Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.11.2024 - 09:09
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7120/1-4 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.
    7120/1-4 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).
    APPRAISAL
    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.
    7120/1-4
    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.
    Lundin Norway 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.
    1513-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.
    73
    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,
    23.05.2014
    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.
    03.08.2014
    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.
    03.08.2016
    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.
    03.08.2016
    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.
    APPRAISAL
    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.
    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.
    NO
    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.
    PERMIAN
    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.
    30.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    331.5
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2520.0
    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).
    2520.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    97
    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.
    RØYE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    71° 56' 19.5'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 10' 8.91'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7982516.01
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    471248.44
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    34
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    7429

  • Wellbore history
    General
    Well 7120/1-4 S was drilled on the 7120/1-3 Gotha structure, situated on the southern end of the Loppa High in the Barents Sea. The discovery well 7120/1-3 found oil and gas in Late Permian karst carbonates of the Røye Formation. The primary objective of 7120/1-4 S was to test the reservoir properties and hydrocarbon potential of the Gohta Karst prospect. The secondary objective was to test the reservoir properties and hydrocarbon potential of a potential sandstone sequences in the Kobbe, Klappmyss and Havert formations.
    Operations and results
    Appraisal well 7120/1-4 S was spudded with the semi-submersible installation Island Innovator on 23 May 2014 and drilled to TD at 2520 m (2520 m TVD) in the Late Permian Røye Formation. No significant problem was encountered in the operations. The well was originally planned as an "S" shaped well. This was due to geological hazards connected to a deep-seated fault. Since TD was set 450 m shallow to plan, no deviation was necessary and the well became vertical despite the "S" denotation in the well name. The well was drilled with seawater and hi-vis pills down to 665 m and with Aquadril mud from 665 m to TD.
    The well encountered blocky sandstones in the upper (764.5-802.5 m) Snadd Formation and thin sandstone beds in the lower Snadd target (interval 1200 to 1300 m), but the reservoirs proved water filled. The Kobbe and Klappmyss formations had no reservoir development. A 12.5 m thick mainly gas bearing conglomeratic sandstone unit (interval 2301-2313.5 m), was found at the Permo-Triassic boundary. This unit had pressure gradient almost identical to that of 7120/1-3, indicating a pressure communication between 7120/1-3 and 7120/1-4 S. Stratigraphic age is uncertain but it is likely of Late Permian to Early Triassic in age. Carbonates consisting of partly dolomitic limestones with thin claystone laminae were found from the base of the cored conglomerates/breccia at 2315.77 m to TD at 2520 m. The Gohta Karst reservoir was poorly developed to absent in this well. The carbonates were hydrocarbon bearing, but due to poor reservoir quality, it was not possible to establish an oil-water contact.
    Isolated hydrocarbon / oil shows were described at 750 m, 770 m, 850 m and 870 m. No further shows were observed before entering the conglomeratic breccia at 2301 m. Continuous shows were described from this depth to 2323 m, where it became more patchy. The deepest show described was at 2464 m.
    A total of 112.25 m core was recovered in the interval 2306 to 2419.16 m (99.2% total recovery). MDT fluid samples were acquired from one station at 2308.57 m. The samples contained condensate. Single flash of the condensate gave a GOR in the range 5800 to 6800 Sm3/Sm3, liquid condensate density in the range 0.724 to 732 g/cm3, and gas gravity in the range 0.667 to 0.670 (air = 1).
    The well was permanently abandoned on 3 August 2014 as an oil and gas appraisal well.
    Testing
    Two DST's were conducted.
    DST 1A tested the carbonate oil zone in the interval 2335 to 2385 m. The test produced 30 Sm3 condensate and 160000 Sm3 gas through a 20/64" choke. It was found that the test produced gas from the gas zone above due to lack of cement behind the liner and that the tested carbonate interval contributed nothing to the flow.
    DST 1A+B tested the interval 2335 to 2385 m + the conglomeratic breccia gas zone in the interval 2295 to 2312 m. This test produced 140 Sm3 condensate and 700000 Sm3 gas /day through a 52/64" choke. The GOR was 4500 Sm3/Sm3, the liquid condensate density was 0.730 g/cm3 and the gas gravity was 0.699 (air = 1). H2S and CO2 was less than 1 ppm and 1.1 %, respectively.

  • 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]
    680.00
    2520.00

  • 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
    2306.0
    2332.6
    [m ]
    2
    2333.0
    2361.3
    [m ]
    3
    2361.3
    2364.2
    [m ]
    4
    2364.5
    2391.3
    [m ]
    5
    2391.5
    2419.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    112.3
    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
    441.6
    36
    445.0
    0.00
    SURF.COND.
    20
    657.8
    26
    665.0
    1.28
    LOT
    PILOT HOLE
    675.0
    9 7/8
    675.0
    0.00
    INTERM.
    13 3/8
    1217.0
    17 1/2
    1226.0
    1.59
    FIT
    INTERM.
    9 5/8
    2111.0
    12 1/4
    2119.0
    1.51
    LOT
    LINER
    7
    2520.0
    8 1/2
    2520.0
    0.00

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2295
    2385
    20.6
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    90
    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
    140
    700000
    0.730
    0.699
    4500

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DSL CN ZDL ORIT XMAC RTEX MLL
    2109
    2516
    DSL FLEX MREX
    2200
    2514
    DSL PCOR
    2159
    2507
    DSL STAR HD ORIT UXPL
    2109
    2508
    DSL VSP
    1659
    2499
    GR MDT ADT
    2302
    2452
    LWD - GR RES SON PWD DIR
    361
    1223
    LWD - LWD-GR ABRES PWD DEN CAL N
    1155
    2520
    LWD - NBGR PWD RES DIR DEN CAL N
    2050
    2305

  • Lithostratigraphy

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    361
    1.03
    1.0
    Water Based
    445
    1.04
    1.0
    Water Based
    480
    1.03
    1.0
    Water Based
    665
    1.20
    14.0
    Water Based
    840
    1.16
    10.0
    Water Based
    889
    1.20
    18.0
    Water Based
    1157
    1.21
    15.0
    Water Based
    1980
    1.16
    12.0
    Water Based
    2119
    1.20
    17.0
    Water Based
    2306
    1.16
    20.0
    Water Based
    2520
    1.16
    17.0
    Water Based

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    680.0
    [m]
    DC
    ROBERTSO
    700.0
    [m]
    DC
    ROBERT
    720.0
    [m]
    DC
    ROBERT
    730.0
    [m]
    DC
    ROBERT
    740.0
    [m]
    DC
    ROBERT
    750.0
    [m]
    DC
    ROBERT
    760.0
    [m]
    DC
    ROBERT
    780.0
    [m]
    DC
    ROBERT
    800.0
    [m]
    DC
    ROBERT
    820.0
    [m]
    DC
    ROBERT
    840.0
    [m]
    DC
    ROBERT
    860.0
    [m]
    DC
    ROBERT
    880.0
    [m]
    DC
    ROBERT
    900.0
    [m]
    DC
    ROBERT
    920.0
    [m]
    DC
    ROBERT
    940.0
    [m]
    DC
    ROBERT
    960.0
    [m]
    DC
    ROBERT
    980.0
    [m]
    DC
    1000.0
    [m]
    DC
    ROBERT
    1020.0
    [m]
    DC
    ROBERT
    1040.0
    [m]
    DC
    ROBERT
    1060.0
    [m]
    DC
    ROBERT
    1080.0
    [m]
    DC
    ROBERT
    1100.0
    [m]
    DC
    ROBERT
    1120.0
    [m]
    DC
    ROBERT
    1140.0
    [m]
    DC
    ROBERT
    1160.0
    [m]
    DC
    ROBERT
    1180.0
    [m]
    DC
    ROBERT
    1200.0
    [m]
    DC
    ROBERT
    1220.0
    [m]
    DC
    ROBERT
    1240.0
    [m]
    DC
    ROBERT
    1260.0
    [m]
    DC
    ROBERT
    1280.0
    [m]
    DC
    ROBERT
    1300.0
    [m]
    DC
    ROBERT
    1320.0
    [m]
    DC
    ROBERT
    1340.0
    [m]
    DC
    ROBERT
    1360.0
    [m]
    DC
    ROBERT
    1380.0
    [m]
    DC
    ROBERT
    1400.0
    [m]
    DC
    ROBERT
    1430.0
    [m]
    DC
    ROBERT
    1440.0
    [m]
    DC
    ROBERT
    1460.0
    [m]
    DC
    ROBERT
    1480.0
    [m]
    DC
    ROBERT
    1500.0
    [m]
    DC
    ROBERT
    1520.0
    [m]
    DC
    ROBERT
    1540.0
    [m]
    DC
    ROBERT
    1560.0
    [m]
    DC
    ROBERT
    1580.0
    [m]
    DC
    ROBERT
    1600.0
    [m]
    DC
    ROBERT
    1620.0
    [m]
    DC
    ROBERT
    1640.0
    [m]
    DC
    ROBERT
    1660.0
    [m]
    DC
    ROBERT
    1680.0
    [m]
    DC
    ROBERT
    1700.0
    [m]
    DC
    ROBERT
    1710.0
    [m]
    DC
    ROBERT
    1725.0
    [m]
    DC
    ROBERT
    1740.0
    [m]
    DC
    ROBERT
    1755.0
    [m]
    DC
    ROBERT
    1770.0
    [m]
    DC
    ROBERT
    1785.0
    [m]
    DC
    ROBERT
    1800.0
    [m]
    DC
    ROBERT
    1815.0
    [m]
    DC
    ROBERT
    1845.0
    [m]
    DC
    ROBERT
    1860.0
    [m]
    DC
    ROBERT
    1880.0
    [m]
    DC
    ROBERT
    1910.0
    [m]
    DC
    ROBERT
    1925.0
    [m]
    DC
    ROBERT
    1940.0
    [m]
    DC
    ROBERT
    1955.0
    [m]
    DC
    ROBERT
    1970.0
    [m]
    DC
    ROBERT
    1985.0
    [m]
    DC
    ROBERT
    1995.0
    [m]
    DC
    ROBERT
    2000.0
    [m]
    DC
    ROBERT
    2015.0
    [m]
    DC
    ROBERT
    2030.0
    [m]
    DC
    ROBERT
    2045.0
    [m]
    DC
    ROBERT
    2060.0
    [m]
    DC
    ROBERT
    2075.0
    [m]
    DC
    ROBERT
    2085.0
    [m]
    DC
    ROBERT
    2100.0
    [m]
    DC
    ROBERT
    2115.0
    [m]
    DC
    ROBERT
    2131.0
    [m]
    DC
    ROBERT
    2149.0
    [m]
    DC
    ROBERT
    2167.0
    [m]
    DC
    ROBERT
    2185.0
    [m]
    DC
    ROBERT
    2203.0
    [m]
    DC
    ROBERT
    2221.0
    [m]
    DC
    ROBERT
    2239.0
    [m]
    DC
    ROBERT
    2257.0
    [m]
    DC
    ROBERT
    2275.0
    [m]
    DC
    ROBERT
    2281.0
    [m]
    DC
    ROBERT
    2287.0
    [m]
    DC
    ROBERT
    2290.0
    [m]
    DC
    ROBERT
    2293.0
    [m]
    DC
    ROBERT
    2296.0
    [m]
    DC
    ROBERT
    2299.0
    [m]
    DC
    ROBERT
    2302.0
    [m]
    DC
    ROBERT
    2306.0
    [m]
    DC
    ROBERT
    2306.0
    [m]
    C
    APT
    2307.3
    [m]
    C
    APT
    2309.5
    [m]
    C
    ROBERT
    2310.9
    [m]
    C
    APT
    2312.1
    [m]
    C
    APT
    2313.8
    [m]
    C
    ROBERT
    2315.5
    [m]
    C
    APT
    2315.5
    [m]
    C
    ROBERT
    2317.7
    [m]
    C
    ROBERT
    2323.8
    [m]
    C
    ROBERT
    2323.8
    [m]
    C
    ROBERT
    2327.4
    [m]
    C
    ROBERT
    2328.9
    [m]
    C
    ROBERT
    2343.9
    [m]
    C
    ROBERT
    2352.3
    [m]
    C
    ROBERT
    2358.5
    [m]
    C
    ROBERT
    2368.7
    [m]
    C
    ROBERT
    2373.8
    [m]
    C
    ROBERT
    2386.8
    [m]
    C
    ROBERT
    2393.0
    [m]
    C
    ROBERT
    2396.7
    [m]
    C
    ROBERT
    2409.0
    [m]
    C
    ROBERT
    2418.4
    [m]
    C
    ROBERT