Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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25.11.2024 - 01:30
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36/4-1

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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.
    36/4-1
    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.
    NORTH SEA
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    36/4-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    BPN 9401 INLINE 2034 CROSSLINE 1196
    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.
    BP Norway Limited U.A.
    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.
    850-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.
    29
    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,
    03.09.1996
    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.
    01.10.1996
    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.
    01.10.1998
    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.
    15.08.2008
    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.
    DRY
    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
    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.
    261.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2717.0
    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).
    2714.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    79
    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.
    61° 43' 56.6'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    4° 2' 1.29'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6844966.43
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    554617.38
    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.
    2847

  • Wellbore history
    Well 36/4-1 is located in the Sogn Graben, ca 18 km south-east of the Agat field and ca 60 km west-northwest of Florø town in western Norway. The objective was to establish the presence, quality and fluid content of Jurassic target horizons (Fensfjord, Krossfjord, Sognefjord Formations and Brent/Dunlin Groups). The overlying Cretaceous sand of Late Cenomanian/Early Turonian age (k68) provided a secondary target.
    Operations and results
    Wildcat well 36/4-1 was spudded with the semi-submersible installation Mærsk Jutlander on 3 September 1996 and drilled to TD in basement rock. Minor delays in the operations were caused by ROV problems during spud and top hole drilling, and BOP problems while setting the 13 3/8" casing at 1108 m. The well was drilled with sea water and gel down to 1108 m and with KCl/Polymer/GEM (Glycol Enhanced Mud) from 1108 m to TD.
    The Jurassic was encountered at 2361 m and consisted of 351 m of Heather Formation overlying Basement rock. No primary reservoir was penetrated only low porosity thin sands were encountered with no shows. Wire line logging and sampling confirmed absence of Jurassic reservoir in the 36/4-1 prospect. The secondary target was penetrated 38 m high to prognosis and contained 77 m of sand. This sand showed no indications of hydrocarbons and was at hydrostatic pressure. Dull hydrocarbon shows were observed in sandstone stringers in the interval 1920-1990 m within the Cretaceous Kyrre Formation. No shows were encountered in the remaining part of the well. The failure of the primary target was attributed to lack of reservoir within the prospect. The secondary target probably failed due to lack of trap. Hydrostatic pressure within this sand indicated connection up-dip to the shelf and hence no up-dip seal. Apart from the Heather Formation with TOC in the range 1.5 to 4.3% and average HI of 340 mg HC/g TOC, no significant source rock formations were encountered in the well. The Heather Formation was found immature for hydrocarbon generation all through with measured vitrinite reflection and Tmax not exceeding 0.5 and 435 deg C, respectively. The Draupne shales were absent in the well.
    One core was cut at TD from 2715.3 - 2717.4 m to confirm basement lithology. Only 40 cm of core was recovered. The low meterage and poor recovery was caused by hard formation. No wire line fluid samples were taken.
    The well was permanently abandoned on at 2 October 1996 as a dry well.
    Testing
    No drill stem test was performed.

  • 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]
    1110.00
    2712.00

  • 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
    2714.0
    2714.4
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    0.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1110.0
    [m]
    DC
    PETROSTR
    1130.0
    [m]
    DC
    PETROS
    1150.0
    [m]
    DC
    PETROS
    1170.0
    [m]
    DC
    PETROS
    1190.0
    [m]
    DC
    PETROS
    1210.0
    [m]
    DC
    PETROS
    1230.0
    [m]
    DC
    PETROS
    1240.0
    [m]
    DC
    PETROS
    1250.0
    [m]
    DC
    PETROS
    1270.0
    [m]
    DC
    PETROS
    1280.0
    [m]
    DC
    PETROS
    1290.0
    [m]
    DC
    PETROS
    1310.0
    [m]
    DC
    PETROS
    1330.0
    [m]
    DC
    PETROS
    1350.0
    [m]
    DC
    PETROS
    1370.0
    [m]
    DC
    PETROS
    1390.0
    [m]
    DC
    PETROS
    1410.0
    [m]
    DC
    PETROS
    1430.0
    [m]
    DC
    PETROS
    1450.0
    [m]
    DC
    PETROS
    1470.0
    [m]
    DC
    PETROS
    1490.0
    [m]
    DC
    PETROS
    1510.0
    [m]
    DC
    PETROS
    1530.0
    [m]
    DC
    PETROS
    1550.0
    [m]
    DC
    PETROS
    1570.0
    [m]
    DC
    PETROS
    1590.0
    [m]
    DC
    PETROS
    1600.0
    [m]
    DC
    RII
    1610.0
    [m]
    DC
    RII
    1610.0
    [m]
    DC
    PETROS
    1620.0
    [m]
    DC
    RII
    1630.0
    [m]
    DC
    RII
    1630.0
    [m]
    DC
    PETROS
    1640.0
    [m]
    DC
    RII
    1650.0
    [m]
    DC
    RII
    1650.0
    [m]
    DC
    PETROS
    1660.0
    [m]
    DC
    RII
    1670.0
    [m]
    DC
    RII
    1670.0
    [m]
    DC
    PETROSTR
    1680.0
    [m]
    DC
    RII
    1690.0
    [m]
    DC
    PETROSTR
    1700.0
    [m]
    DC
    RII
    1710.0
    [m]
    DC
    RII
    1710.0
    [m]
    DC
    PETROSTR
    1720.0
    [m]
    DC
    RII
    1730.0
    [m]
    DC
    RII
    1730.0
    [m]
    DC
    PETROSTR
    1740.0
    [m]
    DC
    RII
    1750.0
    [m]
    DC
    RII
    1750.0
    [m]
    DC
    PETROSTR
    1760.0
    [m]
    DC
    RII
    1770.0
    [m]
    DC
    RII
    1770.0
    [m]
    DC
    PETROSTR
    1780.0
    [m]
    DC
    RII
    1790.0
    [m]
    DC
    RII
    1790.0
    [m]
    DC
    PETROSTR
    1800.0
    [m]
    DC
    RII
    1810.0
    [m]
    DC
    RII
    1810.0
    [m]
    DC
    PETROSTR
    1820.0
    [m]
    DC
    RII
    1830.0
    [m]
    DC
    RII
    1830.0
    [m]
    DC
    PETROSTR
    1840.0
    [m]
    DC
    RII
    1850.0
    [m]
    DC
    RII
    1850.0
    [m]
    DC
    PETROSTR
    1860.0
    [m]
    DC
    RII
    1870.0
    [m]
    DC
    RII
    1870.0
    [m]
    DC
    PETROSTR
    1880.0
    [m]
    DC
    RII
    1890.0
    [m]
    DC
    RII
    1890.0
    [m]
    DC
    PETROSTR
    1900.0
    [m]
    DC
    RII
    1910.0
    [m]
    DC
    RII
    1910.0
    [m]
    DC
    PETROSTR
    1920.0
    [m]
    DC
    RII
    1930.0
    [m]
    DC
    RII
    1930.0
    [m]
    DC
    PETROSTR
    1940.0
    [m]
    DC
    RII
    1940.0
    [m]
    DC
    PETROS
    1950.0
    [m]
    DC
    RII
    1950.0
    [m]
    DC
    PETROSTR
    1960.0
    [m]
    DC
    RII
    1970.0
    [m]
    DC
    RII
    1970.0
    [m]
    DC
    PETROSTR
    1980.0
    [m]
    DC
    RII
    1990.0
    [m]
    DC
    RII
    1990.0
    [m]
    DC
    PETROSTR
    2000.0
    [m]
    DC
    RII
    2009.0
    [m]
    DC
    RII
    2015.0
    [m]
    DC
    PETROSTR
    2021.0
    [m]
    DC
    RII
    2030.0
    [m]
    DC
    RII
    2033.0
    [m]
    DC
    PETROSTR
    2042.0
    [m]
    DC
    RII
    2051.0
    [m]
    DC
    PETROSTR
    2072.0
    [m]
    DC
    RII
    2072.0
    [m]
    DC
    PETROSTR
    2081.0
    [m]
    DC
    RII
    2090.0
    [m]
    DC
    PETROSTR
    2093.0
    [m]
    DC
    RII
    2099.0
    [m]
    DC
    RII
    2108.0
    [m]
    DC
    PETROSTR
    2117.0
    [m]
    DC
    RII
    2126.0
    [m]
    DC
    PETROSTR
    2135.0
    [m]
    DC
    RII
    2144.0
    [m]
    DC
    RII
    2144.0
    [m]
    DC
    PETROSTR
    2162.0
    [m]
    DC
    RII
    2171.0
    [m]
    DC
    RII
    2171.0
    [m]
    DC
    PETROSTR
    2180.0
    [m]
    DC
    RII
    2189.0
    [m]
    DC
    RII
    2198.0
    [m]
    DC
    RII
    2198.0
    [m]
    DC
    PETROSTR
    2207.0
    [m]
    DC
    RII
    2216.0
    [m]
    DC
    RII
    2216.0
    [m]
    DC
    PETROSTR
    2234.0
    [m]
    DC
    RII
    2234.0
    [m]
    DC
    PETROSTR
    2243.0
    [m]
    DC
    RII
    2252.0
    [m]
    DC
    RII
    2252.0
    [m]
    DC
    PETROSTR
    2261.0
    [m]
    DC
    RII
    2261.0
    [m]
    DC
    PETROSTR
    2270.0
    [m]
    DC
    RII
    2270.0
    [m]
    DC
    PETROSTR
    2279.0
    [m]
    DC
    RII
    2279.0
    [m]
    DC
    PETROSTR
    2288.0
    [m]
    DC
    RII
    2288.0
    [m]
    DC
    PETROSTR
    2297.0
    [m]
    DC
    RII
    2301.0
    [m]
    DC
    PETROSTR
    2313.0
    [m]
    DC
    RII
    2313.0
    [m]
    DC
    PETROSTR
    2319.0
    [m]
    DC
    RII
    2325.0
    [m]
    DC
    PETROSTR
    2330.0
    [m]
    DC
    PETROS
    2333.0
    [m]
    DC
    RII
    2337.0
    [m]
    DC
    RII
    2340.0
    [m]
    DC
    PETROSTR
    2346.0
    [m]
    DC
    PETROS
    2349.0
    [m]
    DC
    RII
    2352.0
    [m]
    DC
    PETROSTR
    2358.0
    [m]
    DC
    PETROS
    2361.0
    [m]
    DC
    RII
    2364.0
    [m]
    DC
    PETROSTR
    2370.0
    [m]
    DC
    RII
    2370.0
    [m]
    DC
    PETROSTR
    2373.0
    [m]
    DC
    PETROS
    2376.0
    [m]
    DC
    PETROS
    2382.0
    [m]
    DC
    RII
    2382.0
    [m]
    DC
    PETROSTR
    2388.0
    [m]
    DC
    RII
    2394.0
    [m]
    DC
    PETROSTR
    2397.0
    [m]
    DC
    RII
    2397.0
    [m]
    DC
    PETROSTR
    2403.0
    [m]
    DC
    PETROS
    2412.0
    [m]
    DC
    PETROS
    2418.0
    [m]
    DC
    PETROS
    2424.0
    [m]
    DC
    PETROS
    2427.0
    [m]
    DC
    PETROS
    2433.0
    [m]
    DC
    PETROS
    2439.0
    [m]
    DC
    PETROS
    2442.0
    [m]
    DC
    PETROS
    2448.0
    [m]
    DC
    PETROS
    2454.0
    [m]
    DC
    PETROS
    2460.0
    [m]
    DC
    PETROS
    2472.0
    [m]
    DC
    PETROS
    2478.0
    [m]
    DC
    PETROS
    2481.0
    [m]
    DC
    PETROS
    2490.0
    [m]
    DC
    PETROS
    2496.0
    [m]
    DC
    PETROS
    2502.0
    [m]
    DC
    PETROS
    2505.0
    [m]
    DC
    PETROS
    2517.0
    [m]
    DC
    PETROS
    2532.0
    [m]
    DC
    PETROS

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.02
    pdf
    1.43

  • 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
    21.18

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CHECKSHOT
    710
    2717
    DSI PEX NGT
    1102
    2708
    PEX HALS ACTS SP
    1102
    2711
    RFT RQPS GR ACTS
    1878
    2696

  • 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
    355.0
    36
    357.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    1102.0
    17 1/2
    1108.0
    0.00
    LOT
    OPEN HOLE
    2715.0
    12 1/4
    2715.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    320
    1.05
    SEA WATER
    357
    1.05
    SEA WATER
    442
    1.05
    WATER BASED MUD
    1108
    1.10
    20.0
    WATER BASED MUD
    1666
    1.25
    19.0
    WATER BASED MUD
    1874
    1.25
    21.0
    WATER BASED MUD
    2031
    1.25
    26.0
    WATER BASED MUD
    2412
    1.25
    26.0
    WATER BASED MUD
    2575
    1.29
    28.0
    WATER BASED MUD
    2716
    1.30
    28.0
    WATER BASED MUD
    2717
    1.30
    30.0
    WATER BASED MUD

  • 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