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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1/9-3 R

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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.
    1/9-3 R
    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
    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.
    1/9-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    line No 404-404 & SP 476
    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.
    Den norske stats oljeselskap a.s
    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.
    181-L2
    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.
    127
    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,
    27.05.1978
    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.
    30.09.1978
    Plugged and abondon date
    Date when the P&A-operations of the wellbore was finished, as reported by the operator to the Norwegian Offshore Directorate throught DDRS (Daily Drilling Reporting System). Only applied once pr. wellhead/surface location.
    30.09.1978
    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.
    30.09.1980
    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.
    18.01.2007
    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.
    YES
    Reentry activity
    Reason for reentry of the wellbore. Only relevant for exploration wellbores. Example of legal values: DRILLING, DRILLING/PLUGGING, LOGGING, PLUGGING, TESTING, TESTING/PLUGGING.
    DRILLING/TESTING/PLUGGING
    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.
    GAS/CONDENSATE
    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.
    PALEOCENE
    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.
    EKOFISK 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.
    LATE CRETACEOUS
    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.
    TOR FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    35.8
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    76.5
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4570.0
    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).
    4566.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    8.3
    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 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.
    HAUGESUND FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 24' 55.68'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 54' 15.22'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6252464.47
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    494090.84
    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.
    246

  • Wellbore history
    General
    Well 1/9-3 is located in the Feda Graben, close to the UK border southwest in the Norwegian North Sea. The primary objective of the well was to evaluate the Jurassic sandstones. The secondary objective was to appraise and test the hydrocarbon bearing zones of Danian and Maastrichtian age (Shetland Group) encountered in 1/9-1. The well was drilled in two phases, of which Phase I is named 1/9-3 and Phase II is named 1/9-3 R. This procedure was a requirement from the Norwegian Petroleum Directorate since Dyvi Gamma came directly from the yard and had therefore not accumulated the experience needed to drill the high pressure Jurassic well to a planned TD of 5000 m. The re-entry 1/9-3 R was to be drilled with the rig Dyvi Beta.
    Operations and results
    Well 1/9-3 was re-entered (1/9-3 R) with the semi-submersible installation Dyvi Beta on 27 May 1978 and drilled to TD at 4570 m in the Late Jurassic Haugesund Formation. When running the 9 5/8" casing problems occurred with stuck pipe. This resulted in severe delays, but the casing was landed at planned depth. In the 8 1/2" hole the progress was delayed due to hole problems with high pressure and mud weight combined with lost returns. Tight hole and stuck pipe occurred on several occasions. Max mud weight was 2.04 g/cm. The well was drilled water based, but with several additions of diesel from 9 5/8" casing depth and downwards, resulting in 1 - 12 % diesel in the mud at all times below 3835 m.
    Several problems arose during the logging operations, which in the end resulted in a poor suit of logs over the reservoir.
    In summary the problems were due to uncontrolled stretch in the logging cable, generally poor log quality, especially for FDC/CNL logs, and difficult hole conditions with high pressure/temperature and excessive sticking. Logs that normally are run in combination had to be run separately. This made petrophysical evaluation difficult, and several logs had to be disregarded due to the poor quality.
    The well penetrated a typical stratigraphy for the area with a 2754 m thick Tertiary sequence down to top Rogaland Group (the 1/9-3 well bore), a 215 m thick Rogaland Group, a 709 m thick Shetland Group, and a 475 m thick Early Cretaceous Cromer Knoll Group. The well was terminated 305 m into the Late Jurassic Tyne Group. The Tyne Group contained a sand/shale sequence (Eldfisk Formation), but the sand beds were water bearing without shows.
    Live hydrocarbons were encountered and proved by testing in the Ekofisk and Tor Formations, but only the Ekofisk Formation had good reservoir properties. Petrophysical evaluation showed 36 m net pay in the upper part of the Ekofisk Formation and only 1.75 m net pay in the Tor Formation.
    A total of 100 m core was recovered in eight conventional cores in the interval from 3053 m in the Early Paleocene Maureen Formation to 3234 m in the Late Cretaceous Tor Formation. No fluid samples were taken on wire line.
    The well was permanently abandoned on 30 September 1978 as a gas/condensate appraisal.
    Testing
    Four drill stem tests were conducted in the Shetland Group chalks. DST 1 from 3205 m to 3214 m in the Tor Formation produced only water. Maximum temperature recorded at the end of the 12 hours main flow was 124.8 deg C. DST 2 from 3157 m to 3180 m in the Tor Formation produced 7175 m3 water together with 7.9 Sm3 oil and 4800 Sm3 gas per day through a 9.5 mm choke. Maximum temperature recorded at the end of the 10 hours main flow was 122.6 deg C. DST 3 from 3126 m to 3135 m in the Ekofisk Formation produced only 3 m3/day water with traces of oil and gas. DST 4 from 3094 m to 3112 m in the Ekofisk Formation was a good producer with a maximum flow of 397 Sm3 oil and 648400 Sm3 gas per day on a 19 mm choke. The gravity of the oil was 50 deg API. The maximum temperature recorded in this test was 120.1 deg C.

  • 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
    3053.0
    3065.3
    [m ]
    2
    3066.7
    3082.6
    [m ]
    3
    3105.3
    3123.5
    [m ]
    4
    3164.6
    3170.5
    [m ]
    5
    3175.2
    3178.7
    [m ]
    6
    3191.8
    3207.6
    [m ]
    7
    3208.3
    3214.1
    [m ]
    8
    3214.9
    3233.4
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    95.9
    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
    1150.0
    [m]
    DC
    HRS
    1250.0
    [m]
    DC
    HRS
    1350.0
    [m]
    DC
    HRS
    1450.0
    [m]
    DC
    HRS
    1550.0
    [m]
    DC
    HRS
    1650.0
    [m]
    DC
    HRS
    1750.0
    [m]
    DC
    HRS
    1850.0
    [m]
    DC
    HRS
    1950.0
    [m]
    DC
    HRS
    2050.0
    [m]
    DC
    HRS
    2150.0
    [m]
    DC
    HRS
    2250.0
    [m]
    DC
    HRS
    2350.0
    [m]
    DC
    HRS
    2450.0
    [m]
    DC
    HRS
    2551.0
    [m]
    DC
    HRS
    2650.0
    [m]
    DC
    HRS
    2752.0
    [m]
    DC
    HRS
    2850.0
    [m]
    DC
    HRS
    2952.0
    [m]
    DC
    HRS
    3051.0
    [m]
    DC
    HRS
    3090.0
    [m]
    DC
    HRS
    3825.0
    [m]
    DC
    HRS
    3918.0
    [m]
    DC
    HRS
    4035.0
    [m]
    DC
    HRS
    4134.0
    [m]
    DC
    HRS
    4236.0
    [m]
    DC
    HRS
    4275.0
    [m]
    DC
    HRS
    4278.0
    [m]
    DC
    OD
    4290.0
    [m]
    DC
    OD
    4299.0
    [m]
    DC
    OD
    4308.0
    [m]
    DC
    OD
    4317.0
    [m]
    DC
    OD
    4326.0
    [m]
    DC
    HRS
    4332.0
    [m]
    DC
    OD
    4341.0
    [m]
    DC
    OD
    4350.0
    [m]
    DC
    OD
    4359.0
    [m]
    DC
    OD
    4371.0
    [m]
    DC
    OD
    4377.0
    [m]
    DC
    HRS
    4380.0
    [m]
    DC
    OD
    4389.0
    [m]
    DC
    OD
    4398.0
    [m]
    DC
    OD
    4410.0
    [m]
    DC
    OD
    4419.0
    [m]
    DC
    OD
    4425.0
    [m]
    DC
    HRS
    4431.0
    [m]
    DC
    OD
    4440.0
    [m]
    DC
    OD
    4449.0
    [m]
    DC
    OD
    4461.0
    [m]
    DC
    OD
    4470.0
    [m]
    DC
    OD
    4476.0
    [m]
    DC
    HRS
    4479.0
    [m]
    DC
    OD
    4488.0
    [m]
    DC
    OD
    4500.0
    [m]
    DC
    OD
    4509.0
    [m]
    DC
    OD
    4521.0
    [m]
    DC
    OD
    4527.0
    [m]
    DC
    HRS
    4530.0
    [m]
    DC
    OD
    4539.0
    [m]
    DC
    OD
    4551.0
    [m]
    DC
    OD
    4560.0
    [m]
    DC
    OD
    4569.0
    [m]
    DC
    OD

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.94

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    4.18
    pdf
    3.70

  • 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
    3830.0
    12 1/4
    3830.0
    0.00
    LOT
    OPEN HOLE
    4570.0
    8 1/2
    4570.0
    0.00
    LOT