Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
10.11.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

18/10-1

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.
    18/10-1
    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
    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.
    18/10-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    685402 SP.160
    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.
    Elf Petroleum Norge 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.
    227-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.
    75
    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,
    19.10.1979
    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.
    01.01.1980
    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.
    01.01.1982
    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.
    25.04.2005
    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.
    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.
    MIDDLE 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.
    SANDNES 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.
    MIDDLE JURASSIC
    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.
    BRYNE FM
    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.
    96.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2800.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    88
    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.
    SKAGERRAK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 4' 38.25'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    4° 7' 0.83'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6438006.82
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    565878.03
    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.
    342

  • Wellbore history
    General
    Well 18/10-1 is located in the Egersund Basin in the North Sea, ca 16 km southeast of the 17/12-1R Bream Discovery. It was designed to test a seismic structure on the same trend as the Bream discovery. The primary target was to test possible hydrocarbon accumulation in Jurassic sandstones on. Planned TD is about 150 to 200 m below Jurassic sandstone in a shaly-sandy sequence of Early Jurassic or top of Triassic.
    Operations and results
    Well 18/10-1 was spudded with the semi-submersible installation Dyvi Alpha on 19 October 1979 and drilled to TD at 2800 m in the Triassic Skagerrak Formation.
    A thick Late Jurassic shale sequence with limestone stringers was penetrated before reaching the target Middle Jurassic sands. The sands (Sandnes and Bryne Formations) were encountered at 2405 m, close to prognosis. The reservoir consisted of two zones separated by a thin shale barrier between 2427 and 2433 m. Based on FMT and DST pressure measurements the upper zone appeared slightly overpressured relative to the lower, suggesting a compartmentalized reservoir. The reservoirs were found hydrocarbon bearing and an OWC was found at 2437 m in the lower zone. The lithology below the target reservoir section, from 2483 m to TD, was predominantly sandstone, fine in the upper part, becoming medium to coarse downwards. Frequent thin interbeds of shale and marl, occasionally also thin stringers of limestone were encountered. The sequence was entirely water bearing. Weak direct fluorescence and cut appears at 2420 m, becoming very good in the intervals 2423 m to 2430 m and 2433 m to 2440 m, then the shows get weaker and disappear below 2444 m.
    Organic geochemical analyses showed an immature well all through (%Ro = 0.5 at TD). TOC in the Late Jurassic shale increased gradually from ca 0.8% at top Jurassic to ca 1 % at 2200 m. A peak TOC is reached in the Tau Formation with 4.5 % TOC in cuttings and 6.9 % in a sidewall core. The hydrogen index in the Tau Formation was up to 273 mg HC/g TOC in cuttings and up to 415 mg HC/g TOC in the sidewall core. TOC in the underlying Egersund Formation is also high, from 2 - 4%, but the hydrogen index is lower, in the range 120 to 270 mg HC/g TOC. Next potential source rock is represented by the Bryne coals with HI up to 300 mg HC/g TOC.
    Three conventional cores were cut in the Bryne Formation reservoir section from 2421 m to 2469 m. A total of 39 sidewall cores were recovered between 1080 m to 2791 m. Three FMT runs over the reservoir section gave 10 valid pressure readings and one fluid sample. The fluid sample, at 2434 m, contained only mud filtrate.
    The well was permanently abandoned on 1 January 1980 as an oil discovery.
    Testing
    One Drill Stem Test was performed in the interval 2414.5 m to 2427.0 m. It flowed 295 m3/day of oil and 2850 Sm3/day of gas on a 2" choke. The gas-to-oil ratio was 9.7 m3/m3, oil gravity was 36.4 °API (0.843 g/cm3), and gas gravity was 0.724 (air = 1) with 1.4% CO2 and no detectable H2S. Reservoir temperature (at shut-in) was 80 °C.

  • 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]
    183.00
    2800.00

  • 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
    2421.0
    2432.5
    [m ]
    2
    2432.5
    2450.5
    [m ]
    3
    2450.5
    2469.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    48.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2421-2424m
    Core photo at depth: 2424-2427m
    Core photo at depth: 2427-2430m
    Core photo at depth: 2430-2432m
    Core photo at depth: 2432-2435m
    2421-2424m
    2424-2427m
    2427-2430m
    2430-2432m
    2432-2435m
    Core photo at depth: 2435-2439m
    Core photo at depth: 2439-2442m
    Core photo at depth: 2442-2445m
    Core photo at depth: 2445-2449m
    Core photo at depth: 2449-2450m
    2435-2439m
    2439-2442m
    2442-2445m
    2445-2449m
    2449-2450m
    Core photo at depth: 2450-2453m
    Core photo at depth: 2453-2457m
    Core photo at depth: 2457-2460m
    Core photo at depth: 2460-2463m
    Core photo at depth: 2463-2467m
    2450-2453m
    2453-2457m
    2457-2460m
    2460-2463m
    2463-2467m
    Core photo at depth: 2467-2469m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2467-2469m

  • 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
    2389.50
    2402.00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.43

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.38
    pdf
    0.23

  • 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
    15.28
    pdf
    1.52

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2414
    2427
    50.8
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    23.000
    19.000
    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
    295
    2850
    0.834
    0.724
    9

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CNL CDL GR
    168
    2795
    DIPLOG
    945
    2314
    DLL MLL
    2303
    2497
    IEL BHC
    160
    2793
    MFT
    2416
    2479
    MFT
    2425
    2753
    MFT
    2430
    2465
    VELOCITY
    405
    2791

  • 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
    146.0
    36
    146.0
    0.00
    LOT
    SURF.COND.
    20
    323.0
    26
    332.0
    0.00
    LOT
    INTERM.
    13 3/8
    916.0
    17 1/2
    927.0
    0.00
    LOT
    INTERM.
    9 5/8
    2308.0
    12 1/4
    2310.0
    0.00
    LOT
    LINER
    7
    2478.0
    8 1/2
    2800.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    193
    1.06
    55.0
    seawater
    325
    1.12
    55.0
    waterbased
    920
    1.17
    55.0
    waterbased
    1810
    1.16
    44.0
    waterbased
    2256
    1.18
    30.0
    waterbased
    2775
    1.21
    60.0
    waterbased

  • 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