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

2/11-2

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.
    2/11-2
    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
    Field
    Name of the field the wellbore is related to.
    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.
    2/11-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LINE 73-21 SP.31
    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.
    120-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.
    54
    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,
    06.11.1974
    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.
    29.12.1974
    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.
    29.12.1976
    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.
    22.03.2013
    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.
    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.
    HOD FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    36.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    66.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2806.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    67
    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.
    EARLY CRETACEOUS
    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.
    RØDBY FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 10' 51.2'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 25' 25.9'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6226431.02
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    526312.89
    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.
    285

  • Wellbore history
    General
    Well 2/11-2 was drilled on the Hod prospect on the Skrubbe Fault between the Lindesnes Ridge and the Ål Basin in the southern North Sea. The "Hod" anticline is a satellite or subsidiary feature immediately to the southwest of the large Valhall structure. The primary objective was the Danian/Late Cretaceous chalk section, the productive horizon in surrounding fields. Paleocene sand/siltstones would be secondary objectives, if encountered. These had shows in well 2/11-1, located 6.4 km north.
    Operations and results
    Wildcat well 2/11-2 was spudded with the semi-submersible installation Zapata Explorer on 6 November 1974 and drilled to TD at 2806 m in the Early Cretaceous Rødby Formation. It was drilled in 37 days without major problems, although 10 days were lost due to waiting on water, combating lost circulation after an attempt to kill a gas kick, and waiting on a new BOP stack after a leak was found on the old equipment. The well was drilled with seawater and Milben saltgel mud down to 145 m, with seawater, pre-hydrated Milben, Flosal mud from 145 m to 383 m, with Drispac/Flosal mud from 385 m to 1295 m, with Shale Trol until gumbo, converting to a Unical/seawater mud from 1295 m to 2660 m, and with a Unical/seawater mud from 2660 m to TD.
    High gas readings were recorded from approximately 1415 m to 1675 m. Oil shows (dull yellow fluorescence and poor - fair cut) and free oil in the mud was also noted during the drilling of the above interval. Oil bearing Santonian - Coniacian chalk (Hod Formation) was encountered at 2640.5. The section had 51.5 m net pay with estimated average porosity of 27.7 percent and an average water saturation of 40.3 percent.
    A core was taken from 2660.9 m to 2670.4 m, with 100% recovery. No fluid sample was taken on wire line.
    The well was permanently abandoned on 29 December 1974 as an oil discovery.
    Testing
    Three Drill Stem Tests were performed in the well.
    DST 1 tested the interval 2672.2 m to 2679.8 m in Turonian-Santonian chalk (Hod Formation). The test gave a weak flow, too weak to measure flow rates, but a small amount of 35 deg API oil was produced.
    DST 2 tested the interval 2642.6 m to 2665.5 m in Turonian-Santonian chalk (Hod Formation). The interval was stimulated with acid before testing. On a restricted flow, the well tested 463 Sm3 oil/day with a well head pressure of 160.3 bar. No water was produced. The GOR was 194 Sm3/Sm3 and the oil gravity was 36 deg API. Maximum flow was 546 Sm3 oil and 82120 Sm3 gas /day
    DST 3 tested the interval 1499.6 m to 1503.3 plus 1512.4 m to 1517.3 m plus 1521 m to 1523.4 m in Oligocene silty shales of the Hordaland Group. After acid stimulation the test flowed very weak during all three flow periods. Some oil was produced towards the end of the last flow period.

  • 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]
    143.26
    2806.29

  • 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
    8731.0
    8740.0
    [ft ]
    2
    8740.0
    8749.0
    [ft ]
    3
    8749.0
    8758.0
    [ft ]
    4
    8758.0
    8761.0
    [ft ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    9.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    6550.0
    [ft]
    DC
    HRS
    6610.0
    [ft]
    DC
    HRS
    6670.0
    [ft]
    DC
    HRS
    6730.0
    [ft]
    DC
    HRS
    6790.0
    [ft]
    DC
    HRS
    6930.0
    [ft]
    DC
    HRS
    7050.0
    [ft]
    DC
    HRS
    7170.0
    [ft]
    DC
    HRS
    7290.0
    [ft]
    DC
    HRS
    7410.0
    [ft]
    DC
    HRS
    7530.0
    [ft]
    DC
    HRS
    7650.0
    [ft]
    DC
    HRS
    7770.0
    [ft]
    DC
    HRS
    7870.0
    [ft]
    DC
    HRS
    7990.0
    [ft]
    DC
    HRS
    8110.0
    [ft]
    DC
    HRS
    8230.0
    [ft]
    DC
    HRS
    8350.0
    [ft]
    DC
    HRS
    8390.0
    [ft]
    DC
    HRS
    8430.0
    [ft]
    DC
    HRS
    8470.0
    [ft]
    DC
    HRS
    8510.0
    [ft]
    DC
    HRS
    8530.0
    [ft]
    DC
    HRS
    8550.0
    [ft]
    DC
    HRS
    8570.0
    [ft]
    DC
    HRS
    8600.0
    [ft]
    DC
    HRS
    8620.0
    [ft]
    DC
    HRS
    8640.0
    [ft]
    DC
    HRS
    8660.0
    [ft]
    DC
    HRS
    8680.0
    [ft]
    DC
    HRS

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    102
    1457
    2568
    2568
    2573
    2597
    2640
    2640
    2752
    2752

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.82
    pdf
    2.54

  • 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
    2.34
    pdf
    12.14

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2672
    2680
    0.0
    2.0
    2643
    2665
    0.0
    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
    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
    545
    82120
    0.830
    194

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL CCL GR
    609
    2634
    CBL CCL GR
    2546
    2693
    CNL FDC GR
    1432
    2659
    CNL FDC GR CAL
    2634
    2806
    CNL GR
    91
    1280
    DL MSFL
    2512
    2809
    IES SP
    427
    2659
    IES SP
    2636
    2812
    SON GR CAL
    1280
    2656
    SON GR CAL
    2634
    2808
    TEMP
    94
    1676
    VELOCITY
    304
    2572

  • 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
    149.0
    36
    149.0
    0.00
    LOT
    SURF.COND.
    20
    369.0
    26
    381.0
    0.00
    LOT
    INTERM.
    13 3/8
    1283.0
    17 1/2
    1295.0
    0.00
    LOT
    INTERM.
    9 5/8
    2638.0
    12 1/4
    2660.0
    0.00
    LOT
    LINER
    7
    2716.0
    8 1/2
    2797.0
    0.00
    LOT
    OPEN HOLE
    2806.0
    6
    2806.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    144
    1.08
    sw w gel
    382
    1.13
    sw w gel
    1295
    1.30
    sw w gel
    2660
    1.80
    sw w gel
    2806
    1.70
    sw w gel