Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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sodir.no          Norsk
24.11.2024 - 01:27
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15/3-9

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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.
    15/3-9
    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.
    NORTH 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.
    15/3-9
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    inline 2725 & xline 2721.seismic cube ST 208707
    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.
    Statoil Petroleum AS
    Drill permit
    The drilling permit number together with the version of the drilling permit as stated in the drilling permit granted by the Norwegian Offshore Directorate.
    1306-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.
    87
    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,
    19.05.2010
    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.
    13.08.2010
    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.
    13.08.2012
    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.
    16.10.2012
    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.
    OIL/GAS
    Discovery wellbore
    Indicator which tells if the wellbore made a new discovery. Legal values: YES, NO. Prior to press-release or other information regarding drilling results, the indicator will be “NO” as a default.
    YES
    1st level with HC, age
    Age of lithostratigraphic unit, 1st level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE. See also Norwegian Offshore Directorate bulletins.
    LATE JURASSIC
    1st level with HC, formation
    Name of lithostartigraphic unit, 1st level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP. See also Norwegian Offshore Directorate bulletins.
    INTRA DRAUPNE FM SS
    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.
    HUGIN FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.5
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    108.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4654.0
    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).
    4650.5
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    6.9
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    154
    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.
    MIDDLE 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.
    SLEIPNER FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 49' 14.04'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 46' 20.71'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6520872.03
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    429105.07
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    31
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    6354

  • Wellbore history
    General
    Well 15/3-9 was drilled on the Brynhild prospect situated on the east flank of the south Viking Graben, west of the Utsira High. The Brynhild Prospect was interpreted as the eastwards continuation of the Gudrun Field. The main objective of the 15/3-9 well was to prove economical hydrocarbon columns in the Late Jurassic SST1 and the Late Jurassic SST2 of the Draupne Formation. The Hugin Formation was a secondary objective.
    Operations and results
    Wildcat well 15/3-9 (Brynhild) was drilled with the semi-submersible installation Transocean Leader. A pilot hole 15/3-U6 was drilled to 918 m. No shallow gas was observed by the ROV at the wellhead or by the MWD while drilling the pilot hole. The main well was spudded 15 m off the pilot-hole location on 19 May 2010 and drilled to the Ty Formation where the pipe got stuc stuck. It was not possible to get it loose. A technical sidetrack, 15/3-9 S T2 was decided. The sidetrack was kicked off from 2350 m and the well was drilled to TD at 4654 m in the Middle Jurassic Sleipner Formation without further significant problems. The well was drilled with Seawater and SW/PAC sweeps down to 1001 m, with Performadril WBM from 1001 m to 2724 m (primary well and sidetrack), and with XP-07 OBM from 2724 m to TD.
    The Late Jurassic Draupne Formation was encountered at 3975 m with top Intra Draupne Formation SST1 sandstone at 4112 m. The SST1 was oil bearing down to an oil water contact was at 4132 m TVD. The prognosed SST2 sandstone was encountered at 4226 m and was entirely water filled. The Hugin Formation was encountered at 4475 m and contained both gas and oil, each fluid type with its own down-to contact. The Draupne SST1 had a net to gross ratio of 0.75, while the net to gross ratio in the Hugin Formation was 0.16. Except for the petroleum bearing SST1 and Hugin reservoirs no oil shows were reported from the well.
    Two cores were cut in sidetrack 15/3-9 T2, Core 1 in the Draupne SST1 (23 m), and Core 2 in the upper part of the Hugin Formation (32.15 m). The cored section in the Draupne SST1 extends from 4124 to 4147 m MD, while the cored section in the Hugin Formation extends from 4482 to 4514.17 m MD. Core 1 and Core 2 are shifted against the log curves with +2.13 m and +2.89 m, respectively. MDT fluid sampling was performed. Oil samples were taken at 4115 m and 4128 m in the Intra Draupne Formation SST1 sandstone. In the Hugin Formation a gas/condensate sample was taken at 4580.7 and an oil samples was taken at 4510 m. MDT water samples were taken at 4182.5 m and at 4528.7 m in the Hugin Formation.
    The well was permanently abandoned on 13 August 2010 as an oil and 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]
    1010.00
    2690.00

  • 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
    4124.0
    4147.0
    [m ]
    2
    4482.0
    4514.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    55.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2550.0
    [m]
    DC
    PETROSTR
    2570.0
    [m]
    DC
    PETROS
    2590.0
    [m]
    DC
    PETROS
    2610.0
    [m]
    DC
    PETROS
    2630.0
    [m]
    DC
    PETROS
    2650.0
    [m]
    DC
    PETROS
    2670.0
    [m]
    DC
    PETROS
    2690.0
    [m]
    DC
    PETROS
    2710.0
    [m]
    DC
    PETROS
    2721.0
    [m]
    DC
    PETROS
    2730.0
    [m]
    DC
    PETROS
    2750.0
    [m]
    DC
    PETROS
    2770.0
    [m]
    DC
    PETROS
    2790.0
    [m]
    DC
    PETROS
    2810.0
    [m]
    DC
    PETROS
    2830.0
    [m]
    DC
    PETROS
    2850.0
    [m]
    DC
    PETROS
    2870.0
    [m]
    DC
    PETROS
    2890.0
    [m]
    DC
    PETROS
    2910.0
    [m]
    DC
    PETROS
    2930.0
    [m]
    DC
    PETROS
    2950.0
    [m]
    DC
    PETROS
    2970.0
    [m]
    DC
    PETROS
    2990.0
    [m]
    DC
    PETROS
    3010.0
    [m]
    DC
    PETROS
    3030.0
    [m]
    DC
    PETROS
    3050.0
    [m]
    DC
    PETROS
    3070.0
    [m]
    DC
    PETROS
    3090.0
    [m]
    DC
    PETROS
    3110.0
    [m]
    DC
    PETROS
    3130.0
    [m]
    DC
    PETROS
    3150.0
    [m]
    DC
    PETROS
    3170.0
    [m]
    DC
    PETROS
    3190.0
    [m]
    DC
    PETROS
    3210.0
    [m]
    DC
    PETROS
    3230.0
    [m]
    DC
    PETROS
    3250.0
    [m]
    DC
    PETROS
    3270.0
    [m]
    DC
    PETROS
    3290.0
    [m]
    DC
    PETROS
    3310.0
    [m]
    DC
    PETROS
    3330.0
    [m]
    DC
    PETROS
    3350.0
    [m]
    DC
    PETROS
    3370.0
    [m]
    DC
    PETROS
    3390.0
    [m]
    DC
    PETROS
    3410.0
    [m]
    DC
    PETROS
    3430.0
    [m]
    DC
    PETROS
    3450.0
    [m]
    DC
    PETROS
    3470.0
    [m]
    DC
    PETROS
    3490.0
    [m]
    DC
    PETROS
    3510.0
    [m]
    DC
    PETROS
    3530.0
    [m]
    DC
    PETROS
    3550.0
    [m]
    DC
    PETROS
    3570.0
    [m]
    DC
    PETROS
    3590.0
    [m]
    DC
    PETROS
    3610.0
    [m]
    DC
    PETROS
    3630.0
    [m]
    DC
    PETROS
    3650.0
    [m]
    DC
    PETROS
    3670.0
    [m]
    DC
    PETROS
    3690.0
    [m]
    DC
    PETROS
    3710.0
    [m]
    DC
    PETROS
    3730.0
    [m]
    DC
    PETROS
    3740.0
    [m]
    DC
    PETROS
    3750.0
    [m]
    DC
    PETROS
    3760.0
    [m]
    DC
    PETROS
    3770.0
    [m]
    DC
    PETROS
    3780.0
    [m]
    DC
    PETROS
    3790.0
    [m]
    DC
    PETROS
    3800.0
    [m]
    DC
    PETROS
    3810.0
    [m]
    DC
    PETROS
    3820.0
    [m]
    DC
    PETROS
    3830.0
    [m]
    DC
    PETROS
    3840.0
    [m]
    DC
    PETROS
    3850.0
    [m]
    DC
    PETROS
    3860.0
    [m]
    DC
    PETROS
    3870.0
    [m]
    DC
    PETROS
    3880.0
    [m]
    DC
    PETROS
    3890.0
    [m]
    DC
    PETROS
    3900.0
    [m]
    DC
    PETROS
    3903.0
    [m]
    DC
    PETROS
    3912.0
    [m]
    DC
    PETROS
    3921.0
    [m]
    DC
    PETROS
    3957.0
    [m]
    DC
    PETROS
    3966.0
    [m]
    DC
    PETROS
    3969.0
    [m]
    DC
    PETROS
    3975.0
    [m]
    DC
    PETROS
    3981.0
    [m]
    DC
    PETROS
    3987.0
    [m]
    DC
    PETROS
    3993.0
    [m]
    DC
    PETROS
    3999.0
    [m]
    DC
    PETROS
    4005.0
    [m]
    DC
    PETROS
    4011.0
    [m]
    DC
    PETROS
    4017.0
    [m]
    DC
    PETROS
    4023.0
    [m]
    DC
    PETROS
    4029.0
    [m]
    DC
    PETROS
    4035.0
    [m]
    DC
    PETROS
    4041.0
    [m]
    DC
    PETROS
    4047.0
    [m]
    DC
    PETROS
    4053.0
    [m]
    DC
    PETROS
    4059.0
    [m]
    DC
    PETROS
    4071.0
    [m]
    DC
    PETROS
    4077.0
    [m]
    DC
    PETROS
    4083.0
    [m]
    DC
    PETROS
    4089.0
    [m]
    DC
    PETROS
    4095.0
    [m]
    DC
    PETROS
    4113.0
    [m]
    DC
    PETROS
    4116.0
    [m]
    DC
    PETROS
    4117.0
    [m]
    SWC
    PETROS
    4119.0
    [m]
    DC
    PETROS
    4122.0
    [m]
    DC
    PETROS
    4129.5
    [m]
    C
    PETROS
    4135.2
    [m]
    C
    PETROS
    4141.1
    [m]
    C
    PETROS
    4146.8
    [m]
    C
    PETROS
    4149.0
    [m]
    DC
    PETROS
    4152.0
    [m]
    DC
    PETROS
    4155.0
    [m]
    DC
    PETROS
    4158.0
    [m]
    DC
    PETROS
    4161.0
    [m]
    DC
    PETROS
    4164.0
    [m]
    DC
    PETROS
    4167.0
    [m]
    DC
    PETROS
    4170.0
    [m]
    DC
    PETROS
    4173.0
    [m]
    DC
    PETROS
    4176.0
    [m]
    DC
    PETROS
    4179.0
    [m]
    DC
    PETROS
    4182.0
    [m]
    DC
    PETROS
    4188.0
    [m]
    DC
    PETROS
    4191.0
    [m]
    DC
    PETROS
    4194.0
    [m]
    DC
    PETROS
    4197.0
    [m]
    DC
    PETROS
    4200.0
    [m]
    DC
    PETROS
    4203.0
    [m]
    DC
    PETROS
    4206.0
    [m]
    DC
    PETROS
    4209.0
    [m]
    DC
    PETROS
    4212.0
    [m]
    DC
    PETROS
    4215.0
    [m]
    DC
    PETROS
    4218.0
    [m]
    DC
    PETROS
    4221.0
    [m]
    DC
    PETROS
    4224.0
    [m]
    DC
    PETROS
    4227.0
    [m]
    DC
    PETROS
    4230.0
    [m]
    DC
    PETROS
    4234.0
    [m]
    DC
    PETROS
    4236.0
    [m]
    DC
    PETROS
    4239.0
    [m]
    DC
    PETROS
    4242.0
    [m]
    DC
    PETROS
    4245.0
    [m]
    DC
    PETROS
    4248.0
    [m]
    DC
    PETROS
    4251.0
    [m]
    DC
    PETROS
    4254.0
    [m]
    DC
    PETROS
    4257.0
    [m]
    DC
    PETROS
    4260.0
    [m]
    DC
    PETROS
    4263.0
    [m]
    DC
    PETROS
    4266.0
    [m]
    DC
    PETROS
    4269.0
    [m]
    DC
    PETROS
    4272.0
    [m]
    DC
    PETROS
    4275.0
    [m]
    DC
    PETROS
    4278.0
    [m]
    DC
    PETROS
    4281.0
    [m]
    DC
    PETROS
    4284.0
    [m]
    DC
    PETROS
    4287.0
    [m]
    DC
    PETROS
    4290.0
    [m]
    DC
    PETROS
    4293.0
    [m]
    DC
    PETROS
    4296.0
    [m]
    DC
    PETROS
    4299.0
    [m]
    DC
    PETROS
    4302.0
    [m]
    DC
    PETROS
    4305.0
    [m]
    DC
    PETROS
    4308.0
    [m]
    DC
    PETROS
    4311.0
    [m]
    DC
    PETROS
    4314.0
    [m]
    DC
    PETROS
    4317.0
    [m]
    DC
    PETROS
    4320.0
    [m]
    DC
    PETROS
    4323.0
    [m]
    DC
    PETROS
    4326.0
    [m]
    DC
    PETROS
    4332.0
    [m]
    DC
    PETROS
    4338.0
    [m]
    DC
    PETROS
    4344.0
    [m]
    DC
    PETROS
    4350.0
    [m]
    DC
    PETROS
    4356.0
    [m]
    DC
    PETROS
    4362.0
    [m]
    DC
    PETROS
    4368.0
    [m]
    DC
    PETROS
    4374.0
    [m]
    DC
    PETROS
    4380.0
    [m]
    DC
    PETROS
    4386.0
    [m]
    DC
    PETROS
    4392.0
    [m]
    DC
    PETROS
    4398.0
    [m]
    DC
    PETROS
    4404.0
    [m]
    DC
    PETROS
    4410.0
    [m]
    DC
    PETROS
    4428.0
    [m]
    DC
    PETROS
    4434.0
    [m]
    DC
    PETROS
    4440.0
    [m]
    DC
    PETROS
    4458.0
    [m]
    DC
    PETROS
    4467.0
    [m]
    DC
    PETROS
    4470.0
    [m]
    DC
    PETROS
    4476.0
    [m]
    DC
    PETROS
    4479.0
    [m]
    DC
    PETROS
    4482.5
    [m]
    C
    PETROS
    4484.4
    [m]
    C
    PETROS
    4487.6
    [m]
    C
    PETROS
    4490.6
    [m]
    C
    PETROS
    4493.5
    [m]
    C
    PETROS
    4495.3
    [m]
    C
    PETROS
    4497.2
    [m]
    C
    PETROS
    4501.4
    [m]
    C
    PETROS
    4504.5
    [m]
    C
    PETROS
    4506.4
    [m]
    C
    PETROS
    4509.7
    [m]
    C
    PETROS
    4512.5
    [m]
    C
    PETROS
    4513.9
    [m]
    C
    PETROS
    4517.0
    [m]
    DC
    PETROS
    4520.0
    [m]
    DC
    PETROS
    4523.0
    [m]
    DC
    PETROS
    4526.0
    [m]
    DC
    PETROS
    4529.0
    [m]
    DC
    PETROS
    4532.0
    [m]
    DC
    PETROS
    4535.0
    [m]
    DC
    PETROS
    4538.0
    [m]
    DC
    PETROS
    4541.0
    [m]
    DC
    PETROS
    4544.0
    [m]
    DC
    PETROS
    4547.0
    [m]
    DC
    PETROS
    4550.0
    [m]
    DC
    PETROS
    4553.0
    [m]
    DC
    PETROS
    4556.0
    [m]
    DC
    PETROS
    4559.0
    [m]
    DC
    PETROS
    4562.0
    [m]
    DC
    PETROS
    4565.0
    [m]
    DC
    PETROS
    4568.0
    [m]
    DC
    PETROS
    4571.0
    [m]
    DC
    PETROS
    4574.0
    [m]
    DC
    PETROS
    4577.0
    [m]
    DC
    PETROS
    4580.0
    [m]
    DC
    PETROS
    4583.0
    [m]
    DC
    PETROS
    4586.0
    [m]
    DC
    PETROS
    4589.0
    [m]
    DC
    PETROS
    4592.0
    [m]
    DC
    PETROS
    4595.0
    [m]
    DC
    PETROS
    4598.0
    [m]
    DC
    PETROS
    4601.0
    [m]
    DC
    PETROS
    4604.0
    [m]
    DC
    PETROS
    4607.0
    [m]
    DC
    PETROS

  • 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
    4128.00
    0.00
    OIL
    YES
    DST
    4510.00
    0.00
    OIL
    YES
    FMT
    0.00
    0.00
    YES
    FMT
    4580.70
    0.00
    CONDENSATE
    NO

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CMR RR
    3900
    4658
    DUAL OBMI
    3900
    4658
    IPLT CMR HNGS
    3900
    4658
    MDT
    4115
    4589
    MDT
    4115
    4115
    MDT HC
    4580
    4580
    MDT MINI-DST VIT
    4115
    4117
    MDT MINI-DST VIT RR
    4489
    4510
    MSCT SWC
    4581
    4587
    MSCT SWC RR
    4111
    4182
    MSIP RT SCANNER
    3900
    4658
    MSIP RT SCANNER
    3900
    4618
    MWD - ARC PP POWERDRIVE V
    207
    2690
    MWD - ARC PP SON VIS
    131
    921
    MWD - ARC SON VIS TELE PPMOTOR
    2721
    3900
    MWD - ARC TELE POWERDRIVE
    2350
    2721
    MWD - GVR STETH ARC TELE
    3900
    4654
    MWD - PP
    131
    207
    ZOVSP GR TRISOR
    606
    4598

  • 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
    203.0
    36
    203.0
    0.00
    LOT
    SURF.COND.
    20
    991.0
    26
    1001.0
    1.78
    LOT
    INTERM.
    14
    2715.0
    17 1/2
    2721.0
    1.71
    LOT
    INTERM.
    9 7/8
    3900.0
    12 1/4
    3903.0
    2.13
    LOT
    OPEN HOLE
    4654.0
    8 1/2
    4654.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    685
    1.43
    22.0
    Performadril
    898
    1.43
    21.0
    Performadril
    1000
    1.45
    29.0
    Performadril
    1157
    1.25
    20.0
    Performadril
    1493
    2.04
    36.0
    OBM-Low ECD-HTHP
    1879
    1.37
    32.0
    Performadril
    2566
    1.45
    28.0
    Performadril
    2587
    1.37
    30.0
    Performadril
    2690
    1.37
    32.0
    Performadril
    2718
    1.45
    30.0
    Performadril
    2721
    1.47
    27.0
    XP-07 - #14
    2736
    1.39
    23.0
    XP-07 - #14
    3204
    1.41
    21.0
    XP-07 - #14
    3486
    1.43
    20.0
    XP-07 - #14
    3535
    1.49
    24.0
    XP-07 - #14
    3604
    2.00
    42.0
    OBM-Low ECD-HTHP
    3741
    1.62
    26.0
    XP-07 - #14
    3754
    2.00
    44.0
    OBM-Low ECD-HTHP
    3900
    2.02
    63.0
    OBM-Low ECD-HTHP
    3900
    2.02
    47.0
    OBM-Low ECD-HTHP
    3900
    1.62
    25.0
    XP-07 - #14
    3900
    1.62
    26.0
    XP-07 - #14
    4004
    2.02
    39.0
    OBM-Low ECD-HTHP
    4103
    2.03
    36.0
    OBM-Low ECD-HTHP
    4146
    2.04
    36.0
    OBM-Low ECD-HTHP
    4234
    2.05
    36.0
    OBM-Low ECD-HTHP
    4365
    2.02
    34.0
    OBM-Low ECD-HTHP
    4404
    2.02
    33.0
    OBM-Low ECD-HTHP
    4514
    2.02
    33.0
    OBM-Low ECD-HTHP
    4654
    2.00
    39.0
    OBM-Low ECD-HTHP

  • 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
    0.18