Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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16.07.2024 - 01:28
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31/2-3

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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.
    31/2-3
    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.
    31/2-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    62-4421 SP.175
    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.
    A/S Norske Shell
    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.
    247-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.
    115
    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,
    28.03.1980
    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.
    20.07.1980
    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.
    20.07.1982
    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.
    15.02.2006
    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.
    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.
    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.
    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.
    SOGNEFJORD 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.
    FENSFJORD FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    334.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2601.0
    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).
    2600.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.65
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    73
    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.
    LATE 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.
    HEGRE GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 50' 27.84'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 35' 10.82'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6745386.82
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    531872.26
    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.
    236
  • Wellbore history

    General
    Well 31/2-3 was drilled in the Troll West area, approximately 8 km NNE of the Troll Discovery well 31/2-1. The well was drilled to appraise the Troll Discovery. It should evaluate reservoir parameters along the axis of maximum gross hydrocarbon column; prove maximum hydrocarbon reserves in the major northern fault block; confirm the significance of the seismic flatspot as a direct hydrocarbon indicator; further assess the significance of the oil shows found in 31/2-1; and evaluate the influence of earlier Kimmerian fault movements on reservoir characteristics.
    Operations and results
    Appraisal well 31/2-3 was spudded with the semi-submersible installation Borgny Dolphin on 28 March and drilled to TD at 2601 m in Late Triassic sediments in the Statfjord Formation. Drilling took 115 days. The reason for the long drilling period was safety inspection of the rig as a result of the "Alexander Kielland" accident and a strike amongst the Norwegian rig crew. The well was drilled with bentonite and seawater down to 816 m and with a gypsum/lignosulphonate mud from 816 m to TD.
    No potential reservoir zones were encountered above top Jurassic. The well confirmed that the Late Jurassic sandstone reservoir encountered in wells 31/2-1 and 2 was well developed also in this more northerly part of the structure. A gross gas column of 189 m was penetrated with top at 1384 m. The uppermost 120 m was in a good clean sand (Sognefjord Formation) while the lower part of the gas column was in a micaceous and poor reservoir sand (Heather and Fensfjord Formations). Below the gas a 12 m thick oil zone was encountered, the same thickness and at the same level as in well 31/2-2. In this well however, the oil was in a very micaceous and poorly developed reservoir. The reservoir was uncomformably overlain by Palaeocene claystones, which thus act as an effective seal for the reservoir. Below the OWC at 1585 no moveable hydrocarbons were seen in the well, but shows continued down to 1612 m and isolated shows were seen at 1630 m and at 1638 m.
    The seismic Flatspot did coincide with the base of the gas column in well 31/2-3, supporting that the Flatspot indeed is a direct hydrocarbon indicator over the entire prospect.
    Coring was performed in the Middle to Late Jurassic interval from 1412 m to 1645.5 m. Twenty-one cores with a total recovery of 194.4 m (84%) were cut. Coring started approximately 28 m below the top reservoir and continued well below the hydrocarbon/water contact. Prior to the full scale production test programme, a series of runs were made with the Schlumberger Repeat Formation Tester (RFT). A total of 10 RFT runs were made. The first run indicated pressure gradients very similar to those obtained in Wells 31/2-1 and 31/2-2. It was, however, impossible to confirm the 12-meter oil gradient indicated by RFT's in well 31/2-2. Sampling attempts in the water zone failed as only mud filtrate was recovered. In the suspected oil zone, no samples were obtained in spite of numerous attempts as the tool probe always plugged in the relatively tight and poorly consolidated formation. Only two gas samples were obtained, at 1458 m and 1568.5 m.
    The well was permanently abandoned on 20 July 1980 as a gas and oil appraisal well.
    Testing
    Four Production Tests were conducted in the Middle to Late Jurassic. PT1 tested the interval 1600.5 m to 1605.5 m in the water zone, PT2 tested the interval 1577.5 m to 1582.5 m in the oil zone, PT3 tested the interval 1520 m to 1535 m in the micaceous part of the gas bearing section, and PT4 tested 1435 m to 1460 m in the top clean sand of the gas section.
    After the bottom hole test valve was opened for the test in the water zone, the well flowed for 17 minutes until it died. Some 87.5 litres of formation water (70.000 ppm NaCl equivalent) were recovered.
    In the oil zone test (PT2) the well came in at a low rate and flowed at about 4.5 - 6.6 Sm3/day for four days. The oil was about 24 deg API and the GOR around 36 Sm3/Sm3. The micaceous gas zone test (PT3) stabilized at a rate of about 142000 Sm3/day on 28/64" choke during the clean up period. The produced fluids were gas of gravity 0.617 (air = 1) and condensate of 50.3 API, with some water (mostly brine) and traces of sediment. The gas contained no detectable H2S and approximately 0.4% C02. Sequential rate tests followed where the rates continuously improved up to 923000 Sm3/day. The test was terminated while production rates were still increasing. The reason for the increasing rates was assumed to be development of a channel behind the casing creating communication with the better sand some 10 meters above the top of the perforations. The clean sand gas test was performed with a gravel pack completion. Severe turbulence effects dominated it. After the initial clean up at 368000 - 481000 Sm3/day flow rate, the well produced at maximum rate of about 1133000 Sm3/day. The fluids had similar composition as in PT3.
    Temperatures measured during the test gave a formation temperature of 60 - 62 deg C in the gas-bearing section of the reservoir. This corresponds to a linear temperature gradient from seafloor to top reservoir of ca 50 deg C, which is very high for the area.
  • 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]
    460.00
    2599.00
  • 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
    1412.0
    1415.5
    [m ]
    2
    1421.0
    1425.0
    [m ]
    3
    1425.0
    1441.0
    [m ]
    4
    1443.0
    1449.3
    [m ]
    5
    1450.0
    1461.2
    [m ]
    6
    1462.4
    1467.8
    [m ]
    8
    1469.2
    1473.0
    [m ]
    9
    1473.0
    1475.0
    [m ]
    10
    1484.5
    1496.4
    [m ]
    11
    1496.4
    1514.5
    [m ]
    12
    1514.5
    1529.6
    [m ]
    13
    1533.0
    1540.9
    [m ]
    14
    1551.0
    1564.5
    [m ]
    15
    1564.5
    1566.5
    [m ]
    16
    1566.6
    1584.3
    [m ]
    17
    1584.0
    1599.7
    [m ]
    18
    1601.0
    1619.3
    [m ]
    19
    1619.0
    1623.9
    [m ]
    20
    1624.0
    1627.7
    [m ]
    21
    1628.0
    1645.4
    [m ]
    22
    2116.0
    2133.9
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    216.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 1412-1414m
    Core photo at depth: 1414-1416m
    Core photo at depth: 1421-1423m
    Core photo at depth: 1423-1425m
    Core photo at depth: 1425-1427m
    1412-1414m
    1414-1416m
    1421-1423m
    1423-1425m
    1425-1427m
    Core photo at depth: 1427-1430m
    Core photo at depth: 1430-1433m
    Core photo at depth: 1433-1435m
    Core photo at depth: 1435-1438m
    Core photo at depth: 1438-1441m
    1427-1430m
    1430-1433m
    1433-1435m
    1435-1438m
    1438-1441m
    Core photo at depth: 1443-1445m
    Core photo at depth: 1445-1448m
    Core photo at depth: 1448-1449m
    Core photo at depth: 1450-1452m
    Core photo at depth: 1452-1455m
    1443-1445m
    1445-1448m
    1448-1449m
    1450-1452m
    1452-1455m
    Core photo at depth: 1455-1458m
    Core photo at depth: 1458-1460m
    Core photo at depth: 1460-1461m
    Core photo at depth: 1462-1463m
    Core photo at depth: 1469-1471m
    1455-1458m
    1458-1460m
    1460-1461m
    1462-1463m
    1469-1471m
    Core photo at depth: 1471-1473m
    Core photo at depth: 1473-1475m
    Core photo at depth: 1484-1487m
    Core photo at depth: 1487-1489m
    Core photo at depth: 1489-1492m
    1471-1473m
    1473-1475m
    1484-1487m
    1487-1489m
    1489-1492m
    Core photo at depth: 1492-1495m
    Core photo at depth: 1495-1496m
    Core photo at depth: 1496-1499m
    Core photo at depth: 1499-1501m
    Core photo at depth: 1501-1504m
    1492-1495m
    1495-1496m
    1496-1499m
    1499-1501m
    1501-1504m
    Core photo at depth: 1504-1507m
    Core photo at depth: 1507-1509m
    Core photo at depth: 1509-1512m
    Core photo at depth: 1512-1514m
    Core photo at depth: 1514-1517m
    1504-1507m
    1507-1509m
    1509-1512m
    1512-1514m
    1514-1517m
    Core photo at depth: 1517-1519m
    Core photo at depth: 1519-1522m
    Core photo at depth: 1522-1525m
    Core photo at depth: 1525-1528m
    Core photo at depth: 1528-1529m
    1517-1519m
    1519-1522m
    1522-1525m
    1525-1528m
    1528-1529m
    Core photo at depth: 1533-1535m
    Core photo at depth: 1535-1538m
    Core photo at depth: 1538-1540m
    Core photo at depth: 1551-1553m
    Core photo at depth: 1553-1556m
    1533-1535m
    1535-1538m
    1538-1540m
    1551-1553m
    1553-1556m
    Core photo at depth: 1556-1559m
    Core photo at depth: 1559-1561m
    Core photo at depth: 1561-1564m
    Core photo at depth: 1564-1566m
    Core photo at depth: 1566-1569m
    1556-1559m
    1559-1561m
    1561-1564m
    1564-1566m
    1566-1569m
    Core photo at depth: 1569-1572m
    Core photo at depth: 1572-1574m
    Core photo at depth: 1574-1577m
    Core photo at depth: 1577-1580m
    Core photo at depth: 1580-1582m
    1569-1572m
    1572-1574m
    1574-1577m
    1577-1580m
    1580-1582m
    Core photo at depth: 1582-1584m
    Core photo at depth: 1584-1586m
    Core photo at depth: 1586-1589m
    Core photo at depth: 1589-1592m
    Core photo at depth: 1592-1594m
    1582-1584m
    1584-1586m
    1586-1589m
    1589-1592m
    1592-1594m
    Core photo at depth: 1594-1597m
    Core photo at depth: 1601-1603m
    Core photo at depth: 1603-1606m
    Core photo at depth: 1606-1609m
    Core photo at depth: 1609-1611m
    1594-1597m
    1601-1603m
    1603-1606m
    1606-1609m
    1609-1611m
    Core photo at depth: 1611-1614m
    Core photo at depth: 1614-1617m
    Core photo at depth: 1617-1619m
    Core photo at depth: 1619-1621m
    Core photo at depth: 1621-1623m
    1611-1614m
    1614-1617m
    1617-1619m
    1619-1621m
    1621-1623m
    Core photo at depth: 1624-1626m
    Core photo at depth: 1626-1627m
    Core photo at depth: 1628-1630m
    Core photo at depth: 1730-1633m
    Core photo at depth: 1633-1636m
    1624-1626m
    1626-1627m
    1628-1630m
    1730-1633m
    1633-1636m
    Core photo at depth: 1636-1638m
    Core photo at depth: 1638-1641m
    Core photo at depth: 1641-1644m
    Core photo at depth: 1644-1645m
    Core photo at depth: 2116-2118m
    1636-1638m
    1638-1641m
    1641-1644m
    1644-1645m
    2116-2118m
    Core photo at depth: 2118-2121m
    Core photo at depth: 2121-2124m
    Core photo at depth: 2126-2129m
    Core photo at depth: 2129-2132m
    Core photo at depth: 2132-2133m
    2118-2121m
    2121-2124m
    2126-2129m
    2129-2132m
    2132-2133m
  • 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
    1577.00
    1582.00
    WATER
    06.06.1980 - 20:00
    YES
  • Lithostratigraphy

  • Composite logs

    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.45
  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.29
    pdf
    0.51
  • 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
    35.06
    pdf
    1.29
    pdf
    2.43
    pdf
    0.44
    pdf
    10.79
    pdf
    10.10
    pdf
    0.36
    pdf
    0.06
    pdf
    0.44
    pdf
    0.12
    pdf
    139.86
    pdf
    17.61
    pdf
    20.73
    pdf
    6.05
    pdf
    1.25
    pdf
    0.77
    pdf
    1.51
    pdf
    1.22
    pdf
    1.66
    pdf
    1.43
    pdf
    0.60
    pdf
    0.84
    pdf
    0.54
    pdf
    1.97
    pdf
    2.69
    pdf
    0.50
    pdf
    1.12
    pdf
    0.32
    pdf
    0.71
    pdf
    0.35
    pdf
    0.34
    pdf
    0.33
    pdf
    0.34
    pdf
    0.56
    pdf
    0.28
    pdf
    0.20
    pdf
    0.23
    pdf
    0.38
    pdf
    0.14
    pdf
    0.69
    pdf
    2.60
    pdf
    0.75
    pdf
    2.06
    pdf
    2.29
    pdf
    11.20
    pdf
    6.07
    pdf
    5.32
    pdf
    9.81
    pdf
    3.63
    pdf
    6.10
    pdf
    1.31
  • Drill stem tests (DST)

    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    1575
    1580
    0.0
    2.0
    1552
    1557
    6.4
    3.0
    1495
    1510
    50.8
    4.0
    1410
    1435
    38.1
    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
    3.0
    4.0
    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
    2.0
    14
    560
    0.910
    40
    3.0
    914000
    4.0
    1133000
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL
    350
    1816
    CBL
    630
    1352
    CST
    1
    0
    CST
    2
    0
    CST
    3
    0
    DLL MSFL GR
    1352
    1824
    FDC CNL GR CAL
    445
    818
    FDC CNL GR CAL
    803
    1367
    FDC CNL GR CAL
    1352
    1824
    FDC CNL GR CAL
    1817
    2590
    HDT
    1352
    1819
    HDT
    1817
    2596
    ISF BHC GR SP
    445
    814
    ISF BHC GR SP
    803
    1368
    ISF BHC GR SP
    1352
    1821
    ISF BHC GR SP
    1817
    2593
    LSS GR
    445
    816
    LSS GR
    803
    1364
    LSS GR
    1352
    1819
    LSS GR
    1817
    2594
    RFT
    1387
    1750
  • 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
    420.0
    36
    425.0
    0.00
    LOT
    SURF.COND.
    20
    779.0
    26
    789.0
    1.43
    LOT
    INTERM.
    13 3/8
    1328.0
    17 1/2
    1339.0
    1.55
    LOT
    INTERM.
    9 5/8
    1791.0
    12 1/4
    1798.0
    1.74
    LOT
    LINER
    7
    2576.0
    8 1/2
    2576.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    789
    1.31
    54.0
    seawater
    1338
    1.32
    60.0
    seawater
    1433
    1.28
    52.0
    seawater
    1941
    1.18
    52.0
    seawater
    2267
    1.19
    48.0
    seawater
  • Thin sections at the Norwegian Offshore Directorate

    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    1414.40
    [m ]
    1432.80
    [m ]
    1443.45
    [m ]
    1450.20
    [m ]
    1471.25
    [m ]
    1486.90
    [m ]
    1492.80
    [m ]
    1505.10
    [m ]
    1534.35
    [m ]
    1540.40
    [m ]
    1553.70
    [m ]
    1558.45
    [m ]
    1563.90
    [m ]
    1565.65
    [m ]
    1568.65
    [m ]
    7574.45
    [m ]
    1574.45
    [m ]
    1579.86
    [m ]
    1585.79
    [m ]
    7586.92
    [m ]
    1586.92
    [m ]
    1590.54
    [m ]
    1599.08
    [m ]
    1609.86
    [m ]
    1615.50
    [m ]
    1623.24
    [m ]
    1628.12
    [m ]
    1414.00
    [m ]
    1433.00
    [m ]
    1443.00
    [m ]
    1450.00
    [m ]
    1471.00
    [m ]
    1487.00
    [m ]
    1493.00
    [m ]
    1505.00
    [m ]
    1513.00
    [m ]
    1523.00
    [m ]
    1534.00
    [m ]
    1540.00
    [m ]
    1554.00
    [m ]
    1558.00
    [m ]
    1564.00
    [m ]
    1566.00
    [m ]
    1569.00
    [m ]
    1575.00
    [m ]
    1580.00
    [m ]
    1586.00
    [m ]
    1587.00
    [m ]
    1628.00
    [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
    0.22