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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34/8-14 A

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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.
    34/8-14 A
    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.
    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.
    34/8-14
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    Survey ST0404-inline 1360 & crossline 1556
    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.
    StatoilHydro ASA
    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.
    1207-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.
    34
    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,
    29.10.2008
    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.
    01.12.2008
    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.
    01.12.2010
    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.
    01.12.2010
    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.
    TARBERT 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.
    MIDDLE JURASSIC
    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.
    NESS FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    31.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    292.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3838.0
    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).
    3075.2
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    58.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    113
    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 JURASSIC
    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.
    DRAKE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 18' 37.9'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 20' 32.9'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6797715.24
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    464783.40
    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.
    5954

  • Wellbore history
    General
    Well 34/8-14 S with geological sidetracks A, B, C, and D were drilled on the Pan/Pandora prospect on the structural trend between the Visund and the Gimle Fields in the northern North Sea. The western part of the structure, the Pan structure, is defined by rotated fault blocks while the eastern part, the Pandora structure, consists of slided degradational blocks. The general objective of all the wells was to test the hydrocarbon potential in the structure. Wells 34/8-14 S (Pan) and 34/8-14 A (Pandora) were drilled to provide important information on the hydrocarbon phases and HC/water contacts. Both wells both proved hydrocarbons and sidetracks B, C, and D were subsequently drilled to further delineate hydrocarbon contacts and reserves.
    Operations and results
    Appraisal well 34/8-14 A was kicked off at 1282 m in well 34//8-14 S with the semi-submersible installation Borgland Dolphin on 20 October 2008 and drilled to TD at 3838 m (3075 m TVD) in the Early Jurassic Drake Formation. The well was drilled with XP-07 OBM from kick-off to TD.
    Top Brent Group in well 34/8-14 A was encountered at 3500 m (2849 m TVD RKB) and proved to be oil and gas bearing. The quality of the reservoir sandstones of the Tarbert Formation was excellent. A GOC was found at 3579 m (2902 m TVD RKB). Oil was found down-to the Ness shales at 3591 m (2910 m TVD RKB). Above top Brent Group no oil shows were observed, and gas levels were low.
    Three cores were cut from 3504.6 to 3570 m in well 34/8-14 A. The MDT was run for pressure points and fluid samples. Samples were obtained at 3514 m (gas), 3574 m (gas), and 3585 m (oil).
    The well was plugged back and permanently abandoned on 1 December 2008 as an oil and gas appraisal well.
    Testing
    No drill stem test was performed.

  • 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
    3504.6
    3531.7
    [m ]
    2
    3532.0
    3550.8
    [m ]
    3
    3558.0
    3569.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    57.3
    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
    2060.0
    [m]
    DC
    BIOSTRAT
    2080.0
    [m]
    DC
    BIOSTR
    2100.0
    [m]
    DC
    BIOSTR
    2120.0
    [m]
    DC
    BIOSTR
    2140.0
    [m]
    DC
    BIOSTR
    2160.0
    [m]
    DC
    BIOSTR
    2180.0
    [m]
    DC
    BIOSTR
    2200.0
    [m]
    DC
    BIOSTR
    2210.0
    [m]
    DC
    BIOSTR
    2250.0
    [m]
    DC
    BIOSTR
    2260.0
    [m]
    DC
    BIOSTR
    2280.0
    [m]
    DC
    BIOSTR
    2300.0
    [m]
    DC
    BIOSTR
    2320.0
    [m]
    DC
    BIOSTR
    2340.0
    [m]
    DC
    BIOSTR
    2360.0
    [m]
    DC
    BIOSTR
    2380.0
    [m]
    DC
    BIOSTR
    2400.0
    [m]
    DC
    BIOSTR
    2420.0
    [m]
    DC
    BIOSTR
    2430.0
    [m]
    DC
    BIOSTR
    2460.0
    [m]
    DC
    BIOSTR
    2480.0
    [m]
    DC
    BIOSTR
    2500.0
    [m]
    DC
    BIOSTR
    2520.0
    [m]
    DC
    BIOSTR
    2540.0
    [m]
    DC
    BIOSTR
    2560.0
    [m]
    DC
    BIOSTR
    2570.0
    [m]
    DC
    BIOSTR
    2600.0
    [m]
    DC
    BIOSTR
    2620.0
    [m]
    DC
    BIOSTR
    2640.0
    [m]
    DC
    BIOSTR
    2660.0
    [m]
    DC
    BIOSTR
    2680.0
    [m]
    DC
    BIOSTR
    2700.0
    [m]
    DC
    BIOSTR
    2720.0
    [m]
    DC
    BIOSTR
    2740.0
    [m]
    DC
    BIOSTR
    2760.0
    [m]
    DC
    BIOSTR
    2780.0
    [m]
    DC
    BIOSTR
    2800.0
    [m]
    DC
    BIOSTR
    2820.0
    [m]
    DC
    BIOSTR
    2840.0
    [m]
    DC
    BIOSTR
    2860.0
    [m]
    DC
    BIOSTR
    2880.0
    [m]
    DC
    BIOSTR
    2900.0
    [m]
    DC
    BIOSTR
    2920.0
    [m]
    DC
    BIOSTR
    2940.0
    [m]
    DC
    BIOSTR
    2960.0
    [m]
    DC
    BIOSTR
    2980.0
    [m]
    DC
    BIOSTR
    3000.0
    [m]
    DC
    BIOSTR
    3020.0
    [m]
    DC
    BIOSTR
    3040.0
    [m]
    DC
    BIOSTR
    3060.0
    [m]
    DC
    BIOSTR
    3080.0
    [m]
    DC
    BIOSTR
    3100.0
    [m]
    DC
    BIOSTR
    3120.0
    [m]
    DC
    BIOSTR
    3140.0
    [m]
    DC
    BIOSTR
    3160.0
    [m]
    DC
    BIOSTR
    3180.0
    [m]
    DC
    BIOSTR
    3200.0
    [m]
    DC
    BIOSTR
    3220.0
    [m]
    DC
    BIOSTR
    3240.0
    [m]
    DC
    BIOSTR
    3260.0
    [m]
    DC
    BIOSTR
    3280.0
    [m]
    DC
    BIOSTR
    3300.0
    [m]
    DC
    BIOSTR
    3320.0
    [m]
    DC
    BIOSTR
    3340.0
    [m]
    DC
    BIOSTR
    3360.0
    [m]
    DC
    BIOSTR
    3380.0
    [m]
    DC
    BIOSTR
    3400.0
    [m]
    DC
    BIOSTR
    3410.0
    [m]
    DC
    BIOSTR
    3420.0
    [m]
    DC
    BIOSTR
    3430.0
    [m]
    DC
    BIOSTR
    3440.0
    [m]
    DC
    BIOSTR
    3450.0
    [m]
    DC
    BIOSTR
    3460.0
    [m]
    DC
    BIOSTR
    3470.0
    [m]
    DC
    BIOSTR
    3475.0
    [m]
    DC
    BIOSTR
    3480.0
    [m]
    DC
    BIOSTR
    3485.0
    [m]
    DC
    BIOSTR
    3490.0
    [m]
    DC
    BIOSTR
    3495.0
    [m]
    DC
    BIOSTR
    3500.0
    [m]
    DC
    BIOSTR
    3570.0
    [m]
    DC
    BIOSTR
    3580.0
    [m]
    DC
    BIOSTR
    3590.0
    [m]
    DC
    BIOSTR
    3600.0
    [m]
    DC
    BIOSTR
    3610.0
    [m]
    DC
    BIOSTR
    3620.0
    [m]
    DC
    BIOSTR
    3630.0
    [m]
    DC
    BIOSTR
    3640.0
    [m]
    DC
    BIOSTR
    3650.0
    [m]
    DC
    BIOSTR
    3660.0
    [m]
    DC
    BIOSTR
    3670.0
    [m]
    DC
    BIOSTR
    3680.0
    [m]
    DC
    BIOSTR
    3690.0
    [m]
    DC
    BIOSTR
    3700.0
    [m]
    DC
    BIOSTR
    3705.0
    [m]
    DC
    BIOSTR
    3710.0
    [m]
    DC
    BIOSTR
    3715.0
    [m]
    DC
    BIOSTR
    3720.0
    [m]
    DC
    BIOSTR
    3725.0
    [m]
    DC
    BIOSTR
    3730.0
    [m]
    DC
    BIOSTR
    3735.0
    [m]
    DC
    BIOSTR
    3740.0
    [m]
    DC
    BIOSTR
    3745.0
    [m]
    DC
    BIOSTR
    3750.0
    [m]
    DC
    BIOSTR
    3755.0
    [m]
    DC
    BIOSTR
    3760.0
    [m]
    DC
    BIOSTR
    3765.0
    [m]
    DC
    BIOSTR
    3770.0
    [m]
    DC
    BIOSTR
    3775.0
    [m]
    DC
    BIOSTR
    3780.0
    [m]
    DC
    BIOSTR
    3785.0
    [m]
    DC
    BIOSTR
    3790.0
    [m]
    DC
    BIOSTR
    3795.0
    [m]
    DC
    BIOSTR
    3800.0
    [m]
    DC
    BIOSTR
    3805.0
    [m]
    DC
    BIOSTR
    3810.0
    [m]
    DC
    BIOSTR
    3815.0
    [m]
    DC
    BIOSTR
    3820.0
    [m]
    DC
    BIOSTR
    3825.0
    [m]
    DC
    BIOSTR
    3830.0
    [m]
    DC
    BIOSTR
    3835.0
    [m]
    DC
    BIOSTR
    3838.0
    [m]
    DC
    BIOSTR

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    LWD - CORE ASSY
    3504
    3570
    LWD - GR RES
    1257
    2246
    LWD - GR RES DEN NEU SVWD
    1257
    2246
    LWD - GR RES DEN NEU SVWD
    3570
    3838
    MDT
    3514
    3610
    MDT
    3580
    3585
    SONIC SCANNER OBMI
    1775
    3800

  • 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
    INTERM.
    9 5/8
    2239.0
    12 1/4
    2246.0
    0.00
    LOT
    OPEN HOLE
    3838.0
    8 1/2
    3838.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1352
    1.39
    17.0
    OBM-Low ECD
    1723
    1.48
    23.0
    OBM-Low ECD
    2260
    1.55
    17.0
    OBM-Low ECD
    2304
    1.60
    16.0
    OBM-Low ECD
    2451
    1.60
    20.0
    OBM-Low ECD
    3570
    1.60
    18.0
    OBM-Low ECD
    3838
    1.60
    20.0
    OBM-Low ECD