Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
25.12.2024 - 01:26
Time of last synchronization with Norwegian Offshore Directorate's internal systems

7120/6-1

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.
    7120/6-1
    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).
    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.
    BARENTS 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.
    7120/6-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NPD 2056 - 82 SP. 855
    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.
    450-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.
    90
    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,
    02.02.1985
    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.
    02.05.1985
    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.
    02.05.1987
    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.
    11.02.2005
    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/GAS
    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.
    EARLY 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.
    STØ FM
    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.
    314.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2820.0
    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).
    2820.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    104
    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.
    TUBÅEN FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    71° 37' 11.76'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 55' 59.72'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7946756.85
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    497650.92
    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.
    456

  • Wellbore history
    General
    Wildcat well 7120/6 1 was drilled in the middle eastern part of the block, on a structure comprising an east-west horst block extending into blocks 7121/4 and 7121/5 to the east, and with a central east west oriented fault at Middle Jurassic level. The primary objective of the well was to test Middle Jurassic sand sequences in the Stø Formation. A further objective was to evaluate geologic trends in stratigraphy, structure and reservoir development in a northerly direction in the Hammerfest Basin. The well was prognosed to be drilled into rocks of Triassic age
    Operations and results
    The well was spudded with the semi submersible installation Treasure Scout 2 February 1985 and drilled to TD at 2820 m in Late Triassic rocks (Tubåen Formation). No significant problems occurred during drilling. It was drilled and tested in 90 days with only 4.4 days down time. Of these 3.2 days were wait-on-weather (WOW). The well was drilled with spud mud down to 815 m and with KCl/polymer mud from 815 m to TD.
    The well encountered hydrocarbon bearing Jurassic sands of the Stø Formation from 2385.5 m to 2469.5 m. The interval from 2385.5 to 2427 m was gas bearing and from 2427 to 2443 m oil bearing. In the interval 2559 - 2800 m (Tubåen Formation), thin gas bearing sandstone stringers were encountered. This interval spanned the Jurassic-Triassic boundary, and in the lower intervals below 2660 m net pay was associated with thin interbedded coals. Weak oil shows were observed in claystones in the Cretaceous below 2176 m. Good oil shows in sandstones were recorded throughout the hydrocarbon bearing zone and down to 2500 m. Below this level oil shows were in general associated either with mud stones or with coal seams and fragments.
    Geochemical studies indicated that the Tertiary and Cretaceous sediments were immature. Above 2300 m there were alternating poor source rocks for oil and gas and very good oil-prone source rocks. The top Jurassic interval from 2300 m to 2335 m there was rich oil potential source rocks, whilst below 2335 m there was rich potential for oil or for oil and gas. All indications are that there has been significant oil generation below 2320 m. Mature, good source rocks for gas with oil were present in the Tubåen Formation. Organic geochemical analyses also detected strong shows of a relatively waxy, medium gravity crude within the Stø and Nordmela Formation sandstones over the interval 2420 m to 2540 m. Geochemical fingerprinting indicated this oil to be compatible with the source facies present within the Tubåen Formation and the base of the Nordmela Formation.
    A total of 12 consecutive cores were taken from 2371 m, above the main objective to a depth of 2565 m in the Tubåen Formation. A total of 63 pre-tests in three RFT runs were taken, of which 23 were either too tight or experienced seal failure. Three segregated samples were taken at 2430 m (32 °API oil, gas, and filtrate), 2427.3 m (gas and filtrate), and 2399.5 m (gas, filtrate and a small amount of 50 °API condensate). A total of 107 sidewall cores were recovered from 904 m down to 2811.5 m. Sidewall cores taken in the interval 2040 - 2368 m were taken especially to be used in a Jurassic Shale Geochemical study.
    The well was permanently abandoned as an oil and gas appraisal on 2 May 1985.
    Testing
    Four Drill Stem Tests (DST's) were carried out in the Stø Formation, one water, one oil, and two gas tests.
    DST 1 perforated the interval: 2459 m to 2465 m and flowed 447 Sm3 water/day through an 80/64" choke.
    DST 2 perforated the interval 2432,05 m to 2436,05 m and flowed 1526 Sm3 oil and 178400 Sm3 gas per day through an 80/64" choke. Oil gravity was 31.9 °AP and gas gravity was 0.705 (air = 1). GOR was 117 Sm3/Sm3.
    DST 3 perforated the interval: 2418,35 m to 2424,35 m and gave no flow.
    DST 4 perforated the interval 2386,4 m to 2401,4 m and flowed 1262930 Sm3 gas and 162 Sm3 condensate per day through a 1" choke. Condensate gravity was 57 °API and gas gravity was 0.695 (air = 1). GOR was 7780 Sm3/Sm3.

  • 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]
    410.00
    2820.00

  • 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
    2371.0
    2373.5
    [m ]
    2
    2373.6
    2377.0
    [m ]
    3
    2381.0
    2398.0
    [m ]
    4
    2398.0
    2417.6
    [m ]
    5
    2418.5
    2440.0
    [m ]
    6
    2443.5
    2470.0
    [m ]
    7
    2470.5
    2476.0
    [m ]
    8
    2476.5
    2492.0
    [m ]
    9
    2492.5
    2503.0
    [m ]
    10
    2505.0
    2530.5
    [m ]
    11
    2530.5
    2549.0
    [m ]
    12
    2549.0
    2565.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    182.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2371-2373m
    Core photo at depth: 2373-2377m
    Core photo at depth: 2381-2386m
    Core photo at depth: 2386-2391m
    Core photo at depth: 2391-2396m
    2371-2373m
    2373-2377m
    2381-2386m
    2386-2391m
    2391-2396m
    Core photo at depth: 2396-2398m
    Core photo at depth: 2398-2403m
    Core photo at depth: 2403-2408m
    Core photo at depth: 2408-2413m
    Core photo at depth: 2413-2417m
    2396-2398m
    2398-2403m
    2403-2408m
    2408-2413m
    2413-2417m
    Core photo at depth: 2418-2423m
    Core photo at depth: 2423-2428m
    Core photo at depth: 2428-2433m
    Core photo at depth: 2433-2438m
    Core photo at depth: 2438-2440m
    2418-2423m
    2423-2428m
    2428-2433m
    2433-2438m
    2438-2440m
    Core photo at depth: 2443-2448m
    Core photo at depth: 2448-2453m
    Core photo at depth: 2453-2458m
    Core photo at depth: 2458-2463m
    Core photo at depth: 2463-2468m
    2443-2448m
    2448-2453m
    2453-2458m
    2458-2463m
    2463-2468m
    Core photo at depth: 2468-2470m
    Core photo at depth: 2470-2475m
    Core photo at depth: 2475-2476m
    Core photo at depth: 2476-2481m
    Core photo at depth: 2481-2486m
    2468-2470m
    2470-2475m
    2475-2476m
    2476-2481m
    2481-2486m
    Core photo at depth: 2486-2491m
    Core photo at depth: 2491-2492m
    Core photo at depth: 2492-2497m
    Core photo at depth: 2497-2502m
    Core photo at depth: 2502-2503m
    2486-2491m
    2491-2492m
    2492-2497m
    2497-2502m
    2502-2503m
    Core photo at depth: 2505-2510m
    Core photo at depth: 2510-2515m
    Core photo at depth: 2515-2520m
    Core photo at depth: 2520-2525m
    Core photo at depth: 2525-2530m
    2505-2510m
    2510-2515m
    2515-2520m
    2520-2525m
    2525-2530m
    Core photo at depth: 2530-2531m
    Core photo at depth: 2530-2535m
    Core photo at depth: 2535-2540m
    Core photo at depth: 2540-2545m
    Core photo at depth: 2545-2549m
    2530-2531m
    2530-2535m
    2535-2540m
    2540-2545m
    2545-2549m
    Core photo at depth: 2549-2554m
    Core photo at depth: 2554-2559m
    Core photo at depth: 2559-2564m
    Core photo at depth: 2564-2565m
    Core photo at depth:  
    2549-2554m
    2554-2559m
    2559-2564m
    2564-2565m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    904.0
    [m]
    SWC
    STRAT
    1010.0
    [m]
    DC
    STRAT
    1055.0
    [m]
    DC
    STRAT
    1073.0
    [m]
    SWC
    STRAT
    1078.0
    [m]
    SWC
    STRAT
    1107.5
    [m]
    SWC
    STRAT
    1118.0
    [m]
    SWC
    STRAT
    1123.0
    [m]
    SWC
    STRAT
    1145.0
    [m]
    DC
    STRAT
    1160.0
    [m]
    DC
    STRAT
    1171.1
    [m]
    SWC
    STRAT
    1190.0
    [m]
    DC
    STRAT
    1205.0
    [m]
    DC
    STRAT
    1220.0
    [m]
    DC
    STRAT
    1235.0
    [m]
    DC
    STRAT
    1256.0
    [m]
    SWC
    STRAT
    1265.0
    [m]
    DC
    STRAT
    1280.0
    [m]
    DC
    STRAT
    1295.0
    [m]
    DC
    STRAT
    1310.0
    [m]
    DC
    STRAT
    1325.0
    [m]
    DC
    STRAT
    1343.0
    [m]
    SWC
    STRAT
    1355.0
    [m]
    DC
    STRAT
    1370.0
    [m]
    DC
    STRAT
    1380.1
    [m]
    SWC
    STRAT
    1385.0
    [m]
    DC
    STRAT
    1400.0
    [m]
    DC
    STRAT
    1415.0
    [m]
    DC
    STRAT
    1430.0
    [m]
    DC
    STRAT
    1445.0
    [m]
    DC
    STRAT
    1460.0
    [m]
    DC
    STRAT
    1490.0
    [m]
    DC
    STRAT
    1505.0
    [m]
    DC
    STRAT
    1520.0
    [m]
    DC
    STRAT
    1535.0
    [m]
    DC
    STRAT
    1555.1
    [m]
    SWC
    STRAT
    1565.0
    [m]
    DC
    STRAT
    1580.0
    [m]
    DC
    STRAT
    1604.8
    [m]
    SWC
    STRAT
    1610.0
    [m]
    DC
    STRAT
    1625.0
    [m]
    DC
    STRAT
    1640.0
    [m]
    DC
    STRAT
    1655.0
    [m]
    DC
    STRAT
    1670.0
    [m]
    DC
    STRAT
    1685.0
    [m]
    DC
    STRAT
    1700.0
    [m]
    DC
    STRAT
    1718.8
    [m]
    SWC
    STRAT
    1730.0
    [m]
    DC
    STRAT
    1745.0
    [m]
    DC
    STRAT
    1775.0
    [m]
    DC
    STRAT
    1791.0
    [m]
    SWC
    STRAT
    1805.0
    [m]
    DC
    STRAT
    1820.0
    [m]
    DC
    STRAT
    1837.0
    [m]
    SWC
    STRAT
    1840.1
    [m]
    SWC
    STRAT
    1844.8
    [m]
    SWC
    STRAT
    1848.9
    [m]
    SWC
    STRAT
    1854.9
    [m]
    SWC
    STRAT
    1868.9
    [m]
    SWC
    STRAT
    1891.7
    [m]
    SWC
    STRAT
    1910.0
    [m]
    DC
    STRAT
    1920.0
    [m]
    SWC
    STRAT
    1940.1
    [m]
    SWC
    STRAT
    1955.0
    [m]
    DC
    STRAT
    1980.1
    [m]
    SWC
    STRAT
    2005.9
    [m]
    SWC
    STRAT
    2015.0
    [m]
    DC
    STRAT
    2040.0
    [m]
    SWC
    STRAT
    2063.0
    [m]
    SWC
    STRAT
    2080.0
    [m]
    SWC
    STRAT
    2090.0
    [m]
    DC
    STRAT
    2105.0
    [m]
    DC
    STRAT
    2120.0
    [m]
    DC
    STRAT
    2135.0
    [m]
    DC
    STRAT
    2136.0
    [m]
    SWC
    STRAT
    2150.0
    [m]
    DC
    STRAT
    2160.0
    [m]
    SWC
    STRAT
    2165.0
    [m]
    DC
    STRAT
    2173.0
    [m]
    SWC
    STRAT
    2177.5
    [m]
    SWC
    STRAT
    2180.0
    [m]
    DC
    STRAT
    2196.5
    [m]
    SWC
    STRAT
    2203.0
    [m]
    SWC
    STRAT
    2220.0
    [m]
    DC
    STRAT
    2225.0
    [m]
    DC
    STRAT
    2230.0
    [m]
    DC
    STRAT
    2240.0
    [m]
    DC
    STRAT
    2250.0
    [m]
    DC
    STRAT
    2255.0
    [m]
    DC
    STRAT
    2260.0
    [m]
    DC
    STRAT
    2268.0
    [m]
    SWC
    STRAT
    2280.0
    [m]
    DC
    STRAT
    2285.0
    [m]
    DC
    STRAT
    2290.0
    [m]
    DC
    STRAT
    2300.0
    [m]
    DC
    STRAT
    2310.0
    [m]
    DC
    STRAT
    2315.0
    [m]
    DC
    STRAT
    2320.0
    [m]
    DC
    STRAT
    2330.0
    [m]
    DC
    STRAT
    2340.0
    [m]
    DC
    STRAT
    2345.0
    [m]
    DC
    STRAT
    2350.0
    [m]
    DC
    STRAT
    2355.0
    [m]
    SWC
    STRAT
    2360.0
    [m]
    DC
    STRAT
    2370.0
    [m]
    DC
    STRAT
    2371.4
    [m]
    C
    STRAT
    2371.9
    [m]
    C
    STRAT
    2372.5
    [m]
    C
    STRAT
    2373.0
    [m]
    C
    STRAT
    2373.5
    [m]
    C
    STRAT
    2373.7
    [m]
    C
    STRAT
    2374.3
    [m]
    C
    STRAT
    2375.3
    [m]
    C
    STRAT
    2375.7
    [m]
    C
    STRAT
    2376.3
    [m]
    C
    STRAT
    2380.0
    [m]
    DC
    STRAT
    2381.3
    [m]
    C
    STRAT
    2384.0
    [m]
    C
    ICHRON
    2388.2
    [m]
    C
    ICHRON
    2391.4
    [m]
    C
    STRAT
    2400.6
    [m]
    C
    STRAT
    2406.7
    [m]
    C
    ICHRON
    2410.9
    [m]
    C
    STRAT
    2418.9
    [m]
    C
    ICHRON
    2420.5
    [m]
    C
    STRAT
    2423.4
    [m]
    C
    ICHRON
    2449.9
    [m]
    C
    STRAT
    2470.5
    [m]
    C
    STRAT
    2475.1
    [m]
    C
    ICHRON
    2480.8
    [m]
    C
    STRAT
    2482.4
    [m]
    C
    ICHRON
    2490.9
    [m]
    C
    STRAT
    2494.5
    [m]
    C
    ICHRON
    2502.0
    [m]
    C
    STRAT
    2511.0
    [m]
    C
    STRAT
    2512.0
    [m]
    C
    ICHRON
    2520.6
    [m]
    C
    STRAT
    2530.5
    [m]
    C
    STRAT
    2530.5
    [m]
    C
    ICHRON
    2540.6
    [m]
    C
    STRAT
    2550.2
    [m]
    C
    STRAT
    2560.8
    [m]
    C
    ICHRON
    2570.0
    [m]
    C
    STRAT
    2580.0
    [m]
    DC
    STRAT
    2600.0
    [m]
    SWC
    STRAT
    2605.0
    [m]
    SWC
    STRAT
    2614.0
    [m]
    SWC
    STRAT
    2630.0
    [m]
    DC
    STRAT
    2637.5
    [m]
    SWC
    STRAT
    2640.0
    [m]
    DC
    STRAT
    2660.0
    [m]
    DC
    STRAT
    2670.0
    [m]
    DC
    STRAT
    2678.0
    [m]
    SWC
    STRAT
    2690.0
    [m]
    DC
    STRAT
    2700.0
    [m]
    DC
    STRAT
    2713.0
    [m]
    SWC
    STRAT
    2714.5
    [m]
    SWC
    STRAT
    2717.0
    [m]
    SWC
    STRAT
    2723.5
    [m]
    SWC
    STRAT
    2733.0
    [m]
    SWC
    STRAT
    2737.5
    [m]
    SWC
    STRAT
    2753.0
    [m]
    SWC
    STRAT
    2759.5
    [m]
    SWC
    STRAT
    2765.0
    [m]
    SWC
    STRAT
    2779.5
    [m]
    SWC
    STRAT
    2799.0
    [m]
    SWC
    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
    DST2
    2432.05
    2436.05
    OIL
    13.04.1985 - 00:00
    YES
    DST
    DST4
    2386.00
    2401.00
    CONDENSATE
    25.04.1985 - 00:00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.47

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    3.61
    pdf
    5.05

  • 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
    15.85

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2459
    2465
    20.6
    2.0
    2432
    2436
    31.7
    3.0
    2418
    2424
    0.0
    4.0
    2386
    2401
    25.4
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    4.000
    26.000
    2.0
    6.700
    3.0
    4.0
    14.000
    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
    1526
    178542
    0.866
    0.705
    117
    3.0
    4.0
    162
    1260360
    0.752
    0.695
    7783

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CST
    904
    2006
    CST
    2040
    2355
    CST
    2340
    2811
    DLL MSFL
    2272
    2578
    DLL MSFL
    2674
    2807
    HDT GR
    805
    2032
    ISF LSS GR SP
    399
    2581
    ISF LSS GR SP
    2580
    2810
    LDT CNL GR
    805
    2811
    NGT
    2081
    2727
    NGT
    2282
    2582
    NGT
    2674
    2811
    RFT
    2386
    2562
    RFT
    2455
    2797
    SHDT GR
    2029
    2727
    SHDT GR
    2674
    2811
    VELOCITY
    400
    2800

  • 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
    399.0
    36
    404.0
    0.00
    LOT
    SURF.COND.
    20
    804.0
    26
    815.0
    1.74
    LOT
    INTERM.
    13 3/8
    2031.0
    17 1/2
    2046.0
    1.73
    LOT
    INTERM.
    9 5/8
    2820.0
    12 1/4
    2820.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    387
    1.25
    WATER BASED
    04.02.1985
    404
    1.25
    WATER BASED
    04.02.1985
    404
    1.05
    WATER BASED
    06.02.1985
    404
    1.05
    WATER BASED
    06.02.1985
    670
    1.08
    10.0
    20.0
    WATER BASED
    07.02.1985
    815
    1.09
    10.0
    22.0
    WATER BASED
    10.02.1985
    815
    1.11
    11.0
    22.0
    WATER BASED
    10.02.1985
    815
    1.09
    WATER BASED
    12.02.1985
    815
    1.10
    14.0
    9.0
    WATER BASED
    13.02.1985
    815
    1.10
    13.0
    9.0
    WATER BASED
    14.02.1985
    815
    1.11
    14.0
    10.0
    WATER BASED
    18.02.1985
    815
    1.11
    11.0
    22.0
    WATER BASED
    10.02.1985
    815
    1.09
    10.0
    22.0
    WATER BASED
    10.02.1985
    815
    1.09
    WATER BASED
    12.02.1985
    815
    1.10
    14.0
    9.0
    WATER BASED
    13.02.1985
    815
    1.10
    13.0
    9.0
    WATER BASED
    14.02.1985
    815
    1.11
    14.0
    10.0
    WATER BASED
    18.02.1985
    815
    1.09
    10.0
    22.0
    WATER BASED
    10.02.1985
    824
    1.10
    9.0
    10.0
    WATER BASED
    18.02.1985
    1174
    1.13
    15.0
    12.0
    WATER BASED
    18.02.1985
    1355
    1.16
    15.0
    12.0
    WATER BASED
    18.02.1985
    1564
    1.18
    15.0
    12.0
    WATER BASED
    19.02.1985
    1653
    1.20
    20.0
    16.0
    WATER BASED
    21.02.1985
    1805
    1.20
    18.0
    15.0
    WATER BASED
    25.02.1985
    1892
    1.22
    19.0
    16.0
    WATER BASED
    25.02.1985
    1993
    1.22
    20.0
    14.0
    WATER BASED
    25.02.1985
    2046
    1.22
    19.0
    14.0
    WATER BASED
    26.02.1985
    2046
    1.22
    19.0
    14.0
    WATER BASED
    27.02.1985
    2046
    1.22
    20.0
    9.0
    WATER BASED
    01.03.1985
    2046
    1.22
    19.0
    14.0
    WATER BASED
    27.02.1985
    2046
    1.22
    20.0
    9.0
    WATER BASED
    01.03.1985
    2147
    1.22
    20.0
    12.0
    WATER BASED
    03.03.1985
    2249
    1.22
    21.0
    13.0
    WATER BASED
    03.03.1985
    2371
    1.22
    18.0
    12.0
    WATER BASED
    03.03.1985
    2373
    1.22
    18.0
    12.0
    WATER BASED
    04.03.1985
    2383
    1.22
    15.0
    10.0
    WATER BASED
    05.03.1985
    2398
    1.22
    16.0
    8.0
    WATER BASED
    08.03.1985
    2418
    1.22
    16.0
    10.0
    WATER BASED
    08.03.1985
    2440
    1.22
    18.0
    14.0
    WATER BASED
    10.03.1985
    2443
    1.23
    19.0
    12.0
    WATER BASED
    10.03.1985
    2476
    1.23
    18.0
    12.0
    WATER BASED
    10.03.1985
    2503
    1.22
    17.0
    12.0
    WATER BASED
    11.03.1985
    2530
    1.22
    19.0
    12.0
    WATER BASED
    12.03.1985
    2549
    1.22
    19.0
    12.0
    WATER BASED
    13.03.1985
    2565
    1.22
    17.0
    13.0
    WATER BASED
    14.03.1985
    2584
    1.22
    19.0
    12.0
    WATER BASED
    18.03.1985
    2584
    1.22
    15.0
    11.0
    WATER BASED
    18.03.1985
    2584
    1.22
    15.0
    11.0
    WATER BASED
    18.03.1985
    2604
    1.22
    18.0
    11.0
    WATER BASED
    18.03.1985
    2640
    1.22
    16.0
    10.0
    WATER BASED
    19.03.1985
    2694
    1.22
    17.0
    10.0
    WATER BASED
    19.03.1985
    2732
    1.22
    15.0
    10.0
    WATER BASED
    20.03.1985
    2742
    1.22
    16.0
    11.0
    WATER BASED
    21.03.1985
    2759
    1.22
    16.0
    10.0
    WATER BASED
    29.03.1985
    2759
    1.22
    14.0
    9.0
    WATER BASED
    29.03.1985
    2759
    1.22
    12.0
    7.0
    WATER BASED
    03.04.1985
    2759
    1.22
    15.0
    7.0
    WATER BASED
    03.04.1985
    2759
    1.22
    20.0
    5.0
    WATER BASED
    03.04.1985
    2759
    1.22
    18.0
    7.0
    WATER BASED
    03.04.1985
    2759
    1.22
    13.0
    7.0
    WATER BASED
    09.04.1985
    2759
    1.20
    12.0
    6.0
    WATER BASED
    09.04.1985
    2759
    1.22
    15.0
    9.0
    WATER BASED
    09.04.1985
    2759
    1.22
    19.0
    11.0
    WATER BASED
    15.04.1985
    2759
    1.22
    18.0
    11.0
    WATER BASED
    15.04.1985
    2759
    1.22
    17.0
    10.0
    WATER BASED
    17.04.1985
    2759
    1.22
    17.0
    13.0
    WATER BASED
    18.04.1985
    2759
    1.22
    16.0
    12.0
    WATER BASED
    19.04.1985
    2759
    1.22
    16.0
    10.0
    WATER BASED
    29.03.1985
    2759
    1.22
    14.0
    9.0
    WATER BASED
    29.03.1985
    2759
    1.22
    12.0
    7.0
    WATER BASED
    03.04.1985
    2759
    1.22
    15.0
    7.0
    WATER BASED
    03.04.1985
    2759
    1.22
    20.0
    5.0
    WATER BASED
    03.04.1985
    2759
    1.22
    18.0
    7.0
    WATER BASED
    03.04.1985
    2759
    1.20
    12.0
    6.0
    WATER BASED
    09.04.1985
    2759
    1.22
    15.0
    9.0
    WATER BASED
    09.04.1985
    2759
    1.22
    19.0
    11.0
    WATER BASED
    15.04.1985
    2759
    1.22
    18.0
    11.0
    WATER BASED
    15.04.1985
    2759
    1.22
    17.0
    10.0
    WATER BASED
    17.04.1985
    2759
    1.22
    16.0
    12.0
    WATER BASED
    19.04.1985
    2759
    1.22
    WATER BASED
    27.03.1985
    2759
    1.22
    13.0
    7.0
    WATER BASED
    09.04.1985
    2759
    1.22
    19.0
    12.0
    WATER BASED
    16.04.1985
    2759
    1.22
    17.0
    13.0
    WATER BASED
    18.04.1985
    2759
    1.22
    19.0
    12.0
    WATER BASED
    16.04.1985
    2812
    1.22
    19.0
    16.0
    WATER BASED
    24.03.1985
    2820
    1.22
    16.0
    10.0
    WATER BASED
    25.03.1985
    2820
    1.22
    15.0
    7.0
    WATER BASED
    23.04.1985
    2820
    1.22
    14.0
    8.0
    WATER BASED
    23.04.1985
    2820
    1.22
    16.0
    19.0
    WATER BASED
    23.04.1985
    2820
    1.22
    15.0
    10.0
    WATER BASED
    23.04.1985
    2820
    1.22
    18.0
    12.0
    WATER BASED
    26.04.1985
    2820
    1.22
    17.0
    12.0
    WATER BASED
    26.04.1985
    2820
    1.22
    17.0
    12.0
    WATER BASED
    29.04.1985
    2820
    1.22
    17.0
    10.0
    WATER BASED
    29.04.1985
    2820
    1.22
    15.0
    7.0
    WATER BASED
    23.04.1985
    2820
    1.22
    14.0
    8.0
    WATER BASED
    23.04.1985
    2820
    1.22
    16.0
    19.0
    WATER BASED
    23.04.1985
    2820
    1.22
    15.0
    10.0
    WATER BASED
    23.04.1985
    2820
    1.22
    14.0
    10.0
    WATER BASED
    25.04.1985
    2820
    1.22
    18.0
    12.0
    WATER BASED
    26.04.1985
    2820
    1.22
    17.0
    10.0
    WATER BASED
    29.04.1985
    2820
    1.22
    WATER BASED
    30.04.1985
    2820
    1.22
    17.0
    12.0
    WATER BASED
    26.04.1985
    2820
    1.22
    17.0
    12.0
    WATER BASED
    29.04.1985
    2820
    1.22
    14.0
    10.0
    WATER BASED
    25.04.1985
    2820
    1.22
    WATER BASED
    30.04.1985

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    2389.65
    [m ]
    2398.65
    [m ]
    2401.70
    [m ]
    2406.75
    [m ]
    2420.00
    [m ]
    2428.75
    [m ]
    2444.35
    [m ]
    2451.00
    [m ]
    2471.35
    [m ]
    2485.63
    [m ]
    2492.66
    [m ]
    2495.30
    [m ]
    2546.40
    [m ]
    2562.66
    [m ]
    2388.65
    [m ]
    2395.35
    [m ]
    2398.40
    [m ]
    2401.65
    [m ]
    2403.35
    [m ]
    2429.65
    [m ]
    2431.65
    [m ]
    2444.35
    [m ]
    2447.65
    [m ]
    2450.65
    [m ]
    2453.65
    [m ]
    2457.00
    [m ]
    2460.35
    [m ]
    2462.65
    [m ]
    2465.35
    [m ]
    2470.35
    [m ]
    2472.65
    [m ]
    2474.35
    [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
    0.28