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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7120/5-1

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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.
    7120/5-1
    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.
    BARENTS SEA
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    7120/5-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    TN 6583-346 SP. 495
    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.
    461-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.
    51
    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,
    17.04.1985
    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.
    06.06.1985
    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.
    06.06.1987
    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.
    18.05.2004
    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.
    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.
    22.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    296.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2700.0
    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).
    2699.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    66
    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.
    FRUHOLMEN FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    71° 34' 51.86'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 26' 12.26'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7942513.53
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    480135.74
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    34
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    471

  • Wellbore history
    General
    Wildcat well 7120/5-1 was drilled west of the Snøhvit Field on a separate structure, the Alpha structure in the Hammerfest Basin. The main objective of the well was to test possible hydrocarbon accumulations in the Alpha structure of Middle to Lower Jurassic age. A secondary objective was to drill into rocks of upper Triassic age at a prognosed depth of 3047 m.
    Operations and results
    Well 7120/5-1 was spudded by Smedvigs semi-submersible rig West Vanguard 17 April 1985, and completed 6 June 1985. The well was drilled with spud mud down to 885 m and with gypsum/polymer mud from 885 m to TD. Seventy-four meter below the 20" casing shoe, after the well had penetrated a fault at 954 m, high background gas with heavy components was encountered. The high background gas persisted throughout this section down to the 13 3/8" casing point at 1975 m. Drilling went on without any serious problems.
    The lithology in the Tertiary and Cretaceous comprises clay with scattered Lime-, Dolomite- and Siltstone layers. The Jurassic Stø Formation was encountered at 2285 m represented by clayey sands, while the clean part of that formation came in at 2341 m. Nordmela Formation was found at 2427 m, and top of Triassic rocks, Fruholmen Formation, came in at 2648 m. Both Stø- and Nordmela Formations were water bearing, but with good oil shows. Geochemical analyses of extracts from this interval showed a waxy oil. In a sandy zone between 2405 m to 2420 m high resistivity values were encountered, but RFT tests and pressure measurements gave negative results. Good source potentials were found in mudstones below ca 1900 m. Shales from 1900 m to 2230 m had TOC in the range 1 % - 3.5 %. A 20 m thick, very organic rich shale with 6 - 19 % TOC was encountered from 2251 m to 2271 m in the Hekkingen Formation. Below this level to TD, frequent claystone interbeds had TOC in the range 0.5 % - 5.5 % in cuttings (up to 13.42 % in a swc from 2351.2 m). The highest hydrogen index was seen in the rich Hekkingen shale (200 - 250 mg/g), which correspond to potential for gas with some oil. Six cores were cut in the interval 2286- 2425.5 m, all in the Stø Formation. Close to all of the Stø Formation was cored. A segregated RFT sample was taken at 2346 m. It recovered water with some gas.
    The well was permanently abandoned on 6 June 1985 as dry well with shows.
    Testing
    No drill stem test was performed

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    YES
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    380.00
    2696.00

  • 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
    2286.0
    2312.8
    [m ]
    2
    2313.0
    2323.1
    [m ]
    3
    2323.0
    2351.0
    [m ]
    4
    2351.0
    2377.4
    [m ]
    5
    2378.0
    2398.0
    [m ]
    6
    2398.0
    2424.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    137.9
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2286-2290m
    Core photo at depth: 2291-2295m
    Core photo at depth: 2296-2300m
    Core photo at depth: 2301-2305m
    Core photo at depth: 2306-2310m
    2286-2290m
    2291-2295m
    2296-2300m
    2301-2305m
    2306-2310m
    Core photo at depth: 2311-2312m
    Core photo at depth: 2313-2317m
    Core photo at depth: 2318-2322m
    Core photo at depth: 2323-2323m
    Core photo at depth: 2296-2300m
    2311-2312m
    2313-2317m
    2318-2322m
    2323-2323m
    2296-2300m
    Core photo at depth: 2328-2332m
    Core photo at depth: 2333-2337m
    Core photo at depth: 2338-2342m
    Core photo at depth: 2343-2347m
    Core photo at depth: 2348-2350m
    2328-2332m
    2333-2337m
    2338-2342m
    2343-2347m
    2348-2350m
    Core photo at depth: 2351-2355m
    Core photo at depth: 2356-2360m
    Core photo at depth: 2361-2365m
    Core photo at depth: 2366-2370m
    Core photo at depth: 2371-2375m
    2351-2355m
    2356-2360m
    2361-2365m
    2366-2370m
    2371-2375m
    Core photo at depth: 2376-2377m
    Core photo at depth: 2378-1282m
    Core photo at depth: 2383-2387m
    Core photo at depth: 2388-2392m
    Core photo at depth: 2393-2397m
    2376-2377m
    2378-1282m
    2383-2387m
    2388-2392m
    2393-2397m
    Core photo at depth: 2398-2402m
    Core photo at depth: 2403-2407m
    Core photo at depth: 2408-2412m
    Core photo at depth: 2413-2417m
    Core photo at depth: 2418-2422m
    2398-2402m
    2403-2407m
    2408-2412m
    2413-2417m
    2418-2422m
    Core photo at depth: 2423-2424m
    Core photo at depth: 2323-2327m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2423-2424m
    2323-2327m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    500.0
    [m]
    DC
    GERH
    510.0
    [m]
    DC
    GERH
    520.0
    [m]
    DC
    GERH
    530.0
    [m]
    DC
    GERH
    540.0
    [m]
    DC
    GERH
    550.0
    [m]
    DC
    GERH
    560.0
    [m]
    DC
    GERH
    570.0
    [m]
    DC
    GERH
    580.0
    [m]
    DC
    GERH
    590.0
    [m]
    DC
    GERH
    600.0
    [m]
    DC
    GERH
    610.0
    [m]
    DC
    GERH
    620.0
    [m]
    DC
    GERH
    630.0
    [m]
    DC
    GERH
    640.0
    [m]
    DC
    GERH
    650.0
    [m]
    DC
    GERH
    660.0
    [m]
    DC
    GERH
    670.0
    [m]
    DC
    GERH
    680.0
    [m]
    DC
    GERH
    690.0
    [m]
    DC
    GERH
    700.0
    [m]
    DC
    GERH
    710.0
    [m]
    DC
    GERH
    720.0
    [m]
    DC
    GERH
    730.0
    [m]
    DC
    GERH
    740.0
    [m]
    DC
    GERH
    750.0
    [m]
    DC
    GERH
    760.0
    [m]
    DC
    GERH
    770.0
    [m]
    DC
    GERH
    780.0
    [m]
    DC
    GERH
    790.0
    [m]
    DC
    GERH
    800.0
    [m]
    DC
    GERH
    810.0
    [m]
    DC
    GERH
    820.0
    [m]
    DC
    GERH
    830.0
    [m]
    DC
    GERH
    840.0
    [m]
    DC
    GERH
    870.0
    [m]
    DC
    GERH
    880.0
    [m]
    DC
    GERH
    890.0
    [m]
    DC
    GERH
    901.0
    [m]
    SWC
    GERH
    910.0
    [m]
    DC
    GERH
    920.0
    [m]
    DC
    GERH
    930.0
    [m]
    DC
    GERH
    940.0
    [m]
    DC
    GERH
    950.0
    [m]
    DC
    GERH
    960.0
    [m]
    DC
    GERH
    970.0
    [m]
    DC
    GERH
    980.0
    [m]
    DC
    GERH
    990.0
    [m]
    DC
    GERH
    1000.0
    [m]
    SWC
    GERH
    1010.0
    [m]
    DC
    GERH
    1020.0
    [m]
    DC
    GERH
    1030.0
    [m]
    DC
    GERH
    1040.0
    [m]
    DC
    GERH
    1050.0
    [m]
    DC
    GERH
    1060.0
    [m]
    DC
    GERH
    1070.0
    [m]
    DC
    GERH
    1080.0
    [m]
    DC
    GERH
    1124.0
    [m]
    DC
    GERH
    1136.0
    [m]
    DC
    GERH
    1148.0
    [m]
    DC
    GERH
    1163.0
    [m]
    DC
    GERH
    1205.0
    [m]
    SWC
    GERH
    1209.0
    [m]
    SWC
    GERH
    1234.0
    [m]
    SWC
    GERH
    1256.0
    [m]
    DC
    GERH
    1270.0
    [m]
    SWC
    GERH
    1292.0
    [m]
    DC
    GERH
    1304.0
    [m]
    DC
    GERH
    1316.0
    [m]
    DC
    GERH
    1328.0
    [m]
    DC
    GERH
    1340.0
    [m]
    DC
    GERH
    1352.0
    [m]
    DC
    GERH
    1364.0
    [m]
    DC
    GERH
    1376.0
    [m]
    DC
    GERH
    1388.0
    [m]
    DC
    GERH
    1406.0
    [m]
    DC
    GERH
    1412.0
    [m]
    DC
    GERH
    1448.0
    [m]
    DC
    GERH
    1460.0
    [m]
    DC
    GERH
    1472.0
    [m]
    DC
    GERH
    1484.0
    [m]
    DC
    GERH
    1496.0
    [m]
    DC
    GERH
    1508.0
    [m]
    DC
    GERH
    1520.0
    [m]
    DC
    GERH
    1532.0
    [m]
    DC
    GERH
    1544.0
    [m]
    DC
    GERH
    1565.0
    [m]
    SWC
    GERH
    1580.0
    [m]
    DC
    GERH
    1592.0
    [m]
    DC
    GERH
    1604.0
    [m]
    DC
    GERH
    1616.0
    [m]
    DC
    GERH
    1628.0
    [m]
    DC
    GERH
    1643.0
    [m]
    DC
    GERH
    1663.0
    [m]
    SWC
    GERH
    1673.0
    [m]
    DC
    GERH
    1688.0
    [m]
    DC
    GERH
    1703.0
    [m]
    DC
    GERH
    1718.0
    [m]
    DC
    GERH
    1737.0
    [m]
    SWC
    GERH
    1748.0
    [m]
    DC
    GERH
    1763.0
    [m]
    DC
    GERH
    1778.0
    [m]
    DC
    GERH
    1801.0
    [m]
    SWC
    GERH
    1812.0
    [m]
    SWC
    GERH
    1823.0
    [m]
    DC
    GERH
    1860.0
    [m]
    SWC
    GERH
    1883.0
    [m]
    DC
    GERH
    1906.0
    [m]
    SWC
    GERH
    1928.0
    [m]
    DC
    GERH
    1950.0
    [m]
    SWC
    GERH
    1973.0
    [m]
    DC
    GERH
    1988.0
    [m]
    DC
    GERH
    2000.0
    [m]
    DC
    GERH
    2018.0
    [m]
    DC
    GERH
    2033.0
    [m]
    DC
    GERH
    2048.0
    [m]
    DC
    GERH
    2063.0
    [m]
    DC
    GERH
    2078.0
    [m]
    DC
    GERH
    2100.0
    [m]
    SWC
    GERH
    2123.0
    [m]
    DC
    GERH
    2138.0
    [m]
    DC
    GERH
    2150.0
    [m]
    SWC
    GERH
    2168.0
    [m]
    DC
    GERH
    2183.0
    [m]
    DC
    GERH
    2200.0
    [m]
    SWC
    GERH
    2210.0
    [m]
    SWC
    GERH
    2228.0
    [m]
    DC
    GERH
    2242.0
    [m]
    SWC
    GERH
    2253.0
    [m]
    SWC
    GERH
    2261.5
    [m]
    SWC
    GERH
    2267.0
    [m]
    SWC
    GERH
    2276.0
    [m]
    DC
    RRI
    2284.0
    [m]
    SWC
    GERH
    2286.1
    [m]
    C
    RRI
    2289.2
    [m]
    C
    RRI
    2292.0
    [m]
    C
    RRI
    2295.2
    [m]
    C
    RRI
    2297.9
    [m]
    C
    RRI
    2299.2
    [m]
    C
    RRI
    2301.4
    [m]
    C
    RRI
    2303.0
    [m]
    DC
    GERH
    2304.6
    [m]
    C
    RRI
    2306.8
    [m]
    C
    RRI
    2308.8
    [m]
    C
    RRI
    2311.4
    [m]
    C
    RRI
    2312.0
    [m]
    DC
    GERH
    2312.4
    [m]
    C
    RRI
    2313.6
    [m]
    C
    RRI
    2314.2
    [m]
    C
    RRI
    2314.7
    [m]
    C
    RRI
    2317.6
    [m]
    C
    RRI
    2318.0
    [m]
    DC
    GERH
    2320.6
    [m]
    C
    RRI
    2322.8
    [m]
    C
    RRI
    2323.6
    [m]
    C
    RRI
    2325.6
    [m]
    C
    RRI
    2328.6
    [m]
    C
    RRI
    2331.9
    [m]
    C
    RRI
    2333.0
    [m]
    DC
    GERH
    2334.9
    [m]
    C
    RRI
    2337.8
    [m]
    C
    RRI
    2342.0
    [m]
    DC
    GERH
    2354.0
    [m]
    DC
    GERH
    2363.0
    [m]
    DC
    GERH
    2381.0
    [m]
    DC
    GERH
    2389.5
    [m]
    C
    RRI
    2391.9
    [m]
    C
    RRI
    2393.0
    [m]
    C
    ICHRON
    2393.0
    [m]
    DC
    GERH
    2393.5
    [m]
    C
    RRI
    2396.0
    [m]
    C
    RRI
    2397.5
    [m]
    C
    RRI
    2399.7
    [m]
    C
    RRI
    2403.2
    [m]
    C
    ICHRON
    2403.6
    [m]
    C
    RRI
    2405.9
    [m]
    C
    RRI
    2408.0
    [m]
    DC
    GERH
    2418.8
    [m]
    C
    RRI
    2421.8
    [m]
    C
    RRI
    2426.0
    [m]
    SWC
    GERH
    2429.0
    [m]
    SWC
    GERH
    2435.0
    [m]
    DC
    RRI
    2435.0
    [m]
    DC
    RRI
    2441.0
    [m]
    DC
    RRI
    2441.0
    [m]
    DC
    RRI
    2444.0
    [m]
    DC
    GERH
    2447.0
    [m]
    DC
    RRI
    2447.0
    [m]
    DC
    RRI
    2453.0
    [m]
    DC
    RRI
    2453.0
    [m]
    DC
    RRI
    2456.0
    [m]
    DC
    GERH
    2459.0
    [m]
    DC
    RRI
    2459.0
    [m]
    DC
    RRI
    2465.0
    [m]
    DC
    RRI
    2465.0
    [m]
    DC
    RRI
    2468.0
    [m]
    DC
    GERH
    2477.0
    [m]
    DC
    RRI
    2477.0
    [m]
    DC
    RRI
    2480.0
    [m]
    DC
    GERH
    2483.0
    [m]
    DC
    RRI
    2495.0
    [m]
    DC
    RRI
    2495.0
    [m]
    DC
    RRI
    2501.0
    [m]
    DC
    RRI
    2501.0
    [m]
    DC
    RRI
    2506.0
    [m]
    SWC
    GERH
    2528.0
    [m]
    DC
    GERH
    2540.0
    [m]
    DC
    GERH
    2552.0
    [m]
    DC
    GERH
    2588.0
    [m]
    DC
    GERH
    2600.0
    [m]
    DC
    GERH
    2654.0
    [m]
    SWC
    GERH
    2660.0
    [m]
    SWC
    GERH
    2662.0
    [m]
    SWC
    GERH
    2666.0
    [m]
    SWC
    GERH
    2690.0
    [m]
    DC
    GERH
    2699.0
    [m]
    DC
    GERH

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.53

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    2.68

  • 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
    43.46

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    340
    1975
    CST
    901
    1960
    CST
    1698
    2100
    DLL
    2274
    2694
    DLWD
    885
    2607
    ISF SON MSFL GR SP CAL
    318
    2700
    LDT CNL GR
    381
    1976
    LDT CNL GR NGT
    1975
    2701
    RFT HP
    2286
    2670
    RFT HP
    2286
    2416
    RFT SG
    2286
    2670
    RFT SG
    2286
    2416
    SHDT
    850
    1969
    SHDT
    1975
    2701
    VSP
    540
    2685

  • 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
    381.0
    36
    386.0
    0.00
    LOT
    SURF.COND.
    20
    850.0
    26
    865.0
    1.55
    LOT
    INTERM.
    13 3/8
    1975.0
    17 1/2
    1988.0
    1.47
    LOT
    OPEN HOLE
    2700.0
    12 1/4
    2700.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    382
    1.06
    1000.0
    10.6
    WATER BASED
    18.04.1985
    865
    1.07
    600.0
    12.0
    WATER BASED
    21.04.1985
    865
    1.25
    1100.0
    11.0
    WATER BASED
    25.04.1985
    865
    1.07
    WATER BASED
    29.04.1985
    865
    1.05
    800.0
    7.2
    WATER BASED
    29.04.1985
    865
    1.24
    1100.0
    10.2
    WATER BASED
    26.04.1985
    865
    1.07
    WATER BASED
    29.04.1985
    865
    1.05
    800.0
    7.2
    WATER BASED
    29.04.1985
    865
    1.24
    1100.0
    10.2
    WATER BASED
    26.04.1985
    865
    1.25
    1100.0
    11.0
    WATER BASED
    25.04.1985
    885
    1.05
    800.0
    7.6
    WATER BASED
    29.04.1985
    1082
    1.08
    1300.0
    8.9
    WATER BASED
    30.04.1985
    1299
    1.10
    1200.0
    13.1
    WATER BASED
    02.05.1985
    1440
    1.11
    1100.0
    8.9
    WATER BASED
    02.05.1985
    1637
    1.17
    1200.0
    8.9
    WATER BASED
    03.05.1985
    1666
    1.22
    1200.0
    8.0
    WATER BASED
    06.05.1985
    1788
    1.22
    1300.0
    8.0
    WATER BASED
    06.05.1985
    1843
    1.22
    1300.0
    8.0
    WATER BASED
    06.05.1985
    1918
    1.22
    5.5
    1900.0
    WATER BASED
    08.05.1985
    2089
    1.15
    1100.0
    5.1
    WATER BASED
    14.05.1985
    2250
    1.15
    1100.0
    5.0
    WATER BASED
    20.05.1985
    2286
    1.24
    1100.0
    5.0
    WATER BASED
    20.05.1985
    2330
    1.24
    1500.0
    6.4
    WATER BASED
    20.05.1985
    2368
    1.24
    1500.0
    5.9
    WATER BASED
    20.05.1985
    2378
    1.24
    1500.0
    5.9
    WATER BASED
    21.05.1985
    2411
    1.24
    1600.0
    6.8
    WATER BASED
    22.05.1985
    2425
    1.24
    1500.0
    5.9
    WATER BASED
    23.05.1985
    2456
    1.24
    1500.0
    5.9
    WATER BASED
    24.05.1985
    2545
    1.24
    1600.0
    5.9
    WATER BASED
    28.05.1985
    2581
    1.24
    1600.0
    5.5
    WATER BASED
    28.05.1985
    2613
    1.24
    1700.0
    7.2
    WATER BASED
    28.05.1985
    2681
    1.24
    1800.0
    5.1
    WATER BASED
    28.05.1985
    2700
    1.24
    1800.0
    6.3
    WATER BASED
    29.05.1985
    2700
    1.24
    1700.0
    6.3
    WATER BASED
    30.05.1985
    2700
    1.24
    1700.0
    7.6
    WATER BASED
    31.05.1985
    2700
    1.24
    1700.0
    7.6
    WATER BASED
    31.05.1985
    2700
    1.24
    1700.0
    6.3
    WATER BASED
    30.05.1985

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    2379.35
    [m ]
    2401.65
    [m ]
    2405.65
    [m ]
    2423.65
    [m ]

  • 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
    0.27