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

7125/4-1

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.
    7125/4-1
    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
    Press release
    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.
    BARENTS 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.
    7125/4-1
    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.
    Norsk Hydro Petroleum AS
    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.
    1128-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.
    50
    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,
    17.01.2007
    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.
    07.03.2007
    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.
    07.03.2009
    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.
    09.03.2009
    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/GAS
    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.
    EARLY JURASSIC
    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.
    NORDMELA 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 TRIASSIC
    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.
    FRUHOLMEN 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.
    MIDDLE TRIASSIC
    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.
    KOBBE 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.
    293.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1615.0
    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).
    1615.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    48
    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 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.
    KLAPPMYSS FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    71° 33' 0.8'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    25° 14' 22.32'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7939886.06
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    437821.20
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    35
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    5450

  • Wellbore history
    Wellbore history
    General
    Wildcat well 7125/4-1 was drilled on the Måsøy Fault Complex in the Barents Sea. The primary objective was to prove commercial hydrocarbon resources within the Nucula prospect, a 4-way structural closure dependent on sealing faults. The structure comprises the Middle Jurassic - Late Triassic Realgrunnen Group, the Late - Middle Triassic Snadd Formation and the Middle Triassic Kobbe Formation reservoirs.
    Operations and results
    Well 7125/4-1 was spudded with the semi-submersible installation Polar Pioneer on 17 January 2007 and drilled to TD at 1615 m in the Early Triassic Klappmyss Formation. The well was drilled without significant technical problems. It was drilled with sodium chloride brine down to 465 m and with potassium formate mud from 465 m to TD. No shallow gas was observed.
    The Kapp Toscana Group, penetrated at 872 m, proved movable gas and oil in the Nordmela and Fruholmen Formations with a GOC at 894 m and an ODT at 939 m. Gas and oil samples were recovered at 951.8 m and 967 m respectively, suggest a separate reservoir at this level, but tight formation makes it difficult to evaluate, and these samples may represent a continuation of the reservoir above. The reservoir had a considerably poorer net/gross than expected. The underlying Snadd Formation was encountered at 1002 m. It was water bearing in the upper part where some sandstone intervals with very good reservoir quality were penetrated. Traces of oil and gas were described in the lower part of Snadd. The Kobbe Formation was encountered at 1206 m. It had a few good reservoir sandstones, especially in the upper part, and some residual oil was proven in this zone. Towards the lower part of the formation at 1428 m, some 60 m of gas was proven down to a probable thin oil zone at 1484 m. The lowest part of the Kobbe Formation proved water gradient. The Klappmyss Formation, penetrated outside of the structural closure, contained interbedded claystones and sandstones without shows of hydrocarbons.
    Two cores were cut in the Fruholmen Formation comprising mudstones, sandstones and siltstones. MDT gas samples were recovered at 883.4 m, 951.8 m and 1477.3 m. MDT oil samples were recovered at 914.5 m, 938.1 m, 967.0 m, 898.2 m and 1487.8 m. MDT water samples were collected at 986.5 and 1508.9 m.
    After wire line logging the well was permanently plugged and abandoned as an oil and gas discovery well on 7 March 2007.
    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]
    470.00
    1615.00

  • 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
    885.0
    894.7
    [m ]
    2
    895.0
    909.1
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    23.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    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
    376.0
    36
    376.0
    0.00
    LOT
    SURF.COND.
    20
    454.0
    26
    454.0
    0.00
    LOT
    INTERM.
    13 3/8
    551.0
    17 1/2
    551.0
    1.14
    LOT
    INTERM.
    9 5/8
    838.0
    12 1/4
    838.0
    1.51
    LOT
    OPEN HOLE
    1615.0
    8 1/2
    1615.0
    1.85
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DSI TLD DNL
    556
    844
    FMI APS GR PPC MSIP
    838
    1253
    FMI MSIP PPC
    1230
    1605
    MDT
    862
    1245
    MDT
    873
    986
    MDT PEX ECS HNGS
    1134
    1604
    MDT Q
    1405
    1524
    MSCT
    840
    1593
    MSCT
    1253
    1253
    MSIP PPC IS
    1200
    1284
    MWD - ARC DT RAB APWD DIR
    316
    1615
    SP SMR HRLA PEX ECS HNGS
    838
    1253
    VSP
    317
    1605

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.28

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    txt
    0.00
    txt
    0.33
    pdf
    0.40
    pdf
    2.40

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    404
    1.03
    WATER BASED
    474
    1.07
    14.0
    WATER BASED
    556
    1.08
    11.0
    WATER BASED
    705
    1.30
    19.0
    WATER BASED
    844
    1.30
    19.0
    WATER BASED

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    470.0
    [m]
    DC
    FUGRO
    490.0
    [m]
    DC
    FUGRO
    496.0
    [m]
    DC
    FUGRO
    500.0
    [m]
    DC
    FUGRO
    510.0
    [m]
    DC
    FUGRO
    516.0
    [m]
    DC
    FUGRO
    530.0
    [m]
    DC
    FUGRO
    540.0
    [m]
    DC
    FUGRO
    560.0
    [m]
    DC
    FUGRO
    570.0
    [m]
    DC
    FUGRO
    580.0
    [m]
    DC
    FUGRO
    600.0
    [m]
    DC
    FUGRO
    620.0
    [m]
    DC
    FUGRO
    640.0
    [m]
    DC
    FUGRO
    660.0
    [m]
    DC
    FUGRO
    680.0
    [m]
    DC
    FUGRO
    690.0
    [m]
    DC
    FUGRO
    700.0
    [m]
    DC
    FUGRO
    710.0
    [m]
    DC
    FUGRO
    720.0
    [m]
    DC
    FUGRO
    730.0
    [m]
    DC
    FUGRO
    740.0
    [m]
    DC
    FUGRO
    750.0
    [m]
    DC
    FUGRO
    760.0
    [m]
    DC
    FUGRO
    770.0
    [m]
    DC
    FUGRO
    780.0
    [m]
    DC
    FUGRO
    790.0
    [m]
    DC
    FUGRO
    800.0
    [m]
    DC
    FUGRO
    810.0
    [m]
    DC
    FUGRO
    820.0
    [m]
    DC
    FUGRO
    830.0
    [m]
    DC
    FUGRO
    845.0
    [m]
    DC
    FUGRO
    850.0
    [m]
    DC
    FUGRO
    856.0
    [m]
    DC
    FUGRO
    862.0
    [m]
    DC
    FUGRO
    865.0
    [m]
    DC
    FUGRO
    868.0
    [m]
    DC
    FUGRO
    871.0
    [m]
    DC
    FUGRO
    871.0
    [m]
    SWC
    FUGRO
    874.0
    [m]
    DC
    FUGRO
    877.0
    [m]
    DC
    ROBERT
    879.5
    [m]
    SWC
    FUGRO
    880.0
    [m]
    DC
    FUGRO
    883.0
    [m]
    DC
    FUGRO
    885.0
    [m]
    DC
    FUGRO
    887.3
    [m]
    C
    ICHRON
    889.0
    [m]
    C
    FUGRO
    901.6
    [m]
    C
    ICHRON
    905.0
    [m]
    C
    ICHRON
    906.3
    [m]
    C
    ICHRON
    907.5
    [m]
    C
    ICHRON
    913.0
    [m]
    DC
    FUGRO
    952.0
    [m]
    DC
    FUGRO
    958.0
    [m]
    DC
    FUGRO
    964.0
    [m]
    DC
    FUGRO
    967.0
    [m]
    DC
    FUGRO
    976.0
    [m]
    DC
    FUGRO
    985.0
    [m]
    DC
    FUGRO
    988.0
    [m]
    DC
    FUGRO
    994.0
    [m]
    DC
    FUGRO
    1003.0
    [m]
    DC
    FUGRO
    1009.0
    [m]
    DC
    FUGRO
    1021.0
    [m]
    DC
    FUGRO
    1036.0
    [m]
    DC
    FUGRO
    1042.0
    [m]
    DC
    FUGRO
    1054.0
    [m]
    DC
    FUGRO
    1060.0
    [m]
    DC
    FUGRO
    1066.0
    [m]
    DC
    FUGRO
    1084.0
    [m]
    DC
    FUGRO
    1090.0
    [m]
    DC
    FUGRO
    1096.0
    [m]
    DC
    FUGRO
    1105.0
    [m]
    DC
    FUGRO
    1123.0
    [m]
    DC
    FUGRO
    1126.0
    [m]
    DC
    FUGRO
    1138.0
    [m]
    DC
    FUGRO
    1150.0
    [m]
    DC
    FUGRO
    1168.0
    [m]
    DC
    FUGRO
    1186.0
    [m]
    DC
    FUGRO
    1192.0
    [m]
    DC
    FUGRO
    1198.0
    [m]
    DC
    FUGRO
    1203.0
    [m]
    SWC
    FUGRO
    1204.0
    [m]
    DC
    FUGRO
    1205.0
    [m]
    SWC
    FUGRO
    1213.0
    [m]
    DC
    FUGRO
    1218.0
    [m]
    SWC
    FUGRO
    1219.0
    [m]
    DC
    FUGRO
    1228.0
    [m]
    DC
    FUGRO
    1237.0
    [m]
    SWC
    FUGRO
    1245.0
    [m]
    SWC
    FUGRO
    1249.0
    [m]
    DC
    FUGRO
    1252.0
    [m]
    DC
    FUGRO
    1258.0
    [m]
    DC
    FUGRO
    1285.0
    [m]
    DC
    FUGRO
    1297.0
    [m]
    DC
    FUGRO
    1303.0
    [m]
    DC
    FUGRO
    1306.0
    [m]
    DC
    FUGRO
    1310.0
    [m]
    DC
    FUGRO
    1328.0
    [m]
    DC
    FUGRO
    1333.0
    [m]
    DC
    FUGRO
    1339.0
    [m]
    DC
    FUGRO
    1339.0
    [m]
    SWC
    FUGRO
    1342.0
    [m]
    DC
    FUGRO
    1346.7
    [m]
    SWC
    FUGRO
    1358.6
    [m]
    SWC
    FUGRO
    1378.0
    [m]
    DC
    FUGRO
    1379.1
    [m]
    SWC
    FUGRO
    1384.0
    [m]
    DC
    FUGRO
    1390.0
    [m]
    DC
    FUGRO
    1396.0
    [m]
    DC
    FUGRO
    1409.2
    [m]
    SWC
    FUGRO
    1414.0
    [m]
    DC
    FUGRO
    1421.0
    [m]
    DC
    FUGRO
    1429.0
    [m]
    DC
    FUGRO
    1435.0
    [m]
    DC
    FUGRO
    1441.0
    [m]
    DC
    FUGRO
    1448.0
    [m]
    DC
    FUGRO
    1459.0
    [m]
    DC
    FUGRO
    1465.0
    [m]
    DC
    FUGRO
    1488.0
    [m]
    DC
    FUGRO
    1501.0
    [m]
    DC
    FUGRO
    1505.0
    [m]
    DC
    FUGRO
    1513.0
    [m]
    DC
    FUGRO
    1522.0
    [m]
    DC
    FUGRO
    1525.0
    [m]
    DC
    FUGRO
    1534.0
    [m]
    DC
    FUGRO
    1540.0
    [m]
    DC
    FUGRO
    1548.0
    [m]
    DC
    FUGRO
    1550.0
    [m]
    SWC
    FUGRO
    1555.0
    [m]
    DC
    FUGRO
    1567.0
    [m]
    DC
    FUGRO
    1571.0
    [m]
    DC
    FUGRO
    1573.0
    [m]
    DC
    FUGRO
    1575.2
    [m]
    SWC
    FUGRO
    1579.0
    [m]
    DC
    FUGRO
    1588.0
    [m]
    DC
    FUGRO
    1588.0
    [m]
    SWC
    FUGRO
    1593.0
    [m]
    SWC
    FUGRO
    1600.0
    [m]
    DC
    FUGRO
    1609.0
    [m]
    DC
    FUGRO
    1612.0
    [m]
    DC
    FUGRO
    1615.0
    [m]
    DC
    FUGRO

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    885.20
    [m ]
    886.40
    [m ]
    887.20
    [m ]
    894.20
    [m ]
    899.80
    [m ]
    901.05
    [m ]
    904.50
    [m ]
    905.50
    [m ]