Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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11.11.2024 - 01:26
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9/2-1

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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.
    9/2-1
    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
    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.
    9/2-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 8626 - 212 SP 160
    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.
    538-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.
    67
    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,
    21.02.1987
    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.
    28.04.1987
    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.
    28.04.1989
    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.
    22.04.2005
    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.
    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.
    YES
    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.
    SANDNES FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    29.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    99.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3756.0
    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).
    3755.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    116
    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.
    SKAGERRAK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    57° 49' 58.1'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    4° 31' 27.92'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6411261.00
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    590526.87
    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.
    1038

  • Wellbore history
    General
    Well 9/2-1 was drilled in a new separate structure and designed to test the hydrocarbon potential of the Egersund Basin. The main target of the well was to test sandstones of middle Jurassic age. Furthermore, the well was expected to improve the paleontological, the geological and the geochemical understanding of the area.
    Operations and results
    Wildcat well 9/2-1 was spudded with the semi-submersible installation Dyvi Delta on 21 February 1987 and drilled to TD at 3756 m in the Triassic Skagerrak Formation. The well was drilled with a 36" bit down to 189 m, but the drill bit got stuck due to boulders and the string had to be blown off just above the bit. The well was respudded 23 February 1987 and this time a 17 1/2" pilot hole was drilled before opening to 36". It was drilled to 587 m without a riser. NPD gave suspension from conventional logging through this sequence because the MWD log was of good quality, with continuity and correlatable to other wells in the area. Further drilling proceeded without significant problems. The well was drilled with spud mud down to 788 m and with gypsum/polymer mud from 788 m to TD.
    The top of the Jurassic sand (Sandnes Formation) was reached at 3174 m, 178 m deeper than prognosed. The oil water contact was difficult to determine exactly from logs, but was believed to be somewhere in the transition zone between 3230 and 3239 m. There were good shows down to 3240 m. Core and log analysis indicated a fairly low porosity sandstone with small amounts of silt, shale and limestone. Compaction, quartz cementation, calcite cement, and clay minerals occurring as fine-grained pore filling aggregates, are the main porosity-reducing factor in the reservoir. The core and log analysis indicate a general trend of decreasing reservoir quality with increasing depth. The Bryne Formation at 3309 m to 3601 m was water wet. Organic geochemical analyses show many intervals with good to excellent source rock potential. The best of these is the Late Jurassic shales of the Tau Formation with TOC in the range 1.0 to 4.3 % and hydrogen index from 140 to 560 mg HC/g TOC. Also coals and shales of the Bryne Formation and shales of the Fjerritslev Formation show good source potential. Analyses of the DST 3 oil indicate a maturity corresponding to a source with %Ro = 0.8 to 0.9 (peak oil window), more mature than any source horizon penetrated in the well location. The chemical and isotopic composition of the oil correlate primarily with extracts from the Tau shales, but has also some resemblance with shale extracts from the Fjerritslev Formation. The Bryne coals and shales appear to be the least likely candidate as source for the oil. The gas from DST 3 has a rather unusual isotopic composition that indicates a mixed source.
    One core was cut in the interval 3113 m to 3123 m, and 4 cores in the interval 3174 m to 3287 m. Two FMT runs were performed for fluid and pressure sampling. Several of the pressure readings were affected by super charge due to low formation permeability. The poor quality of the data made it difficult to draw conclusive fluid gradients and to determine an oil/water contact. Four FMT fluid samples were taken at 3346.5 m, 3251.6 m, 3251.0 m, and 3245.0 m. All samples were drained on the rig and all contained mud filtrate.
    The well was permanently abandoned on 28 April 1987 as an oil and gas discovery.
    Testing
    Three DST's were performed to test the oil and water bearing sandstones of Jurassic age. DST 1 perforated the interval from 3245 m to 3263 m, DST 2 perforated 3220 m to 3236 m, and DST 3 perforated 3177 m to 3210 m. The well response from DST 1 (water test) and DST 2 was very poor due to formations of very low permeability. No reservoir fluid was produced to surface during the tests. DST 3 was a successful oil test of the upper part of the oil-bearing reservoir. It produced during main flow 659 m3 oil and 18452 Sm3 gas per day through a 9.53 mm choke. GOR was 28 m3/m3, oil density was 0.834 g/cm3, gas gravity was 0.818 (air = 1) with 1.8 ppm H2S and 3 % CO2.

  • 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]
    793.00
    3756.00

  • 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
    3111.0
    3123.5
    [m ]
    2
    3174.0
    3202.2
    [m ]
    3
    3202.2
    3215.8
    [m ]
    4
    3231.0
    3259.2
    [m ]
    5
    3259.3
    3287.6
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    110.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3111-3123m
    Core photo at depth: 3111-3123m
    Core photo at depth: 3111-3123m
    Core photo at depth: 3111-3123m
    Core photo at depth: 3111-3123m
    3111-3123m
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    Core photo at depth: 3111-3123m
    Core photo at depth: 3111-3123m
    Core photo at depth: 3111-3123m
    Core photo at depth: 3111-3123m
    Core photo at depth: 3111-3123m
    3111-3123m
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    Core photo at depth: 3111-3123m
    Core photo at depth: 3111-3123m
    Core photo at depth: 3111-3123m
    Core photo at depth: 3111-3123m
    Core photo at depth: 3111-3123m
    3111-3123m
    3111-3123m
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    Core photo at depth: 3111-3123m
    Core photo at depth: 3111-3123m
    Core photo at depth: 3111-3123m
    Core photo at depth: 3111-3123m
    Core photo at depth: 3111-3123m
    3111-3123m
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    3111-3123m
    3111-3123m
    Core photo at depth: 3111-3123m
    Core photo at depth: 3111-3123m
    Core photo at depth: 3111-3123m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
    3111-3123m
    3111-3123m
    3111-3123m
    3174-3202m
    3174-3202m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
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    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
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    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
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    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
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    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
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    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
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    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
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    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
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    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
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    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
    Core photo at depth: 3174-3202m
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    3174-3202m
    Core photo at depth: 3202-3216m
    Core photo at depth: 3202-3216m
    Core photo at depth: 3202-3216m
    Core photo at depth: 3202-3216m
    Core photo at depth: 3202-3216m
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    Core photo at depth: 3202-3216m
    Core photo at depth: 3202-3216m
    Core photo at depth: 3202-3216m
    Core photo at depth: 3202-3216m
    Core photo at depth: 3202-3216m
    3202-3216m
    3202-3216m
    3202-3216m
    3202-3216m
    3202-3216m
    Core photo at depth: 3202-3216m
    Core photo at depth: 3202-3216m
    Core photo at depth: 3202-3216m
    Core photo at depth: 3202-3216m
    Core photo at depth: 3202-3216m
    3202-3216m
    3202-3216m
    3202-3216m
    3202-3216m
    3202-3216m
    Core photo at depth: 3202-3216m
    Core photo at depth: 3202-3216m
    Core photo at depth: 3202-3216m
    Core photo at depth: 3202-3216m
    Core photo at depth: 3202-3216m
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    Core photo at depth: 3202-3216m
    Core photo at depth: 3202-3216m
    Core photo at depth: 3202-3216m
    Core photo at depth: 3202-3216m
    Core photo at depth: 3202-3216m
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    3202-3216m
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    3202-3216m
    3202-3216m
    Core photo at depth: 3231-3259m
    Core photo at depth: 3231-3259m
    Core photo at depth: 3231-3259m
    Core photo at depth: 3231-3259m
    Core photo at depth: 3231-3259m
    3231-3259m
    3231-3259m
    3231-3259m
    3231-3259m
    3231-3259m
    Core photo at depth: 3231-3259m
    Core photo at depth: 3231-3259m
    Core photo at depth: 3231-3259m
    Core photo at depth: 3231-3259m
    Core photo at depth: 3231-3259m
    3231-3259m
    3231-3259m
    3231-3259m
    3231-3259m
    3231-3259m
    Core photo at depth: 3231-3259m
    Core photo at depth: 3259-3287m
    Core photo at depth: 3259-3287m
    Core photo at depth: 3259-3287m
    Core photo at depth: 3259-3287m
    3231-3259m
    3259-3287m
    3259-3287m
    3259-3287m
    3259-3287m
    Core photo at depth: 3259-3287m
    Core photo at depth: 3259-3287m
    Core photo at depth: 3259-3287m
    Core photo at depth: 3259-3287m
    Core photo at depth: 3259-3287m
    3259-3287m
    3259-3287m
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    3259-3287m
    Core photo at depth: 3259-3287m
    Core photo at depth: 3259-3287m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3259-3287m
    3259-3287m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2606.0
    [m]
    SWC
    GEAR
    2619.0
    [m]
    SWC
    GEARH
    2630.0
    [m]
    SWC
    GEARH
    2641.0
    [m]
    SWC
    GEARH
    2655.0
    [m]
    SWC
    GEARH
    2675.0
    [m]
    SWC
    GEARH
    2709.0
    [m]
    SWC
    GEARH
    2727.0
    [m]
    SWC
    GEARH
    2808.5
    [m]
    SWC
    GEARH
    2858.0
    [m]
    SWC
    GEARH
    2880.0
    [m]
    SWC
    GEARH
    2910.0
    [m]
    SWC
    GEARH
    2921.0
    [m]
    SWC
    GEARH
    2943.0
    [m]
    SWC
    GEARH
    2957.0
    [m]
    SWC
    GEARH
    2981.0
    [m]
    SWC
    GEARH
    2989.0
    [m]
    SWC
    GEARH
    3000.0
    [m]
    SWC
    GEARH
    3017.5
    [m]
    SWC
    GEARH
    3035.5
    [m]
    SWC
    GEARH
    3047.0
    [m]
    SWC
    GEARH
    3078.0
    [m]
    SWC
    GEARH
    3099.0
    [m]
    SWC
    GEARH
    3111.2
    [m]
    C
    GEARH
    3114.7
    [m]
    C
    GEARH
    3117.8
    [m]
    C
    GEARH
    3120.6
    [m]
    C
    GEARH
    3123.0
    [m]
    C
    GEARH
    3174.4
    [m]
    C
    GEARH
    3185.6
    [m]
    C
    GEARH
    3190.6
    [m]
    C
    GEARH
    3250.4
    [m]
    C
    GEARH
    3253.9
    [m]
    C
    GEARH
    3258.5
    [m]
    C
    GEARH
    3261.0
    [m]
    C
    GEARH
    3269.6
    [m]
    C
    GEARH
    3278.0
    [m]
    C
    GEARH
    3281.9
    [m]
    C
    GEARH
    3328.0
    [m]
    SWC
    GEARH
    3391.0
    [m]
    SWC
    GEARH
    3410.0
    [m]
    SWC
    GEARH
    3424.0
    [m]
    SWC
    GEARH
    3437.0
    [m]
    SWC
    GEARH
    3460.0
    [m]
    SWC
    GEARH
    3508.0
    [m]
    SWC
    GEARH
    3518.0
    [m]
    SWC
    GEARH
    3540.0
    [m]
    SWC
    GEARH
    3582.5
    [m]
    SWC
    GEARH
    3618.0
    [m]
    SWC
    GEARH
    3657.0
    [m]
    SWC
    GEARH
    3679.0
    [m]
    SWC
    GEARH
    3686.0
    [m]
    SWC
    GEARH

  • Oil samples at the Norwegian Offshore Directorate
    Oil samples at the Norwegian Offshore Directorate
    Test type
    Bottle number
    Top depth
    MD [m]
    Bottom depth
    MD [m]
    Fluid type
    Test time
    Samples available
    DST
    TEST3
    3177.00
    3210.00
    20.04.1987 - 00:00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.58

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.30
    pdf
    2.23
    pdf
    1.59
    pdf
    0.23

  • 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
    22.83

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3245
    3263
    12.7
    2.0
    3220
    3236
    12.7
    3.0
    3177
    3210
    14.3
    3.1
    3177
    3210
    9.5
    3.2
    3177
    3210
    11.1
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    1.000
    35.000
    2.0
    28.000
    3.0
    6.000
    28.000
    3.1
    11.000
    8.000
    28.000
    3.2
    11.000
    4.000
    34.000
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    1.0
    2.0
    3
    0.834
    3.0
    850
    20400
    0.835
    0.803
    24
    3.1
    580
    14500
    0.825
    0.845
    25
    3.2
    660
    18480
    0.829
    0.845
    28

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    ACBL VDL GR
    1780
    2571
    ACBL VDL GR
    2392
    3283
    CDL CNL GR CAL
    2571
    3743
    CDL GR CAL
    757
    2600
    DIFL BHC AC GR SP CAL
    757
    3742
    DLL MLL GR
    3150
    3400
    FMT
    3178
    3579
    FMT
    3245
    3251
    HR DIP
    2975
    3743
    MWD - GR RES DIR
    198
    3756
    SPECTRALOG
    3150
    3740
    VELOCITY
    900
    2500

  • 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
    189.0
    36
    318.0
    0.00
    LOT
    INTERM.
    13 3/8
    757.0
    17 1/2
    788.0
    1.54
    LOT
    INTERM.
    9 5/8
    2571.0
    12 1/4
    2603.0
    1.95
    LOT
    LINER
    7
    3756.0
    8 1/2
    3756.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    318
    1.05
    WATERBASED
    26.02.1987
    768
    1.05
    WATERBASED
    02.03.1987
    788
    1.02
    WATER BASED
    02.03.1987
    788
    0.00
    WATERBASED
    02.03.1987
    1028
    1.09
    14.0
    6.2
    WATERBASED
    03.03.1987
    1303
    1.09
    19.0
    6.2
    WATERBASED
    04.03.1987
    1426
    1.09
    16.0
    5.3
    WATERBASED
    05.03.1987
    1768
    1.10
    18.0
    5.8
    WATERBASED
    06.03.1987
    1989
    1.10
    14.0
    4.8
    WATER BASED
    09.03.1987
    2317
    1.10
    13.0
    6.5
    WATERBASED
    09.03.1987
    2482
    1.11
    12.0
    6.2
    WATER BASED
    10.03.1987
    2600
    1.11
    12.0
    5.7
    WATER BASED
    11.03.1987
    2600
    1.11
    12.0
    5.7
    WATER BASED
    12.03.1987
    2600
    1.12
    13.0
    5.7
    WATER BASED
    13.03.1987
    2603
    1.13
    11.0
    4.8
    WATER BASED
    16.03.1987
    2707
    1.13
    12.0
    5.3
    WATER BASED
    16.03.1987
    2807
    1.13
    13.0
    5.3
    WATER BASED
    16.03.1987
    2888
    1.13
    12.0
    5.7
    WATER BASED
    17.03.1987
    2992
    1.16
    18.0
    5.3
    WATER BASED
    18.03.1987
    3085
    1.20
    15.0
    4.8
    WATER BASED
    19.03.1987
    3117
    1.22
    15.0
    5.3
    WATER BASED
    20.03.1987
    3130
    1.25
    8.0
    2.9
    WATER BASED
    24.04.1987
    3139
    1.22
    15.0
    5.2
    WATER BASED
    23.03.1987
    3175
    1.25
    17.0
    5.7
    WATER BASED
    24.03.1987
    3202
    1.22
    14.0
    3.8
    WATER BASED
    23.03.1987
    3202
    1.23
    14.0
    5.3
    WATER BASED
    23.03.1987
    3263
    1.25
    15.0
    4.8
    WATER BASED
    25.03.1987
    3300
    1.26
    15.0
    4.8
    WATER BASED
    26.03.1987
    3340
    1.26
    14.0
    3.4
    WATER BASED
    09.04.1987
    3340
    1.26
    14.0
    3.3
    WATER BASED
    09.04.1987
    3340
    1.25
    14.0
    4.0
    WATER BASED
    09.04.1987
    3340
    1.26
    12.0
    3.4
    WATER BASED
    09.04.1987
    3340
    1.25
    12.0
    3.4
    WATER BASED
    14.04.1987
    3340
    1.25
    12.0
    3.4
    WATER BASED
    15.04.1987
    3386
    1.26
    20.0
    6.2
    WATER BASED
    30.03.1987
    3460
    1.25
    22.0
    7.2
    WATER BASED
    30.03.1987
    3521
    1.25
    20.0
    7.2
    WATER BASED
    30.03.1987
    3611
    1.25
    20.0
    6.2
    WATER BASED
    30.03.1987
    3643
    1.25
    18.0
    5.2
    WATER BASED
    01.04.1987
    3688
    1.25
    20.0
    5.7
    WATER BASED
    01.04.1987
    3756
    1.25
    16.0
    3.8
    WATER BASED
    03.04.1987
    3756
    1.25
    21.0
    6.2
    WATER BASED
    06.04.1987
    3756
    1.25
    17.0
    3.4
    WATER BASED
    06.04.1987
    3756
    1.25
    20.0
    5.7
    WATER BASED
    06.04.1987
    3756
    1.25
    19.0
    5.7
    WATER BASED
    08.04.1987
    3756
    1.25
    18.0
    4.3
    WATERBASED
    09.04.1987
    3756
    1.25
    19.0
    5.7
    WATER BASED
    03.04.1987
    3756
    1.25
    17.0
    3.8
    WATER BASED
    07.04.1987

  • 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