Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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29.04.2024 - 01:33
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34/7-16

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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.
    34/7-16
    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.
    SUSPENDED
    Factmaps in new window
    Main area
    Name of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.
    NORTH SEA
    Field
    Name of the field the wellbore is related to.
    Discovery
    Name of the discovery the wellbore is related to.
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    34/7-16
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    G/E 83 (RP) RAD 253 & KOL. 933
    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.
    Saga Petroleum ASA
    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.
    640-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.
    47
    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,
    28.06.1990
    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.
    13.08.1990
    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.
    13.08.1992
    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.
    28.02.2008
    Purpose - planned
    Pre-drill purpose of the wellbore. Legal values for exploration wellbores: WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS. Example of legal values for development wellbores: OBSERVATION, PRODUCTION, INJECTION.
    WILDCAT
    Reentry
    Status whether the wellbore has been re-entered (YES) or not (NO). Re-entered wellbores are not included in the count when wellbores are presented in statistical overviews.
    NO
    Content
    For exploration wellbores, status of discovery.

    Legal values:
    DRY, SHOWS (trace amounts of hydrocarbons), GAS, GAS/CONDENSATE, OIL or OIL/GAS.
    SHOWS (GAS SHOWS, OIL SHOWS or OIL/GAS SHOWS) are detected as fluorescent cut (organic extract), petroleum odour, or visual stain on cuttings or cores, or as increased gas reading on the mud-loggers gas detection equipment.
    Legal values for WILDCAT-CCS and APPRAISAL-CCS: WATER

    For development wellbores, type of produced/injected fluid.
    Legal values:
    WATER, CUTTINGS, NOT AVAILABLE, OIL, GAS/CONDENSATE, OIL/GAS, CO2, GAS, WATER/GAS, NOT APPLICABLE.
    OIL
    Discovery wellbore
    Indicator which tells if the wellbore made a new discovery. Legal values: YES, NO. Prior to press-release or other information regarding drilling results, the indicator will be “NO” as a default.
    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.
    ETIVE 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.
    MIDDLE 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.
    RANNOCH FM
    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.
    286.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2700.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    98
    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.
    AMUNDSEN FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 23' 13.06'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 6' 59.12'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6806371.84
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    452792.04
    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.
    1550

  • Wellbore history
    General
    Well 34/7-16 is located between the Statfjord and Snorre Fields on Tampen Spur in the Northern North Sea. The primary purpose of the well was to test the Brent Group reservoir on the C-Plus prospect. A secondary objective was to test the reservoir of the Statfjord Formation. The well was drilled on a high position of the structure and was estimated to reach the reservoir at 2349 m MSL. Shallow gas could occur at 448, 500, and 557 m.
    Operations and results
    Wildcat well 34/7-16 was spudded with the semi-submersible installation Scarabeo 5 on 13 August 1990 and drilled to TD at 2700 m in the Early Jurassic Amundsen formation. At this depth the well was temporary abandoned due to time schedule for the rig. No significant problems were encountered in the operations. The resistivity log indicated small amounts of gas in a sand layer at 447 m. Otherwise no indication of shallow gas was observed. The well was drilled with spud mud down to 922 m and with KCl mud from 922 m to TD.
    Apart from the sandy Utsira Formation of Miocene/Pliocene age encountered between 976 - 1081 m the well penetrated mainly clay stone down to the Top Jurassic. Late Cretaceous (Coniacian age) sediments were found to rest unconformable on the Middle Jurassic Brent Group reservoir at 2390 m. The reservoir was hydrocarbon bearing. From the log, pressure gradient analyses, and FMT sampling the OWC was found at 2487 m, in the Rannoch Formation. Shows were recorded from 2 m above and to 2 m below the oil-bearing reservoir. Weak shows were also observed in the upper part of the Cook Formation.
    Eight cores were cut in the well. One core was cut in the Shetland Group, from 1935 to 1953 m, for borehole stability studies. Seven cores were cut in the Brent Group and into the Dunlin Group (8.0 m), in the interval 2389 - 2522 m (driller's depth). The Brent core recovery was 130.8 m, i.e. 98%.
    Four FMT segregated samples were taken in the Brent Group reservoir and the 1 gallon chambers sent to laboratory. Chamber STO 23 (2392 m) contained oil, while chamber STO 15 (2467.1 m) and chamber STO 24 (2486 m) contained small amounts of oil emulsified with water. Chamber STO 02 (2488 m) was filled with water contaminated with mud filtrate.
    The well was suspended on 13 August 1990 for later re-entry and fulfilling of well objectives and testing. It is classified as an oil appraisal on the Vigdis Field.
    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]
    930.00
    2980.00

  • 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
    2
    2389.1
    2408.0
    [m ]
    3
    2408.2
    2432.0
    [m ]
    4
    2436.0
    2459.4
    [m ]
    5
    2460.0
    2487.5
    [m ]
    6
    2487.5
    2504.3
    [m ]
    7
    2504.5
    2512.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    118.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2389-2394m
    Core photo at depth: 2394-2399m
    Core photo at depth: 2399-2404m
    Core photo at depth: 2404-2408m
    Core photo at depth: 2408-2413m
    2389-2394m
    2394-2399m
    2399-2404m
    2404-2408m
    2408-2413m
    Core photo at depth: 2413-2418m
    Core photo at depth: 2418-2423m
    Core photo at depth: 2423-2428m
    Core photo at depth: 2428-2433m
    Core photo at depth: 2433-2436m
    2413-2418m
    2418-2423m
    2423-2428m
    2428-2433m
    2433-2436m
    Core photo at depth: 2436-2441m
    Core photo at depth: 2441-2446m
    Core photo at depth: 2446-2451m
    Core photo at depth: 2451-2456m
    Core photo at depth: 2456-2459m
    2436-2441m
    2441-2446m
    2446-2451m
    2451-2456m
    2456-2459m
    Core photo at depth: 2460-2465m
    Core photo at depth: 2465-2470m
    Core photo at depth: 2470-2475m
    Core photo at depth: 2475-2480m
    Core photo at depth: 2480-2485m
    2460-2465m
    2465-2470m
    2470-2475m
    2475-2480m
    2480-2485m
    Core photo at depth: 2485-2487m
    Core photo at depth: 2487-2492m
    Core photo at depth: 2492-2497m
    Core photo at depth: 2497-2502m
    Core photo at depth: 2502-2504m
    2485-2487m
    2487-2492m
    2492-2497m
    2497-2502m
    2502-2504m
    Core photo at depth: 2504-2509m
    Core photo at depth: 2509-2512m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2504-2509m
    2509-2512m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    930.0
    [m]
    DC
    RRI
    970.0
    [m]
    DC
    RRI
    1010.0
    [m]
    DC
    RRI
    1018.0
    [m]
    DC
    RRI
    1030.0
    [m]
    DC
    RRI
    1080.0
    [m]
    DC
    RRI
    1090.0
    [m]
    DC
    RRI
    1100.0
    [m]
    DC
    RRI
    1110.0
    [m]
    DC
    RRI
    1120.0
    [m]
    DC
    RRI
    1130.0
    [m]
    DC
    RRI
    1140.0
    [m]
    DC
    RRI
    1180.0
    [m]
    DC
    RRI
    1190.0
    [m]
    DC
    RRI
    1200.0
    [m]
    DC
    RRI
    1210.0
    [m]
    DC
    RRI
    1220.0
    [m]
    DC
    RRI
    1230.0
    [m]
    DC
    RRI
    1240.0
    [m]
    DC
    RRI
    1250.0
    [m]
    DC
    RRI
    1260.0
    [m]
    DC
    RRI
    1270.0
    [m]
    DC
    RRI
    1280.0
    [m]
    DC
    RRI
    1290.0
    [m]
    DC
    RRI
    1300.0
    [m]
    DC
    RRI
    1310.0
    [m]
    DC
    RRI
    1320.0
    [m]
    DC
    RRI
    1330.0
    [m]
    DC
    RRI
    1340.0
    [m]
    DC
    RRI
    1350.0
    [m]
    DC
    RRI
    1360.0
    [m]
    DC
    RRI
    1380.0
    [m]
    DC
    RRI
    1390.0
    [m]
    DC
    RRI
    1400.0
    [m]
    DC
    RRI
    1410.0
    [m]
    DC
    RRI
    1420.0
    [m]
    DC
    RRI
    1430.0
    [m]
    DC
    RRI
    1440.0
    [m]
    DC
    RRI
    1450.0
    [m]
    DC
    RRI
    1960.0
    [m]
    DC
    RRI
    1970.0
    [m]
    DC
    RRI
    1980.0
    [m]
    DC
    RRI
    2000.0
    [m]
    DC
    RRI
    2040.0
    [m]
    DC
    RRI
    2060.0
    [m]
    DC
    RRI
    2080.0
    [m]
    DC
    RRI
    2100.0
    [m]
    DC
    RRI
    2140.0
    [m]
    DC
    RRI
    2150.0
    [m]
    DC
    RRI
    2160.0
    [m]
    DC
    RRI
    2170.0
    [m]
    DC
    RRI
    2180.0
    [m]
    DC
    RRI
    2190.0
    [m]
    DC
    RRI
    2210.0
    [m]
    DC
    RRI
    2220.0
    [m]
    DC
    RRI
    2240.0
    [m]
    DC
    RRI
    2250.0
    [m]
    DC
    RRI
    2260.0
    [m]
    DC
    RRI
    2270.0
    [m]
    DC
    RRI
    2280.0
    [m]
    DC
    RRI
    2290.0
    [m]
    DC
    RRI
    2300.0
    [m]
    DC
    RRI
    2310.0
    [m]
    DC
    RRI
    2320.0
    [m]
    DC
    RRI
    2330.0
    [m]
    DC
    RRI
    2340.0
    [m]
    DC
    RRI
    2350.0
    [m]
    DC
    RRI
    2360.0
    [m]
    DC
    RRI
    2370.0
    [m]
    DC
    RRI
    2532.0
    [m]
    DC
    RRI
    2547.0
    [m]
    DC
    RRI
    2592.0
    [m]
    DC
    RRI
    2597.0
    [m]
    DC
    RRI
    2631.0
    [m]
    DC
    RRI
    2632.0
    [m]
    DC
    RRI
    2637.0
    [m]
    DC
    RRI
    2652.0
    [m]
    DC
    RRI
    2667.0
    [m]
    DC
    RRI
    2682.0
    [m]
    DC
    RRI
    2700.0
    [m]
    DC
    RRI
    2709.0
    [m]
    DC
    RRI
    2715.0
    [m]
    DC
    RRI
    2730.0
    [m]
    DC
    RRI
    2745.0
    [m]
    DC
    RRI
    2760.0
    [m]
    DC
    RRI
    2811.0
    [m]
    DC
    RRI
    2839.0
    [m]
    DC
    RRI
    2850.0
    [m]
    DC
    RRI
    2895.0
    [m]
    DC
    RRI
    2931.0
    [m]
    DC
    RRI

  • 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
    DST3
    2401.00
    2414.00
    OIL
    06.10.1990 - 21:30
    YES

  • Lithostratigraphy

  • 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
    13.67

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    482
    1914
    CDL CNL GR
    1914
    2697
    DIFL ACL CDL GR
    907
    1918
    DIFL ACL GR
    1914
    2700
    DIPLOG
    910
    1918
    DIPLOG
    1914
    2538
    DLL MLL GR
    2373
    2698
    FMT
    2392
    2621
    MWD - GR RES DIR TEMP
    311
    2701

  • 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
    383.0
    36
    389.0
    0.00
    LOT
    INTERM.
    20
    907.0
    26
    922.0
    1.43
    LOT
    INTERM.
    13 3/8
    1913.0
    17 1/2
    1928.0
    1.73
    LOT
    INTERM.
    9 5/8
    2685.0
    12 1/4
    2700.0
    1.83
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    380
    1.03
    WATER BASED
    04.07.1990
    778
    1.03
    WATER BASED
    04.07.1990
    915
    1.03
    WATER BASED
    04.07.1990
    915
    1.03
    WATER BASED
    04.07.1990
    915
    1.03
    WATER BASED
    04.07.1990
    915
    1.03
    WATER BASED
    05.07.1990
    922
    1.03
    WATER BASED
    09.07.1990
    922
    1.03
    WATER BASED
    10.07.1990
    922
    1.03
    WATER BASED
    10.07.1990
    922
    1.03
    WATER BASED
    10.07.1990
    1056
    1.09
    13.0
    5.0
    WATER BASED
    12.07.1990
    1464
    1.12
    16.0
    9.0
    WATER BASED
    12.07.1990
    1649
    1.30
    21.0
    14.0
    WATER BASED
    13.07.1990
    1815
    1.48
    26.0
    14.0
    WATER BASED
    16.07.1990
    1928
    1.55
    27.0
    16.0
    WATER BASED
    16.07.1990
    1928
    1.53
    24.0
    14.0
    WATER BASED
    16.07.1990
    1928
    1.53
    25.0
    15.0
    WATER BASED
    19.07.1990
    1928
    1.53
    25.0
    13.0
    WATER BASED
    01.08.1990
    1928
    1.53
    25.0
    14.0
    WATER BASED
    01.08.1990
    1928
    1.53
    25.0
    15.0
    WATER BASED
    01.08.1990
    1928
    1.53
    25.0
    15.0
    WATER BASED
    01.08.1990
    1935
    1.53
    23.0
    14.0
    WATER BASED
    01.08.1990
    1951
    1.53
    23.0
    15.0
    WATER BASED
    01.08.1990
    2030
    1.55
    24.0
    10.0
    WATER BASED
    01.08.1990
    2199
    1.62
    25.0
    12.0
    WATER BASED
    01.08.1990
    2199
    1.62
    25.0
    12.0
    WATER BASED
    31.07.1990
    2351
    1.70
    31.0
    17.0
    WATER BASED
    31.07.1990
    2351
    1.70
    31.0
    17.0
    WATER BASED
    01.08.1990
    2389
    1.71
    31.0
    14.0
    WATER BASED
    01.08.1990
    2389
    1.71
    32.0
    16.0
    WATER BASED
    01.08.1990
    2389
    1.71
    31.0
    17.0
    WATER BASED
    01.08.1990
    2389
    1.71
    36.0
    17.0
    WATER BASED
    01.08.1990
    2389
    1.71
    34.0
    15.0
    WATER BASED
    03.08.1990
    2389
    1.71
    36.0
    15.0
    WATER BASED
    03.08.1990
    2389
    1.71
    34.0
    18.0
    WATER BASED
    03.08.1990
    2389
    1.71
    25.0
    11.0
    WATER BASED
    13.08.1990
    2389
    1.71
    WATER BASED
    14.08.1990
    2389
    1.71
    25.0
    14.0
    WATER BASED
    14.08.1990
    2389
    1.71
    33.0
    16.0
    WATER BASED
    01.08.1990