Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.11.2024 - 09:09
Time of last synchronization with Norwegian Offshore Directorate's internal systems

2/5-3

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.
    2/5-3
    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.
    2/5-3
    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.
    67-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,
    02.04.1972
    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.
    15.06.1972
    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.
    15.06.1974
    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.
    02.04.2007
    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.
    PALEOCENE
    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.
    EKOFISK 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.
    LATE CRETACEOUS
    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.
    TOR FM
    3rd level with HC, age
    Age of lithostratigraphic unit, 3rd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    LATE CRETACEOUS
    3rd level with HC, formation
    Name of lithostartigraphic unit, 3rd 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.
    HOD FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    34.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    67.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3731.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    122
    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 PERMIAN
    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.
    ZECHSTEIN GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 35' 50.8'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 26' 58.8'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6272806.93
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    527611.80
    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.
    258

  • Wellbore history
    General
    Well 2/5-3 was drilled ca 8 km southeast of the Tor Field. The primary target was top Danian chalk. Secondary targets were top Paleocene and base chalk at 3551 m (11650 ft). Planned total depth was 3597 m (11800 ft).
    Operations and results
    Well was spudded with the jack-up installation Zapata Explorer on 2 April 1972 and drilled to TD at 3731 m in the Late Permian Zechstein Group.
    Top Paleocene was encountered at 2929 m, top Ekofisk Formation at 3037 m, top Tor Formation at 3121 m, and top Hod Formation at 3481 m. First show was reported in a limestone stringer at 2259 m. Occasional oils shows, in limestone stringers, were reported in the interval 2604 to 2877 m. The top 3 m of the Paleocene (Balder Formation) was silty and had good oil shows. Oil was found by drill stem testing in the Ekofisk and Tor Formations. Shows continued down to 3261 m in the Tor Formation.
    Fifteen conventional cores were cut in the Ekofisk and Tor Formations, recovering a total length of 123.3 m core.
    The well was suspended on 15 June 1972 as an oil discovery.
    Testing
    Three zones were drill stem tested. The following results are after acidization:
    DST 1 tested the interval 3386 - 3395 m in the lower part of the Tor Formation and flowed 21 m3 water /day.
    DST 2 tested the interval 3120 - 3191 m in the upper part of the Tor Formation. Average flow parameters at maximum choke, 40/64", was 682 Sm3 oil and 340400 Sm3 gas /day. The oil gravity was 36 deg API and the GOR was 463 Sm3/Sm3. The GOR on smaller choke sizes was significantly lower, down to 233 Sm3/Sm3 on a 16/64 "choke.
    DST 3 tested the interval 3053 - 3065 m in the Ekofisk Formation and flowed on average 682 Sm3 oil and 141330 Sm3 gas /day on a 32/64" choke. The water production during this flow decreased from 57 to 17.5 m3 /day and the GOR decreased from 213 to 179 Sm3/Sm3. The oil gravity was 38.2 deg API.

  • 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]
    142.95
    3730.75

  • 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
    9998.0
    10011.0
    [ft ]
    2
    10012.0
    10023.0
    [ft ]
    3
    10025.0
    10064.6
    [ft ]
    4
    10068.0
    10125.0
    [ft ]
    5
    10125.0
    10145.0
    [ft ]
    6
    10145.0
    10208.6
    [ft ]
    7
    10208.6
    10243.0
    [ft ]
    8
    10243.0
    10265.0
    [ft ]
    9
    10265.0
    10301.0
    [ft ]
    10
    10301.0
    10339.0
    [ft ]
    11
    10342.0
    10402.0
    [ft ]
    12
    10402.0
    10430.0
    [ft ]
    13
    10435.0
    10461.0
    [ft ]
    14
    10472.0
    10494.0
    [ft ]
    15
    10505.0
    10549.0
    [ft ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    156.9
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 10015-10032ft
    Core photo at depth: 10015-10032ft
    Core photo at depth: 10032-10049ft
    Core photo at depth: 10049-10064ft
    Core photo at depth: 10064-10081ft
    10015-10032ft
    10015-10032ft
    10032-10049ft
    10049-10064ft
    10064-10081ft
    Core photo at depth: 10081-10097ft
    Core photo at depth: 10097-10112ft
    Core photo at depth: 10112-10127ft
    Core photo at depth: 10127-10142ft
    Core photo at depth: 10142-10145ft
    10081-10097ft
    10097-10112ft
    10112-10127ft
    10127-10142ft
    10142-10145ft
    Core photo at depth: 10145-10161ft
    Core photo at depth: 10161-10208ft
    Core photo at depth: 10208-10226ft
    Core photo at depth: 10226-10246ft
    Core photo at depth: 10246-10260ft
    10145-10161ft
    10161-10208ft
    10208-10226ft
    10226-10246ft
    10246-10260ft
    Core photo at depth: 10260-10279ft
    Core photo at depth: 10279-10297ft
    Core photo at depth: 10297-10314ft
    Core photo at depth: 10314-10330ft
    Core photo at depth: 10330-10350ft
    10260-10279ft
    10279-10297ft
    10297-10314ft
    10314-10330ft
    10330-10350ft
    Core photo at depth: 10350-10364ft
    Core photo at depth: 10364-10379ft
    Core photo at depth: 10379-10395ft
    Core photo at depth: 10395-10412ft
    Core photo at depth: 10412-10427ft
    10350-10364ft
    10364-10379ft
    10379-10395ft
    10395-10412ft
    10412-10427ft
    Core photo at depth: 10427-10443ft
    Core photo at depth: 10443-10458ft
    Core photo at depth: 10458-10483ft
    Core photo at depth: 10483-10510ft
    Core photo at depth: 10510-10527ft
    10427-10443ft
    10443-10458ft
    10458-10483ft
    10483-10510ft
    10510-10527ft
    Core photo at depth: 10527-10542ft
    Core photo at depth: 10542-10549ft
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    10527-10542ft
    10542-10549ft

  • 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
    143.0
    36
    143.0
    0.00
    LOT
    INTERM.
    20
    375.0
    26
    392.0
    0.00
    LOT
    INTERM.
    13 3/8
    1588.0
    17 1/2
    1588.0
    0.00
    LOT
    INTERM.
    9 5/8
    3031.0
    12 1/4
    3044.0
    0.00
    LOT
    LINER
    7
    3717.0
    8 1/2
    3731.0
    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
    3386
    3395
    0.0
    2.0
    3121
    3191
    15.9
    3.0
    3053
    3065
    12.5
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.0
    3.0
    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
    2.0
    682
    340400
    0.844
    464
    3.0
    682
    141330
    0.830
    179

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    ADM AP
    1593
    3731
    BHC
    366
    1597
    BHC-C
    1588
    3733
    CBL
    1402
    3731
    CDM FP
    1593
    3731
    CDM PP
    1593
    3731
    DL
    3032
    3697
    FDC
    3032
    3731
    GR-N
    2957
    2526
    IES
    375
    3737
    ML MLL
    3032
    3505
    SNP
    3032
    3731
    TS
    67
    3005
    VELOCITY
    67
    3732

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    101
    1660
    2929
    2929
    2943
    2958
    3026
    3037
    3037
    3121
    3481
    3616
    3716