Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
04.11.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

16/1-5

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    16/1-5
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    16/1-5
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 9511- INLINE 457 & X-LINE 1361
    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.
    939-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.
    41
    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,
    12.10.1998
    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.
    21.11.1998
    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.
    21.11.2000
    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.
    15.11.2001
    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.
    SHOWS
    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.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    105.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2460.0
    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).
    2457.2
    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.
    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.
    58° 47' 53.52'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 9' 12.14'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6518040.86
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    451073.37
    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.
    3279

  • Wellbore history
    General
    The objectives of well 16/1-5 were to prove hydrocarbon reserves in the Upper Jurassic (Oxfordian - Ryazanian) shallow marine sandstone as well as in the Middle Jurassic shallow to marginal marine sandstone. The well was also planned to provide a good stratigraphic tie to the Paleocene interval and test the possibility for Paleocene sands. A high amplitude at around 2070 ms TWT was also meant to be clarified with this well. The objective of the 16/1-5A sidetrack was to prove hydrocarbon reserves in an Upper Jurassic shallow marine sandstone, up-dip from the hydrocarbon shows that were recorded in well 16/1-5.
    Operations and results
    The main well, 16/1-5, was spudded and drilled with a water based mud to a total depth of 2460 m RKB. Both the Upper Jurassic sandstone, the Heather Formation "Sandstone Unit", and the Middle Jurassic Hugin Formation were encountered. Both sandstone sequences were water bearing, but oil shows were recorded in the upper 3 meters of the Heather Formation. A good stratigraphic tie to the Paleocene interval was established by the well, but no Paleocene sands were encountered. The high amplitude, observed on the seismic data at approximately 2070 ms TWT, most probably stems from the acoustic impedance contrast between the Heather sandstone - siltstone boundary and/or the Heather - Hugin boundary. No Permian sediments were encountered, with a stratigraphic succession going directly from Jurassic sediments into the Basement. Well 16/1-5 was terminated 194.5 m TVD into the Basement. Three cores were cut in the interval 2023 to 2066 m RKB in the Heather Formation. An FMT sample from 2024.5 m contained formation water and filtrate. The well was classified as dry.
    The sidetrack, 16/1-5 A, was kicked off at 1440 m RKB and a 8 1/2" hole section was drilled to a total depth of 2150 m with no casing strings run. Oil based mud was used from kick off to TD. The well encountered the Heather Formation "Sandstone Unit" close to prognosis. Moderate hydrocarbon shows were recorded in the thin, Cretaceous limestone sequence above the Heather Formation as well as in the upper 8 meters of the Heather Formation sandstone. The sidetrack was terminated 24 m TVD into the Heather Formation where a core was cut from 2123 m RKB to TD. No wire line logs were run and the well was permanently plugged and abandoned.
    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]
    1440.00
    2460.00

  • 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
    2023.0
    2028.9
    [m ]
    2
    2031.0
    2038.9
    [m ]
    3
    2039.0
    2066.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    40.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2023-2028m
    Core photo at depth: 2028-2029m
    Core photo at depth: 2031-2036m
    Core photo at depth: 2036-2039m
    Core photo at depth: 2039-2044m
    2023-2028m
    2028-2029m
    2031-2036m
    2036-2039m
    2039-2044m
    Core photo at depth: 2044-2049m
    Core photo at depth: 2049-2054m
    Core photo at depth: 2054-2059m
    Core photo at depth: 2059-2064m
    Core photo at depth: 2064-2066m
    2044-2049m
    2049-2054m
    2054-2059m
    2059-2064m
    2064-2066m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1440.0
    [m]
    DC
    STATO
    1450.0
    [m]
    DC
    STATO
    1460.0
    [m]
    DC
    STATO
    1470.0
    [m]
    DC
    STATO
    1480.0
    [m]
    DC
    STATO
    1490.0
    [m]
    DC
    STATO
    1500.0
    [m]
    DC
    STATO
    1510.0
    [m]
    DC
    STATO
    1520.0
    [m]
    DC
    STATO
    1530.0
    [m]
    DC
    STATO
    1540.0
    [m]
    DC
    STATO
    1550.0
    [m]
    DC
    STATO
    1560.0
    [m]
    DC
    STATO
    1570.0
    [m]
    DC
    STATO
    1580.0
    [m]
    DC
    STATO
    1590.0
    [m]
    DC
    STATO
    1600.0
    [m]
    DC
    STATO
    1610.0
    [m]
    DC
    STATO
    1620.0
    [m]
    DC
    STATO
    1630.0
    [m]
    DC
    STATO
    1640.0
    [m]
    DC
    STATO
    1650.0
    [m]
    DC
    STATO
    1660.0
    [m]
    DC
    STATO
    1670.0
    [m]
    DC
    STATO
    1680.0
    [m]
    DC
    STATO
    1690.0
    [m]
    DC
    STATO
    1700.0
    [m]
    DC
    STATO
    1710.0
    [m]
    DC
    STATO
    1720.0
    [m]
    DC
    STATO
    1730.0
    [m]
    DC
    STATO
    1740.0
    [m]
    DC
    STATO
    1750.0
    [m]
    DC
    STATO
    1760.0
    [m]
    DC
    STATO
    1770.0
    [m]
    DC
    STATO
    1780.0
    [m]
    DC
    STATO
    1790.0
    [m]
    DC
    STATO
    1800.0
    [m]
    DC
    STATO
    1810.0
    [m]
    DC
    STATO
    1820.0
    [m]
    DC
    STATO
    1833.0
    [m]
    SWC
    W-LAB
    1839.0
    [m]
    DC
    STATO
    1845.0
    [m]
    DC
    STATO
    1851.0
    [m]
    DC
    STATO
    1857.0
    [m]
    DC
    STATO
    1862.0
    [m]
    SWC
    W-LAB
    1869.0
    [m]
    DC
    STATO
    1875.0
    [m]
    DC
    STATO
    1880.0
    [m]
    SWC
    W-LAB
    1884.0
    [m]
    DC
    STATO
    1891.0
    [m]
    SWC
    W-LAB
    1900.0
    [m]
    SWC
    W-LAB
    1905.0
    [m]
    DC
    STATO
    1920.0
    [m]
    SWC
    W-LAB
    1924.5
    [m]
    SWC
    W-LAB
    1929.0
    [m]
    DC
    STATO
    1935.0
    [m]
    DC
    STATO
    1940.0
    [m]
    SWC
    W-LAB
    1944.0
    [m]
    DC
    STATO
    1956.0
    [m]
    DC
    STATO
    1962.0
    [m]
    DC
    STATO
    1965.0
    [m]
    DC
    STATO
    1973.5
    [m]
    SWC
    W-LAB
    1980.3
    [m]
    SWC
    W-LAB
    1986.0
    [m]
    DC
    STATO
    1992.0
    [m]
    DC
    STATO
    1998.0
    [m]
    DC
    STATO
    2010.0
    [m]
    DC
    STATO
    2067.0
    [m]
    SWC
    W-LAB
    2067.0
    [m]
    DC
    APT
    2074.0
    [m]
    SWC
    W-LAB
    2079.0
    [m]
    DC
    APT
    2081.3
    [m]
    SWC
    W-LAB
    2091.0
    [m]
    DC
    APT
    2094.0
    [m]
    DC
    STATOIL
    2098.8
    [m]
    SWC
    W-LAB
    2100.0
    [m]
    DC
    APT
    2100.0
    [m]
    DC
    STATOIL
    2103.0
    [m]
    DC
    STATOI
    2107.5
    [m]
    SWC
    W-LAB
    2109.0
    [m]
    DC
    APT
    2109.0
    [m]
    DC
    STATOIL
    2116.1
    [m]
    SWC
    W-LAB
    2118.0
    [m]
    DC
    STATOIL
    2118.0
    [m]
    DC
    APT
    2121.0
    [m]
    DC
    STATOIL
    2121.5
    [m]
    SWC
    W-LAB
    2127.0
    [m]
    DC
    APT
    2130.9
    [m]
    SWC
    W-LAB
    2133.0
    [m]
    DC
    STATOIL
    2136.0
    [m]
    DC
    APT
    2145.0
    [m]
    DC
    APT
    2145.0
    [m]
    DC
    STATOIL
    2147.8
    [m]
    SWC
    W-LAB
    2156.0
    [m]
    SWC
    W-LAB
    2157.0
    [m]
    DC
    APT
    2163.8
    [m]
    SWC
    W-LAB
    2166.0
    [m]
    DC
    APT
    2169.0
    [m]
    DC
    STATOIL
    2174.5
    [m]
    SWC
    W-LAB
    2175.0
    [m]
    DC
    APT
    2180.0
    [m]
    SWC
    W-LAB
    2187.0
    [m]
    DC
    STATOIL
    2187.0
    [m]
    DC
    APT
    2193.0
    [m]
    DC
    STATOIL
    2196.0
    [m]
    DC
    APT
    2199.0
    [m]
    DC
    STATOIL
    2205.0
    [m]
    DC
    STATOI
    2205.0
    [m]
    DC
    APT
    2214.0
    [m]
    DC
    STATOIL
    2214.0
    [m]
    DC
    APT
    2220.0
    [m]
    DC
    STATOIL
    2223.0
    [m]
    DC
    APT
    2232.0
    [m]
    DC
    APT
    2241.0
    [m]
    DC
    APT
    2242.0
    [m]
    DC
    STATOIL
    2250.0
    [m]
    DC
    APT

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.33

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.72

  • 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
    6.75
    .pdf
    26.60

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DIR
    191
    1425
    FMT-GR
    2202
    2024
    HDIL MAC DGR TTRM
    1410
    1975
    HDIL-MAC-DGR-TTRM
    1909
    2461
    MPR GR
    196
    1400
    MPR GR
    1410
    2460
    SWC GR
    1833
    1980
    SWC PFC
    2067
    2459
    SWC-PFC
    2070
    2169
    VSP GR
    1100
    1944
    VSP GR
    1565
    2455
    ZDL CND DSL
    1990
    2461
    ZDL CND DSL CHT
    1410
    1975

  • 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
    191.0
    36
    191.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    1410.0
    17 1/2
    1417.0
    1.81
    LOT
    INTERM.
    9 5/8
    2021.0
    12 1/4
    2023.0
    1.50
    LOT
    OPEN HOLE
    2460.0
    8 1/2
    2460.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    130
    0.00
    sea water
    1410
    1.15
    KCL/PAC/GLY
    1410
    0.00
    sea water
    2021
    1.15
    KCL/PAC/GLY
    2460
    1.92
    hivis pill

  • 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