Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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05.11.2024 - 01:27
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7216/11-1 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.
    7216/11-1 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).
    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
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    7216/11-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH9803 INLINE A 2940 & X-LINE A 4882
    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 Produksjon 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.
    980-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.
    53
    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,
    24.07.2000
    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.
    14.09.2000
    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.
    14.09.2002
    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.
    11.04.2003
    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.
    DRY
    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
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    24.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    361.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4239.0
    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).
    3733.2
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    52.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    114
    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.
    PALEOCENE
    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.
    TORSK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    72° 0' 56.72'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    16° 36' 22'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7991645.42
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    555345.64
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    33
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    4129

  • Wellbore history
    General
    The objective for well 7216/11-1 S was to test the hydrocarbon potential of the A-structure in PL221. Three target horizons were defined in the Palaeogene Lower Torsk Formation (Sotbakken Group). The primary objective was to test the hydrocarbon potential of the A1 prospect, defined as a closure along the flanks of the "A1" horst block at Early Eocene & Late Palaeocene level. The secondary and tertiary objectives were to test the reservoir and hydrocarbon potential of the "A2" and "A3" prospects in the horst block further to the west. The well was originally planned as a straight vertical well east of the horst. The volumes that would be left up dip were, however, considerable. Early in the planning stage the licence therefore decided to drill the well as a deviated borehole.
    Operations and results
    Exploration well 7216/11-1 S was spudded with the semi-submersible installation "Transocean Arctic" on 24 July 2000 and drilled deviated to TD at 4239 m (3733.2 m TVD) in Late Palaeocene sediments of the Torsk Formation. The well was drilled water based with bentonite mud down to 1004 m, and with the "GLYDRIL" mud system from 1004 m to TD. A total of 30 m gross reservoir sequence of excellent quality turbidite sandstone was penetrated in the Late Palaeocene A1 Structure. The reservoirs of the prognosed A2 and A3 prospects were not developed. No HC was encountered in the A1 Formations. No shows were observed while drilling the well. No shows were recorded at well site. After core no 1 was brought onshore and slabbed a bright blue yellow fluorescence was observed in the interval 2991 - 2991.5 m. Neither oil stain nor petroleum odour was observed on the cores. The cuttings gas log indicated an increase in wetness through the claystones above the A1 reservoir, with a maximum wetness in the top of A1. The MWD logs indicated, however, that this sequence was water bearing. Two conventional cores were cut in the Torsk Formation: Core 1 recovered claystone / sandstone from 2988.0 m - 2996.4 m, while core 2 recovered claystone / shale from 4230.0 m & 4238.0 m. One MDT (Modular formation Dynamics Tester) was carried out, but fluid samples were not taken. Due to an obstruction in hole at 2806 m MD, neither logging on wire, TLC or CST was performed in the 8 1/2" section. Thus, only MWD / LWD logs exist from this section. No fluid contacts or fluid gradients was identified from the log and pressure data. A thin gas bearing sand was however observed from density/neutron log at 2012 m. The well was permanently abandoned as a dry well on 14 September 2000.
    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]
    1010.00
    4230.00

  • 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
    2988.0
    2996.4
    [m ]
    2
    4230.0
    4238.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    16.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2988-2993m
    Core photo at depth: 2993-2997m
    Core photo at depth: 4230-4231m
    Core photo at depth: 4231-4236m
    Core photo at depth: 4236-4238m
    2988-2993m
    2993-2997m
    4230-4231m
    4231-4236m
    4236-4238m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1450.0
    [m]
    SWC
    OD
    1550.0
    [m]
    SWC
    OD
    1640.0
    [m]
    SWC
    OD
    1700.0
    [m]
    SWC
    OD
    1760.0
    [m]
    SWC
    OD
    1820.0
    [m]
    SWC
    OD
    1880.0
    [m]
    SWC
    OD
    1940.0
    [m]
    SWC
    OD
    2000.0
    [m]
    SWC
    OD
    2000.0
    [m]
    DC
    OD
    2010.0
    [m]
    DC
    OD
    2020.0
    [m]
    DC
    OD
    2030.0
    [m]
    DC
    OD
    2040.0
    [m]
    DC
    OD
    2050.0
    [m]
    DC
    OD
    2060.0
    [m]
    DC
    OD
    2070.0
    [m]
    DC
    OD
    2080.0
    [m]
    DC
    OD
    2090.0
    [m]
    DC
    OD
    2090.0
    [m]
    SWC
    OD
    2100.0
    [m]
    DC
    OD
    2110.0
    [m]
    DC
    OD
    2120.0
    [m]
    DC
    OD
    2130.0
    [m]
    DC
    OD
    2140.0
    [m]
    DC
    OD
    2150.0
    [m]
    SWC
    OD
    2150.0
    [m]
    DC
    OD
    2160.0
    [m]
    DC
    OD
    2170.0
    [m]
    DC
    OD
    2180.0
    [m]
    SWC
    OD
    2180.0
    [m]
    DC
    OD
    2190.0
    [m]
    DC
    OD
    2200.0
    [m]
    DC
    OD
    2205.0
    [m]
    DC
    OD
    2210.0
    [m]
    DC
    OD
    2215.0
    [m]
    DC
    OD
    2220.0
    [m]
    DC
    OD
    2225.0
    [m]
    DC
    OD
    2230.0
    [m]
    DC
    OD
    2235.0
    [m]
    DC
    OD
    2240.0
    [m]
    SWC
    OD
    2240.0
    [m]
    DC
    OD
    2245.0
    [m]
    DC
    OD
    2250.0
    [m]
    DC
    OD
    2255.0
    [m]
    DC
    OD
    2255.0
    [m]
    DC
    OD
    2260.0
    [m]
    DC
    OD
    2265.0
    [m]
    DC
    OD
    2270.0
    [m]
    DC
    OD
    2275.0
    [m]
    DC
    OD
    2280.0
    [m]
    DC
    OD
    2285.0
    [m]
    DC
    OD
    2290.0
    [m]
    DC
    OD
    2295.0
    [m]
    DC
    OD
    2300.0
    [m]
    SWC
    OD
    2300.0
    [m]
    DC
    OD
    2305.0
    [m]
    DC
    OD
    2310.0
    [m]
    DC
    OD
    2315.0
    [m]
    DC
    OD
    2320.0
    [m]
    SWC
    OD
    2320.0
    [m]
    DC
    OD
    2325.0
    [m]
    DC
    OD
    2330.0
    [m]
    SWC
    OD
    2330.0
    [m]
    DC
    OD
    2335.0
    [m]
    DC
    OD
    2340.0
    [m]
    DC
    OD
    2345.0
    [m]
    DC
    OD
    2350.0
    [m]
    DC
    OD
    2355.0
    [m]
    DC
    OD
    2360.0
    [m]
    SWC
    OD
    2360.0
    [m]
    DC
    OD
    2365.0
    [m]
    DC
    OD
    2370.0
    [m]
    DC
    OD
    2375.0
    [m]
    DC
    OD
    2380.0
    [m]
    SWC
    OD
    2380.0
    [m]
    DC
    OD
    2385.0
    [m]
    DC
    OD
    2390.0
    [m]
    SWC
    OD
    2390.0
    [m]
    DC
    OD
    2395.0
    [m]
    DC
    OD
    2400.0
    [m]
    DC
    OD
    2402.0
    [m]
    SWC
    OD
    2405.0
    [m]
    DC
    OD
    2410.0
    [m]
    DC
    OD
    2415.0
    [m]
    DC
    OD
    2420.0
    [m]
    SWC
    OD
    2420.0
    [m]
    DC
    OD
    2425.0
    [m]
    DC
    OD
    2430.0
    [m]
    DC
    OD
    2435.0
    [m]
    DC
    OD
    2440.0
    [m]
    DC
    OD
    2445.0
    [m]
    DC
    OD
    2450.0
    [m]
    DC
    OD
    2455.0
    [m]
    DC
    OD
    2460.0
    [m]
    DC
    OD
    2465.0
    [m]
    DC
    OD
    2470.0
    [m]
    DC
    OD
    2475.0
    [m]
    DC
    OD
    2480.0
    [m]
    SWC
    OD
    2480.0
    [m]
    DC
    OD
    2485.0
    [m]
    DC
    OD
    2490.0
    [m]
    DC
    OD
    2495.0
    [m]
    DC
    OD
    2500.0
    [m]
    DC
    OD
    2505.0
    [m]
    DC
    OD
    2510.0
    [m]
    SWC
    OD
    2510.0
    [m]
    DC
    OD
    2515.0
    [m]
    DC
    OD
    2520.0
    [m]
    DC
    OD
    2525.0
    [m]
    DC
    OD
    2530.0
    [m]
    DC
    OD
    2535.0
    [m]
    DC
    OD
    2540.0
    [m]
    DC
    OD
    2545.0
    [m]
    DC
    OD
    2550.0
    [m]
    SWC
    OD
    2550.0
    [m]
    DC
    OD
    2555.0
    [m]
    DC
    OD
    2560.0
    [m]
    DC
    OD
    2565.0
    [m]
    DC
    OD
    2570.0
    [m]
    DC
    OD
    2575.0
    [m]
    DC
    OD
    2580.0
    [m]
    DC
    OD
    2585.0
    [m]
    DC
    OD
    2590.0
    [m]
    DC
    OD
    2595.0
    [m]
    DC
    OD
    2600.0
    [m]
    SWC
    OD
    2600.0
    [m]
    DC
    OD
    2605.0
    [m]
    DC
    OD
    2610.0
    [m]
    DC
    OD
    2615.0
    [m]
    DC
    OD
    2620.0
    [m]
    DC
    OD
    2625.0
    [m]
    DC
    OD
    2630.0
    [m]
    DC
    OD
    2635.0
    [m]
    DC
    OD
    2640.0
    [m]
    DC
    OD
    2645.0
    [m]
    DC
    OD
    2650.0
    [m]
    DC
    OD
    2655.0
    [m]
    DC
    OD
    2660.0
    [m]
    SWC
    OD
    2660.0
    [m]
    DC
    OD
    2660.0
    [m]
    DC
    OD
    2665.0
    [m]
    DC
    OD
    2670.0
    [m]
    DC
    OD
    2675.0
    [m]
    DC
    OD
    2680.0
    [m]
    DC
    OD
    2685.0
    [m]
    DC
    OD
    2690.0
    [m]
    SWC
    OD
    2690.0
    [m]
    DC
    OD
    2695.0
    [m]
    DC
    OD
    2700.0
    [m]
    DC
    OD
    2750.0
    [m]
    SWC
    OD

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    385
    2397
    2397

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.67

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.80
    pdf
    1.97
    pdf
    1.84
    pdf
    1.95
    pdf
    1.95
    pdf
    1.83
    pdf
    0.83

  • 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
    1.71
    .PDF
    8.38

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CST - TLC
    1440
    2686
    CST - WIRELINE
    2570
    2750
    MDT
    1435
    1586
    MWD MPR - GR RES DIR
    386
    4239
    MWD ORD/CNN - SON DENS POR
    2758
    4239
    PEX DSI SP
    999
    2752
    SWC
    1390
    2750
    VSP
    1100
    2750

  • 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
    507.0
    36
    507.0
    1.46
    LOT
    SURF.COND.
    20
    999.0
    26
    1000.0
    1.58
    LOT
    INTERM.
    13 3/8
    1390.0
    17 1/2
    1437.0
    1.58
    LOT
    INTERM.
    9 5/8
    2750.0
    12 1/4
    2758.0
    1.72
    LOT
    OPEN HOLE
    4239.0
    8 1/2
    4239.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    450
    1.38
    13.0
    WATER BASED
    685
    1.46
    23.0
    WATER BASED
    1004
    1.03
    WATER BASED
    1012
    1.30
    WATER BASED
    1094
    1.30
    15.0
    WATER BASED
    1337
    1.38
    16.0
    WATER BASED
    1390
    1.39
    16.0
    WATER BASED
    1395
    0.00
    16.0
    WATER BASED
    1437
    1.38
    16.0
    WATER BASED
    1650
    1.39
    14.0
    WATER BASED
    1841
    1.46
    18.0
    WATER BASED
    1888
    1.46
    23.0
    WATER BASED
    2195
    1.46
    17.0
    WATER BASED
    2400
    1.46
    18.0
    WATER BASED
    2618
    1.46
    20.0
    WATER BASED
    2696
    1.55
    25.0
    WATER BASED
    2758
    1.46
    22.0
    WATER BASED
    2793
    1.30
    13.0
    WATER BASED
    2941
    0.00
    14.0
    WATER BASED
    2988
    1.30
    14.0
    WATER BASED
    3011
    0.00
    14.0
    WATER BASED
    3170
    1.31
    15.0
    WATER BASED
    3273
    1.46
    17.0
    WATER BASED
    3511
    1.52
    19.0
    WATER BASED
    3604
    1.52
    23.0
    WATER BASED
    3861
    1.52
    24.0
    WATER BASED
    4041
    1.52
    25.0
    WATER BASED
    4183
    1.52
    24.0
    WATER BASED
    4230
    1.55
    27.0
    WATER BASED
    4239
    1.55
    25.0
    WATER BASED

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    2988.03
    [m ]
    2989.03
    [m ]
    2991.50
    [m ]
    2992.75
    [m ]
    2993.02
    [m ]

  • 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
    0.27