Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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34/7-23 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.
    34/7-23 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.
    34/7-23
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    GE-83:ROW 357 & COLUMN 1109
    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.
    783-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.
    41
    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,
    22.02.1994
    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.
    03.04.1994
    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.
    03.04.1996
    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.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    246.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3375.0
    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).
    2889.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    46.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    103
    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.
    MIDDLE 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.
    TARBERT FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 20' 24.89'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 4' 31.54'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6801198.83
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    450528.18
    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.
    2296

  • Wellbore history
    General
    Well 34/7-23 S is located on the Vigdis Field on Tampen Spur in the Northern North Sea. Located 5200 meters north-northwest of the H-Sentral 34/7-21 oil discovery, the well was primarily designed to test for reservoir presence and hydrocarbons in the Top Draupne Sequence of Portlandian and Ryazanian age. In the case of a discovery, pressure communication with well 34/7-21 would be tested. Secondary objectives of the well included lowermost Early Cretaceous sandstones found oil bearing in 34/7-21, and intra Oxfordian sandstones which were found to yield oil in well 34/7-21 A. Both these sandstones are thin and below seismic resolution. An additional objective was to test the presence of sandstone in Paleocene.
    Operations and results
    Well 34/7-23 S was spudded with the semi-submersible installation Vildkat Explorer on 22 February 1994 and drilled to TD at 3375 m (2889 m TVD) in the Middle Jurassic Tarbert Formation. The subsea Jurassic target location coincided with the pipeline which connects the Snorre TLP to the Statfjord C platform. To avoid any mechanical problems with the rigs anchors, the spud location was chosen to be located 1400 meters east of the Base Cretaceous target location and the borehole was designed as a westward deviated well. Special H2S equipment was mobilized when H2S was observed during coring in the upper part of the reservoir. For operational reasons it was decided to interrupt coring and take a FMT sample. An additional 10 meters were drilled from 3096 down to 3106 m to get a rathole for the FMT logging tool. This interval was thus not cored. The well was drilled with spud mud down to 1175 m, and with KCl mud with a polyalkyleneglycol additive (BP DCP 208) m from 1175 m to TD.
    In the Nordland, Hordaland and Rogaland Groups, the well penetrated mainly clay/claystone with some beds of sand, except for the sandy Utsira Formation between 955 - 1144 m (934 - 1114 m TVD). In the Shetland Group clay stones with limestone beds were penetrated. The condensed Cromer Knoll Group consisted of marls, limestones and minor claystones.
    The Draupne Formation was penetrated at 3078 m (2608.5 m TVD). The upper part was a 24 m thick oil-filled Intra-Draupne Formation Sand. No oil water contact was encountered in the well: the deepest oil down to was observed at 3102 m (2632 m TVD). The Intra-Draupne Formation Sandstone had a measured thickness of 25 (23.5 m TVD). It had an estimated average log porosity of 25.1% and an estimated average water saturation of 19.0%. The net gross ratio is 0.91. The underlying Draupne Formation shale was 80 m thick.
    The Intra-Draupne Formation Sandstone had a pressure gradient of 1.28 g/cc (ref. MSL). The formation pressure in the impermeable rocks of the Viking Group is believed to be in the order of 1.45 - 1.43 g/cc (ref. MSL), whilst the pressure in the Brent Group was measured to be 1.43 - 1.42 g/cc (ref. MSL). The well was interpreted to be differently depleted than the H-Sentral 34/7-21 well.
    Apart from the oil filled Intra-Draupne Formation sand weak shows were observed  in several sections throughout the well. In the Hordaland Group sand beds with traces of shows were observed in cutting samples in the interval 1332 - 1560 m as well as in the Rogaland Formation from 2000 to 2187 m. In the Shetland Group, hydrocarbon shows occurred in thin sandstone horizons from 2735 to 2835 m and sporadically down to 3010 m. Below the reservoir in the Viking Group, traces of weak shows were observed in thin sandstone laminae, claystones, and siltstones. Also the uppermost, massive sandstones of the Brent Group had weak shows.
    A total of five cores were cut in the interval 3079-3096 and 3106-3136 m in the Intra Draupne Formation sand and 34 m into the underlying Draupne shale. The total core recovery was 99.6% (46.8m). FMT samples were taken in the Intra-Draupne Formation sand at 3080 m (oil and gas), 3082 m (oil and gas), and 3084.2 m (water and filtrate). All three samples contained H2S in the range 60 - 75 ppm. The well was plugged back to a depth of 2480 m and permanently abandoned on 3 April as an oil discovery. The well was later sidetracked (34/7-23 A).
    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
    3374.00

  • 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
    3079.0
    3095.9
    [m ]
    2
    3106.0
    3108.0
    [m ]
    3
    3108.0
    3117.0
    [m ]
    4
    3117.0
    3124.0
    [m ]
    5
    3124.0
    3136.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    46.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3097-3084m
    Core photo at depth: 3084-3089m
    Core photo at depth: 3089-3094m
    Core photo at depth: 3094-3095m
    Core photo at depth: 3106-3108m
    3097-3084m
    3084-3089m
    3089-3094m
    3094-3095m
    3106-3108m
    Core photo at depth: 3108-3113m
    Core photo at depth: 3113-3116m
    Core photo at depth: 3117-3122m
    Core photo at depth: 3122-3124m
    Core photo at depth: 3124-3129m
    3108-3113m
    3113-3116m
    3117-3122m
    3122-3124m
    3124-3129m
    Core photo at depth: 3129-3134m
    Core photo at depth: 3134-3136m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3129-3134m
    3134-3136m

  • 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
    6.76

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DLL MLL GR
    3050
    3205
    DPIL MAC ZDL CN DSL
    2318
    3373
    FMT GR
    3077
    3088
    FMT GR
    3078
    3353
    FMT GR
    3078
    3084
    HDIP CBIL GR
    2318
    3334
    MAC-VDL
    2039
    2318
    MWD EWR - GR RES DIR
    271
    3375
    SWC PFC
    2370
    3334
    SWC PFC
    2375
    3333
    TBRT GR
    3050
    3137
    VELOCITY
    780
    3360

  • 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
    368.0
    36
    370.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    1167.0
    17 1/2
    1170.0
    1.57
    LOT
    INTERM.
    9 5/8
    2320.0
    12 1/4
    2323.0
    1.80
    LOT
    OPEN HOLE
    3374.0
    8 1/2
    3374.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    348
    1.06
    WATER BASED
    23.02.1994
    369
    1.06
    WATER BASED
    24.02.1994
    369
    1.06
    WATER BASED
    25.02.1994
    515
    1.17
    11.0
    16.0
    WATER BASED
    28.02.1994
    987
    1.18
    10.0
    60.0
    WATER BASED
    28.02.1994
    1175
    1.20
    7.0
    39.0
    WATER BASED
    28.02.1994
    1175
    1.20
    8.0
    36.0
    WATER BASED
    01.03.1994
    1175
    1.20
    8.0
    36.0
    WATER BASED
    02.03.1994
    1175
    1.20
    8.0
    36.0
    GEL MUD
    03.03.1994
    1175
    1.20
    8.0
    36.0
    GEL MUD
    08.03.1994
    1175
    1.20
    8.0
    36.0
    GEL MUD
    08.03.1994
    1408
    1.35
    18.0
    20.0
    DUMMY
    08.03.1994
    1860
    1.43
    24.0
    25.0
    DUMMY
    08.03.1994
    2187
    1.48
    23.0
    24.0
    DUMMY
    10.03.1994
    2332
    1.51
    31.0
    27.0
    DUMMY
    11.03.1994
    2332
    1.51
    30.0
    28.0
    DUMMY
    14.03.1994
    2332
    1.51
    30.0
    28.0
    DUMMY
    14.03.1994
    2332
    1.51
    30.0
    28.0
    DUMMY
    14.03.1994
    2332
    1.51
    30.0
    28.0
    DUMMY
    15.03.1994
    2332
    1.53
    30.0
    28.0
    DUMMY
    16.03.1994
    2332
    1.51
    30.0
    29.0
    DUMMY
    10.03.1994
    2462
    1.57
    32.0
    24.0
    DUMMY
    17.03.1994
    2612
    1.59
    37.0
    34.0
    DUMMY
    18.03.1994
    2952
    1.60
    43.0
    38.0
    DUMMY
    22.03.1994
    2952
    1.60
    31.0
    29.0
    DUMMY
    23.03.1994
    3096
    1.60
    34.0
    26.0
    DUMMY
    24.03.1994
    3108
    1.60
    29.0
    25.0
    DUMMY
    25.03.1994
    3189
    1.60
    31.0
    24.0
    DUMMY
    28.03.1994
    3265
    1.60
    29.0
    26.0
    DUMMY
    29.03.1994
    3375
    1.60
    27.0
    26.0
    DUMMY
    30.03.1994
    3375
    1.60
    33.0
    19.0
    DUMMY
    05.04.1994
    3375
    1.60
    33.0
    19.0
    DUMMY
    05.04.1994
    3375
    1.60
    22.0
    21.0
    DUMMY
    05.04.1994
    3375
    1.60
    22.0
    21.0
    DUMMY
    05.04.1994

  • 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
    0.23