Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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05.11.2024 - 01:27
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30/2-3

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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.
    30/2-3
    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.
    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.
    30/2-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 8830-313 & COL. 842
    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.
    731-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.
    117
    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,
    11.06.1992
    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.
    05.10.1992
    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.
    05.10.1994
    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.
    07.01.2015
    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.
    TARBERT 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.
    NESS FM
    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.
    123.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4325.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    7.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    160
    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.
    EIRIKSSON FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 50' 49.05'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 39' 19.68'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6745949.82
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    481275.16
    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.
    1970

  • Wellbore history
    General
    Well 30/2-2 was drilled on the Huldra Field in the North Sea. The objective was to appraise the gas/condensate discovery in the Brent Group and reduce the gas-in-place estimates for the field.
    Operations and results
    Appraisal well 30/2-2 was spudded with the semi-submersible installation Ross Isle on 11 June 1992  and drilled to TD at 4325 m in the Early Jurassic Eiriksson Formation. A pilot hole was drilled to 520 m to check for shallow gas. No gas was detected. Drilling proceeded without significant problems. Tool sticking was common in the reservoir section during logging runs. The well was drilled with seawater down to 209 m, with gel spud mud from 209 m to 1115 m, with gypsum/polymer mud from 1115 m to 2298 m, and with Ancotherm mud from 2298 m to TD.
    Although a well-defined Gas-Water-contact was encountered in 30/2-3 at 3896 m, this was some 75 m shallower than the previously deepest gas-down-to for well 30/2-2. This indicates that the Huldra Field is more complex than previously thought. Good porosity and permeability were encountered in all gas bearing intervals, reducing uncertainties regarding well productivity. There were no shows above Brent reservoir level. Below the GWC weak shows on sandstone in the cores gradually diminished down to 3962 m where shows disappeared altogether.
    A total of 178.4 m core was recovered in 17 cores, from 3749 m in the Heather Formation through all of the Brent Group and down to 3985 m at top Drake Formation. The core-to-log depth correction varied between -0.4 to +1.9 m. No wire line fluid samples were taken.
    The well was permanently abandoned on 5 October 1992 as a gas/condensate appraisal well.
    Testing
    Three drill stem tests were performed in the Brent Group.
    DST 1 tested the interval 3895 - 3898 m in the Ness Formation. The average production rates towards the end of the Cleanup/ Main Flow period were approximately 43000 Sm3/d of gas, 24 Sm3/d of condensate and 129 Sm3/d of formation water. This proved a GWC in the tested interval. The condensate density was 0.810 g/cm3 and the gas gravity was 0.720 (air =1). The temperature at reference depth 3895 m was 149.0 °C.
    DST 2 tested the interval 3874 - 3881 m in the Ness Formation. The average gas and condensate production rates during the Main Flow were 671000 Sm3/d and 319 Sm3/d respectively through a 12.7 mm (32/64") choke size. This gave a GOR close to 2100 Sm3/Sm3 at the prevailing separator conditions. The condensed or dissolved water production was approx. 6-8 m3/d. The condensate density was 0.0.800 g/cm3 and the gas gravity was 0.700 (air =1). DST 2 confirmed very good reservoir properties in the tested interval. The temperature at reference depth 3895 m was 147.5 °C.
    DST 3 te3sted the interval 3794 -3803 m in the Tarbert Formation. The average gas and condensate production rates during the Main Flow were 466800 Sm3/d and 215 Sm3/d respectively through a 12.7 mm (32/64") choke size. This gave a GOR of approx. 2170 Sm3/Sm3 at the prevailing separator conditions. The condensed or dissolved water production was approx. 4-6 m3/d. The condensate density was 0.0.797 g/cm3 and the gas gravity was 0.0.690 (air =1). DST 3 confirmed moderate reservoir properties in the tested interval. The temperature at reference depth 3895 m was 146.0 °C.

  • 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]
    1120.00
    4323.00

  • 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
    3749.0
    3755.9
    [m ]
    2
    3756.0
    3761.1
    [m ]
    3
    3792.0
    3813.3
    [m ]
    4
    3816.0
    3829.1
    [m ]
    5
    3830.0
    3836.3
    [m ]
    6
    3836.3
    3855.0
    [m ]
    7
    3855.1
    3867.0
    [m ]
    8
    3868.0
    3873.9
    [m ]
    9
    3857.0
    3886.5
    [m ]
    10
    3886.5
    3897.0
    [m ]
    11
    3897.7
    3915.0
    [m ]
    12
    3915.6
    3928.0
    [m ]
    13
    3928.1
    3932.0
    [m ]
    15
    3954.5
    3962.0
    [m ]
    16
    3962.0
    3968.8
    [m ]
    17
    3968.8
    3986.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    194.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3749-3754m
    Core photo at depth: 3754-3755m
    Core photo at depth: 3756-3761m
    Core photo at depth: 3761-3761m
    Core photo at depth: 3793-3798m
    3749-3754m
    3754-3755m
    3756-3761m
    3761-3761m
    3793-3798m
    Core photo at depth: 3798-3803m
    Core photo at depth: 3803-3808m
    Core photo at depth: 3808-3813m
    Core photo at depth: 3813-3813m
    Core photo at depth: 3816-3821m
    3798-3803m
    3803-3808m
    3808-3813m
    3813-3813m
    3816-3821m
    Core photo at depth: 3821-3826m
    Core photo at depth: 3826-3829m
    Core photo at depth: 3830-3835m
    Core photo at depth: 3835-3836m
    Core photo at depth: 3836-3841m
    3821-3826m
    3826-3829m
    3830-3835m
    3835-3836m
    3836-3841m
    Core photo at depth: 3846-3851m
    Core photo at depth: 3851-3855m
    Core photo at depth: 3855-3860m
    Core photo at depth: 3860-3865m
    Core photo at depth: 3865-3867m
    3846-3851m
    3851-3855m
    3855-3860m
    3860-3865m
    3865-3867m
    Core photo at depth: 3865-3873m
    Core photo at depth: 3873-3873m
    Core photo at depth: 3875-3880m
    Core photo at depth: 3880-3885m
    Core photo at depth: 3885-3886m
    3865-3873m
    3873-3873m
    3875-3880m
    3880-3885m
    3885-3886m
    Core photo at depth: 3886-3891m
    Core photo at depth: 3891-3896m
    Core photo at depth: 3896-3897m
    Core photo at depth: 3897-3902m
    Core photo at depth: 3902-3907m
    3886-3891m
    3891-3896m
    3896-3897m
    3897-3902m
    3902-3907m
    Core photo at depth: 3907-3912m
    Core photo at depth: 3912-3915m
    Core photo at depth: 3915-3920m
    Core photo at depth: 3920-3925m
    Core photo at depth: 3925-3928m
    3907-3912m
    3912-3915m
    3915-3920m
    3920-3925m
    3925-3928m
    Core photo at depth: 3928-3932m
    Core photo at depth: 3954-3959m
    Core photo at depth: 3959-3962m
    Core photo at depth: 3962-3967m
    Core photo at depth: 3967-3968m
    3928-3932m
    3954-3959m
    3959-3962m
    3962-3967m
    3967-3968m
    Core photo at depth: 3968-3973m
    Core photo at depth: 3973-3978m
    Core photo at depth: 3978-3983m
    Core photo at depth: 3983-3906m
    Core photo at depth:  
    3968-3973m
    3973-3978m
    3978-3983m
    3983-3906m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1130.0
    [m]
    DC
    GEOST
    1160.0
    [m]
    DC
    GEOST
    1190.0
    [m]
    DC
    GEOST
    1210.0
    [m]
    DC
    GEOST
    1230.0
    [m]
    DC
    GEOST
    1300.0
    [m]
    DC
    GEOST
    1342.0
    [m]
    DC
    GEOST
    1354.0
    [m]
    DC
    GEOST
    1420.0
    [m]
    DC
    GEOST
    1447.0
    [m]
    DC
    GEOST
    1477.0
    [m]
    DC
    GEOST
    1492.0
    [m]
    DC
    GEOST
    1501.0
    [m]
    DC
    GEOST
    1516.0
    [m]
    DC
    GEOST
    1528.0
    [m]
    DC
    GEOST
    1543.0
    [m]
    DC
    GEOST
    1558.0
    [m]
    DC
    GEOST
    1564.0
    [m]
    DC
    GEOST
    1579.0
    [m]
    DC
    GEOST
    1600.0
    [m]
    DC
    GEOST
    1645.0
    [m]
    DC
    GEOST
    1660.0
    [m]
    DC
    GEOST
    1675.0
    [m]
    DC
    GEOST
    1702.0
    [m]
    DC
    GEOST
    1759.0
    [m]
    DC
    GEOST
    1783.0
    [m]
    DC
    GEOST
    1804.0
    [m]
    DC
    GEOST
    1825.0
    [m]
    DC
    GEOST
    1846.0
    [m]
    DC
    GEOST
    1858.0
    [m]
    DC
    GEOST
    1882.0
    [m]
    DC
    GEOST
    2191.0
    [m]
    DC
    GEOST
    2257.0
    [m]
    DC
    GEOST
    2278.0
    [m]
    DC
    GEOST
    2296.0
    [m]
    DC
    GEOST
    2320.0
    [m]
    DC
    GEOST
    2340.0
    [m]
    DC
    GEOST
    2360.0
    [m]
    DC
    GEOST
    2380.0
    [m]
    DC
    GEOST
    2400.0
    [m]
    DC
    GEOST
    2420.0
    [m]
    DC
    GEOST
    2440.0
    [m]
    DC
    GEOST
    2460.0
    [m]
    DC
    GEOST
    2480.0
    [m]
    DC
    GEOST
    2500.0
    [m]
    DC
    GEOST
    2520.0
    [m]
    DC
    GEOST
    2540.0
    [m]
    DC
    GEOST
    2560.0
    [m]
    DC
    GEOST
    2580.0
    [m]
    DC
    GEOST
    2600.0
    [m]
    DC
    GEOST
    2620.0
    [m]
    DC
    GEOST
    2640.0
    [m]
    DC
    GEOST
    2660.0
    [m]
    DC
    GEOST
    2680.0
    [m]
    DC
    GEOST
    2700.0
    [m]
    DC
    GEOST
    2720.0
    [m]
    DC
    GEOST
    2740.0
    [m]
    DC
    GEOST
    2770.0
    [m]
    DC
    GEOST
    2780.0
    [m]
    DC
    GEOST
    2800.0
    [m]
    DC
    GEOST
    2820.0
    [m]
    DC
    GEOST
    2840.0
    [m]
    DC
    GEOST
    2860.0
    [m]
    DC
    GEOST
    2880.0
    [m]
    DC
    GEOST
    2900.0
    [m]
    DC
    GEOST
    2920.0
    [m]
    DC
    GEOST
    2940.0
    [m]
    DC
    GEOST
    2960.0
    [m]
    DC
    GEOST
    2980.0
    [m]
    DC
    GEOST
    3000.0
    [m]
    DC
    GEOST
    3020.0
    [m]
    DC
    GEOST
    3040.0
    [m]
    DC
    GEOST
    3060.0
    [m]
    DC
    GEOST
    3080.0
    [m]
    DC
    GEOST
    3100.0
    [m]
    DC
    GEOST
    3120.0
    [m]
    DC
    GEOST
    3140.0
    [m]
    DC
    GEOST
    3160.0
    [m]
    DC
    GEOST
    3180.0
    [m]
    DC
    GEOST
    3200.0
    [m]
    DC
    GEOST
    3220.0
    [m]
    DC
    GEOST
    3240.0
    [m]
    DC
    GEOST
    3260.0
    [m]
    DC
    GEOST
    3280.0
    [m]
    DC
    GEOST
    3300.0
    [m]
    DC
    GEOST
    3320.0
    [m]
    DC
    GEOST
    3340.0
    [m]
    DC
    GEOST
    3360.0
    [m]
    DC
    GEOST
    3380.0
    [m]
    DC
    GEOST
    3400.0
    [m]
    DC
    GEOST
    3420.0
    [m]
    DC
    GEOST
    3520.0
    [m]
    DC
    GEOST
    3540.0
    [m]
    DC
    GEOST
    3560.0
    [m]
    DC
    GEOST
    3580.0
    [m]
    DC
    GEOST
    3600.0
    [m]
    DC
    GEOST
    3618.0
    [m]
    DC
    GEOST
    3624.0
    [m]
    DC
    GEOST
    3627.0
    [m]
    DC
    GEOST
    3636.0
    [m]
    DC
    GEOST
    3645.0
    [m]
    DC
    GEOST
    3654.0
    [m]
    DC
    GEOST
    3672.0
    [m]
    DC
    GEOST
    3681.0
    [m]
    DC
    GEOST
    3690.0
    [m]
    DC
    GEOST
    3699.0
    [m]
    DC
    GEOST
    3708.0
    [m]
    DC
    GEOST
    3708.5
    [m]
    SWC
    STATO
    3717.0
    [m]
    SWC
    STATO
    3717.0
    [m]
    DC
    GEOST
    3728.0
    [m]
    SWC
    STATO
    3729.0
    [m]
    DC
    GEOST
    3735.0
    [m]
    SWC
    STATO
    3738.0
    [m]
    DC
    GEOST
    3747.0
    [m]
    DC
    GEOST
    3749.5
    [m]
    C
    GEOST
    3758.5
    [m]
    C
    GEOST
    3765.0
    [m]
    DC
    GEOST
    3774.0
    [m]
    DC
    GEOST
    3783.0
    [m]
    DC
    GEOST
    3789.5
    [m]
    SWC
    STATO
    3791.5
    [m]
    SWC
    STATO
    3792.0
    [m]
    DC
    GEOST
    3792.5
    [m]
    SWC
    STATO
    3794.8
    [m]
    C
    GEOST
    3804.6
    [m]
    C
    GEOST
    3807.7
    [m]
    C
    GEOST
    3812.0
    [m]
    C
    GEOST
    3821.7
    [m]
    C
    GEOST
    3830.2
    [m]
    C
    GEOST
    3837.3
    [m]
    C
    GEOST
    3845.2
    [m]
    C
    GEOST
    3852.2
    [m]
    C
    GEOST
    3860.0
    [m]
    C
    GEOST
    3867.0
    [m]
    C
    GEOST
    3875.7
    [m]
    C
    GEOST
    3883.8
    [m]
    C
    GEOST
    3887.2
    [m]
    C
    GEOST
    3894.3
    [m]
    C
    GEOST
    3902.8
    [m]
    C
    GEOST
    3910.2
    [m]
    C
    GEOST
    3919.3
    [m]
    C
    GEOST
    3927.6
    [m]
    C
    GEOST
    3932.7
    [m]
    C
    GEOST
    3934.5
    [m]
    SWC
    STATO
    3938.0
    [m]
    SWC
    STATO
    3944.0
    [m]
    SWC
    STATO
    3949.5
    [m]
    SWC
    STATO
    3954.5
    [m]
    C
    GEOST
    3962.5
    [m]
    C
    GEOST
    3967.6
    [m]
    C
    GEOST
    3973.0
    [m]
    C
    GEOST
    3974.6
    [m]
    C
    GEOST
    3979.4
    [m]
    C
    GEOST
    3981.3
    [m]
    C
    GEOST
    3986.2
    [m]
    C
    GEOST
    3990.0
    [m]
    DC
    GEOST
    3999.0
    [m]
    DC
    GEOST
    4008.0
    [m]
    DC
    GEOST
    4017.0
    [m]
    DC
    GEOST
    4026.0
    [m]
    DC
    GEOST
    4035.0
    [m]
    DC
    GEOST
    4044.0
    [m]
    DC
    GEOST
    4053.0
    [m]
    DC
    GEOST
    4062.0
    [m]
    DC
    GEOST
    4071.0
    [m]
    DC
    GEOST
    4080.0
    [m]
    DC
    GEOST
    4095.0
    [m]
    DC
    GEOST
    4098.0
    [m]
    DC
    GEOST
    4107.0
    [m]
    DC
    GEOST
    4116.0
    [m]
    DC
    GEOST
    4128.0
    [m]
    DC
    GEOST
    4134.0
    [m]
    DC
    GEOST
    4146.0
    [m]
    DC
    GEOST
    4152.0
    [m]
    DC
    GEOST
    4161.0
    [m]
    DC
    GEOST
    4170.0
    [m]
    DC
    GEOST
    4179.0
    [m]
    DC
    GEOST
    4188.0
    [m]
    DC
    GEOST
    4197.0
    [m]
    DC
    GEOST
    4206.0
    [m]
    DC
    GEOST
    4215.0
    [m]
    DC
    GEOST
    4224.0
    [m]
    DC
    GEOST
    4233.0
    [m]
    DC
    GEOST
    4242.0
    [m]
    DC
    GEOST
    4251.0
    [m]
    DC
    GEOST
    4260.0
    [m]
    DC
    GEOST
    4269.0
    [m]
    DC
    GEOST
    4278.0
    [m]
    DC
    GEOST
    4287.0
    [m]
    DC
    GEOST
    4293.0
    [m]
    DC
    GEOST
    4299.0
    [m]
    DC
    GEOST
    4308.0
    [m]
    DC
    GEOST
    4317.0
    [m]
    DC
    GEOST
    4323.0
    [m]
    DC
    GEOST

  • 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
    3895.00
    0.00
    09.09.1992 - 01:00
    YES
    DST
    DST2
    3874.00
    0.00
    15.09.1992 - 22:00
    YES
    DST
    DST3
    3794.00
    0.00
    23.09.1992 - 13:00
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.54
    pdf
    3.15
    pdf
    1.15
    pdf
    1.93

  • 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
    22.86

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3895
    3898
    12.7
    2.0
    3874
    3881
    12.7
    3.1
    3794
    3803
    12.7
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    4.000
    2.0
    53.000
    40.000
    3.1
    14.000
    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
    24
    4300
    0.810
    0.720
    1790
    2.0
    319
    671000
    0.800
    0.700
    2100
    3.1
    215
    466800
    0.797
    0.690
    2180

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    1650
    2283
    CBL VDL GR
    2972
    3692
    CBL VDL GR
    3550
    4041
    CST GR
    1118
    2227
    CST GR
    3708
    3952
    CST GR
    3717
    3722
    DIL BHC MSFL GR
    3706
    4323
    DIL SLS GR CAL
    1099
    3723
    DLL GR
    3706
    3875
    FMS GR
    3706
    4000
    LDL CNL GR
    2280
    3722
    LDL CNL NGT
    3706
    4325
    MWD
    209
    4325
    RFT HP GR
    3797
    4317
    VSP
    1780
    4324

  • 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
    205.0
    36
    206.0
    0.00
    LOT
    INTERM.
    20
    1099.0
    26
    1100.0
    1.70
    LOT
    INTERM.
    13 3/8
    2283.0
    17 1/2
    2285.0
    1.91
    LOT
    INTERM.
    9 5/8
    3706.0
    12 1/4
    3708.0
    2.05
    LOT
    LINER
    7
    4088.0
    8 1/2
    4325.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    520
    1.03
    WATER BASED
    756
    1.03
    WATER BASED
    1099
    1.03
    WATER BASED
    1115
    1.03
    WATER BASED
    1597
    1.39
    35.0
    WATER BASED
    2298
    1.59
    42.0
    WATER BASED
    2301
    1.64
    33.0
    WATER BASED
    2346
    1.67
    35.0
    WATER BASED
    2604
    1.75
    40.0
    WATER BASED
    2742
    1.75
    32.0
    WATER BASED
    2859
    1.75
    36.0
    WATER BASED
    2894
    1.78
    37.0
    WATER BASED
    2973
    1.78
    38.0
    WATER BASED
    3044
    1.78
    36.0
    WATER BASED
    3149
    1.78
    36.0
    WATER BASED
    3284
    1.78
    30.0
    WATER BASED
    3545
    1.82
    28.0
    WATER BASED
    3560
    1.82
    28.0
    WATER BASED
    3723
    1.85
    37.0
    WATER BASED
    3723
    1.85
    37.0
    WATER BASED
    3727
    1.85
    27.0
    WATER BASED
    3749
    1.85
    26.0
    WATER BASED
    3756
    1.85
    26.0
    WATER BASED
    3791
    1.87
    43.0
    WATER BASED
    3792
    1.89
    30.0
    WATER BASED
    3793
    1.85
    DUMMY
    3816
    1.85
    DUMMY
    3830
    1.87
    DUMMY
    3855
    1.87
    32.0
    WATER BASED
    3886
    1.87
    30.0
    WATER BASED
    3911
    1.87
    32.0
    WATER BASED
    3953
    1.87
    33.0
    WATER BASED
    3968
    1.87
    29.0
    WATER BASED
    4011
    1.87
    26.0
    WATER BASED
    4091
    1.87
    27.0
    WATER BASED
    4325
    1.86
    18.0
    WATER BASED
    4325
    1.87
    17.0
    WATER 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
    0.21