Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
04.11.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

30/7-7

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    30/7-7
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    30/7-7
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    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.
    207-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.
    196
    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,
    18.12.1978
    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.
    01.07.1979
    Release date
    Date when raw data which has been reported to the authorities from the wellbore is not confidential any longer. Normally 2 years after finishing the drilling. May be earlier if the area of the production license is relinquished.
    01.07.1981
    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.
    24.09.2004
    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.
    GAS SHOWS
    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.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    110.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    5127.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    17.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    167
    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.
    STATFJORD GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 16' 19.3'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 16' 7.3'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6682087.96
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    459543.34
    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.
    390

  • Wellbore history
    General
    The main objective of the well was to test the SE prospect on the 30/7 block. The objective of the well was to test possible sandstone reservoirs of Jurassic age, which were predicted to occur-in a large structure (150 km2) at the Kimmerian unconformity) located on the eastern flank of the Viking basin. The specific targets were possible turbiditic sandstone deposits within a thick Late Jurassic sequence, Middle Jurassic Brent Formation sandstones, and Early Jurassic Statfjord Formation sandstones. The well was planned to penetrate 50 m into the Statfjord Formation to approximately 5250 m.
    The well is Reference Well for the Cook Formation.
    Operations and results
    The well 30/7-7 was drilled between December 16th 1978 and May 30th 1979 with the rig Treasure Seeker. It reached TD at 5127 m in the Early Jurassic/Late Triassic Statfjord Formation. 34.5% of the total rig time was lost time due to fishing, waiting on weather, waiting for replacement of equipment, and hole problems. The problem that had most serious consequences for the geological program occurred while reaming from 5114 m to 5125 m where the string got stuck. After 9.5 days of fishing for the drill string it was finally backed of at 4804 m. At this point it was decided to abandon the well leaving the fish in the hole. Before this happened the well had been logged down to 5122 m, but the fish made it impossible to test the Statfjord Formation sandstone. The well was drilled with Seawater/gel/hi-vis pills spotting LCM pills as needed down to 763 m and with a Spersene/XP20/Drispac mud with 0 % to 4% oil and LCM pills as needed from 763 m to TD.
    Sandstone levels interbedded with shales were encountered below 2187 m in the Tertiary. They were mainly developed between 2216 and 2320 m. Some calcareous levels in the Maastrichtian limestones between 2531 and 2575 m could be considered as reservoirs. Limestone stringers in the Turonian calcareous section from 3520 m to 3720 m showed fluorescence but were water-bearing. A 636 m thick Upper Jurassic sequence was penetrated, consisting of shales and thin interbedded limestones and dolomites. No turbiditic sandstones occurred. The expected well-developed Middle Jurassic deposits were found to be completely missing. No Middle Jurassic sandstones were encountered. Two reservoir intervals were present in the Early Jurassic. The Upper Sandstone from 4735 m to 4801 m (Cook Formation) consisted of interbedded sandstones and shales. The Lower Sandstone (Statfjord Formation) was penetrated at 4884 m and extended as a homogeneous sandstone with only a single coal bed and minor argillaceous intervals down to 4975 m. Below this a sequence of interbedded sandstones, siltstones and claystones/shales occurred down to TD.
    Shows were recorded as follows: Major gas shows appeared in the interval 3502 m to 3930 m (Turonian limestones) and from 4723 m to 4886 m (Lower Jurassic, calcareous sands). Oil Shows and Fluorescence were noted from 2315 m to 2320 m on sandstone (traces of light brown stain, golden fluorescence, fast streaming light yellow cut); from 2805 m to 2813 m on siltstone (dark yellowish brown stain, light yellow fluorescence, white slowly streaming cut); from 3709 m to 3730 m in limestone (traces of slow, white, streaming cut hydrocarbon fluorescence masked by mineral fluorescence); and from 3908 m to 3912 m in shale (no fluorescence, uniform, weak dull yellow crush-cut and light yellow residue).
    There were no significant hydrocarbon shows observed during drilling the Jurassic sequence. However, log analyses indicated hydrocarbons in both Jurassic sandstone intervals. The Upper Sandstone (Cook Formation) was hydrocarbon bearing from 4735 m to 4776 m while the Lower Sandstone (Statfjord Formation) was hydrocarbon bearing from 4884 m to 4924 m. The lack of oil shows in the Jurassic and the DST results indicated the hydrocarbons could be gas in a tight formation. One conventional core was cut from 4758 m to 4766.4 m (recovery 96%) in the Cook Formation. The core consisted of 7.15 m cemented fine to very fine sandstone with 1.25 m of shale at the base. No RFT fluid samples were attempted due to bad hole conditions. The planned TD was not reached because of the drill string left in the hole. The well was permanently abandoned as a well with shows on 1 July 1979.
    Testing
    A drill stem test (DST 1) was performed on the upper sandstone (4735 m to 4797 m). An approximate volume of 12 m3 of effluent was recovered in about 4 hours from DST 1. The effluent was not considered representative of the Formation fluid. During the reverse circulation no gas flow occurred, only gas bubbles were observed. The composition of these bubbles was 10% CO2, 77.4% C1 9.4% C2, and C3+ up to 100%. The tested level was considered tight. The lower sandstone was not tested due to the broken drill string (fish between 4807 m and 5127 m).

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    NO
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    185.00
    5060.00

  • 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
    4758.3
    4767.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    8.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    NO

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    870.0
    [m]
    DC
    ROBERTSO
    900.0
    [m]
    DC
    ROBERT
    930.0
    [m]
    DC
    ROBERT
    960.0
    [m]
    DC
    ROBERT
    990.0
    [m]
    DC
    ROBERT
    1020.0
    [m]
    DC
    ROBERT
    1050.0
    [m]
    DC
    ROBERT
    1080.0
    [m]
    DC
    ROBERT
    1110.0
    [m]
    DC
    ROBERT
    1140.0
    [m]
    DC
    ROBERT
    1170.0
    [m]
    DC
    ROBERT
    1200.0
    [m]
    DC
    ROBERT
    1230.0
    [m]
    DC
    ROBERT
    1260.0
    [m]
    DC
    ROBERT
    1290.0
    [m]
    DC
    ROBERT
    1320.0
    [m]
    DC
    ROBERT
    1350.0
    [m]
    DC
    ROBERT
    1380.0
    [m]
    DC
    ROBERT
    1410.0
    [m]
    DC
    ROBERT
    1440.0
    [m]
    DC
    ROBERT
    1470.0
    [m]
    DC
    ROBERT
    1500.0
    [m]
    DC
    ROBERT
    1530.0
    [m]
    DC
    ROBERT
    1560.0
    [m]
    DC
    ROBERT
    1590.0
    [m]
    DC
    ROBERT
    1600.0
    [m]
    DC
    1620.0
    [m]
    DC
    1620.0
    [m]
    DC
    ROBERT
    1640.0
    [m]
    DC
    1650.0
    [m]
    DC
    ROBERT
    1660.0
    [m]
    DC
    1680.0
    [m]
    DC
    ROBERT
    1680.0
    [m]
    DC
    1700.0
    [m]
    DC
    1710.0
    [m]
    DC
    ROBERT
    1720.0
    [m]
    DC
    1740.0
    [m]
    DC
    1740.0
    [m]
    DC
    ROBERT
    1760.0
    [m]
    DC
    1770.0
    [m]
    DC
    ROBERT
    1780.0
    [m]
    DC
    1800.0
    [m]
    DC
    1800.0
    [m]
    DC
    ROBERT
    1820.0
    [m]
    DC
    1830.0
    [m]
    DC
    ROBERT
    1840.0
    [m]
    DC
    1860.0
    [m]
    DC
    1860.0
    [m]
    DC
    ROBERT
    1880.0
    [m]
    DC
    1890.0
    [m]
    DC
    ROBERT
    1900.0
    [m]
    DC
    1920.0
    [m]
    DC
    1920.0
    [m]
    DC
    ROBERT
    1940.0
    [m]
    DC
    1950.0
    [m]
    DC
    ROBERT
    1960.0
    [m]
    DC
    1980.0
    [m]
    DC
    1980.0
    [m]
    DC
    ROBERT
    2000.0
    [m]
    DC
    2010.0
    [m]
    DC
    ROBERT
    2020.0
    [m]
    DC
    2040.0
    [m]
    DC
    2040.0
    [m]
    DC
    ROBERT
    2060.0
    [m]
    DC
    2070.0
    [m]
    DC
    ROBERT
    2080.0
    [m]
    DC
    2100.0
    [m]
    DC
    2100.0
    [m]
    DC
    ROBERT
    2120.0
    [m]
    DC
    2130.0
    [m]
    DC
    ROBERT
    2140.0
    [m]
    DC
    2150.0
    [m]
    DC
    2160.0
    [m]
    DC
    ROBERT
    2170.0
    [m]
    DC
    2180.0
    [m]
    DC
    2190.0
    [m]
    DC
    ROBERT
    2200.0
    [m]
    DC
    2215.0
    [m]
    DC
    2220.0
    [m]
    DC
    ROBERT
    2225.0
    [m]
    DC
    2240.0
    [m]
    DC
    2250.0
    [m]
    DC
    ROBERT
    2275.0
    [m]
    DC
    2280.0
    [m]
    DC
    ROBERT
    2295.0
    [m]
    DC
    2310.0
    [m]
    DC
    2310.0
    [m]
    DC
    ROBERT
    2325.0
    [m]
    DC
    2340.0
    [m]
    DC
    ROBERT
    2350.0
    [m]
    DC
    2370.0
    [m]
    DC
    2370.0
    [m]
    DC
    ROBERT
    2390.0
    [m]
    DC
    2400.0
    [m]
    DC
    2400.0
    [m]
    DC
    ROBERT
    2415.0
    [m]
    DC
    2430.0
    [m]
    DC
    2430.0
    [m]
    DC
    ROBERT
    2440.0
    [m]
    DC
    2460.0
    [m]
    DC
    2460.0
    [m]
    DC
    ROBERT
    2480.0
    [m]
    DC
    2490.0
    [m]
    DC
    ROBERT
    2500.0
    [m]
    DC
    2510.0
    [m]
    DC
    2520.0
    [m]
    DC
    ROBERT
    2520.0
    [m]
    DC
    2520.0
    [m]
    DC
    2530.0
    [m]
    DC
    2540.0
    [m]
    DC
    3865.0
    [m]
    DC
    CFP-LABO
    3880.0
    [m]
    SWC
    SNEA(P)
    3883.0
    [m]
    SWC
    SNEA(P
    3884.5
    [m]
    SWC
    SNEA(P
    3890.0
    [m]
    DC
    CFP-LABO
    3900.0
    [m]
    DC
    CFP-LA
    3900.0
    [m]
    SWC
    SNEA(P)
    3915.0
    [m]
    SWC
    SNEA(P
    3916.0
    [m]
    DC
    CFP-LABO
    3924.0
    [m]
    DC
    CFP-LA
    3934.0
    [m]
    DC
    CFP-LA
    3934.0
    [m]
    SWC
    SNEA(P)
    3952.0
    [m]
    DC
    CFP-LAB
    3980.0
    [m]
    DC
    CFP-LA
    3997.0
    [m]
    SWC
    SNEA(P)
    4006.0
    [m]
    DC
    CFP-LABO
    4022.0
    [m]
    DC
    CFP-LA
    4040.0
    [m]
    DC
    CFP-LA
    4050.0
    [m]
    DC
    CFP-LA
    4060.0
    [m]
    DC
    CFP-LA
    4070.0
    [m]
    DC
    CFP-LA
    4098.0
    [m]
    DC
    CFP-LA
    4125.0
    [m]
    DC
    IKU
    4128.0
    [m]
    SWC
    SNEA(P)
    4145.0
    [m]
    SWC
    IKU
    4148.0
    [m]
    DC
    CFP-LABO
    4150.0
    [m]
    DC
    CFP-LA
    4164.0
    [m]
    DC
    CFP-LA
    4165.0
    [m]
    SWC
    IKU
    4165.0
    [m]
    SWC
    SNEA(P)
    4187.0
    [m]
    SWC
    IKU
    4190.0
    [m]
    DC
    CFP-LABO
    4205.0
    [m]
    SWC
    IKU
    4230.0
    [m]
    SWC
    IKU
    4230.0
    [m]
    DC
    CFP-LABO
    4248.0
    [m]
    SWC
    SNEA(P)
    4250.0
    [m]
    DC
    CFP-LABO
    4255.0
    [m]
    SWC
    IKU
    4264.0
    [m]
    DC
    CFP-LABO
    4275.0
    [m]
    SWC
    IKU
    4284.0
    [m]
    DC
    CFP-LABO
    4285.0
    [m]
    SWC
    IKU
    4285.0
    [m]
    SWC
    SNEA(P)
    4302.0
    [m]
    SWC
    SNEA(P
    4302.0
    [m]
    DC
    CFP-LABO
    4302.0
    [m]
    SWC
    IKU
    4305.0
    [m]
    SWC
    IKU
    4330.0
    [m]
    SWC
    IKU
    4331.0
    [m]
    SWC
    SNEA(P)
    4336.0
    [m]
    DC
    CFP-LABO
    4350.0
    [m]
    DC
    CFP-LA
    4350.0
    [m]
    DC
    CFP-LA
    4358.0
    [m]
    DC
    CFP-LA
    4370.0
    [m]
    DC
    CFP-LA
    4381.0
    [m]
    SWC
    IKU
    4398.5
    [m]
    SWC
    IKU
    4398.5
    [m]
    SWC
    SNEA(P)
    4408.0
    [m]
    DC
    CFP-LABO
    4430.0
    [m]
    DC
    CFP-LA
    4450.0
    [m]
    DC
    CFP-LA
    4450.0
    [m]
    SWC
    IKU
    4460.0
    [m]
    DC
    CFP-LABO
    4474.0
    [m]
    DC
    CFP-LA
    4478.0
    [m]
    SWC
    SNEA(P)
    4478.0
    [m]
    SWC
    IKU
    4492.0
    [m]
    DC
    IKU
    4494.0
    [m]
    DC
    IKU
    4498.0
    [m]
    DC
    HYDRO
    4500.0
    [m]
    SWC
    IKU
    4502.0
    [m]
    DC
    IKU
    4504.0
    [m]
    DC
    HYDRO
    4506.0
    [m]
    DC
    IKU
    4508.0
    [m]
    DC
    CFP-LABO
    4510.0
    [m]
    DC
    HYDRO
    4514.0
    [m]
    DC
    HYDRO
    4515.0
    [m]
    SWC
    IKU
    4516.0
    [m]
    DC
    IKU
    4520.0
    [m]
    DC
    HYDRO
    4520.0
    [m]
    DC
    HYDRO
    4520.0
    [m]
    SWC
    SNEA(P)
    4530.0
    [m]
    SWC
    IKU
    4536.0
    [m]
    DC
    IKU
    4540.0
    [m]
    DC
    CFP-LABO
    4548.0
    [m]
    DC
    CFP-LA
    4552.0
    [m]
    DC
    IKU
    4560.0
    [m]
    DC
    CFP-LABO
    4560.0
    [m]
    SWC
    IKU
    4560.0
    [m]
    DC
    IKU
    4560.0
    [m]
    DC
    HYDRO
    4570.0
    [m]
    DC
    SNEA(P)
    4570.0
    [m]
    DC
    HYDRO
    4575.0
    [m]
    SWC
    IKU
    4580.0
    [m]
    DC
    CFP-LABO
    4580.0
    [m]
    DC
    HYDRO
    4592.0
    [m]
    DC
    IKU
    4608.0
    [m]
    DC
    CFP-LABO
    4610.0
    [m]
    DC
    IKU
    4615.0
    [m]
    DC
    SNEA(P)
    4620.0
    [m]
    SWC
    IKU
    4632.0
    [m]
    DC
    CFP-LABO
    4632.0
    [m]
    DC
    IKU
    4650.0
    [m]
    DC
    CFP-LABO
    4652.0
    [m]
    DC
    IKU
    4652.0
    [m]
    DC
    CFP-LA
    4665.0
    [m]
    SWC
    IKU
    4672.0
    [m]
    DC
    IKU
    4674.0
    [m]
    DC
    CFP-LABO
    4692.0
    [m]
    DC
    IKU
    4698.0
    [m]
    DC
    CFP-LABO
    4700.0
    [m]
    DC
    CFP-LA
    4704.0
    [m]
    SWC
    SNEA(P)
    4704.0
    [m]
    SWC
    IKU
    4710.0
    [m]
    DC
    CFP-LAB
    4710.0
    [m]
    DC
    CFP-LA
    4712.0
    [m]
    DC
    IKU
    4720.0
    [m]
    SWC
    IKU
    4720.0
    [m]
    SWC
    SNEA(P)
    4726.0
    [m]
    DC
    CFP-LAB
    4732.0
    [m]
    DC
    IKU
    4740.0
    [m]
    DC
    IKU
    4744.0
    [m]
    SWC
    IKU
    4744.0
    [m]
    DC
    CFP-LAB
    4750.0
    [m]
    SWC
    IKU
    4750.0
    [m]
    SWC
    SNEA(P)
    4750.0
    [m]
    DC
    IKU
    4751.0
    [m]
    SWC
    IKU
    4752.0
    [m]
    DC
    IKU
    4758.0
    [m]
    DC
    CFP-LAB
    4758.5
    [m]
    C
    SNEA(P)
    4759.0
    [m]
    C
    UNKNOWN
    4760.7
    [m]
    C
    SNEA(P)
    4760.8
    [m]
    C
    HYDRO
    4761.0
    [m]
    C
    UNKNOWN
    4762.7
    [m]
    C
    SNEA(P)
    4764.5
    [m]
    C
    HYDRO
    4765.1
    [m]
    C
    SNEA(P)
    4765.8
    [m]
    C
    UNKNOWN
    4766.0
    [m]
    C
    SNEA(P)
    4766.2
    [m]
    C
    HYDRO
    4766.4
    [m]
    C
    U.OF SHE
    4766.5
    [m]
    C
    UNKNOWN
    4766.6
    [m]
    C
    U.OF SHE
    4766.8
    [m]
    C
    U.OF S
    4767.0
    [m]
    C
    UNKNOWN
    4772.0
    [m]
    DC
    CFP-LAB
    4772.0
    [m]
    DC
    IKU
    4775.0
    [m]
    SWC
    SNEA(P)
    4790.0
    [m]
    DC
    CFP-LAB
    4792.0
    [m]
    DC
    IKU
    4799.0
    [m]
    SWC
    IKU
    4800.0
    [m]
    DC
    CFP-LAB
    4800.0
    [m]
    DC
    SNEA(P)
    4804.0
    [m]
    SWC
    SNEA(P
    4804.0
    [m]
    SWC
    IKU
    4812.0
    [m]
    DC
    IKU
    4812.0
    [m]
    DC
    IKU
    4818.0
    [m]
    DC
    CFP-LAB
    4832.0
    [m]
    DC
    IKU
    4840.0
    [m]
    DC
    SNEA(P)
    4852.0
    [m]
    DC
    IKU
    4872.0
    [m]
    DC
    IKU
    4880.0
    [m]
    DC
    SNEA(P)
    4892.0
    [m]
    DC
    IKU
    4912.0
    [m]
    DC
    IKU
    4920.0
    [m]
    DC
    SNEA(P)
    4924.0
    [m]
    DC
    SNEA(P
    4932.0
    [m]
    DC
    IKU
    4940.0
    [m]
    DC
    IKU
    4952.0
    [m]
    DC
    IKU
    4954.0
    [m]
    DC
    IKU
    4956.0
    [m]
    DC
    IKU
    4960.0
    [m]
    DC
    SNEA(P)
    4972.0
    [m]
    DC
    IKU
    4992.0
    [m]
    DC
    IKU
    5012.0
    [m]
    DC
    IKU
    5032.0
    [m]
    DC
    IKU
    5038.0
    [m]
    DC
    SNEA(P)
    5046.0
    [m]
    DC
    IKU
    5050.0
    [m]
    DC
    IKU
    5058.0
    [m]
    DC
    IKU
    5080.0
    [m]
    DC
    SNEA(P)
    5110.0
    [m]
    DC
    SNEA(P

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.64

  • Geochemical information

  • 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
    14.39
    pdf
    4.35

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    4735
    4762
    6.4
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    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

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CST
    4758
    4766
    DLL MSFL
    4700
    5042
    FDC CNL
    769
    5047
    HDT
    2677
    4803
    ISF SONIC
    764
    3686
    ISF SONIC
    3874
    5046

  • 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
    184.0
    36
    185.0
    0.00
    LOT
    SURF.COND.
    20
    764.0
    26
    781.0
    1.14
    LOT
    INTERM.
    13 3/8
    2681.0
    17 1/2
    2701.0
    1.85
    LOT
    INTERM.
    9 5/8
    3877.0
    12 1/4
    3888.0
    2.17
    LOT
    LINER
    7
    4500.0
    8 3/8
    4509.0
    2.20
    LOT
    LINER
    4 1/2
    5127.0
    6
    5127.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    185
    1.04
    spud mud
    781
    1.04
    45.0
    seawater
    1822
    1.09
    52.0
    seawater
    2503
    1.14
    46.0
    seawater
    2681
    1.16
    45.0
    seawater
    3071
    1.70
    46.0
    seawater
    3414
    1.73
    43.0
    seawater
    3888
    1.80
    70.0
    seawater
    4440
    2.04
    48.0
    seawater
    5060
    2.09
    61.0
    seawater