Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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16.07.2024 - 01:28
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1/5-3 S

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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.
    1/5-3 S
    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
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    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.
    1/5-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    CN1/93- INLINE 1237 & X-LINE 2433
    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.
    Conoco Norway Inc.
    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.
    918-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.
    57
    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,
    10.06.1998
    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.
    06.08.1998
    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.
    06.08.2000
    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.
    07.01.2003
    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.
    MIOCENE
    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.
    NO FORMAL NAME
    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.
    69.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1565.0
    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).
    1565.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5.7
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    54
    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.
    MIOCENE
    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.
    HORDALAND GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 41' 24.52'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 36' 54.13'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6283101.44
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    476419.16
    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.
    3257
  • Wellbore history

    General
    Block 1/5 is situated in the Norwegian Central Trough at the transition of the Feda Graben and the Breiflabb Basin. Well 1/5-3 S was planned as an exploration well with TD at 2910 m in the Tor Chalk Formation. The well was positioned in a seismically defined "gas chimney" on the crest of a salt induced diapir and was the first well drilled on this diapir. Similar cases have been drilled successfully by STATOIL on the Tommeliten Discovery 1/9-2 and 1/9-3 wells. The primary objective of well 1/5-3 S was to test the presence of moveable hydrocarbons in fractured, reservoir quality chalk of the Ekofisk and Tor formations along the southwestern flank of the diapir. A secondary potential objective was in the Paleocene Rogaland Group. A total depth of 1566 m was reached in the 12 1/4" hole section on June 29, 1998 before deciding to permanently abandon the well due to increasing pore pressure, without fulfilling any of the well objectives.
    Operations and results
    Exploration 1/5-3 S well was spudded with the semi-submersible "Byford Dolphin" on 10 June 1998 and drilled to TD at 1566 m in rocks of Late Miocene age (undifferentiated Nordland Group). The well was drilled with seawater and hi-vis pills down to 792 m and with Baroid "BARASILC" silicate / KCl glycol enhanced ("GEM GP") mud from 792 m to TD. Due to possible shallow gas hazard at 466 m, a 9 7/8" pilot hole was drilled below the 30" conductor to 780 m. The 9 7/8" hole was opened up to 26" at 792 m prior to setting 20" casing at 785 m. No shallow gas was observed from the MWD resistivity in this hole section.
    Record setting overpressures were experienced in the 17 1/2" hole section in well 1/5-3 S. Abnormal pressures were indicated first at 700 - 800 m. Pore pressures built quickly to 1.4 g/cc due to gas just below 1000 m in. Having passed that depth, the hole drilled without problems until below 1200 m where it again became gassy. Mud weight was increased to 1.52 g/cc, thus reducing 30% gas to 5-10%. This weight was sufficient until below 1400 m when gas again increased. By 1450 m, the DXC was beginning to show signs of increasing pore pressure, as was the MWD resistivity. Below 1500 m, gas went off scale and an oil kick to 1.70 BMW was taken at 1544 m. Pressures of this magnitude were not forecast at all. Lost circulation was experienced during well control operations, which eventually lead to cementing of the BHA, and plugging back to sidetrack around the fish. The 17 l/2" hole was re-drilled as 1/5-3 S T2 from 1246 m to a revised 13 3/8" casing point at 1412 m. Although re-drilled with 1.60 g/cc mud weight versus the original 1.52 g/cc mud, the hole drilled nearly as gassy as the original hole. Following the 13 3/8" casing, an excellent leak-off was tested to nearly overburden gradient at 1.98 BMW.
    The 12 1/4" drilling was done with Statoil's Tommeliten method which emphasized ignoring gas in favour of other pressure parameters while minimizing mud weight builds but this proved to be unsuccessful for 1/5-3S. After drilling out with 1.76 g/cc mud weight, the hole became so gassy (up to 50%) from limestone stringers oozing oil that it had to be circulated clean at 1494 m, and 1.80 g/cc mud was circulated around. This should have balanced the 1.7 BMW kick zone coming up at 1544 m, as well as leading to increased confidence, as gas and cuttings size would diminish. Although the cuttings remained small until growing to 7 cm splinters near TD, gas was again off scale. By 1566 m, only 22 m beyond the second kick zone, the well was shut-in. 1.86 g/cc mud weight was required to balance the formation, and 1.90 g/cc mud weight was eventually circulated around on a dead well. Well 1/5-3 S T2 had transitioned from a pore pressure of 1.7 EMW at 1544 m to 1.86 EMW at 1566 m in only 22m of new hole. At this point the decision was taken to plug and abandon the well.
    Three kicks taken were regional records for both overpressure magnitude and shallowness of depth. Statoil's Tommeliten Field in block 1/9 did not see anywhere near the overpressure magnitude and shallow onset; mud weight was able to control mud gas far more successfully on Tommeliten and multiple hydrocarbon kicks were not experienced. Conoco's 1/6-5 crestal diapir well also exhibited a lesser overpressure profile. In hindsight the most important methods to monitor the pressure during drilling were the MWD resistivity and the cuttings shape and size. Gas in the mud was carefully monitored and plotted in units of percent methane in air. Gas was commonly 5% in the claystones, some of which showed bleeding gas at the surface, and ran 30-50% and higher in the carbonate stringers, which bled oil at the surface. The gas chimney section drilled with high gas background all the way from the top of overpressure to the terminal kicks below 1500 m. While the mud gas gave a general indication of overpressure, the high background levels actually obscured both of the final two kicks.
    Good trace of crude oil in the mud was observed from 1498m. At 1544 m, a kick was taken which resulted in crude oil being circulated up to the rig. Circulating gas varied between 40-100%, with peaks way above 100% caused by large amount of hydrocarbons. The crude oil collected at surface was dark yellowish brown and had a density of 0.84 g/cc (37 API) measured with a pressurised mud balance. Later laboratory analysis onshore gave a density of 0.80 g/cc (35.1 API).
    No conventional or sidewall cores were taken in this well. The well was permanently abandoned as a junked well with minor oil on 6 August 1998.
    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]
    800.00
    1560.00
  • Lithostratigraphy

    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    94
    1309
  • Composite logs

    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.21
  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.61
  • 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
    5.25
    .pdf
    41.89
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    GR DPIL ZDL CN MAC TTRM
    1246
    1422
    MWD - DGR EWR-S
    792
    1544
    MWD - DIR
    1246
    1422
    MWD - DIR DGR EWR PH4
    167
    780
    MWD - DIR DGR EWR-S
    1422
    1566
    TEMP CCL SONIAN
    792
    1544
  • 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
    166.7
    36
    167.0
    0.00
    LOT
    SURF.COND.
    20
    784.7
    26
    785.0
    1.79
    LOT
    INTERM.
    13 3/8
    1412.0
    17 1/2
    1412.0
    1.98
    LOT
    OPEN HOLE
    1565.0
    12 1/4
    1565.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    600
    1.03
    10.0
    KCL/GEM GP
    930
    1.27
    12.0
    KCL/PAC/GLYCOL
    1024
    1.33
    15.0
    BARASILC
    1044
    1.45
    10.0
    BARASILC
    1070
    1.71
    30.0
    BARASILC
    1103
    1.60
    24.0
    BARASILC
    1156
    1.62
    24.0
    BARASILC
    1201
    1.50
    28.0
    BARASILC
    1221
    1.61
    26.0
    BARASILC
    1234
    1.61
    31.0
    BARASILC
    1240
    1.60
    29.0
    BARASILC
    1342
    1.52
    30.0
    BARASILC
    1362
    1.89
    34.0
    BARASILC
    1422
    1.61
    26.0
    BARASILC
    1426
    1.75
    33.0
    BARASILC
    1544
    1.58
    20.0
    BARASILC
    1545
    1.70
    29.0
    BARASILC
    1566
    1.89
    40.0
    BARASILC
    1566
    1.80
    33.0
    BARASILC