Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
06.11.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

8/3-1

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.
    8/3-1
    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.
    8/3-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    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.
    Esso Exploration and Production Norway 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.
    1-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.
    84
    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,
    19.07.1966
    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.
    10.10.1966
    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.
    10.10.1968
    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.
    22.04.2005
    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.
    26.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    94.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3015.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    77
    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.
    57° 59' 13.16'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 40' 13.29'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6427604.28
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    539640.29
    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.
    142

  • Wellbore history
    General
    Wildcat well 8/3-1 was the first exploration well to be drilled in Norwegian waters. The chosen location was northwestern part of the Danish Norwegian. The well was proposed to investigate the largely unknown stratigraphic sequence and lithologies in a virgin area on an attractive, representative seismic structure. Although the seismic feature was based on low-density reconnaissance control, the structure qualified for testing in terms of vertical and areal closure and inferred thickness of sediments. The well site location was thought to lie on the east flank of the Tertiary "Viking" basin, but on the west flank of a Mesozoic sub basin. The position and delineation of older basins was uncertain, although Permian? salts of sufficient thickness to flow were recognized as probably present at depth. Interpretation of data from a seismic grid with about 7 Km line spacing indicated a regionally high, west-dipping, normally faulted block to be present. The well location was sited near the crest of the highest step faulted block. A diapiric Zechstein? salt plug was interpreted to be present, to the east on the down side of the principal fault block. The salt could have partially intruded along the fault plane, up through the Kimmerian horizon."
    Operations and results
    Well 8/3-1 was spudded with the semi-submersible installation Ocean Traveller on 19 July 1966 and drilled to TD at 3015 m in Caledonian schists. While pulling out of the hole to pick up a core barrel at a depth of 296I m the pipe stuck at 1660 m, and was pumped free with seawater. The hole began caving immediately. Extensive caving over the interval 1320 m to 2030 m lead to bridging, stuck pipe, and logging problems. Eighteen rig-days were spent to cure the problems by reaming and raising the mud weight and to log the section in various logging attempts. The hole was eventually cased to 2963 m. No further problems developed. From sea bed to 277 m the initial drilling was with seawater and gel without casing.  Below 277 m to approximately 2290 m a sea water slurry with Spersene, XP-2, and 0-12% diesel oil was used.  At 2284 m a salt section was reached and the drilling fluid was converted to a salt saturated mud.
    The lithology in the upper 1/3 was strongly dominated by shales and clays, followed by chalk and shales in the middle 1/3. The lower 1/3, below top Permian at 2205 m (Zechstein Group) the lithology was dominated by evaporites. The well drilled through the evaporites and 50 m into the basement. A minor part of the column consisted of sands, and sandstones interbedded with shale and clays. Potential reservoir rocks with sufficient porosity to be attractive were present in the Danian chalk section (Ekofisk Formation) and in the Middle Jurassic sands (Sandnes Formation). No oil or gas shows were recorded in the well. Organic geochemical analyses of cuttings showed low TOC throughout the Cretaceous. TOC rose to 2.5 % to 5 % in the Late Jurassic section (around the level of the Tau Formation). Hydrogen indexes in this section were in the range 100 to 250 mg HC/g TOC. Maturity is evaluated as top oil window somewhere between 2500 m and 3000 m (%Ro = 0.5).
    Hence, reservoirs, cap rocks and potential source rock were confirmed although no hydrocarbons were found in this first well. Five conventional and 19 sidewall cores were taken in the well. A quarter section cut of the conventional cores is stored at the Directorate. The length of the cores range from 4 to 10 m and the recoveries were from 40 % to 100 %. The sidewall cores were taken in the 2963 - 3004 m interval. These were not deposited with the Directorate. Storing a quarter of all conventional cores at the Norwegian Petroleum Directorate (but no sidewall cores) has since been standard NPD practice.
    No wire line tests were conducted and therefore no fluid samples taken, due to the caving problems in the hole.
    The well was permanently abandoned on 10 October 1966 as a dry hole.
    Testing
    No drill stem test was performed.

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    NO
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    287.00
    2996.00

  • 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
    2075.0
    2075.5
    [m ]
    2
    2079.0
    2083.0
    [m ]
    3
    2206.0
    2214.8
    [m ]
    4
    2968.4
    2972.0
    [m ]
    5
    3007.0
    3015.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    24.9
    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
    449.0
    [m]
    DC
    479.0
    [m]
    DC
    509.0
    [m]
    DC
    539.0
    [m]
    DC
    575.0
    [m]
    DC
    608.0
    [m]
    DC
    638.0
    [m]
    DC
    662.0
    [m]
    DC
    685.0
    [m]
    DC
    690.0
    [m]
    DC
    715.0
    [m]
    DC
    720.0
    [m]
    DC
    745.0
    [m]
    DC
    750.0
    [m]
    DC
    775.0
    [m]
    DC
    780.0
    [m]
    DC
    785.0
    [m]
    DC
    795.0
    [m]
    DC
    805.0
    [m]
    DC
    810.0
    [m]
    DC
    815.0
    [m]
    DC
    820.0
    [m]
    DC
    830.0
    [m]
    DC
    835.0
    [m]
    DC
    840.0
    [m]
    DC
    865.0
    [m]
    DC
    870.0
    [m]
    DC
    895.0
    [m]
    DC
    900.0
    [m]
    DC
    925.0
    [m]
    DC
    930.0
    [m]
    DC
    935.0
    [m]
    DC
    950.0
    [m]
    DC
    955.0
    [m]
    DC
    960.0
    [m]
    DC
    970.0
    [m]
    DC
    975.0
    [m]
    DC
    980.0
    [m]
    DC
    980.0
    [m]
    DC
    985.0
    [m]
    DC
    990.0
    [m]
    DC
    995.0
    [m]
    DC
    1000.0
    [m]
    DC
    1005.0
    [m]
    DC
    1015.0
    [m]
    DC
    1020.0
    [m]
    DC
    1030.0
    [m]
    DC
    1035.0
    [m]
    DC
    1045.0
    [m]
    DC
    1050.0
    [m]
    DC
    1055.0
    [m]
    DC
    1060.0
    [m]
    DC
    1075.0
    [m]
    DC
    1080.0
    [m]
    DC
    1085.0
    [m]
    DC
    1120.0
    [m]
    DC
    1140.0
    [m]
    DC
    1170.0
    [m]
    DC
    1315.0
    [m]
    DC
    1335.0
    [m]
    DC
    1355.0
    [m]
    DC
    1395.0
    [m]
    DC
    1415.0
    [m]
    DC
    1435.0
    [m]
    DC
    1480.0
    [m]
    DC
    1510.0
    [m]
    DC
    1525.0
    [m]
    DC
    1545.0
    [m]
    DC
    1565.0
    [m]
    DC
    1585.0
    [m]
    DC
    1620.0
    [m]
    DC
    1640.0
    [m]
    DC
    1650.0
    [m]
    DC
    1660.0
    [m]
    DC
    1680.0
    [m]
    DC
    1695.0
    [m]
    DC
    1700.0
    [m]
    DC
    1720.0
    [m]
    DC
    1740.0
    [m]
    DC
    1755.0
    [m]
    DC
    1755.0
    [m]
    DC
    1760.0
    [m]
    DC
    1780.0
    [m]
    DC
    1790.0
    [m]
    DC
    1795.0
    [m]
    DC
    1800.0
    [m]
    DC
    1820.0
    [m]
    DC
    1840.0
    [m]
    DC
    1850.0
    [m]
    DC
    1855.0
    [m]
    DC
    1860.0
    [m]
    DC
    1880.0
    [m]
    DC
    1900.0
    [m]
    DC
    1905.0
    [m]
    DC
    1920.0
    [m]
    DC
    1925.0
    [m]
    DC
    1930.0
    [m]
    DC
    1940.0
    [m]
    DC
    1945.0
    [m]
    DC
    1950.0
    [m]
    DC
    1960.0
    [m]
    DC
    1965.0
    [m]
    DC
    1970.0
    [m]
    DC
    1980.0
    [m]
    DC
    1985.0
    [m]
    DC
    1990.0
    [m]
    DC
    2000.0
    [m]
    DC
    2005.0
    [m]
    DC
    2010.0
    [m]
    DC
    2015.0
    [m]
    DC
    2020.0
    [m]
    DC
    2025.0
    [m]
    DC
    2030.0
    [m]
    DC
    2040.0
    [m]
    DC
    2045.0
    [m]
    DC
    2050.0
    [m]
    DC
    2060.0
    [m]
    DC
    2070.0
    [m]
    DC
    2070.0
    [m]
    DC
    2075.0
    [m]
    DC
    2075.0
    [m]
    C
    2075.3
    [m]
    C
    2076.0
    [m]
    DC
    2076.6
    [m]
    C
    2079.0
    [m]
    DC
    2079.1
    [m]
    C
    2079.2
    [m]
    C
    2079.4
    [m]
    C
    2080.1
    [m]
    C
    2080.2
    [m]
    C
    2080.3
    [m]
    C
    2080.5
    [m]
    C
    2080.9
    [m]
    C
    2081.5
    [m]
    C
    2082.5
    [m]
    C
    2082.6
    [m]
    C
    2083.0
    [m]
    C
    2085.0
    [m]
    DC
    2100.0
    [m]
    DC
    2120.0
    [m]
    DC
    2125.0
    [m]
    DC
    2150.0
    [m]
    DC
    2160.0
    [m]
    DC
    2165.0
    [m]
    DC
    2170.0
    [m]
    DC
    2180.0
    [m]
    DC
    2190.0
    [m]
    DC
    2190.0
    [m]
    DC
    2206.4
    [m]
    C
    2206.5
    [m]
    C
    2207.0
    [m]
    C
    2208.0
    [m]
    C
    2209.0
    [m]
    C
    2210.0
    [m]
    C
    2210.0
    [m]
    DC
    2211.4
    [m]
    C
    2212.1
    [m]
    C
    2212.3
    [m]
    C
    2212.3
    [m]
    C
    2216.0
    [m]
    DC
    2231.0
    [m]
    DC
    2249.0
    [m]
    DC
    2270.0
    [m]
    DC
    2282.0
    [m]
    DC
    2291.0
    [m]
    DC
    2300.0
    [m]
    DC
    2351.0
    [m]
    DC
    2369.0
    [m]
    DC
    2405.0
    [m]
    DC
    2459.0
    [m]
    DC
    2513.0
    [m]
    DC
    2567.0
    [m]
    DC
    2615.0
    [m]
    DC
    2663.0
    [m]
    DC
    2717.0
    [m]
    DC
    2765.0
    [m]
    DC
    2813.0
    [m]
    DC
    2837.0
    [m]
    DC
    2861.0
    [m]
    DC
    2885.0
    [m]
    DC
    2910.0
    [m]
    DC
    2940.0
    [m]
    DC
    2960.0
    [m]
    DC
    2963.0
    [m]
    DC
    2963.0
    [m]
    DC
    2964.0
    [m]
    DC
    2964.5
    [m]
    C
    2966.0
    [m]
    DC
    2969.0
    [m]
    DC
    2972.0
    [m]
    DC
    2975.0
    [m]
    DC
    2981.0
    [m]
    DC
    2987.0
    [m]
    DC
    2993.0
    [m]
    DC

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.29

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    4.33

  • 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
    3.65

  • Documents – Norwegian Offshore Directorate papers
    Documents – Norwegian Offshore Directorate papers
    Document name
    Document format
    Document size [MB]
    pdf
    16.81
    pdf
    54.86

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BHC SONIC
    273
    1100
    BHC SONIC
    2961
    3014
    CALI
    1063
    1880
    CBL
    1900
    2200
    CCL
    1000
    1140
    DEV
    2150
    3015
    GR BHC SONIC
    145
    277
    GR BHC SONIC
    1063
    2958
    GR NEUTRON
    273
    1112
    GR NEUTRON
    1800
    3015
    LL-7
    273
    1879
    LL-7
    2961
    3015
    ML
    273
    1100
    SWC
    2962
    3004
    VELOCITY
    150
    3016

  • 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
    SURF.COND.
    30
    145.0
    36
    174.0
    0.00
    LOT
    INTERM.
    20
    274.0
    26
    280.0
    0.00
    LOT
    INTERM.
    13 3/8
    1063.0
    17 1/2
    1115.0
    0.00
    LOT
    INTERM.
    9 5/8
    3015.0
    12 1/4
    3015.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    277
    1.07
    seawater
    1465
    1.25
    spersene xp
    1815
    1.37
    spersene xp

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    3010.00
    [m ]