Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
10.11.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

7122/6-1

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.
    7122/6-1
    Type
    Wellbore type. Legal values: EXPLORATION, DEVELOPMENT, OTHER (see 'Purpose' for more information)
    EXPLORATION
    Purpose
    Final classification of the wellbore.

    Legal values for exploration wellbores:
    WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS.

    Legal values for development wellbores:
    OBSERVATION, PRODUCTION, INJECTION, INJECTION-CCS, OBSERVATION-CCS.

    Legal values for other wellbores:
    SOIL DRILLING (drilling in connection with track surveys and other subsurface surveys to investigate the soil conditions prior to placement of facilities),
    SHALLOW GAS (drilling to investigate shallow gas before the first 'real' drilling on the location),
    PILOT (drilling to investigate the geology and fluid connectors for location of the main wellbore),
    SCIENTIFIC (drilling according to Law of Scientific research and exploration),
    STRATIGRAPHIC (driling according to Law of Petroleum activities §2-1).
    WILDCAT
    Status
    Status for the wellbore. Legal values are:

    BLOWOUT: A blowout has occurred in the well.
    CLOSED: A development wellbore that has been closed in a shorter or longer periode. Also applies to development wellbores where drilling is completed, but production/injection has not yet been reported.
    DRILLING: The well is in the drilling phase - can be active drilling, logging, testing or plugging,
    JUNKED: The drilling operation has been terminated due to technical problems.
    P&A: Exploration: The well is plugged and abandoned, and can not be reentered for further use. Development wells: The production/injection from/to the well is stopped and the well is plugged. The wellhead is removed or else made unavailable for further well operations.
    PLUGGED: The wellbore has been plugged, but the upper parts of the wellbore can be re-used. A sidetrack might be drilled at a later stage.
    PRODUCING: It was produced from the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    INJECTING: It was injected to the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    PREDRILLED: The upper part of the well has been drilled, usually as part of a batch-drilling campaign covering several wellbores.
    RE-CLASS TO DEV: Exploration wellbore that is reclassified to a development wellbore.
    RE-CLASS TO TEST: Exploration wellbore that is reclassified to test production.
    SUSPENDED: The drilling operation in the wellbore has been temporarily stopped. The current plan is to continue drilling later on.
    P&A
    Factmaps in new window
    Main area
    Name of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.
    BARENTS 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.
    7122/6-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    FWGS 84-314 SP.1658/TO 8514-04 SP.293.2
    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.
    Total Norge 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.
    559-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.
    67
    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,
    06.09.1987
    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.
    11.11.1987
    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.
    11.11.1989
    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.
    18.05.2004
    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
    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.
    EARLY 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.
    STØ 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.
    LATE TRIASSIC
    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.
    SNADD 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.
    401.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2707.0
    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).
    2707.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    89
    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 TRIASSIC
    Oldest penetrated formation
    Name of the oldest lithostratigraphic unit penetrated by the wellbore. Shown only for released wells. In most wellbores this is formation or group at total depth. May differ from formation or group at TD for example in wellbores drilled with high deviation or through faults. Examples of legal values: AMUNDSEN FM, BALDER FM, BASEMENT, BLODØKS FM, BRYNE FM, BURTON FM, COOK FM, DRAKE FM, DRAUPNE FM, EKOFISK FM, DUNLIN GP.
    SNADD FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    71° 38' 19.32'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    22° 48' 42.8'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7949804.84
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    563698.43
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    34
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    1140

  • Wellbore history
    General
    Wildcat well 7122/6-1 was designed to drill a prospect located in the central part of the block, located in the eastern part of the Hammerfest Basin. The purpose of well 7122/6-1 was to test the hydrocarbon potential of the Middle Jurassic to Upper Triassic sandstones in the main structure of the block.
    Operations and results
    Wildcat well 7122/6-1 was spudded with Polar Frontier Drilling semi-submersible installation Polar Pioneer on 6 September 1987 and drilled to TD at 2707 m in the Middle - Late Triassic Snadd Formation.
    The structure penetrated by the well is a large tilted block dipping southwards. The northern closure is a major WNW-ESE fault. Top of the main markers were encountered higher than prognosed: top Stø Formation came in 71 m higher, and top Trias came in 183 m higher than expected. The Jurassic reservoirs were found water bearing, however, some oil recovered by RFT indicated the presence of a thin (1.5 m) oil zone at the top of the Stø formation. The late Triassic Snadd Formation proved gas and condensate in a 71.5 m gross thickness reservoir. Weak shows were recorded in cuttings from the Hekkingen shale. Strong whitish yellow direct fluorescence was observed in the cored sandstones all through the Stø Formation down to 2040 m. Weak shows were recorded on the cored sandstones in the Nordmela, Tubåen, and Fruholmen Formations. Below this level, in the Triassic section, weak oil shows were recorded in sandstones, including the reservoir section between 2400 to 2450 m that produced gas and condensate in the DST.
    A very dense geochemical screening in this well showed only very lean source rocks (< 1% TOC) above 1340 m. Between 1340 m and 1931 m, the average TOC is around 1% with a somewhat richer interval between 1750 m and 1900 m (TOC 1.5 to 3%), but with HI generally lower than 100 mg/g. Between 1931 m and 2015 m, high organic content (TOC 10 to 15%) and high HI (280 - 350 mg/g) indicate a very good source rock in the Hekkingen Formation. Between 2040 m to 2099 m) high TOC values are related to coal beds or organic shales (Nordmela and Tubåen formations). From 2100 m to 2710 m (TD), TOC was generally low, but with some moderately good intervals such as 2100 m - 2150 m (up to 3%). The HI was generally < 100 mg/g with some intervals at 100 - 150 mg/g. Thus, this section presents a low source rock potential. The vitrinite Ro and Tmax indicate that the well enters the oil window at around 2000-2100 m, just where the best source rock is found (Ro = 0.6% and Tmax = 435°C).
    Four cores were cut in the interval from 2019 m to 2099 m in the Stø, Nordmela, Tubåen, and Fruholmen Formations. A total of eleven RFT fluid samples were taken below 2015 m in the Jurassic and Triassic sections. The sample at 2015.8 m contained a small amount of condensate (0.5 cm3), while the sample at 2425 m contained a good quantity of condensate (600 cm3) with density 0.752 g/cm3. The other samples recovered various compositions of mud filtrate, water, and gas.
    Well 7122/6-1 was permanently abandoned on 11 November 1987 as a gas and condensate discovery.
    Testing
    Two DST's were performed in the Late Triassic reservoirs (Snadd Formation). DST1 perforated 2439.5 m to 2449 m and gave no flow. DST2 perforated 2424 m to 2434 m. During this test the well flowed gas and condensate with flow rates ranging from 530 000 to 567 000 Sm3/d of gas and 73 to 66 Sm3/D condensate through a 17.5 mm choke. GOR varied from 7377 Sm3/Sm3 to 8558 Sm3/Sm3.

  • 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]
    800.00
    2710.00

  • 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
    2019.0
    2039.2
    [m ]
    2
    2039.2
    2063.9
    [m ]
    3
    2064.0
    2086.9
    [m ]
    4
    2087.0
    2098.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    79.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2019-2023m
    Core photo at depth: 2024-2028m
    Core photo at depth: 2029-2033m
    Core photo at depth: 2034-2038m
    Core photo at depth: 2039-2039m
    2019-2023m
    2024-2028m
    2029-2033m
    2034-2038m
    2039-2039m
    Core photo at depth: 2039-2043m
    Core photo at depth: 2044-2048m
    Core photo at depth: 2049-2053m
    Core photo at depth: 2054-2058m
    Core photo at depth: 2059-2063m
    2039-2043m
    2044-2048m
    2049-2053m
    2054-2058m
    2059-2063m
    Core photo at depth: 2064-2068m
    Core photo at depth: 2069-2073m
    Core photo at depth: 2074-2078m
    Core photo at depth: 2079-2083m
    Core photo at depth: 2084-2086m
    2064-2068m
    2069-2073m
    2074-2078m
    2079-2083m
    2084-2086m
    Core photo at depth: 2087-2091m
    Core photo at depth: 2092-2098m
    Core photo at depth: 2097-2098m
    Core photo at depth:  
    Core photo at depth:  
    2087-2091m
    2092-2098m
    2097-2098m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    744.2
    [m]
    C
    C.F.P
    744.4
    [m]
    C
    C.F.P
    758.4
    [m]
    C
    C.F.P
    760.1
    [m]
    C
    C.F.P
    764.9
    [m]
    C
    C.F.P
    765.2
    [m]
    C
    C.F.P
    767.7
    [m]
    C
    C.F.P
    768.0
    [m]
    C
    C.F.P
    771.4
    [m]
    C
    C.F.P
    775.0
    [m]
    C
    C.F.P
    780.0
    [m]
    C
    C.F.P
    785.0
    [m]
    C
    C.F.P
    790.0
    [m]
    C
    C.F.P
    795.0
    [m]
    C
    C.F.P
    900.0
    [m]
    C
    C.F.P
    1100.0
    [m]
    C
    C.F.P
    1300.0
    [m]
    C
    C.F.P
    1500.0
    [m]
    C
    C.F.P
    1700.0
    [m]
    C
    C.F.P
    1740.0
    [m]
    C
    C.F.P
    1875.0
    [m]
    C
    C.F.P
    1930.0
    [m]
    C
    C.F.P
    1952.5
    [m]
    C
    C.F.P
    1972.0
    [m]
    C
    C.F.P
    1972.5
    [m]
    C
    C.F.P
    1979.0
    [m]
    C
    C.F.P
    1985.5
    [m]
    C
    C.F.P
    1990.0
    [m]
    C
    C.F.P
    1992.5
    [m]
    C
    C.F.P
    2001.5
    [m]
    C
    C.F.P
    2002.0
    [m]
    C
    C.F.P
    2006.0
    [m]
    C
    C.F.P
    2008.0
    [m]
    C
    C.F.P
    2011.0
    [m]
    C
    C.F.P
    2013.0
    [m]
    C
    C.F.P
    2014.0
    [m]
    C
    C.F.P
    2038.1
    [m]
    C
    OD
    2039.0
    [m]
    C
    C.F.P
    2039.2
    [m]
    C
    OD
    2039.3
    [m]
    C
    C.F.P
    2041.4
    [m]
    C
    OD
    2041.4
    [m]
    C
    C.F.P
    2044.2
    [m]
    C
    OD
    2046.5
    [m]
    C
    C.F.P
    2047.8
    [m]
    C
    OD
    2048.6
    [m]
    C
    C.F.P
    2049.9
    [m]
    C
    ICHRON
    2050.8
    [m]
    C
    C.F.P
    2054.0
    [m]
    C
    C.F.P
    2062.9
    [m]
    C
    ICHRON
    2063.0
    [m]
    C
    C.F.P
    2064.0
    [m]
    C
    C.F.P
    2068.8
    [m]
    C
    C.F.P
    2069.5
    [m]
    C
    C.F.P
    2072.8
    [m]
    C
    C.F.P
    2073.6
    [m]
    C
    C.F.P
    2076.3
    [m]
    C
    C.F.P
    2078.0
    [m]
    C
    C.F.P
    2079.0
    [m]
    C
    C.F.P
    2083.4
    [m]
    C
    C.F.P
    2083.8
    [m]
    C
    C.F.P
    2086.8
    [m]
    C
    C.F.P
    2089.5
    [m]
    C
    C.F.P
    2092.3
    [m]
    C
    C.F.P
    2093.0
    [m]
    C
    C.F.P
    2097.0
    [m]
    C
    C.F.P
    2098.5
    [m]
    C
    C.F.P
    2103.0
    [m]
    C
    C.F.P
    2125.0
    [m]
    C
    C.F.P
    2131.0
    [m]
    C
    C.F.P
    2146.0
    [m]
    C
    C.F.P
    2147.5
    [m]
    C
    C.F.P
    2200.0
    [m]
    C
    C.F.P
    2228.0
    [m]
    C
    C.F.P
    2242.0
    [m]
    C
    C.F.P
    2314.0
    [m]
    C
    C.F.P
    2341.0
    [m]
    C
    C.F.P
    2371.0
    [m]
    C
    C.F.P
    2461.0
    [m]
    C
    C.F.P
    2467.0
    [m]
    DC
    OD
    2473.0
    [m]
    C
    C.F.P
    2500.0
    [m]
    C
    C.F.P
    2545.0
    [m]
    C
    C.F.P
    2574.5
    [m]
    C
    C.F.P
    2587.5
    [m]
    C
    C.F.P
    2595.0
    [m]
    C
    C.F.P
    2603.0
    [m]
    C
    C.F.P
    2611.0
    [m]
    C
    C.F.P
    2617.5
    [m]
    C
    C.F.P
    2626.5
    [m]
    C
    C.F.P
    2651.0
    [m]
    C
    C.F.P
    2655.5
    [m]
    C
    C.F.P
    2657.5
    [m]
    C
    C.F.P
    2658.0
    [m]
    C
    C.F.P
    2662.0
    [m]
    C
    C.F.P
    2671.5
    [m]
    C
    C.F.P
    2678.0
    [m]
    C
    C.F.P

  • 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
    2424.00
    2434.00
    03.11.1987 - 00:00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.42

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    4.88
    pdf
    2.12

  • 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
    12.06

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.1
    2449
    2439
    0.0
    2.2
    2434
    2424
    17.4
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.1
    20.500
    73
    2.2
    25.000
    21.000
    28.000
    79
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    1.1
    2.2
    69
    579393
    0.749
    0.680
    8397

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    600
    1853
    CST
    485
    798
    CST
    783
    1840
    CST
    1887
    2700
    DIS LSS GR
    485
    794
    DIS LSS GR
    781
    1841
    DITE BHC GR
    1860
    2497
    DITE GR
    1860
    2269
    DITE GR
    2450
    2703
    DLL BHC MSFL
    1860
    2701
    LDL CNL GR
    1860
    2253
    LDL CNL SGR
    1860
    2481
    LDL CNL SGR
    2450
    2696
    LDL GR
    485
    773
    LDL GR
    781
    1823
    MWD
    424
    2710
    RFT
    2012
    2231
    RFT
    2186
    2448
    RFT
    2433
    2654
    SHDT GR
    781
    1845
    SHDT GR
    1860
    2490
    SHDT GR
    2475
    2705
    VSP
    700
    2497

  • 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
    485.0
    36
    489.0
    1.03
    LOT
    SURF.COND.
    20
    783.0
    26
    928.0
    1.47
    LOT
    INTERM.
    13 3/8
    1860.0
    17 1/2
    1875.0
    0.00
    LOT
    OPEN HOLE
    2707.0
    12 1/4
    2707.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    424
    1.03
    WATER BASED
    12.11.1987
    450
    1.03
    4.0
    7.6
    WATER BASED
    09.09.1987
    486
    0.00
    3.0
    6.0
    WATER BASED
    09.09.1987
    489
    1.03
    WATER BASED
    10.09.1987
    798
    1.03
    WATER BASED
    11.09.1987
    798
    1.03
    WATER BASED
    18.09.1987
    928
    1.12
    21.0
    12.4
    WATER BASED
    18.09.1987
    1148
    1.12
    8.7
    10.0
    WATER BASED
    18.09.1987
    1279
    1.12
    8.6
    10.0
    WATER BASED
    18.09.1987
    1435
    1.13
    20.0
    8.5
    WATER BASED
    18.09.1987
    1524
    1.13
    21.0
    8.6
    WATER BASED
    22.09.1987
    1639
    1.13
    21.0
    8.6
    WATER BASED
    22.09.1987
    1730
    1.14
    20.0
    8.6
    WATER BASED
    22.09.1987
    1761
    1.14
    21.0
    8.6
    WATER BASED
    22.09.1987
    1875
    1.20
    22.0
    8.6
    WATER BASED
    28.09.1987
    1875
    1.18
    21.0
    7.7
    WATER BASED
    23.09.1987
    1875
    1.28
    20.0
    7.1
    WATER BASED
    24.09.1987
    1875
    1.28
    21.0
    7.2
    WATER BASED
    25.09.1987
    1875
    1.28
    21.0
    7.6
    WATER BASED
    28.09.1987
    1891
    1.20
    23.0
    9.1
    WATER BASED
    28.09.1987
    2019
    1.25
    23.0
    7.6
    WATER BASED
    29.09.1987
    2019
    1.30
    24.0
    10.0
    WATER BASED
    30.09.1987
    2039
    1.30
    23.0
    10.0
    WATER BASED
    02.10.1987
    2064
    1.30
    26.0
    19.0
    WATER BASED
    02.10.1987
    2080
    1.31
    25.0
    11.0
    WATER BASED
    05.10.1987
    2087
    1.31
    26.0
    10.0
    WATER BASED
    05.10.1987
    2098
    1.31
    24.0
    10.0
    WATER BASED
    05.10.1987
    2137
    1.31
    22.0
    13.0
    WATER BASED
    07.10.1987
    2164
    1.31
    20.0
    12.4
    WATER BASED
    07.10.1987
    2218
    1.31
    28.0
    12.0
    WATER BASED
    08.10.1987
    2264
    1.31
    25.0
    14.4
    WATER BASED
    09.10.1987
    2373
    1.31
    25.0
    12.4
    WATER BASED
    14.10.1987
    2417
    1.31
    25.0
    12.0
    WATER BASED
    16.10.1987
    2437
    1.20
    13.0
    6.0
    WATER BASED
    03.11.1987
    2469
    1.00
    13.0
    5.5
    WATER BASED
    30.10.1987
    2471
    1.20
    19.0
    6.5
    WATER BASED
    29.10.1987
    2488
    1.31
    25.0
    12.0
    WATER BASED
    19.10.1987
    2500
    1.31
    25.0
    11.0
    WATER BASED
    19.10.1987
    2500
    1.31
    25.0
    11.0
    WATER BASED
    20.10.1987
    2514
    1.32
    21.0
    11.0
    WATER BASED
    20.10.1987
    2575
    1.30
    20.0
    11.5
    WATER BASED
    21.10.1987
    2624
    1.30
    23.0
    11.0
    WATER BASED
    22.10.1987
    2680
    1.30
    20.0
    12.5
    WATER BASED
    23.10.1987
    2710
    1.30
    23.0
    15.3
    WATER BASED
    26.10.1987
    2710
    1.30
    18.0
    9.5
    WATER BASED
    27.10.1987
    2710
    1.30
    14.0
    10.5
    WATER BASED
    28.10.1987
    2710
    1.20
    14.0
    6.5
    WATER BASED
    04.11.1987
    2710
    1.20
    12.0
    5.5
    WATER BASED
    05.11.1987
    2710
    1.20
    16.0
    4.7
    WATER BASED
    06.11.1987
    2710
    1.30
    18.0
    4.7
    WATER BASED
    09.11.1987
    2710
    1.20
    14.0
    6.5
    WATER BASED
    02.11.1987
    2710
    1.20
    13.0
    6.0
    WATER BASED
    02.11.1987

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    2020.25
    [m ]
    2023.75
    [m ]
    2030.00
    [m ]
    2037.75
    [m ]
    2041.50
    [m ]
    2052.50
    [m ]
    2082.55
    [m ]
    2092.75
    [m ]
    2019.00
    [m ]
    2023.00
    [m ]
    2029.25
    [m ]
    2034.50
    [m ]
    2037.50
    [m ]
    2040.75
    [m ]
    2044.75
    [m ]
    2051.25
    [m ]
    2057.00
    [m ]
    2060.25
    [m ]

  • Pressure plots
    Pressure plots
    The pore pressure data is sourced from well logs if no other source is specified. In some wells where pore pressure logs do not exist, information from Drill stem tests and kicks have been used. The data has been reported to the NPD, and further processed and quality controlled by IHS Markit.
    Pressure plots
    Document name
    Document format
    Document size [MB]
    pdf
    0.28