Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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05.11.2024 - 01:27
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6507/8-4

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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.
    6507/8-4
    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.
    NORWEGIAN 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.
    6507/8-4
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    CN 8502-211 SP.568
    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.
    631-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.
    61
    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,
    14.06.1990
    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.
    13.08.1990
    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.
    13.08.1992
    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.
    17.09.2007
    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.
    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.
    ÅRE 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.
    354.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2560.0
    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).
    2559.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    86
    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.
    GREY BEDS (INFORMAL)
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    65° 23' 17.18'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 23' 59.65'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7252835.58
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    425643.79
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    32
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    1340

  • Wellbore history
    General
    Well 6507/8-4 was designed to drill the Heidrun North Structure, a horst block northeast of the Heidrun Field situated in the transition zone between the Nordland Ridge to the north and the Halten Terrace to the southwest. The primary objective of the well was to test sandstones of Early Jurassic age. The well would also test the geophysical and structural interpretation and improve the paleontological, geological and geochemical understanding of the area.
    Shallow gas warning was given at 608 m, 745 m and 686 m, the last one classified as a medium/ high risk anomaly. Problems with gumbo clay and sloughing shale had been experienced in the Eocene / Paleocene sections in the Haltenbanken area.
    Operations and results
    Wildcat well 6507/8-4 was spudded with the semi-submersible installation Deepsea Bergen on 14 June 1990 and drilled to TD at 2560 m in the Triassic Grey Beds. Apart from some tight hole spots, drilling proceeded without significant problems. The well was drilled with seawater and hi-vis sweeps down to 654 m, with seawater and CMC EHV mud from 654 m to 1555 m, with gypsum/polymer mud from 1555 m to 2100 m, and with gel/ligno mud from 2100 m to TD. Shallow gas was encountered at 596 m and at 686 m.
    The only shows reported above the target reservoir were on claystones at 2102 m and at 2104 m. Top reservoir (Åre Formation) was encountered directly underlying Late Cretaceous sediments at 2124 m. The hiatus was from the Early Jurassic, Sinemurian to the Late Cretaceous, Santonian. The well proved gas and oil in the Åre formation. The GOC was set at 2142 m and the OWC at 2251.5 m. Shows continued down to 2290 m.
    A total of 170.25 m core was recovered in eleven cores, all from the Åre Formation in the interval 2128 to 2318 m. Twenty-five sidewall cores were attempted and 22 were recovered. An FMT fluid sample was taken at 2158.5 m. It contained only 500 cc mud filtrate due to plugging. Another sample was taken at 2133.7 m and contained oil, mud filtrate and some water.
    The well was abandoned on 13 August 1990 as a gas and oil discovery.
    Testing
    A number of tests were performed in the Åre Formation.
    No 1 tested the interval 2250 to 2254 m. The interval produced only small quantities of water.
    No 2 tested two intervals.
    Test 2.1 tested the interval 2200 to 2202 m, which produced 1023.8 Sm3 oil and 58700 Sm3 gas /day through a 48/64" choke. The GOR was 59 Sm3/Sm3, the oil gravity was 0.905 g/cm3 (24.9 deg API), and the gas gravity was 0.644 (air = 1). The bottom hole temperature was 76 deg C.
    Test 2.2 tested the interval 2204 to 2221 m, which produced 1395.3 Sm3 oil and 60900 Sm3 gas /day through a 52/64" choke. The GOR was 51 Sm3/Sm3, the oil gravity was 0.904 g/cm3 (25 deg API), and the gas gravity was 0.642 (air = 1). The bottom hole temperature was 76 deg C.
    No 3 tested two intervals.
    Test no 3.1 tested the interval 2150 to 2161.5 m, which produced 1480 Sm3 oil and 70100 Sm3 gas /day through a 56/64" choke. The GOR was 61 Sm3/Sm3, the oil gravity was 0.904 g/cm3 (25 deg API), and the gas gravity was 0.635 (air = 1). The bottom hole temperature was 75 deg C.
    Test no 3.2 tested the interval 2163.5 to 2168 m, which produced 986 Sm3 oil and 45300 Sm3 gas /day through a 40/64" choke. The GOR was 56 Sm3/Sm3, the oil gravity was 0.904 g/cm3 (25 deg API), and the gas gravity was 0.635 (air = 1). The bottom hole temperature was 75.5 deg C.
    No 4 tested the interval 2126 to 2135 m which produced 16.1 Sm3 condensate and 756777 Sm3 Gas /day through a 40/64" choke. The GOR was 47078 Sm3/Sm3, the condensate gravity was 0.78 g/cm3 (49.9 deg API), and the gas gravity was 0.648 (air = 1). The bottom hole temperature was 73.8 deg C.
    All tests produced sand, filling up the separator several times.

  • 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]
    584.00
    2560.00

  • 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
    2128.0
    2150.0
    [m ]
    2
    2155.0
    2171.0
    [m ]
    3
    2172.0
    2185.0
    [m ]
    4
    2185.0
    2198.0
    [m ]
    5
    2200.0
    2205.0
    [m ]
    6
    2207.0
    2226.0
    [m ]
    7
    2227.0
    2245.0
    [m ]
    8
    2246.0
    2264.0
    [m ]
    9
    2265.0
    2291.2
    [m ]
    10
    2292.0
    2295.6
    [m ]
    11
    2301.0
    2317.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    170.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2128-2133m
    Core photo at depth: 2133-2138m
    Core photo at depth: 2138-2143m
    Core photo at depth: 2143-2148m
    Core photo at depth: 2148-2150m
    2128-2133m
    2133-2138m
    2138-2143m
    2143-2148m
    2148-2150m
    Core photo at depth: 2155-2160m
    Core photo at depth: 2160-2165m
    Core photo at depth: 2165-2170m
    Core photo at depth: 2170-2171m
    Core photo at depth: 2172-2177m
    2155-2160m
    2160-2165m
    2165-2170m
    2170-2171m
    2172-2177m
    Core photo at depth: 2177-2182m
    Core photo at depth: 2182-2185m
    Core photo at depth: 2185-2190m
    Core photo at depth: 2190-2195m
    Core photo at depth: 2195-2198m
    2177-2182m
    2182-2185m
    2185-2190m
    2190-2195m
    2195-2198m
    Core photo at depth: 2200-2205m
    Core photo at depth: 2205-2205m
    Core photo at depth: 2207-2212m
    Core photo at depth: 2212-2217m
    Core photo at depth: 2217-2222m
    2200-2205m
    2205-2205m
    2207-2212m
    2212-2217m
    2217-2222m
    Core photo at depth: 2222-2226m
    Core photo at depth: 2227-2232m
    Core photo at depth: 2232-2237m
    Core photo at depth: 2237-2242m
    Core photo at depth: 2242-2245m
    2222-2226m
    2227-2232m
    2232-2237m
    2237-2242m
    2242-2245m
    Core photo at depth: 2246-2251m
    Core photo at depth: 2251-2256m
    Core photo at depth: 2256-2261m
    Core photo at depth: 2261-2264m
    Core photo at depth: 2265-2270m
    2246-2251m
    2251-2256m
    2256-2261m
    2261-2264m
    2265-2270m
    Core photo at depth: 2270-2275m
    Core photo at depth: 2275-2280m
    Core photo at depth: 2280-2285m
    Core photo at depth: 2285-2290m
    Core photo at depth: 2290-2291m
    2270-2275m
    2275-2280m
    2280-2285m
    2285-2290m
    2290-2291m
    Core photo at depth: 2292-2295m
    Core photo at depth: 2301-2306m
    Core photo at depth: 2306-2311m
    Core photo at depth: 2311-2316m
    Core photo at depth: 2316-2317m
    2292-2295m
    2301-2306m
    2306-2311m
    2311-2316m
    2316-2317m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1504.0
    [m]
    DC
    STRAT
    1554.0
    [m]
    DC
    STRAT
    1574.0
    [m]
    DC
    STRAT
    1594.0
    [m]
    DC
    STRAT
    1654.0
    [m]
    DC
    STRAT
    1704.0
    [m]
    DC
    STRAT
    1714.0
    [m]
    DC
    STRAT
    1721.0
    [m]
    SWC
    STATO
    1734.0
    [m]
    DC
    STRAT
    1754.0
    [m]
    DC
    STRAT
    1779.0
    [m]
    DC
    STATO
    1784.0
    [m]
    DC
    STRAT
    1794.0
    [m]
    DC
    STRAT
    1810.0
    [m]
    SWC
    STATO
    1830.0
    [m]
    SWC
    STATO
    1840.0
    [m]
    SWC
    STATO
    1850.0
    [m]
    DC
    STRAT
    1858.0
    [m]
    SWC
    STATO
    1870.0
    [m]
    DC
    STRAT
    1880.0
    [m]
    SWC
    STATO
    1890.0
    [m]
    DC
    STRAT
    1900.0
    [m]
    SWC
    STATO
    1910.0
    [m]
    DC
    STRAT
    1920.0
    [m]
    SWC
    STATO
    1925.0
    [m]
    DC
    STRAT
    1940.0
    [m]
    SWC
    STATO
    1950.0
    [m]
    SWC
    STATO
    1962.0
    [m]
    SWC
    STATO
    1970.0
    [m]
    SWC
    STATO
    1980.0
    [m]
    DC
    STRAT
    1986.0
    [m]
    SWC
    STATO
    1990.0
    [m]
    DC
    STRAT
    2000.0
    [m]
    SWC
    STATO
    2014.0
    [m]
    SWC
    STATO
    2020.0
    [m]
    SWC
    STATO
    2025.0
    [m]
    DC
    STRAT
    2030.0
    [m]
    SWC
    STATO
    2040.0
    [m]
    SWC
    STATO
    2050.0
    [m]
    SWC
    STATO
    2065.0
    [m]
    DC
    STRAT
    2070.0
    [m]
    DC
    STATO
    2080.0
    [m]
    DC
    STRAT
    2092.0
    [m]
    DC
    STRAT
    2110.0
    [m]
    DC
    STRAT
    2125.0
    [m]
    DC
    STRAT
    2132.2
    [m]
    C
    STATO
    2133.5
    [m]
    C
    STATO
    2136.4
    [m]
    C
    STATO
    2144.0
    [m]
    C
    STATO
    2149.7
    [m]
    C
    STATO
    2163.5
    [m]
    C
    STATO
    2172.4
    [m]
    C
    STATO
    2177.5
    [m]
    C
    STATO
    2182.8
    [m]
    C
    STATO
    2186.3
    [m]
    C
    STATO
    2188.4
    [m]
    C
    STATO
    2195.7
    [m]
    C
    STATO
    2202.8
    [m]
    C
    STATO
    2209.4
    [m]
    C
    STATO
    2214.7
    [m]
    C
    STATO
    2222.5
    [m]
    C
    STATO
    2228.5
    [m]
    C
    STATO
    2232.9
    [m]
    C
    STATO
    2237.8
    [m]
    C
    STATO
    2243.6
    [m]
    C
    STATO
    2246.8
    [m]
    C
    STATO
    2246.8
    [m]
    C
    STATO
    2251.4
    [m]
    C
    STATO
    2252.0
    [m]
    C
    STATO
    2257.4
    [m]
    C
    STATO
    2259.6
    [m]
    C
    STATO
    2261.3
    [m]
    C
    STATO
    2281.3
    [m]
    C
    STATO
    2283.7
    [m]
    C
    STATO
    2290.7
    [m]
    C
    STATO
    2303.3
    [m]
    C
    STATO
    2307.6
    [m]
    C
    STATO
    2311.4
    [m]
    C
    STATO
    2313.1
    [m]
    C
    STATO
    2314.5
    [m]
    C
    STATO
    2320.0
    [m]
    DC
    STRAT
    2335.0
    [m]
    DC
    STRAT
    2356.0
    [m]
    DC
    STRAT
    2368.0
    [m]
    DC
    STRAT
    2380.0
    [m]
    DC
    STRAT
    2398.0
    [m]
    DC
    STRAT
    2410.0
    [m]
    DC
    STRAT
    2428.0
    [m]
    DC
    STRAT
    2446.0
    [m]
    DC
    STRAT
    2458.0
    [m]
    DC
    STRAT
    2473.0
    [m]
    DC
    STRAT
    2488.0
    [m]
    DC
    STRAT
    2503.0
    [m]
    DC
    STRAT
    2518.0
    [m]
    DC
    STRAT
    2534.0
    [m]
    DC
    STRAT
    2545.0
    [m]
    DC
    STRAT
    2552.0
    [m]
    DC
    STRAT
    2560.0
    [m]
    DC
    STRAT
    2560.0
    [m]
    DC
    STATO

  • 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
    TEST2
    2200.00
    2221.00
    25.07.1990 - 12:00
    YES
    DST
    TEST3
    2163.50
    2168.00
    30.07.1990 - 23:00
    YES
    DST
    TEST4
    2126.00
    2135.00
    07.08.1990 - 23:55
    YES

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    377
    1455
    1788
    1788
    1951
    1951
    1974
    2018
    2124
    2124
    2435

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.13
    pdf
    0.07
    pdf
    0.13
    pdf
    0.04
    pdf
    0.30
    pdf
    0.75

  • 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
    15.29

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2250
    2254
    12.7
    1.1
    2250
    2254
    6.3
    2.0
    2200
    2221
    12.7
    3.0
    2150
    2168
    19.1
    3.1
    2163
    2168
    22.2
    4.0
    2126
    2135
    15.9
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    1.1
    2.0
    3.0
    3.1
    4.0
    56.000
    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
    1.1
    2.0
    1024
    58700
    0.900
    0.685
    59
    3.0
    986
    45300
    0.908
    0.635
    55
    3.1
    1480
    70100
    0.908
    0.634
    61
    4.0
    16
    756777
    0.780
    0.648
    47078

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    377
    1534
    CBL VDL GR
    1046
    2081
    CBL VDL GR
    1835
    2490
    CDL CNL GR
    2081
    2543
    CDL GR
    377
    1538
    CDL GR
    1534
    2078
    DIFL ACL GR CAL
    377
    2560
    DIPLOG
    2075
    2552
    FMT GR
    2125
    2298
    MWD - GR RES DIR
    437
    2560
    SWC
    1721
    2088
    VELOCITY
    700
    2500

  • 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
    437.0
    36
    441.0
    0.00
    LOT
    INTERM.
    20
    564.7
    26
    574.0
    1.32
    LOT
    INTERM.
    13 3/8
    1533.0
    17 1/2
    1555.0
    1.66
    LOT
    INTERM.
    9 5/8
    2084.0
    12 1/4
    2100.0
    1.77
    LOT
    LINER
    7
    2546.0
    8 1/2
    2560.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1101
    1.20
    10.0
    5.0
    WATER BASED
    25.06.1990
    1550
    1.20
    7.0
    3.0
    WATER BASED
    28.06.1990
    1555
    1.22
    10.0
    5.0
    WATER BASED
    25.06.1990
    1555
    1.20
    7.0
    3.5
    WATER BASED
    26.06.1990
    1555
    1.18
    7.0
    3.5
    WATER BASED
    27.06.1990
    1770
    1.35
    16.0
    6.0
    WATER BASED
    28.06.1990
    1850
    1.35
    18.0
    7.0
    WATER BASED
    02.07.1990
    1850
    1.35
    19.0
    5.5
    WATER BASED
    04.07.1990
    1850
    1.35
    WATER BASED
    09.07.1990
    1850
    1.35
    WATER BASED
    04.07.1990
    1850
    1.35
    WATER BASED
    04.07.1990
    1880
    1.35
    19.0
    6.0
    WATER BASED
    04.07.1990
    2100
    1.38
    19.0
    6.0
    WATER BASED
    04.07.1990
    2100
    1.45
    19.0
    5.5
    WATER BASED
    04.07.1990
    2100
    1.38
    18.0
    7.0
    WATER BASED
    02.07.1990
    2100
    1.45
    WATER BASED
    04.07.1990
    2100
    1.45
    WATER BASED
    04.07.1990
    2100
    1.30
    20.0
    3.5
    WATER BASED
    09.07.1990
    2100
    1.30
    WATER BASED
    09.07.1990
    2100
    1.30
    WATER BASED
    09.07.1990
    2100
    1.30
    24.0
    7.5
    WATER BASED
    09.07.1990
    2100
    1.30
    20.0
    5.0
    WATER BASED
    09.07.1990
    2100
    1.30
    26.0
    6.5
    WATER BASED
    09.07.1990
    2100
    1.30
    34.0
    7.0
    WATER BASED
    10.07.1990
    2100
    1.30
    37.0
    6.5
    WATER BASED
    11.07.1990
    2100
    1.30
    28.0
    3.5
    WATER BASED
    12.07.1990
    2100
    1.30
    22.0
    9.0
    WATER BASED
    16.07.1990
    2100
    1.41
    19.0
    6.0
    WATER BASED
    04.07.1990
    2130
    1.30
    23.0
    3.5
    WATER BASED
    16.07.1990
    2130
    1.18
    7.0
    3.0
    WATER BASED
    09.08.1990
    2130
    1.18
    WATER BASED
    10.08.1990
    2130
    1.18
    7.0
    3.0
    WATER BASED
    10.08.1990
    2155
    1.30
    WATER BASED
    09.07.1990
    2160
    1.18
    10.0
    3.5
    WATER BASED
    30.07.1990
    2160
    1.18
    10.0
    3.5
    WATER BASED
    31.07.1990
    2160
    1.18
    10.0
    3.5
    WATER BASED
    02.08.1990
    2160
    1.18
    10.0
    3.5
    WATER BASED
    03.08.1990
    2160
    1.18
    8.0
    3.5
    WATER BASED
    06.08.1990
    2160
    1.18
    10.0
    3.5
    WATER BASED
    02.08.1990
    2160
    1.18
    10.0
    3.5
    WATER BASED
    06.08.1990
    2185
    1.30
    20.0
    3.5
    WATER BASED
    09.07.1990
    2201
    1.30
    23.0
    3.5
    WATER BASED
    16.07.1990
    2201
    1.18
    13.0
    3.5
    WATER BASED
    24.07.1990
    2201
    1.18
    13.0
    3.5
    WATER BASED
    26.07.1990
    2201
    1.18
    11.0
    3.5
    WATER BASED
    27.07.1990
    2217
    1.18
    11.0
    4.0
    WATER BASED
    30.07.1990
    2217
    1.18
    11.0
    4.0
    WATER BASED
    30.07.1990
    2217
    1.18
    11.0
    3.5
    WATER BASED
    30.07.1990
    2227
    1.30
    24.0
    7.5
    WATER BASED
    09.07.1990
    2246
    1.30
    23.0
    3.5
    WATER BASED
    16.07.1990
    2252
    1.18
    14.0
    3.5
    WATER BASED
    23.07.1990
    2252
    1.18
    14.0
    7.0
    WATER BASED
    23.07.1990
    2252
    1.18
    14.0
    3.5
    WATER BASED
    23.07.1990
    2265
    1.30
    20.0
    5.0
    WATER BASED
    09.07.1990
    2307
    1.30
    26.0
    6.5
    WATER BASED
    09.07.1990
    2411
    1.30
    34.0
    7.0
    WATER BASED
    10.07.1990
    2534
    1.30
    37.0
    6.5
    WATER BASED
    11.07.1990
    2560
    1.30
    22.0
    9.0
    WATER BASED
    16.07.1990
    2560
    1.30
    28.0
    3.5
    WATER BASED
    12.07.1990

  • 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
    0.27