Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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25.11.2024 - 01:30
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35/1-1

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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.
    35/1-1
    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.
    35/1-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    Supergrid line 30280&Supergrid trace 782
    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.
    Phillips Petroleum Company Norway
    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.
    1038-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.
    52
    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,
    28.05.2002
    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.
    18.07.2002
    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.
    18.07.2004
    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.
    18.07.2004
    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.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    408.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4540.0
    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).
    4540.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    152
    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.
    LUNDE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 50' 9.11'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 4' 24.21'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6856062.02
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    503864.91
    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.
    4541

  • Wellbore history
    General
    The objectives of drilling the Sturlason 35/1-1 well were to test the hydrocarbon potential of the Jurassic Cook and Statfjord Formations and the Triassic Lunde Formation in the Marflo Ridge structural complex located northeast of the Tampen Spur. The well location was designed to test a significant hydrocarbon column height that would potentially spill into additional fault blocks without leaving commercial reserves up dip. The location should further, if possible, evaluate Paleocene potential without compromising the Mesozoic target.
    Operations and results
    Exploration well 35/1-1 was spudded with the semi-submersible installation Deepsea Bergen on 28 May 2002 and drilled to TD at 4540 m.
    Site survey and gravity coring showed that the shallow geology at the well site consists of soft, silty clay down to 16-18 meters below the seabed. A flat topography is interspersed by frequent pockmarks (seabed depressions). These pockmarks are up to 100 meters in diameter and up to 5 meters deep and are scattered throughout the survey area. The closest pockmark is 50 m south of the 35/1-1 location. Pockmarks are believed to have formed as a result of fluid or gas escape originating in or beneath the soft surface sediments.
    The well was drilled with seawater and bentonite sweeps down to 878 m, with KCl brine/Glydril from 878 m to 2245 m, and with Versaport oil based mud from 2245 m to TD No shallow high-pressured water pocket was encountered in the 35/1-1 drilling operation.
    No producible hydrocarbons were encountered in the well. The well did not encounter any potential reservoir in the Paleocene interval. All three potential reservoir intervals were evaluated by MWD/LWD log and open hole wire line data. In the 8 1/2" hole section sidewall cores were collected and one run was performed using Schlumbergers Modular Formation Dynamics Tester (MDT) for pressure measurements and fluid sampling. The MDT tool was configured with 2 x 1 gallon chambers and 6 x 450 cc bottles for pressurized samples. Fluid samples were collected at 4043.12 in the Cook Formation, and at 4471 m and 4322.27 in the Statfjord Formation. The CPI made from the wire line log data indicated the presence of small amounts of residual hydrocarbons. Additionally, the sidewall cores and MDT samples contained traces of hydrocarbons. However, geochemical analyses showed that only the MDT sample from the Cook Formation contained trace hydrocarbons that could represent migrated petroleum. The hydrocarbons in the other samples were from the oil-based mud. It should also be noted that the potassium in the KCL/Glycol mud system masked the natural gamma ray readings of the formation in the 17 1/2" section and affected the CDR resistivity resulting in a useless LWD log. Conventional cores were not cut not in this well.
    The well was permanently abandoned on 18 July 2002 as a dry hole.
    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]
    890.00
    4540.00

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1200.0
    [m]
    DC
    PETROSTR
    1210.0
    [m]
    DC
    PETROS
    1220.0
    [m]
    DC
    PETROS
    1230.0
    [m]
    DC
    PETROS
    1250.0
    [m]
    DC
    PETROS
    1260.0
    [m]
    DC
    PETROS
    1270.0
    [m]
    DC
    PETROS
    1280.0
    [m]
    DC
    PETROS
    1310.0
    [m]
    DC
    PETROS
    1320.0
    [m]
    DC
    PETROS
    1330.0
    [m]
    DC
    PETROS
    1340.0
    [m]
    DC
    PETROS
    1350.0
    [m]
    DC
    PETROS
    1360.0
    [m]
    DC
    PETROS
    1370.0
    [m]
    DC
    PETROS
    1380.0
    [m]
    DC
    PETROS
    1390.0
    [m]
    DC
    PETROS
    1400.0
    [m]
    DC
    PETROS
    1420.0
    [m]
    DC
    PETROS
    1430.0
    [m]
    DC
    PETROS
    1440.0
    [m]
    DC
    PETROS
    1450.0
    [m]
    DC
    PETROS
    1460.0
    [m]
    DC
    PETROS
    1470.0
    [m]
    DC
    PETROS
    1480.0
    [m]
    DC
    PETROS
    1490.0
    [m]
    DC
    PETROS
    1500.0
    [m]
    DC
    PETROS
    1510.0
    [m]
    DC
    PETROS
    1520.0
    [m]
    DC
    PETROS
    1530.0
    [m]
    DC
    PETROS
    1550.0
    [m]
    DC
    PETROS
    1560.0
    [m]
    DC
    PETROS
    1570.0
    [m]
    DC
    PETROS
    1580.0
    [m]
    DC
    PETROS
    1610.0
    [m]
    DC
    PETROS

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.79

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.69

  • 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
    3.83
    .PDF
    3.22

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    GR HDIL XMAC ZDL CN TTRM
    405
    2238
    GR HDIL XMAC ZDL CN TTRM
    2150
    3830
    GR HDIL XMAC ZDL CN TTRM
    3645
    4531
    MDT GR SAMPLES
    4489
    0
    MSCT
    4510
    0
    MWD - CDR DIR
    503
    878
    MWD - CDR DIR
    878
    2245
    MWD - CDR DIR
    3834
    4540
    MWD CDR DIR
    2245
    3834

  • 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
    503.0
    36
    503.0
    0.00
    LOT
    INTERM.
    20
    872.0
    26
    878.0
    0.00
    LOT
    INTERM.
    13 3/8
    2239.0
    17 1/2
    2245.0
    1.65
    LOT
    INTERM.
    9 5/8
    3826.0
    12 1/4
    3834.0
    1.75
    LOT
    OPEN HOLE
    4540.0
    8 1/2
    4540.0
    2.15
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    431
    0.00
    SPUD MUD
    672
    0.00
    34.0
    VERSAPORT
    678
    0.00
    SEAWATER
    863
    0.00
    33.0
    VERSAPORT
    878
    0.12
    SPUD MUD
    1675
    1.34
    18.0
    KCL/POLYMER
    2245
    0.00
    32.0
    VERSAPORT
    2678
    1.50
    39.0
    VERSAPORT
    3452
    1.52
    36.0
    VERSAPORT
    3834
    1.61
    32.0
    VERSAPORT
    3950
    0.00
    36.0
    VERSAPORT
    4129
    0.00
    35.0
    VERSAPORT
    4516
    0.00
    49.0
    VERSAPORT
    4540
    0.00
    48.0
    VERSAPORT

  • 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
    0.22