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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6407/7-4

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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.
    6407/7-4
    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.
    NORWEGIAN 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.
    6407/7-4
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 8604- row 859 & column 1055
    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.
    Norsk Hydro Produksjon 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.
    600-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.
    75
    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,
    13.01.1989
    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.
    28.03.1989
    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.
    31.01.2017
    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.
    28.03.1991
    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.
    09.03.2009
    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
    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.
    ILE 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.
    EARLY 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.
    BÅT GP
    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.
    329.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3211.0
    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).
    3204.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    9.7
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    122
    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.
    ÅRE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    64° 15' 43.43'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 13' 25.84'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7127595.36
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    413943.15
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    32
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    1360

  • Wellbore history
    General
    Well 6407/7-4 was drilled on the Njord A-East structure in the southern part of the Halten Terrace. The Njord structure is located ca 30 km west of the Draugen Field . The location was within a gentle ice berg plough mark with a trend southwest-northeast. The primary objective was to establish the oil-water contact in the Tilje Formation. Secondary objectives were to obtain a better mapping of the reservoir quality of the Tilje Formation on the east flank, to test productivity and injectivity of the Tilje Formation, and to appraise the down flank oil bearing potential and productivity of the Ile Formation. Reservoir fluids including formation water should be sampled. Boulders were expected at 395 m, and shallow gas from 509 - 528 m and especially at 553 m.
    Operations and results
    Appraisal well 6407/7-4 was spudded by the semi-submersible rig Polar Pioneer on 11 January 1989 drilled to TD at 3211 m in Early Jurassic sediments of the Åre Formation. Spudding was delayed due to severe weather conditions causing the rig to drift 43 nautical miles off location. No shallow gas was encountered. Further periods of bad weather led to some problems and WOW, but apart from this the drilling proceeded without significant problems. The well was drilled with spud mud down to 538 m and with KCl mud from 538 m to TD.
    The well proved oil in sands of the Ile, Tilje, and Åre Formations. The Ile Formation had oil from 2873.5 to 2896 m with a net pay of 14.8 m. The Tilje Formation had oil from 2972.5 m and down to 3120 m. Net pay in the Tilje Formation was 89.5 m. From logs, cores, and DST data an OWC could be placed at ca 3120 m in the Tilje Formation, while RFT data indicated a contact at 3110 m. The CPI log also showed a thin oil zone between 3148 and 3153 m in the Åre Formation. Weak shows (minor spotted blue-white to yellow white direct and cut fluorescence) were seen on limestones at 1850 - 1890 m. At 2435 to 2450 m in the Kvitnos Formation sandstones had direct and crush cut yellow-white fluorescence. From 3120 m to 3142 m there were no shows. Below 3142 m only weak shows were observed.
    One core was cut from 2877 - 2896 m, and a total of nine cores were cut from 2974 - 3140 m. Twenty-six of 30 sidewall cores were recovered. Segregated RFT samples were taken at 2885 m (water/filtrate with traces of oil and gas), and at 3037 m (0.85 Sm3 gas and 5 litres 42.5 deg API oil in 2 3/4 gallon chamber).
    The well was permanently abandoned on 28 March 1989 as an oil appraisal well.
    Testing
    Three DST tests were performed in this well.
    Test no 1 was performed in the interval 3126 - 3138.5 m in the water zone. It produced 147 m3 water and 424 Sm3 gas /day through a 11.11 mm choke. The gas gravity was 0.69 (air = 1) with 11% CO2 and 0.1 ppm H2S. The down-hole temperature in the test, measured at 3065.7 m, was 118.5 deg C.
    Test no 2 A was performed in the interval 2999 - 3008 m. It produced 242 Sm3 oil and 46000 Sm3 gas /day through a 7.94 mm choke. The GOR was 185 Sm3/Sm3, oil density was 0.83 g/cm3, gas gravity was 0.74 (air = 1) with 2% CO2 and 2 ppm H2S. The down-hole temperature in the test, measured at 2957.7 m, was 115.7 deg C.
    Test no 2 B was performed in the combined intervals 2999 - 3008 m and 3028 - 3071 m. It produced 740 Sm3 oil and 125000 Sm3 gas /day through a 12.7 mm choke. The GOR was169 Sm3/Sm3, oil density was 0.84 g/cm3, gas gravity was 0.72 (air = 1) with 2% CO2 and 2 ppm H2S. The down-hole temperature in the test, measured at 3005.7 m, was 117.1 deg C.

  • 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]
    550.00
    3210.00

  • 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
    2877.0
    2897.0
    [m ]
    2
    2974.6
    2982.8
    [m ]
    3
    2982.8
    3010.5
    [m ]
    4
    3010.6
    3037.3
    [m ]
    5
    3037.3
    3040.6
    [m ]
    6
    3040.6
    3068.1
    [m ]
    7
    3069.0
    3097.3
    [m ]
    8
    3087.0
    3100.0
    [m ]
    9
    3101.1
    3127.7
    [m ]
    10
    3128.0
    3140.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    193.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2877-2882m
    Core photo at depth: 2882-2887m
    Core photo at depth: 2887-2892m
    Core photo at depth: 2887-2897m
    Core photo at depth: 2892-2895m
    2877-2882m
    2882-2887m
    2887-2892m
    2887-2897m
    2892-2895m
    Core photo at depth: 2974-2979m
    Core photo at depth: 2979-2983m
    Core photo at depth: 2983-2988m
    Core photo at depth: 2988-2993m
    Core photo at depth: 2993-2998m
    2974-2979m
    2979-2983m
    2983-2988m
    2988-2993m
    2993-2998m
    Core photo at depth: 2998-3003m
    Core photo at depth: 3003-3008m
    Core photo at depth: 3008-3012m
    Core photo at depth: 3012-3017m
    Core photo at depth: 3017-3022m
    2998-3003m
    3003-3008m
    3008-3012m
    3012-3017m
    3017-3022m
    Core photo at depth: 3022-3027m
    Core photo at depth: 3027-3032m
    Core photo at depth: 3032-3037m
    Core photo at depth: 3037-3040m
    Core photo at depth: 3040-3045m
    3022-3027m
    3027-3032m
    3032-3037m
    3037-3040m
    3040-3045m
    Core photo at depth: 3045-3050m
    Core photo at depth: 3050-3055m
    Core photo at depth: 3055-3060m
    Core photo at depth: 3060-3065m
    Core photo at depth: 3065-3068m
    3045-3050m
    3050-3055m
    3055-3060m
    3060-3065m
    3065-3068m
    Core photo at depth: 3068-3073m
    Core photo at depth: 3073-3078m
    Core photo at depth: 3078-3083m
    Core photo at depth: 3083-3088m
    Core photo at depth: 3088-3093m
    3068-3073m
    3073-3078m
    3078-3083m
    3083-3088m
    3088-3093m
    Core photo at depth: 3093-3098m
    Core photo at depth: 3098-3103m
    Core photo at depth: 3103-3108m
    Core photo at depth: 3108-3113m
    Core photo at depth: 3113-3118m
    3093-3098m
    3098-3103m
    3103-3108m
    3108-3113m
    3113-3118m
    Core photo at depth: 3118-3123m
    Core photo at depth: 3123-3127m
    Core photo at depth: 3128-3133m
    Core photo at depth: 3133-3138m
    Core photo at depth: 3138-3140m
    3118-3123m
    3123-3127m
    3128-3133m
    3133-3138m
    3138-3140m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1690.0
    [m]
    DC
    STRAT
    1700.0
    [m]
    DC
    STRAT
    1720.0
    [m]
    DC
    STRAT
    1730.0
    [m]
    DC
    STRAT
    1750.0
    [m]
    DC
    STRAT
    1760.0
    [m]
    DC
    STRAT
    1780.0
    [m]
    DC
    STRAT
    1790.0
    [m]
    DC
    STRAT
    1805.0
    [m]
    DC
    STRAT
    1820.0
    [m]
    DC
    STRAT
    1835.0
    [m]
    DC
    STRAT
    1850.0
    [m]
    DC
    STRAT
    1865.0
    [m]
    DC
    STRAT
    1880.0
    [m]
    DC
    STRAT
    1895.0
    [m]
    DC
    STRAT
    1910.0
    [m]
    DC
    STRAT
    1925.0
    [m]
    DC
    STRAT
    1940.0
    [m]
    DC
    STRAT
    1955.0
    [m]
    DC
    STRAT
    1970.0
    [m]
    DC
    STRAT
    1985.0
    [m]
    DC
    STRAT
    2000.0
    [m]
    DC
    STRAT
    2015.0
    [m]
    DC
    STRAT
    2030.0
    [m]
    DC
    STRAT
    2045.0
    [m]
    DC
    STRAT
    2060.0
    [m]
    DC
    STRAT
    2075.0
    [m]
    DC
    STRAT
    2090.0
    [m]
    DC
    STRAT
    2105.0
    [m]
    DC
    STRAT
    2120.0
    [m]
    DC
    STRAT
    2135.0
    [m]
    DC
    STRAT
    2150.0
    [m]
    DC
    STRAT
    2165.0
    [m]
    DC
    STRAT
    2180.0
    [m]
    DC
    STRAT
    2195.0
    [m]
    DC
    STRAT
    2205.0
    [m]
    DC
    STRAT
    2220.0
    [m]
    DC
    STRAT
    2490.0
    [m]
    DC
    STRAT
    2505.0
    [m]
    DC
    STRAT
    2520.0
    [m]
    DC
    STRAT
    2535.0
    [m]
    DC
    STRAT
    2550.0
    [m]
    DC
    STRAT
    2565.0
    [m]
    DC
    STRAT
    2580.0
    [m]
    DC
    STRAT
    2595.0
    [m]
    DC
    STRAT
    2610.0
    [m]
    DC
    STRAT
    2625.0
    [m]
    DC
    STRAT
    2650.0
    [m]
    DC
    STRAT
    2660.0
    [m]
    DC
    STRAT
    2670.0
    [m]
    DC
    STRAT
    2680.0
    [m]
    DC
    STRAT
    2690.0
    [m]
    DC
    STRAT
    2700.0
    [m]
    DC
    STRAT
    2710.0
    [m]
    DC
    STRAT
    2720.0
    [m]
    DC
    STRAT
    2730.0
    [m]
    DC
    STRAT
    2740.0
    [m]
    DC
    STRAT
    2750.0
    [m]
    DC
    STRAT
    2760.0
    [m]
    DC
    STRAT
    2770.0
    [m]
    DC
    STRAT
    2780.0
    [m]
    DC
    STRAT
    2790.0
    [m]
    DC
    STRAT
    2805.0
    [m]
    SWC
    HYDRO
    2815.0
    [m]
    SWC
    HYDRO
    2827.0
    [m]
    SWC
    HYDRO
    2846.0
    [m]
    SWC
    HYDRO
    2850.0
    [m]
    SWC
    HYDRO
    2855.0
    [m]
    SWC
    HYDRO
    2860.0
    [m]
    SWC
    HYDRO
    2866.0
    [m]
    SWC
    HYDRO
    2872.0
    [m]
    DC
    STRAT
    2878.1
    [m]
    C
    HYDRO
    2886.4
    [m]
    C
    HYDRO
    2891.7
    [m]
    C
    HYDRO
    2894.7
    [m]
    C
    HYDRO
    2898.5
    [m]
    SWC
    HYDRO
    2905.0
    [m]
    DC
    STRAT
    2912.0
    [m]
    SWC
    HYDRO
    2920.0
    [m]
    DC
    STRAT
    2927.0
    [m]
    SWC
    HYDRO
    2932.0
    [m]
    DC
    STRAT
    2940.0
    [m]
    SWC
    HYDRO
    2950.0
    [m]
    SWC
    HYDRO
    2950.0
    [m]
    SWC
    HYDRO
    2957.0
    [m]
    DC
    STRAT
    2965.0
    [m]
    SWC
    HYDRO
    2975.2
    [m]
    C
    HYDRO
    2979.7
    [m]
    C
    HYDRO
    2982.5
    [m]
    C
    HYDRO
    2987.5
    [m]
    C
    HYDRO
    2996.6
    [m]
    C
    HYDRO
    3000.0
    [m]
    DC
    STRAT
    3009.5
    [m]
    C
    HYDRO
    3020.8
    [m]
    C
    HYDRO
    3026.8
    [m]
    C
    HYDRO
    3033.3
    [m]
    C
    HYDRO
    3038.3
    [m]
    C
    HYDRO
    3046.6
    [m]
    C
    HYDRO
    3056.9
    [m]
    C
    HYDRO
    3059.4
    [m]
    C
    HYDRO
    3069.2
    [m]
    C
    HYDRO
    3073.5
    [m]
    C
    HYDRO
    3078.5
    [m]
    C
    HYDRO
    3086.8
    [m]
    C
    HYDRO
    3089.5
    [m]
    C
    HYDRO
    3096.3
    [m]
    C
    HYDRO
    3099.5
    [m]
    C
    HYDRO
    3107.7
    [m]
    C
    HYDRO
    3118.6
    [m]
    C
    HYDRO
    3123.2
    [m]
    C
    HYDRO
    3132.5
    [m]
    C
    HYDRO
    3137.2
    [m]
    C
    HYDRO
    3139.8
    [m]
    C
    HYDRO
    3142.5
    [m]
    C
    HYDRO
    3152.0
    [m]
    DC
    STRAT
    3161.0
    [m]
    SWC
    HYDRO
    3170.0
    [m]
    SWC
    HYDRO
    3180.0
    [m]
    DC
    STRAT
    3187.0
    [m]
    DC
    STRAT
    3197.0
    [m]
    SWC
    HYDRO
    3210.0
    [m]
    SWC
    HYDRO
    3210.0
    [m]
    DC
    STRAT

  • 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
    DST2A
    2999.00
    3008.00
    21.03.1989 - 00:00
    YES
    DST
    DST 2B
    2999.00
    3008.00
    25.03.1989 - 00:00
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.34
    pdf
    0.19

  • 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
    21.39

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3126
    3139
    11.1
    2.0
    2999
    3008
    7.9
    3.0
    3028
    3071
    12.7
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    119
    2.0
    115
    3.0
    117
    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
    424
    0.690
    2.0
    242
    46000
    0.830
    0.740
    185
    3.0
    740
    125000
    0.840
    0.720
    169

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL CET GR
    2280
    3168
    CST GR
    2805
    3210
    DIL LSS LDL CNL GR SP AMS
    1040
    2805
    DIL LSS LDL CNL NGS GR SP AMS
    2792
    3214
    DLL MSFL GR
    2792
    3210
    FEWD - GR RES NEU POR DENS
    2965
    3208
    MWD - GR RES DIR
    352
    2877
    MWD - GR RES DIR
    2896
    2974
    RFT HP AMS
    2876
    3201
    RFT HP AMS
    3037
    3037
    SHDT GR
    2792
    3214
    VSP
    1200
    3160

  • 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
    440.0
    36
    0.0
    0.00
    LOT
    INTERM.
    20
    524.0
    26
    541.0
    1.41
    LOT
    INTERM.
    13 3/8
    1099.0
    18 1/2
    1118.0
    1.96
    LOT
    INTERM.
    9 5/8
    2790.0
    12 1/4
    2812.0
    1.60
    LOT
    LINER
    7
    3209.0
    8 1/2
    3211.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    366
    1.05
    10.0
    35.0
    WATER BASED
    17.01.1989
    390
    1.05
    10.0
    35.0
    WATER BASED
    17.01.1989
    419
    1.05
    10.0
    35.0
    WATER BASED
    17.01.1989
    440
    1.05
    10.0
    35.0
    WATER BASED
    17.01.1989
    500
    1.47
    19.0
    4.0
    WATER BASED
    28.03.1989
    524
    1.05
    10.0
    35.0
    WATER BASED
    18.01.1989
    538
    1.20
    20.0
    8.0
    WATER BASED
    20.01.1989
    538
    1.05
    10.0
    35.0
    WATER BASED
    19.01.1989
    938
    1.22
    14.0
    7.0
    WATER BASED
    24.01.1989
    1115
    1.20
    10.0
    7.0
    WATER BASED
    24.01.1989
    1115
    1.23
    11.0
    7.0
    WATER BASED
    24.01.1989
    1570
    1.60
    26.0
    8.0
    WATER BASED
    24.01.1989
    1959
    1.60
    19.0
    8.0
    WATER BASED
    25.01.1989
    2197
    1.60
    18.0
    5.0
    WATER BASED
    26.01.1989
    2273
    1.60
    17.0
    6.0
    WATER BASED
    27.01.1989
    2293
    1.60
    25.0
    9.0
    WATER BASED
    30.01.1989
    2330
    1.60
    26.0
    7.0
    WATER BASED
    30.01.1989
    2330
    1.60
    25.0
    7.0
    WATER BASED
    30.01.1989
    2330
    1.60
    25.0
    7.0
    WATER BASED
    31.01.1989
    2333
    1.60
    23.0
    6.0
    WATER BASED
    01.02.1989
    2387
    1.60
    23.0
    6.0
    WATER BASED
    02.02.1989
    2399
    1.60
    23.0
    6.0
    WATER BASED
    03.02.1989
    2399
    1.60
    21.0
    5.0
    WATER BASED
    07.02.1989
    2404
    1.60
    22.0
    5.0
    WATER BASED
    07.02.1989
    2404
    1.60
    22.0
    5.0
    WATER BASED
    08.02.1989
    2481
    1.60
    18.0
    6.0
    WATER BASED
    09.02.1989
    2580
    1.60
    24.0
    9.0
    WATER BASED
    10.02.1989
    2645
    1.60
    20.0
    8.0
    WATER BASED
    13.02.1989
    2703
    1.60
    21.0
    10.0
    WATER BASED
    13.02.1989
    2775
    1.60
    19.0
    8.0
    WATER BASED
    13.02.1989
    2808
    1.60
    19.0
    9.0
    WATER BASED
    16.02.1989
    2808
    1.47
    12.0
    5.0
    WATER BASED
    24.02.1989
    2808
    1.60
    18.0
    5.0
    WATER BASED
    14.02.1989
    2808
    1.60
    19.0
    9.0
    WATER BASED
    15.02.1989
    2808
    1.60
    19.0
    9.0
    WATER BASED
    17.02.1989
    2808
    1.60
    19.0
    9.0
    WATER BASED
    20.02.1989
    2808
    1.60
    19.0
    9.0
    WATER BASED
    21.02.1989
    2808
    1.60
    19.0
    9.0
    WATER BASED
    22.02.1989
    2808
    1.60
    19.0
    9.0
    WATER BASED
    23.02.1989
    2877
    1.47
    26.0
    7.0
    WATER BASED
    27.02.1989
    2920
    1.47
    27.0
    6.0
    WATER BASED
    27.02.1989
    2949
    1.47
    19.0
    4.0
    WATER BASED
    28.03.1989
    2974
    1.47
    29.0
    7.0
    WATER BASED
    27.02.1989
    3010
    1.47
    27.0
    7.0
    WATER BASED
    28.02.1989
    3040
    1.47
    31.0
    8.0
    WATER BASED
    01.03.1989
    3068
    1.47
    28.0
    7.0
    WATER BASED
    02.03.1989
    3101
    1.47
    28.0
    7.0
    WATER BASED
    03.03.1989
    3121
    1.47
    20.0
    5.0
    WATER BASED
    28.03.1989
    3121
    1.47
    21.0
    7.0
    WATER BASED
    20.03.1989
    3121
    1.47
    20.0
    5.0
    WATER BASED
    20.03.1989
    3121
    1.47
    20.0
    5.0
    WATER BASED
    21.03.1989
    3121
    1.47
    19.0
    4.0
    WATER BASED
    28.03.1989
    3129
    1.47
    25.0
    7.0
    WATER BASED
    06.03.1989
    3171
    1.47
    27.0
    8.0
    WATER BASED
    09.03.1989
    3171
    1.47
    19.0
    6.0
    WATER BASED
    10.03.1989
    3171
    1.47
    20.0
    6.0
    WATER BASED
    13.03.1989
    3171
    1.47
    20.0
    7.0
    WATER BASED
    14.03.1989
    3171
    1.47
    20.0
    7.0
    WATER BASED
    16.03.1989
    3171
    1.47
    20.0
    7.0
    WATER BASED
    17.03.1989
    3171
    1.47
    21.0
    7.0
    WATER BASED
    20.03.1989
    3171
    1.47
    21.0
    7.0
    WATER BASED
    13.03.1989
    3182
    1.47
    25.0
    7.0
    WATER BASED
    06.03.1989
    3211
    1.47
    26.0
    6.0
    WATER BASED
    07.03.1989
    3211
    1.47
    26.0
    6.0
    WATER BASED
    06.03.1989
    3211
    1.47
    24.0
    5.0
    WATER BASED
    08.03.1989

  • 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
    0.29