Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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14.07.2024 - 01:28
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6506/11-6

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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.
    6506/11-6
    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).
    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
    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.
    6506/11-6
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    HWM 94- INLINE 3194 & X-LINE 906
    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.
    Den norske stats oljeselskap 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.
    922-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.
    180
    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,
    24.02.1998
    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.
    22.08.1998
    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.
    22.08.2000
    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.
    13.12.2005
    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.
    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.
    GARN 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.
    ILE 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.
    380.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    5275.0
    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).
    5273.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    173
    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.
    65° 1' 26.24'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    6° 25' 10.71'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7213786.47
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    378448.14
    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.
    3306
  • Wellbore history

    General
    Well 6506/11-6 was drilled on a structure on the northern segment of the Kristin Discovery, ca 5 km west of the southern part of the Smørbukk Discovery offshore Mid Norway. The main objective was to evaluate and appraise the hydrocarbon potential of the Middle Jurassic Garn and Ile Formations.
    Operations and results
    Appraisal well 6506/11-6 was spudded with the semi-submersible installation Deepsea Bergen on 24 February 1998 and drilled to TD at 5275 m in Early Jurassic sediments of the Åre Formation. The well was drilled with bentonite spud mud down to 1412 m, with Glydril mud from 1412 m to 2739 m, and with Versapro oil based mud from 2739 m to TD.
    The well proved gas/condensate in the Garn and Ile Formations. Isolated shows were recorded on sidewall cores at 3563 m (Lysing Formation) and at 4517 m (Lange Formation), both in thin sandstone stringers. Shows were recorded from top of the Garn Formation sand reservoir at 4645 m to the top of the Upper Ror Formation at 4891 m (MWD depth, correspond to 4896 m loggers depth). Shows were also observed from 4952 to 4980 m (MWD depth) in the Tofte Formation, but these are probably a result of mud invasion. Ten conventional cores were cut in the interval 4652 m to 5125 m in the Middle to Early Jurassic, recovering a total of 297 m of core from the Garn, Not, Ile, Upper Ror, Tofte and Tilje Formations. Several runs with the Schlumberger MDT tool were performed. Pressure points and sampling were attempted in the Lysing and Lange sands, but with no success due to poor reservoir quality. Formation pressure measurements and fluid samples (gas and water) were collected in the Garn, Ile, Tofte and Tilje Formations. For the Åre Formation pressure measurements were achieved but no cores or fluid samples were taken.
    The well was permanently abandoned on 22 August 1998 as a gas and condensate appraisal well on the Kristin Discovery.
    Testing
    Three tests were performed, one in the Ile Formation and two in the Garn Formation.
    DST 1 in the Ile Formation tested the interval 4839.2 m - 4849.2 m and produced 568000 Sm3 gas and 557 Sm3 condensate pr day on a 36/64" choke. The measured down hole DST temperature was 172.6 deg C.
    DST2 in the Garn Formation tested the interval 4695 m to 4736.7 m and produced 78000 Sm3 gas and 105 Sm3 condensate pr day on a 12/64" choke. The measured down hole DST temperature was 162.8 deg C.
    DST3 in the Garn Formation tested the interval 4649.4 m to 4668.3 m and produced 533000 Sm3 gas and 770 Sm3 condensate pr day on a 36/64" choke. The measured down hole DST temperature was 167.7 deg C.
    Both wire line bottom hole temperatures and DST temperatures were recorded in this well. The wire line data from the final logging gave a Horner corrected temperature at final well TD of 173 deg C. The temperature data from well testing is believed to be the most reliable, but for all of the tests there were quite large pressure draw down and this reduces the quality of the evaluated temperature. DST 2 measurement had the largest pressure drop and lowest flow rate, and data from this test is considered the least reliable. At these high temperature and pressures Joule Thompson effects are assumed to give ca 7 deg C temperature increase in the flowing DST 1 and 3 well bore fluids compared to the true formation temperature.
  • 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
    5275.00
  • 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
    4652.0
    4661.3
    [m ]
    2
    4661.3
    4688.5
    [m ]
    3
    4688.5
    4710.9
    [m ]
    4
    4711.0
    4738.0
    [m ]
    5
    4738.0
    4792.8
    [m ]
    6
    4813.0
    4836.8
    [m ]
    7
    4837.0
    4858.0
    [m ]
    8
    4858.0
    4913.6
    [m ]
    9
    4952.0
    4980.8
    [m ]
    10
    5098.0
    5125.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    297.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 4652-4657m
    Core photo at depth: 4657-4661m
    Core photo at depth: 4661-4666m
    Core photo at depth: 4666-4671m
    Core photo at depth: 4671-4676m
    4652-4657m
    4657-4661m
    4661-4666m
    4666-4671m
    4671-4676m
    Core photo at depth: 4676-4681m
    Core photo at depth: 4681-4686m
    Core photo at depth: 4686-4688m
    Core photo at depth: 4688-4693m
    Core photo at depth: 4693-4698m
    4676-4681m
    4681-4686m
    4686-4688m
    4688-4693m
    4693-4698m
    Core photo at depth: 4698-4703m
    Core photo at depth: 4703-4708m
    Core photo at depth: 4708-4710m
    Core photo at depth: 4711-4716m
    Core photo at depth: 4716-4721m
    4698-4703m
    4703-4708m
    4708-4710m
    4711-4716m
    4716-4721m
    Core photo at depth: 4721-4726m
    Core photo at depth: 4726-4731m
    Core photo at depth: 4731-4736m
    Core photo at depth: 4736-4738m
    Core photo at depth: 4738-4743m
    4721-4726m
    4726-4731m
    4731-4736m
    4736-4738m
    4738-4743m
    Core photo at depth: 4743-4748m
    Core photo at depth: 4748-4753m
    Core photo at depth: 4753-4758m
    Core photo at depth: 4758-4763m
    Core photo at depth: 4763-4768m
    4743-4748m
    4748-4753m
    4753-4758m
    4758-4763m
    4763-4768m
    Core photo at depth: 4768-4773m
    Core photo at depth: 4773-4776m
    Core photo at depth: 4778-4783m
    Core photo at depth: 4783-4788m
    Core photo at depth: 4788-4792m
    4768-4773m
    4773-4776m
    4778-4783m
    4783-4788m
    4788-4792m
    Core photo at depth: 4813-4818m
    Core photo at depth: 4818-4823m
    Core photo at depth: 4823-4828m
    Core photo at depth: 4828-4833m
    Core photo at depth: 4833-4836m
    4813-4818m
    4818-4823m
    4823-4828m
    4828-4833m
    4833-4836m
    Core photo at depth: 4837-4842m
    Core photo at depth: 4842-4847m
    Core photo at depth: 4847-4852m
    Core photo at depth: 4852-4857m
    Core photo at depth: 4857-4858m
    4837-4842m
    4842-4847m
    4847-4852m
    4852-4857m
    4857-4858m
    Core photo at depth: 4858-4863m
    Core photo at depth: 4863-4868m
    Core photo at depth: 4868-4873m
    Core photo at depth: 4873-4878m
    Core photo at depth: 4878-4883m
    4858-4863m
    4863-4868m
    4868-4873m
    4873-4878m
    4878-4883m
    Core photo at depth: 4883-4888m
    Core photo at depth: 48884893m
    Core photo at depth: 4893-4898m
    Core photo at depth: 4898-4903m
    Core photo at depth: 4903-4908m
    4883-4888m
    48884893m
    4893-4898m
    4898-4903m
    4903-4908m
    Core photo at depth: 4908-4913m
    Core photo at depth: 4913-4914m
    Core photo at depth: 4952-4957m
    Core photo at depth: 4957-4962m
    Core photo at depth: 4962-4967m
    4908-4913m
    4913-4914m
    4952-4957m
    4957-4962m
    4962-4967m
    Core photo at depth: 4967-4972m
    Core photo at depth: 4972-4977m
    Core photo at depth: 4977-4980m
    Core photo at depth: 5098-5103m
    Core photo at depth: 5103-5108m
    4967-4972m
    4972-4977m
    4977-4980m
    5098-5103m
    5103-5108m
    Core photo at depth: 5108-5113m
    Core photo at depth: 5113-5118m
    Core photo at depth: 5118-5123m
    Core photo at depth: 5123-5125m
    Core photo at depth:  
    5108-5113m
    5113-5118m
    5118-5123m
    5123-5125m
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1420.0
    [m]
    DC
    RRI
    1440.0
    [m]
    DC
    RRI
    1460.0
    [m]
    DC
    RRI
    1480.0
    [m]
    DC
    RRI
    1500.0
    [m]
    DC
    RRI
    1520.0
    [m]
    DC
    RRI
    1540.0
    [m]
    DC
    RRI
    1560.0
    [m]
    DC
    RRI
    1580.0
    [m]
    DC
    RRI
    1600.0
    [m]
    DC
    RRI
    1620.0
    [m]
    DC
    RRI
    1640.0
    [m]
    DC
    RRI
    1660.0
    [m]
    DC
    RRI
    1680.0
    [m]
    DC
    RRI
    1700.0
    [m]
    DC
    RRI
    1720.0
    [m]
    DC
    RRI
    1740.0
    [m]
    DC
    RRI
    1760.0
    [m]
    DC
    RRI
    1780.0
    [m]
    DC
    RRI
    1800.0
    [m]
    DC
    RRI
    1820.0
    [m]
    DC
    RRI
    1840.0
    [m]
    DC
    RRI
    1860.0
    [m]
    DC
    RRI
    1880.0
    [m]
    DC
    RRI
    1900.0
    [m]
    DC
    RRI
    1920.0
    [m]
    DC
    RRI
    1940.0
    [m]
    DC
    RRI
    1960.0
    [m]
    DC
    RRI
    1980.0
    [m]
    DC
    RRI
    2000.0
    [m]
    DC
    RRI
    2020.0
    [m]
    DC
    RRI
    2040.0
    [m]
    DC
    RRI
    2060.0
    [m]
    DC
    RRI
    2080.0
    [m]
    DC
    RRI
    2100.0
    [m]
    DC
    RRI
    2120.0
    [m]
    DC
    RRI
    2140.0
    [m]
    DC
    RRI
    2160.0
    [m]
    DC
    RRI
    2180.0
    [m]
    DC
    RRI
    2200.0
    [m]
    DC
    RRI
    2220.0
    [m]
    DC
    RRI
    2240.0
    [m]
    DC
    RRI
    2260.0
    [m]
    DC
    RRI
    2280.0
    [m]
    DC
    RRI
    2300.0
    [m]
    DC
    RRI
    2320.0
    [m]
    DC
    RRI
    2340.0
    [m]
    DC
    RRI
    2360.0
    [m]
    DC
    RRI
    2380.0
    [m]
    DC
    RRI
    2400.0
    [m]
    DC
    RRI
    2420.0
    [m]
    DC
    RRI
    2440.0
    [m]
    DC
    RRI
    2480.0
    [m]
    DC
    RRI
    2500.0
    [m]
    DC
    RRI
    2520.0
    [m]
    DC
    RRI
    2540.0
    [m]
    DC
    RRI
    2560.0
    [m]
    DC
    RRI
    2600.0
    [m]
    DC
    RRI
    2620.0
    [m]
    DC
    RRI
    2640.0
    [m]
    DC
    RRI
    2660.0
    [m]
    DC
    RRI
    2680.0
    [m]
    DC
    RRI
    2700.0
    [m]
    DC
    RRI
    2720.0
    [m]
    DC
    RRI
    2740.0
    [m]
    DC
    RRI
    2780.0
    [m]
    DC
    RRI
    2800.0
    [m]
    DC
    RRI
    2840.0
    [m]
    DC
    RRI
    2860.0
    [m]
    DC
    RRI
    2880.0
    [m]
    DC
    RRI
    2900.0
    [m]
    DC
    RRI
    2920.0
    [m]
    DC
    RRI
    2940.0
    [m]
    DC
    RRI
    2960.0
    [m]
    DC
    RRI
    2980.0
    [m]
    DC
    RRI
    3000.0
    [m]
    DC
    RRI
    3020.0
    [m]
    DC
    RRI
    3040.0
    [m]
    DC
    RRI
    3060.0
    [m]
    DC
    RRI
    3080.0
    [m]
    DC
    RRI
    3100.0
    [m]
    DC
    RRI
    3120.0
    [m]
    DC
    RRI
    3140.0
    [m]
    DC
    RRI
    3160.0
    [m]
    DC
    RRI
    3180.0
    [m]
    DC
    RRI
    3210.0
    [m]
    DC
    RRI
    3220.0
    [m]
    DC
    RRI
    3240.0
    [m]
    DC
    RRI
    3260.0
    [m]
    DC
    RRI
    3280.0
    [m]
    DC
    RRI
    3300.0
    [m]
    DC
    RRI
    3320.0
    [m]
    DC
    RRI
    3340.0
    [m]
    DC
    RRI
    3360.0
    [m]
    DC
    RRI
    3380.0
    [m]
    DC
    RRI
    3400.0
    [m]
    DC
    RRI
    3420.0
    [m]
    DC
    RRI
    3440.0
    [m]
    DC
    RRI
    3460.0
    [m]
    DC
    RRI
    3480.0
    [m]
    DC
    RRI
    3500.0
    [m]
    DC
    RRI
    3520.0
    [m]
    DC
    RRI
    3540.0
    [m]
    DC
    RRI
    3580.0
    [m]
    DC
    RRI
    3600.0
    [m]
    DC
    RRI
    3620.0
    [m]
    DC
    RRI
    3640.0
    [m]
    DC
    RRI
    3660.0
    [m]
    DC
    RRI
    3685.0
    [m]
    DC
    RRI
    3700.0
    [m]
    DC
    RRI
    3720.0
    [m]
    DC
    RRI
    3760.0
    [m]
    DC
    RRI
    3780.0
    [m]
    DC
    RRI
    3800.0
    [m]
    DC
    RRI
    3820.0
    [m]
    DC
    RRI
    3840.0
    [m]
    DC
    RRI
    3860.0
    [m]
    DC
    RRI
    3880.0
    [m]
    DC
    RRI
    3900.0
    [m]
    DC
    RRI
    3910.0
    [m]
    DC
    RRI
    3930.0
    [m]
    DC
    RRI
    3945.0
    [m]
    DC
    RRI
    3980.0
    [m]
    DC
    RRI
    4000.0
    [m]
    DC
    RRI
    4020.0
    [m]
    DC
    RRI
    4040.0
    [m]
    DC
    RRI
    4060.0
    [m]
    DC
    RRI
    4080.0
    [m]
    DC
    RRI
    4100.0
    [m]
    DC
    RRI
    4120.0
    [m]
    DC
    RRI
    4140.0
    [m]
    DC
    RRI
    4160.0
    [m]
    DC
    RRI
    4180.0
    [m]
    DC
    RRI
    4220.0
    [m]
    DC
    RRI
    4260.0
    [m]
    DC
    RRI
    4300.0
    [m]
    DC
    RRI
    4320.0
    [m]
    DC
    RRI
    4340.0
    [m]
    DC
    RRI
    4380.0
    [m]
    DC
    RRI
    4400.0
    [m]
    DC
    RRI
    4420.0
    [m]
    DC
    RRI
    4460.0
    [m]
    DC
    RRI
    4470.0
    [m]
    DC
    RRI
    4480.0
    [m]
    DC
    RRI
    4490.0
    [m]
    DC
    RRI
    4500.0
    [m]
    DC
    RRI
    4527.0
    [m]
    DC
    RRI
    4536.0
    [m]
    DC
    RRI
    4545.0
    [m]
    DC
    RRI
    4554.0
    [m]
    DC
    RRI
    4563.0
    [m]
    DC
    RRI
    4572.0
    [m]
    DC
    RRI
    4581.0
    [m]
    DC
    RRI
    4590.0
    [m]
    DC
    RRI
    4599.0
    [m]
    DC
    RRI
    4605.0
    [m]
    DC
    RRI
    4608.0
    [m]
    DC
    RRI
    4626.0
    [m]
    DC
    RRI
    4635.0
    [m]
    DC
    RRI
    4678.0
    [m]
    C
    RRI
    4684.0
    [m]
    C
    RRI
    4694.0
    [m]
    C
    RRI
    4709.0
    [m]
    C
    RRI
    4719.0
    [m]
    C
    RRI
    4739.0
    [m]
    C
    RRI
    4743.0
    [m]
    C
    RRI
    4764.0
    [m]
    C
    RRI
    4767.0
    [m]
    C
    RRI
    4773.0
    [m]
    C
    RRI
    4779.0
    [m]
    C
    RRI
    4788.0
    [m]
    C
    RRI
    4790.0
    [m]
    C
    RRI
    4809.0
    [m]
    DC
    RRI
    4815.0
    [m]
    C
    RRI
    4821.0
    [m]
    C
    RRI
    4827.0
    [m]
    C
    RRI
    4833.0
    [m]
    C
    RRI
    4838.0
    [m]
    C
    RRI
    4844.0
    [m]
    C
    RRI
    4850.0
    [m]
    C
    RRI
    4858.0
    [m]
    C
    RRI
    4864.0
    [m]
    C
    RRI
    4869.0
    [m]
    C
    RRI
    4883.0
    [m]
    C
    RRI
    4890.0
    [m]
    C
    RRI
    4893.0
    [m]
    C
    RRI
    4902.0
    [m]
    C
    RRI
    4905.0
    [m]
    C
    RRI
    4913.0
    [m]
    C
    RRI
    4955.0
    [m]
    C
    RRI
    4958.0
    [m]
    C
    RRI
    4965.0
    [m]
    C
    RRI
    4977.0
    [m]
    C
    RRI
    4980.0
    [m]
    C
    RRI
    5022.0
    [m]
    DC
    RRI
    5034.0
    [m]
    DC
    RRI
    5046.0
    [m]
    DC
    RRI
    5058.0
    [m]
    DC
    RRI
    5064.0
    [m]
    DC
    RRI
    5070.0
    [m]
    DC
    RRI
    5082.0
    [m]
    DC
    RRI
    5094.0
    [m]
    DC
    RRI
    5101.0
    [m]
    C
    RRI
    5106.0
    [m]
    C
    RRI
    5110.0
    [m]
    C
    RRI
    5116.0
    [m]
    C
    RRI
    5121.0
    [m]
    C
    RRI
    5122.0
    [m]
    C
    RRI
    5127.0
    [m]
    DC
    RRI
    5133.0
    [m]
    DC
    RRI
    5151.0
    [m]
    DC
    RRI
    5157.0
    [m]
    DC
    RRI
    5163.0
    [m]
    DC
    RRI
    5169.0
    [m]
    DC
    RRI
    5175.0
    [m]
    DC
    RRI
    5181.0
    [m]
    DC
    RRI
    5187.0
    [m]
    DC
    RRI
    5199.0
    [m]
    DC
    RRI
    5205.0
    [m]
    DC
    RRI
    5211.0
    [m]
    DC
    RRI
    5217.0
    [m]
    DC
    RRI
    5223.0
    [m]
    DC
    RRI
    5229.0
    [m]
    DC
    RRI
    5235.0
    [m]
    DC
    RRI
    5241.0
    [m]
    DC
    RRI
    5247.0
    [m]
    DC
    RRI
    5253.0
    [m]
    DC
    RRI
    5259.0
    [m]
    DC
    RRI
    5265.0
    [m]
    DC
    RRI
    5268.0
    [m]
    DC
    RRI
  • 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
    DST1
    4849.00
    4839.00
    06.07.1998 - 08:15
    YES
    DST
    TEST2
    4737.00
    4695.00
    CONDENSATE
    21.07.1998 - 01:12
    YES
    DST
    TEST3
    4669.00
    4651.00
    CONDENSATE
    YES
  • Lithostratigraphy

  • Composite logs

    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.69
  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    3.65
  • 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
    4.71
    .pdf
    37.84
  • Drill stem tests (DST)

    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    4839
    4849
    14.3
    2.0
    4695
    4736
    4.7
    3.0
    4649
    4668
    14.3
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    172
    2.0
    163
    3.0
    168
    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
    557
    568000
    0.789
    0.715
    1019
    2.0
    105
    78000
    0.795
    0.715
    743
    3.0
    770
    533000
    0.795
    0.715
    692
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT DSI GR
    1019
    2917
    CMR IPLT
    4611
    5000
    DITE DSI GR
    4500
    5275
    IPL GR LEH-Q
    2730
    4400
    LDT CNT GR
    4500
    5275
    LDT CNT GR AMS
    4495
    4666
    MDT
    4519
    4666
    MDT
    4652
    4960
    MDT
    4652
    4885
    MDT GR
    3432
    4421
    MDT GR
    4666
    4888
    MDT GR
    4749
    4958
    MDT GR
    4959
    5251
    MWD - DPR RAW
    403
    2739
    MWD - MPR MDP
    2742
    5275
    OBDT GR
    2850
    5275
    PEX HALS DSI
    1400
    2730
    SWC
    2766
    4497
    SWC
    2898
    4497
    SWC
    4517
    5274
    VSP
    1750
    5235
  • 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
    463.0
    36
    464.0
    0.00
    LOT
    SURF.COND.
    20
    1402.0
    26
    1403.0
    1.69
    LOT
    INTERM.
    13 3/8
    2730.0
    17 1/2
    2730.0
    2.00
    LOT
    INTERM.
    9 7/8
    4493.0
    12 1/4
    4494.0
    2.18
    LOT
    LINER
    7
    5275.0
    8 1/2
    5275.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1300
    1.20
    BENTONITE/FW
    1412
    1.20
    34.0
    BENTONITE/FW
    2185
    1.64
    38.0
    GLYDRILL
    2739
    1.66
    42.0
    GLYDRILL
    2839
    1.64
    31.0
    VERSAPRO
    3685
    1.75
    48.0
    VERSAPRO
    4290
    1.80
    54.0
    VERSAPRO
    4643
    2.06
    57.0
    VERSAPRO
    4648
    2.02
    63.0
    VERSAPRO
    4695
    2.06
    71.0
    VERSAPRO
    4837
    2.02
    60.0
    VERSAPRO
    4980
    2.02
    64.0
    VERSAPRO
    5275
    2.02
    55.0
    VERSAPRO
  • 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