Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
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7/11-10 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.
    7/11-10 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.
    SUSPENDED
    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.
    7/11-10
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 8601 ROW 206
    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.
    641-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.
    68
    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,
    05.07.1990
    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.
    10.09.1990
    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.
    10.09.1992
    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.
    19.10.2006
    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
    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.
    LATE 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.
    ULA FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.5
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    78.5
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4566.0
    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).
    4241.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    50
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    169
    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.
    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.
    SMITH BANK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    57° 7' 12.51'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 29' 10.56'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6331018.86
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    468891.06
    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.
    1563

  • Wellbore history
    General
    Well 7/11-10 S was designed to drill the 7/11-A structure on the Mime Field, on the eastern margin of the Central Graben. The structure is salt induced and consists of a northern, western, eastern and a southern compartment. Oil is proven in the northern compartment by the 7/11-5 well in the Late Jurassic Ula formation sandstone. The reservoir sandstone was deposited in a shallow marine environment mainly by storm episodes into an approximately 100 km long and 20 km wide "fairway". Shales of the Late Jurassic Farsund- and Mandal formations make up the cap-rock. The well was to be vertical down to 2002 m MSL and then kicked off towards the target with an angle of 33.28 degrees. The primary objective was a long term test production from the oil-bearing Ula formation of Area 1 in the northern compartment. Secondary objective was to improve the geological control, and coring was supposed to give good information about the silica cementation above and below the OWC. Shallow gas was indicated in the interval from 318 m - to 425 m MSL.
    Operations and results
    Appraisal well 7/11-10 S was spudded with the semi-submersible installation Transocean 8 on 5 July 1990 and drilled to TD at 4566 m in the Triassic Smith Bank Formation. No shallow gas of importance, only background gas, was encountered while drilling. Gumbo problems were encountered in the upper part of the 17 1/2" hole, but hole conditions improved after increasing the mud weight. The well was kicked off at 2010 m in 40° direction, and the angle built to 35° at 2610 m. While pulling out, the bit came out with three cones lost. The string got stuck at 3740 m. Fishing operation was unsuccessful, and a cement plug was set above the fish. The hole was kicked off from the cement plug at 3550 m and sidetracked. No severe problems were experienced in the last part of the hole except from low penetration rate at times and some tight spots on the bit trips. The top hole was drilled with seawater and hi-vis pills down to 621 m, the 17 1/2" section was drilled with KCl/PHPA/PAC mud from 621 m to 1941 m, the 12 1/4" section from 1941 m to 4220 m was drilled oil based, and the final 8 1/2 section to TD was again drilled water based.
    The average petrophysical results from The Ula Formation and uppermost Triassic in well 7/11-10S was comparable to the discovery well 7/11-5. A total of 27 meters of net pay was penetrated, with porosities ranging from 13% up to 21%. The entire analysed Jurassic interval (4340.5-4395.5 m /4010.25-4062.75 m TVDMSL) in well 7/11-10S was regarded as oil bearing. The deepest oil observed in the well was at 4388 m (4053.5 m TVDMSL), which was regarded as an ODT. The lowermost 5 meters did not contain hydrocarbons, probably due to the extremely tight nature of the rock. This tight interval might also have acted as a vertical barrier, preventing hydrocarbons migrating into the somewhat more permeable Triassic sandstones. Also well 7/11-5 contained this impermeable section.
    No logs were run beneath 4493 m. Three cores were cut in the Ula Formation and uppermost Triassic, from 4350 to 4403 m. No fluid samples were obtained in the well bore
    The well was suspended on 10 September 1990 as an oil appraisal well.
    Testing
    The perforated interval for the test production was 4347 m through 4381 m (4016.6-4048.9 m TVDMSL). The long term production test was however to be performed in a re-entry.

  • 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]
    200.00
    4566.00

  • 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
    4350.0
    4359.3
    [m ]
    2
    4366.0
    4388.7
    [m ]
    3
    4389.0
    4402.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    45.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 4350-4354m
    Core photo at depth: 4355-4359m
    Core photo at depth: 4366-4370m
    Core photo at depth: 4371-4375m
    Core photo at depth: 4376-4380m
    4350-4354m
    4355-4359m
    4366-4370m
    4371-4375m
    4376-4380m
    Core photo at depth: 4381-4385m
    Core photo at depth: 4386-4388m
    Core photo at depth: 4389-4393m
    Core photo at depth: 4394-4398m
    Core photo at depth: 4399-4402m
    4381-4385m
    4386-4388m
    4389-4393m
    4394-4398m
    4399-4402m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    4200.0
    [m]
    DC
    RRI
    4210.0
    [m]
    DC
    RRI
    4220.0
    [m]
    DC
    RRI
    4230.0
    [m]
    DC
    RRI
    4240.0
    [m]
    DC
    RRI
    4250.0
    [m]
    DC
    RRI
    4260.0
    [m]
    DC
    RRI
    4270.0
    [m]
    DC
    RRI
    4280.0
    [m]
    DC
    RRI
    4290.0
    [m]
    DC
    RRI
    4300.0
    [m]
    DC
    RRI
    4310.0
    [m]
    DC
    RRI
    4320.0
    [m]
    DC
    RRI
    4330.0
    [m]
    DC
    RRI
    4340.0
    [m]
    DC
    RRI
    4352.7
    [m]
    C
    RRI
    4355.5
    [m]
    C
    RRI
    4368.7
    [m]
    C
    RRI
    4369.8
    [m]
    C
    RRI
    4374.3
    [m]
    C
    RRI
    4382.6
    [m]
    C
    RRI
    4386.9
    [m]
    C
    RRI
    4390.7
    [m]
    C
    RRI
    4392.9
    [m]
    C
    RRI
    4394.6
    [m]
    C
    RRI
    4395.7
    [m]
    C
    RRI
    4402.4
    [m]
    C
    RRI
    4410.0
    [m]
    DC
    RRI
    4420.0
    [m]
    C
    RRI
    4430.0
    [m]
    DC
    RRI
    4440.0
    [m]
    DC
    RRI
    4450.0
    [m]
    DC
    RRI
    4460.0
    [m]
    DC
    RRI
    4470.0
    [m]
    DC
    RRI
    4480.0
    [m]
    DC
    RRI
    4490.0
    [m]
    DC
    RRI
    4500.0
    [m]
    DC
    RRI

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.51

  • 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
    15.20

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AMS
    4205
    4384
    CBL VDL CCL GR
    3269
    4054
    CBL VDL CCL GR
    4053
    4501
    CBL VDL GR
    1250
    1969
    DIL LSS GR
    1894
    4209
    DITE LSS GR AMS
    4205
    4505
    DITE MSFL GR
    4205
    4494
    GR
    125
    1950
    LDL CNL GR
    3205
    4486
    MWD - GR RES DIR
    102
    4566
    VELOCITY
    1950
    4060

  • 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
    185.0
    36
    192.0
    0.00
    LOT
    INTERM.
    18 5/8
    597.0
    24
    620.0
    0.00
    LOT
    INTERM.
    13 3/8
    1941.0
    17 1/2
    1957.0
    0.00
    LOT
    INTERM.
    9 5/8
    4205.0
    12 1/4
    4220.0
    1.97
    LOT
    LINER
    7
    4564.0
    8 1/2
    4566.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    192
    1.20
    WATER BASED
    10.07.1990
    192
    1.03
    WATER BASED
    10.07.1990
    359
    1.60
    15.0
    9.0
    WATER BASED
    27.09.1990
    425
    1.07
    6.0
    7.0
    WATER BASED
    11.07.1990
    611
    1.10
    9.0
    10.0
    WATER BASED
    12.07.1990
    611
    1.20
    15.0
    8.0
    WATER BASED
    13.07.1990
    618
    1.20
    15.0
    8.0
    WATER BASED
    16.07.1990
    1102
    1.30
    17.0
    13.0
    WATER BASED
    16.07.1990
    1499
    1.44
    23.0
    13.0
    WATER BASED
    16.07.1990
    1874
    1.50
    22.0
    9.0
    WATER BASED
    17.07.1990
    1957
    1.53
    21.0
    11.0
    WATER BASED
    18.07.1990
    1957
    1.52
    21.0
    10.0
    WATER BASED
    19.07.1990
    1957
    1.50
    21.0
    12.0
    WATER BASED
    20.07.1990
    2277
    1.52
    54.0
    12.0
    OIL BASED
    23.07.1990
    2741
    1.51
    50.0
    10.0
    OIL BASED
    23.07.1990
    2865
    1.52
    49.0
    12.0
    OIL BASED
    23.07.1990
    2952
    1.53
    51.0
    11.0
    OIL BASED
    24.07.1990
    3137
    1.52
    53.0
    10.0
    OIL BASED
    25.07.1990
    3167
    1.52
    51.0
    11.0
    OIL BASED
    26.07.1990
    3313
    1.51
    51.0
    10.0
    OIL BASED
    27.07.1990
    3388
    1.52
    53.0
    11.0
    OIL BASED
    30.07.1990
    3406
    1.53
    54.0
    10.0
    OIL BASED
    30.07.1990
    3434
    1.53
    50.0
    11.0
    OIL BASED
    09.08.1990
    3471
    1.52
    56.0
    10.0
    OIL BASED
    30.07.1990
    3488
    1.52
    55.0
    11.0
    OIL BASED
    31.07.1990
    3529
    1.52
    56.0
    10.0
    OIL BASED
    01.08.1990
    3557
    1.51
    55.0
    12.0
    OIL BASED
    10.08.1990
    3608
    1.52
    54.0
    9.0
    OIL BASED
    13.08.1990
    3626
    1.52
    56.0
    12.0
    OIL BASED
    02.08.1990
    3682
    1.52
    53.0
    9.0
    OIL BASED
    13.08.1990
    3725
    1.52
    49.0
    9.0
    OIL BASED
    03.08.1990
    3760
    1.52
    49.0
    9.0
    OIL BASED
    06.08.1990
    3760
    1.52
    41.0
    9.0
    OIL BASED
    06.08.1990
    3760
    1.52
    41.0
    9.0
    OIL BASED
    06.08.1990
    3810
    1.51
    46.0
    10.0
    OIL BASED
    13.08.1990
    3841
    1.52
    46.0
    11.0
    OIL BASED
    14.08.1990
    3937
    1.52
    42.0
    9.0
    OIL BASED
    15.08.1990
    3998
    1.52
    44.0
    10.0
    OIL BASED
    16.08.1990
    4020
    1.58
    21.0
    5.0
    WATER BASED
    28.09.1990
    4075
    1.52
    47.0
    9.0
    OIL BASED
    17.08.1990
    4078
    1.52
    46.0
    9.0
    OIL BASED
    20.08.1990
    4099
    1.52
    44.0
    10.0
    OIL BASED
    20.08.1990
    4116
    1.52
    47.0
    10.0
    OIL BASED
    20.08.1990
    4126
    1.52
    47.0
    9.0
    OIL BASED
    21.08.1990
    4138
    1.52
    44.0
    9.0
    OIL BASED
    22.08.1990
    4159
    1.52
    49.0
    10.0
    OIL BASED
    23.08.1990
    4208
    1.52
    51.0
    10.0
    OIL BASED
    27.08.1990
    4220
    1.52
    43.0
    9.0
    OIL BASED
    27.08.1990
    4220
    1.52
    43.0
    8.0
    OIL BASED
    29.08.1990
    4220
    1.54
    23.0
    6.0
    WATER BASED
    29.08.1990
    4220
    1.52
    43.0
    7.0
    OIL BASED
    27.08.1990
    4366
    1.55
    21.0
    8.0
    WATER BASED
    31.08.1990
    4397
    1.54
    20.0
    6.0
    WATER BASED
    03.09.1990
    4503
    1.54
    19.0
    7.0
    WATER BASED
    03.09.1990
    4511
    1.58
    20.0
    5.0
    WATER BASED
    02.10.1990
    4511
    1.53
    16.0
    4.0
    WATER BASED
    02.10.1990
    4511
    1.50
    21.0
    6.0
    WATER BASED
    02.10.1990
    4517
    1.60
    22.0
    4.0
    WATER BASED
    10.09.1990
    4517
    1.60
    22.0
    4.0
    WATER BASED
    10.09.1990
    4566
    1.57
    24.0
    10.0
    WATER BASED
    03.09.1990
    4566
    1.57
    23.0
    10.0
    WATER BASED
    04.09.1990
    4566
    1.60
    24.0
    10.0
    WATER BASED
    05.09.1990
    4566
    1.60
    25.0
    9.0
    WATER BASED
    06.09.1990
    4566
    1.60
    25.0
    9.0
    WATER BASED
    07.09.1990