Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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sodir.no          Norsk
23.11.2024 - 01:30
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25/7-5

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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.
    25/7-5
    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.
    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.
    25/7-5
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 9603- INLINE 1156 & CROSSLINE 5382
    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.
    Norsk Hydro Produksjon 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.
    896-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.
    46
    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,
    16.07.1997
    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.
    30.08.1997
    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.
    30.08.1999
    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.
    29.05.2002
    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
    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.
    PALEOCENE
    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.
    HERMOD 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.
    PALEOCENE
    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.
    HEIMDAL 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.
    124.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2736.0
    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).
    2735.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    99
    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.
    PALEOCENE
    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.
    VÅLE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 29' 39.81'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 1' 3.44'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6595668.94
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    444369.86
    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.
    3132

  • Wellbore history
    General
    Well 25/7-5 was the first exploration well drilled in PL203 and was designed to test the hydrocarbon potential of a sand prospect within the Sele Formation in the northwest corner of block 25/7. This prospect was a stratigraphic trap with structural elements formed by the pinch out of the Hermod T80 sand. Oil was prognosed to be encountered within the Hermod T80 sand. A very small closure in the top of the underlying Heimdal sand was also expected to contain hydrocarbons, but this closure was not defined as a secondary target due to the small volumes expected within the structure. The well commitment was to drill to a total depth of 2735 m within the Shetland Group. The objectives of the well were to test commercial oil volumes within the Hermod T80 sand, to test the geological and geophysical models for the presence of the Hermod T80 sand, and to test the model for hydrocarbon migration within the license area.
    Operations and results
    The semi-submersible drilling rig "West Vanguard" was used to drill wildcat well 25/7-5. The well was spudded 16 July 1997 and reached a total depth of 2736m on the 7 August 1997 in the Early Paleocene Våle Formation The well was drilled water based with spud mud to 1338 m and with the ANCO 2000 mud system from 1338 m to TD. Total rig time for the well, including testing, was 46.7 days.

    Oil was encountered within the Hermod T80 sands between 2044 - 2052 m. There was 3.5 m of net reservoir within the interval (N/G 0,4372) with an average porosity of 0.25 and an excellent permeability of up to 6 Darcy. The rest of the non-reservoir sand was tightly cemented with calcite. No Oil-Water contact was seen in these sands.
    The Heimdal formation was penetrated at 2126 m and contained approximately 1m of oil in the top of the reservoir (0.85 gm/cc density). The reservoir quality of these sands is excellent with an average porosity of 0.234 and permeabilities in the low Darcy range. Approximately 6m of residual hydrocarbons were found under the Oil-Water contact at 2127m. The well was cored (11 cores) from 1976m in the top of the Balder Formation tuffaceous clay stone unit and down through the Sele, Hermod and Lista formations and into the Heimdal sands. Coring was stopped at 2150m, 24m into the Heimdal Formation. Core recovery was generally excellent. MDT oil samples were taken at 2045.4 m and 2116.4 m. MDT samples containing both water and oil were taken at 2126.3 m and 2126.6 m, while MDT samples containing only water was taken at 2127.1 m

    The well was permanently plugged and abandoned as an oil discovery on 30 August 1997.
    Testing
    One Drill Stem test was performed over the Hermod T80 sands (perforation 2043 - 2052 m) with a stable flow rate of 900 Sm3 oil/day through a 48/64"choke. The GOR was 88 Sm3 /Sm3 and the oil gravity was 0.870 gm/cc. Traces of produced sand and water were found in the oil.

  • 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]
    1350.00
    2737.00

  • 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
    2
    1977.0
    1983.0
    [m ]
    3
    1983.0
    2002.8
    [m ]
    4
    2003.0
    2031.5
    [m ]
    5
    2031.5
    2048.0
    [m ]
    6
    2048.0
    2057.5
    [m ]
    7
    2058.0
    2059.7
    [m ]
    8
    2060.0
    2076.1
    [m ]
    9
    2078.0
    2084.7
    [m ]
    10
    2093.0
    2122.0
    [m ]
    11
    2122.0
    2149.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    161.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1977-1982m
    Core photo at depth: 1982-1983m
    Core photo at depth: 1983-1988m
    Core photo at depth: 1988-1993m
    Core photo at depth: 1993-1998m
    1977-1982m
    1982-1983m
    1983-1988m
    1988-1993m
    1993-1998m
    Core photo at depth: 1998-2002m
    Core photo at depth: 2003-2008m
    Core photo at depth: 2008-2013m
    Core photo at depth: 2013-2018m
    Core photo at depth: 2018-2023m
    1998-2002m
    2003-2008m
    2008-2013m
    2013-2018m
    2018-2023m
    Core photo at depth: 2028-2031m
    Core photo at depth: 2031-2036m
    Core photo at depth: 2036-2041m
    Core photo at depth: 2041-2046m
    Core photo at depth: 2046-2048m
    2028-2031m
    2031-2036m
    2036-2041m
    2041-2046m
    2046-2048m
    Core photo at depth: 2048-2053m
    Core photo at depth: 2053-2057m
    Core photo at depth: 2058-2060m
    Core photo at depth: 2060-2065m
    Core photo at depth: 2065-2070m
    2048-2053m
    2053-2057m
    2058-2060m
    2060-2065m
    2065-2070m
    Core photo at depth: 2070-2075m
    Core photo at depth: 2075-2076m
    Core photo at depth: 2078-2083m
    Core photo at depth: 2083-2084m
    Core photo at depth: 2093-2098m
    2070-2075m
    2075-2076m
    2078-2083m
    2083-2084m
    2093-2098m
    Core photo at depth: 2098-2103m
    Core photo at depth: 2103-2108m
    Core photo at depth: 2108-2113m
    Core photo at depth: 2113-2118m
    Core photo at depth: 2118-2122m
    2098-2103m
    2103-2108m
    2108-2113m
    2113-2118m
    2118-2122m
    Core photo at depth: 2122-2127m
    Core photo at depth: 2127-2132m
    Core photo at depth: 2132-2137m
    Core photo at depth: 2137-2142m
    Core photo at depth: 2142-2147m
    2122-2127m
    2127-2132m
    2132-2137m
    2137-2142m
    2142-2147m
    Core photo at depth: 2147-2150m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2147-2150m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1350.0
    [m]
    DC
    RRI
    1370.0
    [m]
    DC
    RRI
    1390.0
    [m]
    DC
    RRI
    1410.0
    [m]
    DC
    RRI
    1430.0
    [m]
    DC
    RRI
    1460.0
    [m]
    DC
    RRI
    1470.0
    [m]
    DC
    RRI
    1490.0
    [m]
    DC
    RRI
    1510.0
    [m]
    DC
    RRI
    1530.0
    [m]
    DC
    RRI
    1550.0
    [m]
    DC
    RRI
    1570.0
    [m]
    DC
    RRI
    1590.0
    [m]
    DC
    RRI
    1610.0
    [m]
    DC
    RRI
    1630.0
    [m]
    DC
    RRI
    1650.0
    [m]
    DC
    RRI
    1670.0
    [m]
    DC
    RRI
    1690.0
    [m]
    DC
    RRI
    1710.0
    [m]
    DC
    RRI
    1730.0
    [m]
    DC
    RRI
    1750.0
    [m]
    DC
    RRI
    1770.0
    [m]
    DC
    RRI
    1790.0
    [m]
    DC
    RRI
    1810.0
    [m]
    DC
    RRI
    1830.0
    [m]
    SWC
    RRI
    1850.0
    [m]
    SWC
    RRI
    1860.0
    [m]
    SWC
    RRI
    1870.0
    [m]
    DC
    RRI
    1870.0
    [m]
    SWC
    RRI
    1875.0
    [m]
    SWC
    RRI
    1880.0
    [m]
    DC
    RRI
    1890.0
    [m]
    DC
    RRI
    1890.0
    [m]
    SWC
    RRI
    1900.0
    [m]
    DC
    RRI
    1901.0
    [m]
    SWC
    RRI
    1907.0
    [m]
    DC
    RRI
    1914.0
    [m]
    SWC
    RRI
    1927.0
    [m]
    DC
    RRI
    1937.0
    [m]
    DC
    RRI
    1947.0
    [m]
    DC
    RRI
    1951.0
    [m]
    SWC
    RRI
    1957.0
    [m]
    DC
    RRI
    1977.0
    [m]
    C
    RRI
    1982.0
    [m]
    C
    RRI
    1988.0
    [m]
    C
    RRI
    1994.0
    [m]
    C
    RRI
    1999.0
    [m]
    C
    RRI
    2005.0
    [m]
    C
    RRI
    2012.0
    [m]
    C
    RRI
    2018.0
    [m]
    C
    RRI
    2019.0
    [m]
    C
    RRI
    2020.0
    [m]
    C
    RRI
    2023.0
    [m]
    C
    RRI
    2028.0
    [m]
    C
    RRI
    2033.0
    [m]
    C
    RRI
    2038.0
    [m]
    C
    RRI
    2044.0
    [m]
    C
    RRI
    2046.0
    [m]
    C
    RRI
    2050.0
    [m]
    C
    RRI
    2052.0
    [m]
    C
    RRI
    2054.0
    [m]
    C
    RRI
    2056.0
    [m]
    C
    RRI
    2057.0
    [m]
    C
    RRI
    2059.0
    [m]
    C
    RRI
    2061.0
    [m]
    C
    RRI
    2063.0
    [m]
    C
    RRI
    2067.0
    [m]
    C
    RRI
    2068.0
    [m]
    C
    RRI
    2072.0
    [m]
    C
    RRI
    2075.0
    [m]
    DC
    RRI
    2078.0
    [m]
    C
    RRI
    2084.0
    [m]
    C
    RRI
    2093.0
    [m]
    C
    RRI
    2096.0
    [m]
    C
    RRI
    2102.0
    [m]
    C
    RRI
    2108.0
    [m]
    C
    RRI
    2114.0
    [m]
    C
    RRI
    2120.0
    [m]
    C
    RRI
    2125.0
    [m]
    C
    RRI
    2127.0
    [m]
    C
    RRI
    2137.0
    [m]
    C
    RRI
    2141.0
    [m]
    C
    RRI
    2147.0
    [m]
    C
    RRI
    2160.0
    [m]
    DC
    RRI
    2170.0
    [m]
    DC
    RRI
    2180.0
    [m]
    DC
    RRI
    2190.0
    [m]
    DC
    RRI
    2196.0
    [m]
    SWC
    RRI
    2210.0
    [m]
    DC
    RRI
    2222.0
    [m]
    DC
    RRI
    2226.0
    [m]
    SWC
    RRI
    2240.0
    [m]
    DC
    RRI
    2250.0
    [m]
    DC
    RRI
    2260.0
    [m]
    DC
    RRI
    2270.0
    [m]
    DC
    RRI
    2275.0
    [m]
    SWC
    RRI
    2280.0
    [m]
    SWC
    RRI
    2290.0
    [m]
    DC
    RRI
    2300.0
    [m]
    DC
    RRI
    2310.0
    [m]
    DC
    RRI
    2320.0
    [m]
    DC
    RRI
    2330.0
    [m]
    DC
    RRI
    2340.0
    [m]
    DC
    RRI
    2350.0
    [m]
    DC
    RRI
    2360.0
    [m]
    DC
    RRI
    2370.0
    [m]
    DC
    RRI
    2380.0
    [m]
    DC
    RRI
    2390.0
    [m]
    DC
    RRI
    2400.0
    [m]
    DC
    RRI
    2410.0
    [m]
    DC
    RRI
    2420.0
    [m]
    DC
    RRI
    2430.0
    [m]
    DC
    RRI
    2440.0
    [m]
    DC
    RRI
    2460.0
    [m]
    DC
    RRI
    2470.0
    [m]
    DC
    RRI
    2480.0
    [m]
    DC
    RRI
    2490.0
    [m]
    DC
    RRI
    2500.0
    [m]
    DC
    RRI
    2510.0
    [m]
    DC
    RRI
    2520.0
    [m]
    DC
    RRI
    2535.0
    [m]
    DC
    RRI
    2545.0
    [m]
    DC
    RRI
    2555.0
    [m]
    DC
    RRI
    2565.0
    [m]
    DC
    RRI
    2609.0
    [m]
    SWC
    RRI
    2648.0
    [m]
    SWC
    RRI
    2661.0
    [m]
    SWC
    RRI

  • 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
    2043.00
    2052.00
    18.08.1997 - 06:32
    YES

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    146
    410
    702
    1184
    1324
    1915
    1915
    2017
    2044
    2061
    2071
    2126
    2490
    2526
    2688

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.34

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.84
    pdf
    1.95
    pdf
    1.90
    pdf
    1.98
    pdf
    1.88
    pdf
    0.14

  • 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
    8.98
    pdf
    15.94

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2043
    2052
    17.5
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    7.000
    5.260
    18.981
    67
    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
    900
    78000
    0.870
    0.671
    88

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL AMS GR
    1205
    1876
    CST AMS GR
    1870
    2704
    FMI DSI AMS GR
    1810
    2730
    MDT ACTS GR
    2044
    2625
    MWD DPR GR-DIR
    146
    2736
    PEX NGT
    1810
    2732
    VSP
    1400
    2730

  • 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
    207.5
    36
    209.0
    0.00
    LOT
    INTERM.
    13 3/8
    1332.0
    17 1/2
    1338.0
    0.00
    LOT
    INTERM.
    9 5/8
    1860.0
    12 1/4
    1866.0
    0.00
    LOT
    LINER
    7
    2736.0
    8 1/2
    2736.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    209
    1.06
    WATER BASED
    350
    1.27
    17.0
    WATER BASED
    671
    1.06
    WATER BASED
    702
    1.06
    WATER BASED
    850
    1.27
    17.0
    WATER BASED
    1221
    1.06
    WATER BASED
    1338
    1.45
    29.0
    WATER BASED
    1341
    1.45
    23.0
    WATER BASED
    1800
    1.21
    15.0
    WATER BASED
    1886
    1.45
    26.0
    WATER BASED
    1986
    1.20
    17.0
    WATER BASED
    2058
    1.20
    19.0
    WATER BASED
    2060
    1.23
    18.0
    WATER BASED
    2093
    1.25
    19.0
    WATER BASED
    2144
    1.21
    17.0
    WATER BASED
    2148
    1.25
    19.0
    WATER BASED
    2148
    1.21
    18.0
    WATER BASED
    2491
    1.23
    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
    0.22