Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
08.05.2024 - 01:33
Time of last synchronization with Norwegian Offshore Directorate's internal systems

1/3-8

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.
    1/3-8
    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.
    1/3-8
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    RANDOM LINES SH 9201 S1 OG S2
    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.
    Amoco Norway Oil Company
    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.
    855-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.
    167
    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,
    12.12.1996
    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.
    27.05.1997
    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.
    27.05.1999
    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.
    30.04.2010
    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.
    41.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    70.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    5201.0
    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).
    5199.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    179
    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.
    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.
    SMITH BANK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 52' 7.14'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 53' 20.75'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6302911.22
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    493238.84
    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.
    2829

  • Wellbore history
    General
    Well 1/3-8 is located on the Hidra High in the North Sea. The primary objective was to test the Jurassic Upper Ula sand package within the Kamskjell prospect. The secondary objective was a sand package at the base of the Jurassic. Planned TD was tagging the Triassic or reaching 5085 meters TVD SS.
    Operations and results
    Wildcat well 1/3-8 was spudded with the 3 legs jack-up installation Transocean Nordic on 12 December 1996 and drilled to TD at 5199 m in the Triassic Smith Bank Formation. Two major unscheduled events occurred in the 12 1/4" section. First, the mud line hanger failed. A total of 16 days was required to repair this before drilling could be resumed. Secondly, and more serious, a 3.5 bbl kick was taken at 4529 m while drilling a limestone interval in the Early Cretaceous Cromer Knoll Group. Based on the worst case scenario interpretation of the kick, there could be a large volume of hydrocarbons (estimated at up to 300 bbls) in the annulus between the kick and thief zones. For this reason it was decided to rig up flare booms to increase the rig safety should it become necessary to by-pass the MGS whilst circulating out the influx. The well was opened up, and the influx circulated out at 3.3 bpm. Initially returns were taken through the MGS. After pumping 1464 bbls returns were switched from the MGS to the boom. This decision was taken as gas levels in the pit room were rising, and the seal leg pressure was dropping steadily (from 11.5 to 6.4 psi) indicating the onset of possible blow-down. The flare lit immediately with the clear burn characteristic of condensate. A total of 420 bbls was flared before mud was at surface and the flare extinguished. A total of 15 days were spent stabilising the well to permit running casing and continue drilling the next section. The well was drilled with seawater down to 303 m, with pre-hydrated gel mud down to 1105 m, with KCl/polymer/glycol mud from 1105 m to 3445 m, and with Ancovert oil based mud from 3445 m to TD.
    The only live hydrocarbons found in the well was the condensate kick at 4529 m in the Cromer Knoll Group, believed to originate from a fracture in the Sola Formation limestone. The target Upper Ula Formation was not found in the well. Poorly developed and generally tight Basal Jurassic sands were encountered at 5005 m with a pooled thickness of ca 22 m. Poor oil shows were recorded in the interval 5007 to 5024 m in these sands. Thin sands were present also in the Triassic, but no shows were recorded in these.
    One core was cut in the interval 5024 to 5041 m with 15.07 m recovery. One FMT fluid sample was taken at 5006.3 m, recovering muddy water with 190000 ppm of chloride.
    The well was permanently abandoned on 27 May 1997 as a dry well with shows.
    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]
    320.00
    5200.00

  • 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
    5024.0
    5039.1
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    15.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 5024-5029m
    Core photo at depth: 5029-5034m
    Core photo at depth: 5034-5039m
    Core photo at depth:  
    Core photo at depth:  
    5024-5029m
    5029-5034m
    5034-5039m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    4738.0
    [m]
    DC
    PETROSTR
    4837.0
    [m]
    DC
    PETROS
    4891.0
    [m]
    DC
    PETROS
    4990.0
    [m]
    DC
    PETROS
    5024.5
    [m]
    C
    PETROS
    5032.8
    [m]
    C
    PETROS

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.19
    pdf
    4.88

  • 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
    12.73

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBIL
    4515
    4627
    CBIL HEXDIP
    4903
    5188
    DPIL ZDEN CN GR
    3350
    4528
    FMT
    4530
    4894
    FMT
    5005
    5172
    HDIL CAL MAC GR
    3435
    4528
    HDIL MAC GR
    1098
    3445
    HDIL MAC SL
    4515
    4905
    HDIL MAC SL
    4903
    5186
    HEXDIP
    4515
    4905
    MULTI-ARM CAL
    10
    2919
    MWD - GR RES
    310
    1105
    PRES GRAD
    10
    4519
    RCOR
    4920
    4928
    SWC
    4920
    5181
    TEMP GR CCL
    100
    4524
    TEMP GR CCL
    1000
    4515
    ZDEN CN GR
    2425
    3445
    ZDEN CN GR
    4515
    4905
    ZDEN CN GR
    4902
    5198
    ZO VSP
    1085
    4520
    ZO VSP
    4360
    5190

  • 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
    303.0
    36
    310.0
    0.00
    LOT
    PILOT HOLE
    310.0
    9 7/8
    1105.0
    0.00
    LOT
    SURF.COND.
    20
    1098.0
    26
    1105.0
    0.00
    LOT
    INTERM.
    14
    3435.0
    17 1/2
    3445.0
    0.00
    LOT
    INTERM.
    9 5/8
    4515.0
    12 1/2
    4529.0
    0.00
    LOT
    LINER
    7 5/8
    4904.0
    8 1/2
    4910.0
    0.00
    LOT
    OPEN HOLE
    5021.0
    6 1/4
    5021.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    310
    0.90
    5.0
    water based
    351
    2.14
    74.0
    oil based
    1105
    1.52
    46.0
    water based
    1502
    1.62
    44.0
    water based
    1959
    1.62
    44.0
    water based
    2442
    1.66
    45.0
    water based
    2451
    1.64
    43.0
    water based
    2465
    1.64
    46.0
    water based
    2622
    1.64
    55.0
    water based
    2920
    1.53
    28.0
    oil based
    3045
    1.64
    49.0
    water based
    3065
    1.64
    46.0
    water based
    3199
    1.64
    41.0
    water based
    3200
    1.64
    40.0
    water based
    3297
    1.64
    35.0
    water based
    3366
    1.64
    36.0
    water based
    3410
    1.53
    35.0
    oil based
    3435
    1.55
    29.0
    oil based
    3445
    1.64
    36.0
    water based
    3687
    1.55
    33.0
    oil based
    4104
    1.55
    36.0
    oil based
    4242
    1.55
    37.0
    oil based
    4290
    2.14
    74.0
    oil based
    4401
    1.68
    43.0
    oil based
    4463
    1.80
    56.0
    oil based
    4500
    1.81
    60.0
    oil based
    4529
    1.74
    37.0
    oil based
    4531
    1.03
    35.0
    oil based
    4654
    2.00
    54.0
    oil based
    4866
    2.04
    68.0
    oil based
    4905
    2.04
    60.0
    oil based
    4960
    2.10
    68.0
    oil based
    5053
    2.10
    68.0
    oil based
    5179
    2.10
    65.0
    oil based
    5201
    2.14
    74.0
    oil based

  • 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