Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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13.11.2024 - 01:26
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7120/6-2 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.
    7120/6-2 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
    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
    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.
    7120/6-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    HR line ST0691-05006-SP 1254 line ST0691-SP 1258
    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.
    Statoil ASA (old)
    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.
    936-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.
    39
    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,
    14.06.2007
    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.
    22.07.2007
    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.
    22.07.2009
    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.
    22.07.2009
    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.
    APPRAISAL
    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/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.
    MIDDLE 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.
    STØ 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.
    321.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3242.0
    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).
    3035.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    32
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    111
    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 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.
    SNADD FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    71° 36' 0.6'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 49' 41.7'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7944559.34
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    493948.96
    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.
    3558

  • Wellbore history
    General
    Well 7120/6-2 S is an appraisal well on the Snøhvit Field in the Hammerfest Basin in the Barents Sea. The primary objective for the well was to prove that there are 36 MSm3 oil in place in the best reservoir zones where the oil is producible, in the Stø 2 and Stø 1 Formations. The well was also to confirm that the oil-water contact is located in the clean quartz sandstone at Stø 2 level in the Stø Formation. In addition, the assumed good quality and the thickening of the reservoir that was expected in the western part of the Snøhvit Field would be proven. A secondary objective for this well was to prove larger gas volumes in the western part of the Snøhvit Field than was calculated earlier.
    Operations and results
    Well 7120/6-2 S was spudded with the semi-submersible installation Polar Pioneer on 14 June 2007 and drilled to TD at 3242 m (3035 m TVD) in the Late Triassic Snadd formation. It was designed as an S-well in order to avoid shallow gas in the area and maintain stratigraphic/seismic control while drilling. The well started to build inclination from 470 m and reached maximum inclination of 32 deg in the interval ca 1600 to 2000 m in the 12 1/4" section. The hole packed of several times in the 17 1/2" section. This caused no significant delay in the drilling progress, but no logs were run in this section, from 932 - 1259 m. Formation tops in this section are based on the prognosis. No shallow gas was expected, and no shallow gas was observed. The well was drilled with sea water and bentonite down to 1259 m and with FORMPRO mud from 1259 m to TD.
    The observed stratigraphy was well within the uncertainties given in the prognosis, with the exception of the Hekkingen Formation which was 16.5 m shallower than anticipated. Generally the difference from prognosis to result was within +/- 6.5 m and there were no trends in the discrepancies. The Stø Formation (target reservoir) was encountered at 2564 m (2371 m TVD RKB). The gas-oil contact was found at 2626 m (2429.6 m TVD RKB) and the oil-water contact at 2637 m (2440.3 m TVD RKB), both contacts at Stø 2 level. However, the oil rim was thinner than expected, only 10.7 m thick in this area. The in-place oil volume in the western part of the Snøhvit Field called Main Oil Province was reduced from 36 MSm3 to 26 MSm3. These oil reserves were proven to be too small to be of economic interest. Weak shows were recorded on the cores below OWC and down to the base of the Stø Formation at 2678 m. No hydrocarbons were identified in the Snadd Formation and no shows were reported above the Stø Formation reservoir.
    Two cores were cut from 2566.5 to 2683.0 m in the Stø Formation and 5 m into to Nordmela Formation. MDT gas, water and oil samples were collected at 13 depths in the Stø Formation. A water sample was also collected in the Tubåen Formation at 2802 m.
    The well was suspended on 22 July 2007 as a possible future injector for formation water or CO2. It is classified as an oil and gas appraisal well.
    Testing
    No drill stem test was performed.
    ies.

  • 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]
    1260.00
    3242.00

  • 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
    2566.5
    2598.2
    [m ]
    2
    2599.5
    2681.9
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    114.1
    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
    1260.0
    [m]
    DC
    APT
    1280.0
    [m]
    DC
    APT
    1300.0
    [m]
    DC
    APT
    1320.0
    [m]
    DC
    APT
    1340.0
    [m]
    DC
    APT
    1360.0
    [m]
    DC
    APT
    1380.0
    [m]
    DC
    APT
    1400.0
    [m]
    DC
    APT
    1550.0
    [m]
    DC
    APT
    1570.0
    [m]
    DC
    APT
    1590.0
    [m]
    DC
    APT
    1610.0
    [m]
    DC
    APT
    1630.0
    [m]
    DC
    APT
    1650.0
    [m]
    DC
    APT
    1670.0
    [m]
    DC
    APT
    1680.0
    [m]
    DC
    APT
    1700.0
    [m]
    DC
    APT
    1720.0
    [m]
    DC
    APT
    1740.0
    [m]
    DC
    APT
    1760.0
    [m]
    DC
    APT
    1780.0
    [m]
    DC
    APT
    1800.0
    [m]
    DC
    APT
    1820.0
    [m]
    DC
    APT
    1840.0
    [m]
    DC
    APT
    1860.0
    [m]
    DC
    APT
    1880.0
    [m]
    DC
    APT
    1900.0
    [m]
    DC
    APT
    1920.0
    [m]
    DC
    APT
    1940.0
    [m]
    DC
    APT
    1960.0
    [m]
    DC
    APT
    1980.0
    [m]
    DC
    APT
    2000.0
    [m]
    DC
    APT
    2020.0
    [m]
    DC
    APT
    2040.0
    [m]
    DC
    APT
    2060.0
    [m]
    DC
    APT
    2080.0
    [m]
    DC
    APT
    2100.0
    [m]
    DC
    APT
    2120.0
    [m]
    DC
    APT
    2140.0
    [m]
    DC
    APT
    2160.0
    [m]
    DC
    APT
    2180.0
    [m]
    DC
    APT
    2200.0
    [m]
    DC
    APT
    2210.0
    [m]
    DC
    APT
    2220.0
    [m]
    DC
    APT
    2230.0
    [m]
    DC
    APT
    2240.0
    [m]
    DC
    APT
    2250.0
    [m]
    DC
    APT
    2260.0
    [m]
    DC
    APT
    2270.0
    [m]
    DC
    APT
    2280.0
    [m]
    DC
    APT
    2290.0
    [m]
    DC
    APT
    2300.0
    [m]
    DC
    APT
    2310.0
    [m]
    DC
    APT
    2320.0
    [m]
    DC
    APT
    2330.0
    [m]
    DC
    APT
    2340.0
    [m]
    DC
    APT
    2350.0
    [m]
    DC
    APT
    2360.0
    [m]
    DC
    APT
    2370.0
    [m]
    DC
    APT
    2380.0
    [m]
    DC
    APT
    2390.0
    [m]
    DC
    APT
    2400.0
    [m]
    DC
    APT
    2406.0
    [m]
    DC
    APT
    2412.0
    [m]
    DC
    APT
    2418.0
    [m]
    DC
    APT
    2424.0
    [m]
    DC
    APT
    2430.0
    [m]
    DC
    APT
    2436.0
    [m]
    DC
    APT
    2442.0
    [m]
    DC
    APT
    2448.0
    [m]
    DC
    APT
    2454.0
    [m]
    DC
    APT
    2460.0
    [m]
    DC
    APT
    2466.0
    [m]
    DC
    APT
    2472.0
    [m]
    DC
    APT
    2478.0
    [m]
    DC
    APT
    2484.0
    [m]
    DC
    APT
    2490.0
    [m]
    DC
    APT
    2496.0
    [m]
    DC
    APT
    2502.0
    [m]
    DC
    APT
    2508.0
    [m]
    DC
    APT
    2514.0
    [m]
    DC
    APT
    2526.0
    [m]
    DC
    APT
    2532.0
    [m]
    DC
    APT
    2538.0
    [m]
    DC
    APT
    2544.0
    [m]
    DC
    APT
    2550.0
    [m]
    DC
    APT
    2556.0
    [m]
    DC
    APT
    2562.0
    [m]
    DC
    APT
    2565.0
    [m]
    DC
    APT
    2572.7
    [m]
    C
    APT
    2576.1
    [m]
    C
    APT
    2578.7
    [m]
    C
    APT
    2583.5
    [m]
    C
    APT
    2585.5
    [m]
    C
    APT
    2595.4
    [m]
    C
    APT
    2596.4
    [m]
    C
    APT
    2601.4
    [m]
    C
    APT
    2607.9
    [m]
    C
    APT
    2637.6
    [m]
    C
    APT
    2639.2
    [m]
    C
    APT
    2654.5
    [m]
    C
    APT
    2658.0
    [m]
    C
    APT
    2660.3
    [m]
    C
    APT
    2663.8
    [m]
    C
    APT
    2667.2
    [m]
    C
    APT
    2671.9
    [m]
    C
    APT
    2674.7
    [m]
    C
    APT
    2675.3
    [m]
    C
    APT
    2676.8
    [m]
    C
    APT
    2676.9
    [m]
    C
    APT
    2677.3
    [m]
    C
    APT
    2677.6
    [m]
    C
    APT
    2678.2
    [m]
    C
    APT
    2680.4
    [m]
    C
    APT
    2680.9
    [m]
    C
    APT
    2681.5
    [m]
    C
    APT
    2685.0
    [m]
    DC
    APT
    2694.0
    [m]
    DC
    APT
    2703.0
    [m]
    DC
    APT
    2712.0
    [m]
    DC
    APT
    2721.0
    [m]
    DC
    APT
    2730.0
    [m]
    DC
    APT
    2739.0
    [m]
    DC
    APT
    2748.0
    [m]
    DC
    APT
    2757.0
    [m]
    DC
    APT
    2766.0
    [m]
    DC
    APT
    2775.0
    [m]
    DC
    APT
    2784.0
    [m]
    DC
    APT
    2793.0
    [m]
    DC
    APT
    2802.0
    [m]
    DC
    APT
    2811.0
    [m]
    DC
    APT
    2820.0
    [m]
    DC
    APT
    2829.0
    [m]
    DC
    APT
    2841.0
    [m]
    DC
    APT
    2850.0
    [m]
    DC
    APT
    2859.0
    [m]
    DC
    APT
    2868.0
    [m]
    DC
    APT
    2877.0
    [m]
    DC
    APT
    2886.0
    [m]
    DC
    APT
    2895.0
    [m]
    DC
    APT
    2904.0
    [m]
    DC
    APT
    2913.0
    [m]
    DC
    APT
    2922.0
    [m]
    DC
    APT
    2931.0
    [m]
    DC
    APT
    2940.0
    [m]
    DC
    APT
    2949.0
    [m]
    DC
    APT
    2958.0
    [m]
    DC
    APT
    2967.0
    [m]
    DC
    APT
    2976.0
    [m]
    DC
    APT
    2985.0
    [m]
    DC
    APT
    2994.0
    [m]
    DC
    APT
    3003.0
    [m]
    DC
    APT
    3012.0
    [m]
    DC
    APT
    3021.0
    [m]
    DC
    APT
    3030.0
    [m]
    DC
    APT
    3036.0
    [m]
    DC
    APT
    3045.0
    [m]
    DC
    APT
    3054.0
    [m]
    DC
    APT
    3063.0
    [m]
    DC
    APT
    3072.0
    [m]
    DC
    APT
    3081.0
    [m]
    DC
    APT
    3090.0
    [m]
    DC
    APT
    3102.0
    [m]
    DC
    APT
    3108.0
    [m]
    DC
    APT
    3114.0
    [m]
    DC
    APT
    3120.0
    [m]
    DC
    APT
    3126.0
    [m]
    DC
    APT
    3132.0
    [m]
    DC
    APT
    3138.0
    [m]
    DC
    APT
    3144.0
    [m]
    DC
    APT
    3150.0
    [m]
    DC
    APT
    3156.0
    [m]
    DC
    APT
    3162.0
    [m]
    DC
    APT
    3168.0
    [m]
    DC
    APT
    3174.0
    [m]
    DC
    APT
    3180.0
    [m]
    DC
    APT
    3186.0
    [m]
    DC
    APT
    3192.0
    [m]
    DC
    APT
    3198.0
    [m]
    DC
    APT
    3204.0
    [m]
    DC
    APT
    3213.0
    [m]
    DC
    APT
    3222.0
    [m]
    DC
    APT
    3231.0
    [m]
    DC
    APT
    3240.0
    [m]
    DC
    APT
    3242.0
    [m]
    DC
    APT

  • 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
    0
    2630.00
    0.00
    OIL
    YES
    MDT
    2632.00
    0.00
    OIL
    11.07.2007 - 03:05
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.30

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.23

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    FMI MSIP PPC XPT ACTS ECRD
    1730
    3242
    MDT
    2615
    2632
    MDT
    2627
    2623
    MDT
    2630
    2630
    MDT
    2631
    2631
    MDT
    2676
    2802
    MWD - DI
    344
    411
    MWD - GR RES ECD ESD DI
    411
    3242
    PEX HRLA HNGS CMR
    3242
    2664
    WAVSP
    344
    3200

  • 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
    407.0
    36
    411.0
    0.00
    LOT
    INTERM.
    13 3/8
    1218.0
    17 1/2
    1259.0
    1.46
    LOT
    INTERM.
    9 5/8
    2564.0
    12 1/4
    2566.0
    1.59
    LOT
    LINER
    7
    3241.0
    8 1/2
    3242.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    411
    1.03
    SW / BENTONITE 1
    500
    1.03
    SW / BENTONITE 1
    1034
    1.03
    SW / BENTONITE 1
    1259
    1.03
    SW / BENTONITE 1
    2490
    1.33
    21.0
    FORM PRO
    2566
    1.27
    14.0
    FORM PRO
    2567
    1.22
    14.0
    POTASSIUM FORMATE
    2568
    1.27
    8.0
    FORM PRO

  • Pressure plots
    Pressure plots
    The pore pressure data is sourced from well logs if no other source is specified. In some wells where pore pressure logs do not exist, information from Drill stem tests and kicks have been used. The data has been reported to the NPD, and further processed and quality controlled by IHS Markit.
    Pressure plots
    Document name
    Document format
    Document size [MB]
    pdf
    0.28