Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
25.11.2024 - 01:30
Time of last synchronization with Norwegian Offshore Directorate's internal systems

2/6-5

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.
    2/6-5
    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
    Multilateral
    Indicator telling if the parent well is multilateral, meaning it has more than one branch radiating from the main borehole. Example of legal values: YES, NO. See also Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    NO
    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.
    2/6-5
    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.
    Saga Petroleum ASA
    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.
    866-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.
    56
    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,
    17.11.1996
    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.
    11.01.1997
    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.
    11.01.1999
    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.
    24.09.2003
    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
    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.
    LATE CRETACEOUS
    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.
    TOR FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.0
    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).
    3260.0
    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).
    3258.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    125
    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.
    56° 35' 36.69'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 45' 42.73'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6272539.87
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    546787.12
    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.
    2885

  • Wellbore history
    General
    Block 2/6 is structurally located on the eastern margin of the Norwegian part of the Feda Graben. The block partly covers the Piggvar Terrace, the metamorphic Mandal high and the northwestern part of the Søgne basin.
    Well 2/6-5 is located in the central western part of the block, high on a structural closure defined on Top Shetland Group
    The main objective of well 2/6-5 was to test the presence of hydrocarbons and reservoir properties within the primary target intervals of the Shetland Group, located within a structural closure above the northern part of the Mandal High. It was prognosed approximately 40 m below the distinct Late Cretaceous Top Ekofisk Formation reflector.
    Reservoir units were expected in several intervals, some in pressure communication and some not. A possible secondary target of sediment fill in the interval between the Shetland Group and the basement topography would be penetrated before reaching TD in metamorphic rocks. However, this possible wedge was defined on a poor seismic response and could represent intra basement reflectivity. The well was planned as a possible future producer.
    Operations and results
    Exploration well 2/6-5 was spudded by the semi-submersible installation "Deepsea Bergen" 17 November 1996 and drilled to TD at 3260 m in metamorphic rocks. The well was drilled with a sea water/bentonite mud system down through the 12 1/2" hole section to 2515 m. The deeper part of the well was drilled with a KCL polymer glycol mud system.
    Above the Shetland Group the formation tops and lithologies were drilled within the uncertainty limits of the prognosis. The Tertiary succession (including Quaternary) was found to be 2872 m thick. The Nordland Group was 1404.7 m thick and consisted of clay/claystones and sands. Top of the Hordaland Group was encountered at 1499.5 m and the Group was found to be 1229.4 m thick, generally consisting of reactive clays. Top Rogaland Group was drilled at 2729 m Top. The Rogaland succession contained Balder, Sele/Lista, and Våle Formations and was 88 m thick. Top of the Shetland Group was drilled at 2817 m. Top Tor Formation was drilled at 2897.5 m.
    The Shetland Group interval velocity was experienced to be much higher than the prognosis based on stacking velocities indicated. The explanation to the observed discrepancy in seismic velocities contra the experienced well velocities is explained as azimuthal anisotropy combined with the seismic sampling configuration. The result is a reasonable seismic tie in two-way travel time to the well, but a significant mismatch in depth prognosis for the Top Hod and deeper strata.
    Top Hod Formation was prognosed at 3015 +/- 75 m and was drilled at 3155 m. The Base Cretaceous Unconformity was prognosed at 3103 +/- 125 m and was drilled at 3230.5 m (+125.5m). The secondary target, defined as a possible wedge resting on basement turned out not to be present and the seismic image had to be considered as intra basement reflectivity. Logs and core data both conclude that a rather tight chalk lithology is present in the well. Only few intervals of allochthonous chalk were observed. Immediately below the chalk interval, only separated by thin clay unit (altered basement rocks), fractured metamorphic basement consisting of chists were penetrated. A short core was cut, confirming oil shows in fractures within the basement rocks.
    Weak oil shows were reported from the Ekofisk Formation (2817-2897.5 m), and one core was cut. Six more cores were cut in the Tor Formation (2897.5- 3155 m). The cores had variable recovery, especially in core # 6 with only 7.5 % recovery. In addition to the weak shows reported from the Ekofisk Formation, shows were observed in fractures both in the Tor Formation and in the Basement. Matrix staining was only seen within the Tor Formation, in zones of less than 30 cm thickness in the interval from 2929 to 2935 m. A Modular Formation Dynamics Tester (MDT) with a RPQS gauge was used to obtain formation pressure measurements and fluid samples. Due to very tight formation, the pressure measurements were of questionable quality. Two segregated samples were taken at respectively 2929.5 m and 2951.5 m. Two multi samples chambers and one 1 gal chamber were taken at 3026.3 m. Unfortunately, the obtained MDT fluid samples were not representative due to mud contamination and low chamber pressure at shut-in. The MDT fluid sample from 2929.5 m contained 1: 3 oil/water. Only water was retrieved in the samples from 2951.5 and 3026.3 m. The water samples held a high concentration of Na, Ca, K, and Cl. These concentrations can partly be explained by mud invasion of KCl mud. The remaining salinity has to be explained as abnormal NaCl concentrations, which complicates the petrophysical well evaluation. Based on the limited pressure information and log interpretation an OWC was indicated at 2944.8 m (2942.8 m TVD RKB).
    After a drill stem test lasting from 24 December 1996 to 8 January 1997 the well was permanently abandoned as an oil discovery on 11 January.
    Testing
    A drill stem test with two perforated intervals (2955-2948 m and 2941-2929 m) within the Tor Formation was conducted. The test results show a very tight reservoir with a test permeability of 0.4 mD. No indications of natural fractures were observed. After acid stimulation (LCA acid frac.), the perforated intervals produced water with 3% oil content at a stable rate. The test was shut in after a flow period of 46 hours. The reservoir pressure was 447 bar and the temperature 117.3 deg C at mid-perforation (2938.5 m).

  • 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]
    820.00
    3252.00

  • 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
    2852.0
    2854.0
    [m ]
    2
    2904.0
    2917.0
    [m ]
    3
    2929.0
    2934.7
    [m ]
    4
    2935.0
    2953.0
    [m ]
    5
    2953.0
    2956.8
    [m ]
    6
    2957.0
    2958.5
    [m ]
    7
    2977.0
    2980.1
    [m ]
    8
    3252.0
    3254.1
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    49.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2852-2854m
    Core photo at depth: 2904-2909m
    Core photo at depth: 2909-2914m
    Core photo at depth: 2914-2917m
    Core photo at depth: 2929-2934m
    2852-2854m
    2904-2909m
    2909-2914m
    2914-2917m
    2929-2934m
    Core photo at depth: 2934-2935m
    Core photo at depth: 2935-2940m
    Core photo at depth: 2940-2945m
    Core photo at depth: 2945-2950m
    Core photo at depth: 2950-2953m
    2934-2935m
    2935-2940m
    2940-2945m
    2945-2950m
    2950-2953m
    Core photo at depth: 2953-2956m
    Core photo at depth: 2957-2958m
    Core photo at depth: 2977-2980m
    Core photo at depth: 3252-3254m
    Core photo at depth:  
    2953-2956m
    2957-2958m
    2977-2980m
    3252-3254m

  • 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
    DST1
    0.00
    0.00
    04.01.1997 - 14:00
    YES

  • 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
    170.0
    36
    170.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    802.0
    17 1/2
    805.0
    1.82
    LOT
    INTERM.
    9 5/8
    2494.0
    12 1/4
    2496.0
    1.78
    LOT
    LINER
    7
    3260.0
    8 1/2
    3260.0
    0.00
    LOT

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2955
    2919
    11.1
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    44.000
    30.000
    117
    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
    8
    0.831

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DSI DLL NGT GR ACTS
    2490
    3257
    FMI
    2490
    3257
    FMI GR ACTS
    2832
    2993
    LDT DSI BGT GR ACTS
    802
    2519
    MDT GR ACTS
    2800
    2968
    MDT GR ACTS
    2951
    2951
    MDT GR ACTS
    3020
    3026
    MDT GR AMS
    2832
    2993
    MWD - GR RES DIR
    170
    3260
    PEX CMR ACTS
    2423
    3257
    VSP
    1689
    3159

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    93
    1500
    2729
    2729
    2738
    2777
    2809
    2817
    2817
    2898
    3155
    3231

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.44

  • 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
    9.96
    pdf
    26.87

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    130
    1.03
    WATER BASED
    709
    1.04
    WATER BASED
    808
    0.00
    WATER BASED
    1086
    1.35
    24.0
    WATER BASED
    2515
    1.60
    36.0
    WATER BASED
    2801
    1.60
    44.0
    WATER BASED
    2904
    1.60
    38.0
    WATER BASED
    2919
    1.60
    39.0
    WATER BASED
    2955
    1.62
    32.0
    WATER BASED
    2984
    1.61
    30.0
    WATER BASED
    3129
    1.60
    32.0
    WATER BASED
    3176
    1.60
    39.0
    WATER BASED
    3252
    1.60
    38.0
    WATER BASED
    3260
    1.62
    WATER BASED

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2410.0
    [m]
    DC
    UNIVSHET
    2430.0
    [m]
    DC
    UNIVSH
    2450.0
    [m]
    DC
    UNIVSH
    2470.0
    [m]
    DC
    UNIVSH
    2490.0
    [m]
    DC
    UNIVSH
    2510.0
    [m]
    DC
    UNIVSH
    2530.0
    [m]
    DC
    UNIVSH
    2550.0
    [m]
    DC
    UNIVSH
    2570.0
    [m]
    DC
    UNIVSH
    2590.0
    [m]
    DC
    UNIVSH
    2610.0
    [m]
    DC
    UNIVSH
    2630.0
    [m]
    DC
    UNIVSH
    2650.0
    [m]
    DC
    UNIVSH
    2670.0
    [m]
    DC
    UNIVSH
    2690.0
    [m]
    DC
    UNIVSH
    2709.0
    [m]
    DC
    UNIVSH
    2727.0
    [m]
    DC
    UNIVSH
    2730.0
    [m]
    DC
    UNIVSH
    2733.0
    [m]
    DC
    UNIVSH
    2748.0
    [m]
    DC
    UNIVSH
    2769.0
    [m]
    DC
    UNIVSH
    2787.0
    [m]
    DC
    UNIVSH
    2802.0
    [m]
    DC
    UNIVSH
    2811.0
    [m]
    DC
    UNIVSH
    2814.0
    [m]
    DC
    UNIVSH
    3228.0
    [m]
    DC
    UNIVSH
    3237.0
    [m]
    DC
    UNIVSH
    3246.0
    [m]
    DC
    UNIVSH
    3257.0
    [m]
    DC
    UNIVSH

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    3231.00
    [m ]
    3234.00
    [m ]
    3237.00
    [m ]
    3240.00
    [m ]
    3243.00
    [m ]
    3246.00
    [m ]
    3249.00
    [m ]
    3252.00
    [m ]
    3253.00
    [m ]
    3254.00
    [m ]