Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
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7128/4-1

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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.
    7128/4-1
    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
    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.
    7128/4-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 9103-417 & SP. 288
    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.
    779-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.
    72
    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,
    17.12.1993
    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.
    26.02.1994
    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.
    26.02.1996
    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.
    11.04.2003
    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 PERMIAN
    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.
    RØYE FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    24.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    370.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2530.0
    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).
    2528.1
    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.
    82
    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.
    PRE-DEVONIAN
    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.
    BASEMENT
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    71° 32' 27.33'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    28° 4' 54.08'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7938285.08
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    538226.27
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    35
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    2049

  • Wellbore history
    General
    Well 7128/4-1 is located in the Finmark Øst area. The main objective for the well was to test the potential for hydrocarbons in Visean sandstone on the "Omd Vest" structure. The secondary objective was to test the hydrocarbon potential, reservoir and trap possibilities of the Asselian - Sakmarian carbonates and the upper Permian succession.
    Operations
    Exploration well 7128/4-1 was spudded with the semi-submersible installation "Ross Rig" on 17 December 1993 and drilled to TD at 2530 m in pre-Devonian basement rocks, 27 m below base of the Early Carboniferous Soldogg Formation. The well was drilled with seawater and bentonite / CMC EHV spud mud down to 770 m and with GYP/PAC mud from 770 m to TD.
    The well penetrated Quaternary, Tertiary, Triassic, Permian, and Carboniferous sediments. The Cretaceous and Jurassic sequences were not present. Gas chromatography readings during drilling and log evaluation indicated gas saturation in the primary target. The sandstone was very tight and therefore not production tested. However, the Late Permian spiculite was partly very porous and permeable with a gas cap over moveable oil. A GOC was indicated at 1575 m.
    A total of five conventional cores were cut in the well 1574 m t 1577 m (Late Permian Røye Formation), 1814 m to 1837 m (Isbjørn and Ørn Formations of  Early Permian age), 1837 m to 1865 m (Early Permian Ørn Formation), 2362 m to 2389.47 m (Early Carboniferous Soldogg Formation), and 2526 m to 2530 m (Pre-Devonian basement).
    FMT wire line samples were obtained from three levels: 1572.7 m, 1576 m, and 1588.8 m. In the FMT samples taken at 1572.7 m, the 10-litre chamber contained 0.106 m3 of gas with an initial pressure of 8274 kPa. The 4-litre chamber contained 183 litre of gas, 0.5 ml of oil and 1380 ml of water/mud filtrate. Geco measured the density of the gas to 0.637 (air = l). For the samples taken at 1576 m the 10 litre chamber contained 2,5 litre of oil with a density of 0.81 g/cm3, 0.190 m3 of gas and the total liquid (mud filtrate + oil) volume was 9.3 litre. The 4 litre chamber contained 63.5 litre of gas, 225 ml of oil and the water volume was not possible to measure due to water leakage past the piston when the Geco transferred from FMT bottle to a PVT bottle. The gas gravity was measured to 0.790 (air = l). The oil density of stabilized oil was measured to 0.817 g/cm3 at 15 °C. One 10-litre sample taken at 1588.8 m contained 2.5 litre of mud filtrate. The sampling aborted after 4 hrs and 17 min. The well was permanently abandoned on 26 February 1994 as an oil and gas discovery.
    Testing
    Two zones were perforated and tested: Test no. 1 from 1592 -1610 m, and test no. 2 from 1577 -1586 m. For test no. 1 both diesel and Nitrogen was used to increase the under-balance, but the well did not flow. Finally, after stimulation with HCl test no. 1 produced 320 000 Sm3/d gas, 17 m3/d oil, and 70 m3/d water on a 72 mm choke. The HCl stimulation may have affected the cement, and the producing interval was probably the porous spiculite at 1569 m to 1590 m. Test no. 2 produced 215 000 Sm3/d gas, 15 m3/d oil, and 85 m3/d water on a 25.4 mm choke.
    l>

  • 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]
    780.00
    2529.00

  • 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
    1574.0
    1576.3
    [m ]
    2
    1814.0
    1836.0
    [m ]
    3
    1837.0
    1865.7
    [m ]
    4
    2362.0
    2389.5
    [m ]
    5
    2526.0
    2528.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    82.9
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1574-1576m
    Core photo at depth: 1814-1818m
    Core photo at depth: 1818-1822m
    Core photo at depth: 1822-1826m
    Core photo at depth: 1826-1830m
    1574-1576m
    1814-1818m
    1818-1822m
    1822-1826m
    1826-1830m
    Core photo at depth: 1830-1834m
    Core photo at depth: 1834-1836m
    Core photo at depth: 1837-1841m
    Core photo at depth: 1841-1845m
    Core photo at depth: 1845-1849m
    1830-1834m
    1834-1836m
    1837-1841m
    1841-1845m
    1845-1849m
    Core photo at depth: 1849-1853m
    Core photo at depth: 1853-1857m
    Core photo at depth: 1857-1861m
    Core photo at depth: 1861-1865m
    Core photo at depth: 1865-1866m
    1849-1853m
    1853-1857m
    1857-1861m
    1861-1865m
    1865-1866m
    Core photo at depth: 2362-2366m
    Core photo at depth: 2362-2466m
    Core photo at depth: 2366-2370m
    Core photo at depth: 2366-2470m
    Core photo at depth: 2370-2374m
    2362-2366m
    2362-2466m
    2366-2370m
    2366-2470m
    2370-2374m
    Core photo at depth: 2370-2474m
    Core photo at depth: 2374-2378m
    Core photo at depth: 2374-2478m
    Core photo at depth: 2378-2382m
    Core photo at depth: 2378-2482m
    2370-2474m
    2374-2378m
    2374-2478m
    2378-2382m
    2378-2482m
    Core photo at depth: 2382-2386m
    Core photo at depth: 2382-2486m
    Core photo at depth: 2386-2390m
    Core photo at depth: 2386-2489m
    Core photo at depth: 2526-2529m
    2382-2386m
    2382-2486m
    2386-2390m
    2386-2489m
    2526-2529m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    892.0
    [m]
    SWC
    STATO
    925.0
    [m]
    SWC
    STATO
    981.0
    [m]
    SWC
    STATO
    1055.0
    [m]
    SWC
    STATO
    1281.0
    [m]
    SWC
    STATO
    1323.5
    [m]
    SWC
    STATO
    1339.0
    [m]
    SWC
    STATO
    1399.0
    [m]
    SWC
    STATO
    1514.5
    [m]
    SWC
    STATO
    1538.0
    [m]
    SWC
    STATO
    1543.0
    [m]
    SWC
    STATO
    1555.0
    [m]
    SWC
    STATO
    1561.0
    [m]
    SWC
    STATO
    1566.0
    [m]
    SWC
    STATO
    1568.5
    [m]
    SWC
    STATO
    1668.0
    [m]
    SWC
    STATO
    1682.5
    [m]
    SWC
    STATO
    1693.0
    [m]
    SWC
    STATO
    1701.5
    [m]
    SWC
    STATO
    1814.7
    [m]
    C
    STATO
    1819.6
    [m]
    C
    STATO
    1824.9
    [m]
    C
    STATO
    1828.2
    [m]
    C
    STATO
    1851.5
    [m]
    C
    STATO
    2009.0
    [m]
    SWC
    STATO
    2015.3
    [m]
    SWC
    STATO
    2057.0
    [m]
    SWC
    STATO
    2058.0
    [m]
    DC
    UIB
    2061.0
    [m]
    DC
    UIB
    2073.0
    [m]
    DC
    UIB
    2082.0
    [m]
    DC
    UIB
    2091.0
    [m]
    SWC
    STATOIL
    2094.0
    [m]
    DC
    UIB
    2097.0
    [m]
    DC
    UIB
    2103.0
    [m]
    SWC
    STATOIL
    2106.0
    [m]
    DC
    UIB
    2115.0
    [m]
    DC
    UIB
    2124.0
    [m]
    DC
    UIB
    2130.8
    [m]
    SWC
    STATOIL
    2133.0
    [m]
    DC
    UIB
    2145.0
    [m]
    DC
    UIB
    2160.0
    [m]
    DC
    UIB
    2169.0
    [m]
    DC
    UIB
    2170.0
    [m]
    SWC
    STATOIL
    2181.0
    [m]
    DC
    UIB
    2182.0
    [m]
    SWC
    STATOIL
    2205.0
    [m]
    DC
    UIB
    2211.0
    [m]
    SWC
    STATOIL
    2214.0
    [m]
    DC
    UIB
    2220.0
    [m]
    DC
    UIB
    2243.5
    [m]
    SWC
    STATOIL
    2244.0
    [m]
    DC
    UIB
    2253.0
    [m]
    DC
    UIB
    2256.0
    [m]
    DC
    UIB
    2257.0
    [m]
    SWC
    STATOIL
    2280.0
    [m]
    DC
    UIB
    2282.0
    [m]
    SWC
    STATOIL
    2283.0
    [m]
    DC
    UIB
    2286.0
    [m]
    DC
    UIB
    2286.0
    [m]
    SWC
    STATOIL
    2286.0
    [m]
    DC
    UIB
    2295.0
    [m]
    DC
    UIB
    2311.0
    [m]
    SWC
    STATOIL
    2313.0
    [m]
    DC
    UIB
    2328.0
    [m]
    DC
    UIB
    2331.5
    [m]
    SWC
    STATOIL
    2331.5
    [m]
    SWC
    STATOI
    2337.0
    [m]
    DC
    UIB
    2342.0
    [m]
    SWC
    STATOIL
    2343.0
    [m]
    DC
    UIB
    2343.0
    [m]
    DC
    UIB
    2349.0
    [m]
    DC
    UIB
    2349.0
    [m]
    DC
    UIB
    2358.0
    [m]
    DC
    UIB
    2358.0
    [m]
    DC
    UIB
    2363.7
    [m]
    SWC
    STATOIL
    2364.0
    [m]
    DC
    UIB
    2366.2
    [m]
    C
    UIB
    2366.6
    [m]
    C
    UIB
    2367.2
    [m]
    C
    UIB
    2368.7
    [m]
    C
    UIB
    2368.9
    [m]
    C
    STATOIL
    2375.3
    [m]
    C
    STATOI
    2376.0
    [m]
    C
    UIB
    2376.4
    [m]
    C
    UIB
    2376.6
    [m]
    C
    UIB
    2379.0
    [m]
    DC
    UIB
    2381.6
    [m]
    C
    STATOIL
    2384.5
    [m]
    C
    UIB
    2384.7
    [m]
    C
    UIB
    2385.6
    [m]
    C
    UIB
    2385.8
    [m]
    C
    UIB
    2386.1
    [m]
    C
    UIB
    2386.5
    [m]
    C
    UIB
    2389.2
    [m]
    C
    UIB
    2389.5
    [m]
    C
    STATOIL
    2391.0
    [m]
    DC
    UIB
    2394.0
    [m]
    DC
    UIB
    2396.0
    [m]
    SWC
    STATOIL
    2448.0
    [m]
    DC
    UIB
    2450.0
    [m]
    SWC
    STATOIL
    2472.0
    [m]
    DC
    UIB
    2527.4
    [m]
    DC
    UIB

  • 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
    DST1-1A
    1610.00
    1595.00
    09.02.1994 - 00:00
    YES
    DST
    DST1A-1B
    1610.00
    1577.00
    10.02.1994 - 21:00
    YES
    DST
    DST2
    1577.00
    0.00
    17.02.1994 - 14:15
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.41

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.84
    pdf
    1.03
    pdf
    1.91
    pdf
    5.05

  • 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
    51.84

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    1592
    1610
    72.0
    2.0
    1577
    1586
    25.4
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.0
    30.000
    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
    17
    320000
    18823
    2.0
    15
    215000
    0.797
    0.638
    14333

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBIL GR
    1502
    2469
    CBL VDL GR
    1100
    1502
    DIFL ACL ZDL CNL GR
    1502
    2023
    DIFL ACL ZDL GR
    750
    1517
    DIFL ACL ZDL GR
    2432
    2530
    DIFL MAC SL GR
    1502
    2471
    DLL MLL GR
    1540
    1718
    FMT
    1570
    1594
    FMT GR
    1573
    1574
    FMT GR
    1576
    1576
    FMT GR
    1585
    1589
    FMT GR
    1594
    2447
    FMT GR
    1594
    2420
    FMT GR
    1658
    1685
    MWD
    460
    2526
    SHDT GR
    1503
    2463
    SWC GR
    756
    1515
    SWC GR
    1533
    1691
    SWC GR
    1693
    2072
    SWC GR
    2076
    2467
    VSP GR
    493
    2460
    ZDL CNL GR
    1988
    2469

  • 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
    455.0
    36
    455.0
    0.00
    LOT
    INTERM.
    20
    750.0
    26
    750.0
    1.40
    LOT
    INTERM.
    13 3/8
    1502.0
    17 1/2
    1504.0
    1.74
    LOT
    INTERM.
    9 5/8
    2432.0
    12 1/4
    2432.0
    1.50
    LOT
    OPEN HOLE
    2530.0
    8 1/2
    2530.0
    0.00
    LOT
    OPEN HOLE
    2530.0
    8 1/2
    0.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    715
    1.20
    15.0
    WATER BASED
    770
    1.12
    17.0
    WATER BASED
    815
    1.03
    17.0
    WATER BASED
    1307
    1.20
    18.0
    WATER BASED
    1495
    1.20
    15.0
    WATER BASED
    1525
    1.20
    18.0
    WATER BASED
    1589
    1.12
    WATER BASED
    1701
    1.20
    19.0
    WATER BASED
    1814
    1.20
    19.0
    WATER BASED
    1951
    1.20
    21.0
    WATER BASED
    2092
    1.20
    23.0
    WATER BASED
    2141
    1.20
    26.0
    WATER BASED
    2356
    1.20
    26.0
    WATER BASED
    2468
    1.10
    9.0
    WATER BASED
    2523
    1.10
    17.0
    WATER BASED
    2530
    1.12
    WATER BASED

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    1574.15
    [m ]
    1574.40
    [m ]
    1575.92
    [m ]
    1576.20
    [m ]
    1574.30
    [m ]
    1575.85
    [m ]
    1815.12
    [m ]
    1821.40
    [m ]
    1849.50
    [m ]
    1832.40
    [m ]
    1837.80
    [m ]
    1841.68
    [m ]
    1843.90
    [m ]
    1851.85
    [m ]
    1855.50
    [m ]
    1858.50
    [m ]
    1861.55
    [m ]
    1865.47
    [m ]
    2362.23
    [m ]
    2368.50
    [m ]
    2382.75
    [m ]
    2388.56
    [m ]
    2527.98
    [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
    0.29