Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
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34/7-25 S

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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.
    34/7-25 S
    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
    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.
    34/7-25
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    CTM 94-INLINE 1052 & CROSSLINE 1389
    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.
    852-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.
    46
    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,
    31.07.1996
    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.
    14.09.1996
    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.
    14.09.1998
    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.
    YES
    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.
    LATE 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.
    INTRA DRAUPNE FM SS
    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.
    187.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3235.0
    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).
    2596.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    52.1
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    94
    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.
    DRAKE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 15' 9.24'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 8' 41.14'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6791381.74
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    454110.02
    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.
    2863

  • Wellbore history
    General
    Well 34/7-25 S is located near the southern extension of the Tordis field and North of the Gullfaks field in the Tampen area in the Northern North Sea. The main objective of the well was to test the presence of sand and hydrocarbon in a Late Jurassic prospect (the Southern Triangle Upper Jurassic (STUJ) prospect). The STUJ prospect was defined between Base Cretaceous Unconformity (BCU) and a Base Draupne reflector. Secondary objectives were to obtain pressure measurements in the Brent Group, test presence of sand and hydrocarbons in the Cretaceous and in the Paleocene and prove migration route.
    Operations and results
    Well 34/7-25 S was spudded with the semi-submersible installation Deepsea Bergen on 31 July 1996 and drilled to TD at 3235 m (2596 m TVD) in the Early Jurassic Drake Formation. No significant problems occurred during operations. The well was drilled with spud mud down to 1271 m and with oil based mud (Anco Vert) from 1271 m to TD. No shallow gas was encountered.
    Well 34/7-25 S penetrated several sands in the interval from 1250 m to 1700 m within the Hordaland Group. Weak shows were described in the interval 2275 to 2295 m in the Lista Formation. The shows had no odour and no stain in the description, due to oil based mud. The Cretaceous section had only traces of thin sandstone beds in the Shetland Group. The well successfully encountered 27.5 m TVD oil bearing sandstones belonging to the Draupne Formation, with top at 2791 m (2193 m TVD). No OWC was proven. The uppermost 2 m was cemented and had the same log response as the limestone of the Cromer Knoll Group. The next 21 m (2195 - 2216 TVD) showed excellent reservoir properties with porosity around 30% and permeability between 6 and 7 Darcy. This upper massive sandstone was bioturbated and showed a coarsening up character. The lower part of the Draupne Formation comprised sandstones interbedded with more silty parts. This part of the formation had a very high gamma response due to a high content of uranium isotopes. The sand beds in this section had oil shows but petrophysical interpretation concluded that it had no HC saturation. The top Heather Formation was penetrated at 2822 m (2220.5 m TVD). Between the sandy Draupne Formation and the shaly Heather Formation there was an unconformity of Callovian - Volgian age. Pressure measurements in the Late Jurassic showed communication with the Tordis field.
    Two cores were cut at 2805 to 2860.2 m within the Viking Group with close to 100 % overall recovery. No wire line fluid samples were taken since the main zone was going to be tested.
    The well was permanently abandoned on 14 September 1996 as an oil discovery.
    Testing
    The interval 2791 - 2816 m (2193.0 - 2214.6 m TVD) in the Intra Draupne Formation sand was perforated and tested. After the clean-up flow and build-up the well was opened for the 48 hour main flow period. The final flow rate was 1045 Sm3 oil and 102200 Sm3 gas/day through a 15.9 mm choke at a wellhead pressure of 124 bar and a GOR of 94 Sm3/m3 at separator conditions. The oil density was 0.844 g/cm3, and the gas gravity was 0.72 (air = 1). The maximum bottom hole temperature in the test was measured to 82 deg C.

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    YES
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    430.00
    3235.00

  • 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
    2805.0
    2831.5
    [m ]
    2
    2832.0
    2860.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    54.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2805-2810m
    Core photo at depth: 2810-2815m
    Core photo at depth: 2815-2810m
    Core photo at depth: 2820-2825m
    Core photo at depth: 2825-2830m
    2805-2810m
    2810-2815m
    2815-2810m
    2820-2825m
    2825-2830m
    Core photo at depth: 2830-2831m
    Core photo at depth: 2832-2837m
    Core photo at depth: 2837-2842m
    Core photo at depth: 2842-2847m
    Core photo at depth: 2847-2852m
    2830-2831m
    2832-2837m
    2837-2842m
    2842-2847m
    2847-2852m
    Core photo at depth: 2852-2857m
    Core photo at depth: 2857-2860m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2852-2857m
    2857-2860m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1270.0
    [m]
    DC
    RRI
    1310.0
    [m]
    DC
    RRI
    1350.0
    [m]
    DC
    RRI
    1390.0
    [m]
    DC
    RRI
    1430.0
    [m]
    DC
    RRI
    1470.0
    [m]
    DC
    RRI
    1510.0
    [m]
    DC
    RRI
    1550.0
    [m]
    DC
    RRI
    1590.0
    [m]
    DC
    RRI
    1630.0
    [m]
    DC
    RRI
    1670.0
    [m]
    DC
    RRI
    1710.0
    [m]
    DC
    RRI
    1750.0
    [m]
    DC
    RRI
    1790.0
    [m]
    DC
    RRI
    1830.0
    [m]
    DC
    RRI
    1910.0
    [m]
    DC
    RRI
    1950.0
    [m]
    DC
    RRI
    1990.0
    [m]
    DC
    RRI
    2030.0
    [m]
    DC
    RRI
    2070.0
    [m]
    DC
    RRI
    2110.0
    [m]
    DC
    RRI
    2160.0
    [m]
    DC
    RRI
    2190.0
    [m]
    DC
    RRI
    2230.0
    [m]
    DC
    RRI
    2270.0
    [m]
    DC
    RRI
    2310.0
    [m]
    DC
    RRI
    2330.0
    [m]
    DC
    RRI
    2350.0
    [m]
    DC
    RRI
    2370.0
    [m]
    DC
    RRI
    2390.0
    [m]
    DC
    RRI
    2410.0
    [m]
    DC
    RRI
    2430.0
    [m]
    DC
    RRI
    2450.0
    [m]
    DC
    RRI
    2490.0
    [m]
    DC
    RRI
    2510.0
    [m]
    DC
    RRI
    2530.0
    [m]
    DC
    RRI
    2550.0
    [m]
    DC
    RRI
    2570.0
    [m]
    DC
    RRI
    2590.0
    [m]
    DC
    RRI
    2610.0
    [m]
    DC
    RRI
    2630.0
    [m]
    DC
    RRI
    2650.0
    [m]
    DC
    RRI
    2670.0
    [m]
    DC
    RRI
    2690.0
    [m]
    DC
    RRI
    2710.0
    [m]
    DC
    RRI
    2730.0
    [m]
    DC
    RRI
    2750.0
    [m]
    DC
    RRI
    2770.0
    [m]
    DC
    RRI
    2790.0
    [m]
    DC
    RRI
    2961.0
    [m]
    DC
    RRI
    2970.0
    [m]
    DC
    RRI
    2985.0
    [m]
    DC
    RRI
    2988.0
    [m]
    DC
    RRI
    2997.0
    [m]
    DC
    RRI
    3006.0
    [m]
    DC
    RRI
    3015.0
    [m]
    DC
    RRI
    3024.0
    [m]
    DC
    RRI
    3033.0
    [m]
    DC
    RRI
    3042.0
    [m]
    DC
    RRI
    3051.0
    [m]
    DC
    RRI
    3060.0
    [m]
    DC
    RRI
    3069.0
    [m]
    DC
    RRI
    3078.0
    [m]
    DC
    RRI
    3087.0
    [m]
    DC
    RRI
    3097.0
    [m]
    DC
    RRI
    3105.0
    [m]
    DC
    RRI
    3114.0
    [m]
    DC
    RRI
    3123.0
    [m]
    DC
    RRI
    3132.0
    [m]
    DC
    RRI
    3141.0
    [m]
    DC
    RRI
    3150.0
    [m]
    DC
    RRI
    3159.0
    [m]
    DC
    RRI
    3168.0
    [m]
    DC
    RRI
    3177.0
    [m]
    DC
    RRI
    3186.0
    [m]
    DC
    RRI
    3195.0
    [m]
    DC
    RRI
    3204.0
    [m]
    DC
    RRI
    3222.0
    [m]
    DC
    RRI
    3228.0
    [m]
    DC
    RRI
    3235.0
    [m]
    DC
    RRI

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.21
    pdf
    1.45
    pdf
    0.17

  • 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
    26.82

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2817
    2791
    15.9
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    30.000
    82
    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
    1039
    101920
    0.840
    0.730
    98

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DIPL DAC ZDL GR TTRM
    350
    1235
    DIPL MAC DSL TTRM
    2232
    3235
    FMT QDYNE GR TTRM
    2232
    3235
    HEXDIP GR TTRM
    2232
    3235
    MRIL ZDL CNC GR TTRM
    2232
    3235
    MWD DPR - DIR GR RES
    258
    3235
    PVFT QDYNE GR TTRM
    2232
    3235
    SWC
    2805
    2832
    SWC
    2832
    2860
    VELOCITY
    1265
    3155

  • 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
    258.0
    36
    260.0
    0.00
    LOT
    SURF.COND.
    18 5/8
    393.0
    26
    394.0
    1.48
    LOT
    INTERM.
    13 3/8
    1253.0
    17 1/2
    1255.0
    1.70
    LOT
    INTERM.
    9 5/8
    2232.0
    12 1/4
    2233.0
    0.00
    LOT
    LINER
    7
    3235.0
    8 1/2
    3235.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    363
    1.25
    SPUD MUD
    1088
    1.22
    20.0
    KCL MUD
    1380
    1.39
    21.0
    PSEUDO OIL BASE
    1380
    1.25
    24.0
    KCL MUD
    1384
    1.39
    20.0
    PSEUDO OIL BASE
    4103
    1.48
    33.0
    PSEUDO OIL BASE
    4193
    1.50
    33.0
    PSEUDO OIL BASE
    4690
    1.54
    36.0
    PSEUDO OIL BASE

  • 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
    0.22