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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35/1-2 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.
    35/1-2 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).
    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.
    NORTH SEA
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    35/1-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    3D seismic NH06M04 inline 4899 & crossline 2832
    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 Petroleum 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.
    1319-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.
    99
    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,
    12.09.2010
    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.
    19.12.2010
    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.
    01.04.2012
    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.
    01.04.2012
    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.
    23.5
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    409.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4202.0
    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).
    4122.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    19
    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.
    STATFJORD GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 51' 56.18'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 3' 21.37'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6859374.43
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    502942.83
    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.
    6427

  • Wellbore history
    General
    Well 35/1-2 S was drilled on the Soleie Graben Prospect on the Tampen Spur between the Knarr and Peon discoveries in the northern North Sea. The main objective was to prove commercial hydrocarbon accumulation in the Early Jurassic Cook Formation. Secondary objectives were to drill through leads in the Paleocene Lista Formation and in the Cretaceous Kyrre Formation. The well commitment was to drill 50 m into the Statfjord Formation.
    Operations and results
    Drilling was performed with the semi-submersible installation Transocean Leader. A pilot hole 35/1-U-1 was drilled first to check for shallow gas. No gas was seen. The main well was spudded 15 m south-east of the pilot and drilled to TD in 26" section. Casing and conductor were run, but due to a leak in the casing the well was abandoned and re-named 35/1-U-2. Wildcat well 35/1-2 S was spudded 15 m north-east of the abandoned on 12 September 2010 and drilled to TD at 4202 m (4122 m TVD) in the Early Jurassic Statfjord Formation. The Lista Formation was drilled with a 17" hole and opened up to 20" after the wire line logging was performed. Due to interbedded clay and hard limestone layers 8 runs were necessary to under ream the section. The well was drilled with sea water down to 1293 m, with Performadril mud from 1293 m to 2358 m, with XP-07 oil based mud from 2358 m to 3698 m, and with Low ECD-HTHP oil based mud from 3698 m to TD.
    The tops in the overburden came in within the given uncertainties. Bigger differences were seen below the BCU. Five meters of Cromer Knoll Group were drilled before the Heather Formation was encountered at 3624 m. The Viking Group was thinner than expected and no Brent Group Equivalent was identified, therefore the Heather was directly in contact with the Drake Formation, which then came in 192 m shallower than prognosed. The Cook Formation came in 30 m shallower than prognosed and was thinner than expected, leading to a 75 m shallower top Statfjord Formation than expected. All the potential reservoirs and leads were dry and no hydrocarbon shows were observed.
    Only GR-Resistivity-Density-Neutron-Sonic and sidewall cores were run on wire line. Pressure points were taken while drilling. No cores were cut and no wire line fluid samples were taken.
    The well was permanently abandoned on 19 December 2010 and classified as dry.
    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]
    1290.00
    4201.00

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    EMS EDTC GR LEHQT 6-ARM-CAL
    1275
    2067
    GPIT EMS EDTC GR LEHQT 6-ARM-CAL
    1275
    1751
    MSCT
    3926
    4171
    MWD LWD - ARCVRES PP
    532
    2355
    MWD LWD - ARCVRES6 STET TELE
    3695
    4202
    MWD LWD - ARCVRES8 PP STET PD G
    2304
    3695
    MWD LWD - POWERPULSE
    432
    532
    PEX DSI AIT
    2304
    2869
    PEX DSI AIT
    3594
    4202
    PEX HRLA DSI GR
    1276
    2330
    PWX DSI AIT
    2849
    3695
    VSP
    567
    2325

  • 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
    528.0
    36
    532.0
    0.00
    LOT
    SURF.COND.
    20
    1276.0
    26
    1293.0
    1.60
    LOT
    INTERM.
    16
    2304.0
    20
    2358.0
    1.81
    LOT
    INTERM.
    14
    2849.0
    17 1/2
    2875.0
    1.85
    LOT
    LINER
    9 7/8
    3694.0
    12 1/4
    3698.0
    2.06
    LOT
    OPEN HOLE
    4202.0
    8 1/2
    4202.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1243
    1.35
    17.0
    Spud Mud
    1344
    1.45
    34.0
    Performadril
    1620
    1.45
    34.0
    Performadril
    1776
    1.45
    23.0
    Performadril
    2010
    1.45
    28.0
    Performadril
    2264
    1.48
    28.0
    Performadril
    2317
    1.43
    28.0
    XP-07 - #14
    2335
    1.45
    23.0
    Performadril
    2346
    1.48
    36.0
    Performadril
    2355
    1.45
    25.0
    Performadril
    2859
    1.41
    26.0
    XP-07 - #14
    2869
    1.43
    27.0
    XP-07 - #14
    2872
    1.41
    25.0
    XP-07 - #14
    3695
    1.79
    50.0
    XP-07 - #14
    3696
    1.79
    53.0
    XP-07 - #14
    3698
    1.93
    39.0
    OBM-Low ECD-HTHP
    4202
    1.98
    34.0
    OBM-Low ECD-HTHP