]
    DC
    STRAT
    3995.0
    [m]
    DC
    STRAT
    4015.0
    [m]
    DC
    STRAT
    4035.0
    [m]
    DC
    STRAT
    4055.0
    [m]
    DC
    STRAT
    4075.0
    [m]
    DC
    STRAT
    4095.0
    [m]
    DC
    STRAT
    4115.0
    [m]
    DC
    STRAT
    4135.0
    [m]
    DC
    STRAT
    4155.0
    [m]
    DC
    STRAT
    4175.0
    [m]
    DC
    STRAT
    4195.0
    [m]
    DC
    STRAT
    4215.0
    [m]
    DC
    STRAT
    4235.0
    [m]
    DC
    STRAT
    4255.0
    [m]
    DC
    STRAT
    4275.0
    [m]
    DC
    STRAT
    4295.0
    [m]
    DC
    STRAT
    4315.0
    [m]
    DC
    STRAT
    4335.0
    [m]
    DC
    STRAT
    4355.0
    [m]
    DC
    STRAT
    4375.0
    [m]
    DC
    STRAT
    4395.0
    [m]
    DC
    STRAT
    4415.0
    [m]
    DC
    STRAT
    4424.0
    [m]
    DC
    STRAT
    4433.0
    [m]
    DC
    STRAT
    4436.0
    [m]
    DC
    STRAT
    4442.0
    [m]
    DC
    STRAT
    4451.0
    [m]
    DC
    STRAT
    4460.0
    [m]
    DC
    STRAT
    4469.0
    [m]
    DC
    STRAT
    4478.0
    [m]
    DC
    STRAT
    4487.0
    [m]
    DC
    STRAT
    4496.0
    [m]
    DC
    STRAT
    4504.0
    [m]
    DC
    STRAT
    4512.0
    [m]
    DC
    STRAT
    4524.0
    [m]
    DC
    STRAT
    4530.0
    [m]
    DC
    STRAT
    4538.0
    [m]
    DC
    STRAT
    4547.0
    [m]
    DC
    STRAT
    4553.0
    [m]
    DC
    STRAT
    4562.0
    [m]
    DC
    STRAT
    4571.0
    [m]
    DC
    STRAT
    4580.0
    [m]
    DC
    STRAT
    4589.0
    [m]
    DC
    STRAT
    4598.0
    [m]
    DC
    STRAT
    4606.0
    [m]
    DC
    STRAT
    4616.0
    [m]
    DC
    STRAT
    4625.0
    [m]
    DC
    STRAT
    4634.0
    [m]
    DC
    STRAT
    4643.0
    [m]
    DC
    STRAT
    4652.0
    [m]
    DC
    STRAT
    4661.0
    [m]
    DC
    STRAT
    4670.0
    [m]
    DC
    STRAT
    4697.0
    [m]
    DC
    STRAT
    4706.0
    [m]
    DC
    STRAT
    4733.0
    [m]
    DC
    STRAT
    4787.0
    [m]
    DC
    STRAT
    4796.0
    [m]
    DC
    STRAT
    4805.0
    [m]
    DC
    STRAT
    4814.0
    [m]
    DC
    STRAT
    4877.0
    [m]
    DC
    STRAT
    4886.0
    [m]
    DC
    STRAT
    4895.0
    [m]
    DC
    STRAT
    4904.0
    [m]
    DC
    STRAT
    4913.0
    [m]
    DC
    STRAT
    4922.0
    [m]
    DC
    STRAT
    4931.0
    [m]
    DC
    STRAT
    4952.0
    [m]
    DC
    STRAT
    4961.0
    [m]
    DC
    STRAT
    4970.0
    [m]
    DC
    STRAT
    4973.0
    [m]
    DC
    STRAT
    4979.0
    [m]
    DC
    STRAT
    4982.0
    [m]
    DC
    STRAT
    4988.0
    [m]
    DC
    STRAT
    4991.0
    [m]
    DC
    STRAT
    4997.0
    [m]
    DC
    STRAT
    5000.0
    [m]
    DC
    STRAT
    5009.0
    [m]
    DC
    STRAT
    5018.0
    [m]
    DC
    STRAT
    5036.0
    [m]
    DC
    STRAT
    5045.0
    [m]
    DC
    STRAT
    5054.0
    [m]
    DC
    STRAT
    5072.0
    [m]
    DC
    STRAT
    5081.0
    [m]
    DC
    STRAT
    5090.0
    [m]
    DC
    STRAT
    5099.0
    [m]
    DC
    STRAT
    5108.0
    [m]
    DC
    STRAT
    5117.0
    [m]
    DC
    STRAT
    5126.0
    [m]
    DC
    STRAT
    5135.0
    [m]
    DC
    STRAT
    5144.0
    [m]
    DC
    STRAT
    5153.0
    [m]
    DC
    STRAT
    5162.0
    [m]
    DC
    STRAT
    5171.0
    [m]
    DC
    STRAT
    5180.0
    [m]
    DC
    STRAT
    5189.0
    [m]
    DC
    STRAT
    5198.0
    [m]
    DC
    STRAT
    5207.0
    [m]
    DC
    STRAT
    5216.0
    [m]
    DC
    STRAT
    5225.0
    [m]
    DC
    STRAT
    5234.0
    [m]
    DC
    STRAT
    5243.0
    [m]
    DC
    STRAT
    5252.0
    [m]
    DC
    STRAT
    5263.0
    [m]
    DC
    STRAT

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.54

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.84
    pdf
    1.85
    pdf
    1.81
    pdf
    0.31

  • 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
    36.16

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT DSI GR
    4408
    5261
    AIT GR
    4406
    4877
    CMR IPLT
    4408
    5244
    LDT CNT AMS GR
    2748
    4577
    LDT CNT GR
    4408
    4577
    MDT AMS GR
    2745
    4307
    MDT GR
    2745
    5261
    MSCT GR
    2748
    5251
    MWD - RWD GR RES DIR
    302
    5263
    PI DSI LDT AMS GR
    1405
    2750
    PI DSI LDT CNT GR
    2745
    4416
    VSP
    4406
    5261

  • 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
    412.0
    36
    412.0
    0.00
    LOT
    INTERM.
    18 5/8
    1408.0
    24
    1408.0
    1.66
    LOT
    INTERM.
    13 3/8
    2748.0
    17 1/2
    2748.0
    2.07
    LOT
    INTERM.
    9 5/8
    4406.0
    12 1/4
    4406.0
    2.18
    LOT
    OPEN HOLE
    5263.0
    8 1/2
    5263.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    585
    1.20
    7.0
    WATER BASED
    660
    1.20
    21.0
    WATER BASED
    685
    1.03
    SPUD MUD
    1413
    1.30
    WATER BASED
    1418
    1.30
    28.0
    WATER BASED
    2549
    1.68
    45.0
    WATER BASED
    2760
    1.68
    51.0
    WATER BASED
    3236
    1.64
    43.0
    OIL BASED
    3661
    1.70
    48.0
    OIL BASED
    3825
    1.74
    47.0
    OIL BASED
    4053
    1.74
    49.0
    OIL BASED
    4415
    1.85
    52.0
    OIL BASED
    4430
    2.04
    62.0
    OIL BASED
    4504
    2.04
    58.0
    OIL BASED
    4525
    2.04
    59.0
    OIL BASED
    4531
    2.04
    59.0
    OIL BASED
    4575
    2.02
    58.0
    OIL BASED
    4665
    2.04
    63.0
    OIL BASED
    4700
    2.04
    63.0
    OIL BASED
    4872
    2.04
    62.0
    OIL BASED
    4913
    2.04
    61.0
    OIL BASED
    5030
    2.04
    68.0
    OIL BASED
    5086
    2.04
    72.0
    OIL BASED
    5263
    2.04
    73.0
    OIL BASED

  • 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