Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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15.07.2024 - 01:28
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34/7-23 A

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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 A
    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.
    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.
    788-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.
    43
    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,
    08.04.1994
    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.
    20.05.1994
    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.
    20.05.1996
    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.
    APPRAISAL
    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.
    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).
    3412.0
    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).
    2769.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    45.7
    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.
    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.
    HEATHER 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.
    2326
  • Wellbore history

    General
    Exploration well 34/7-23 A was drilled in the H-Vest prospect as a sidetrack to well 34/7-23 S, located on the Vigdis Field on Tampen Spur in the Northern North Sea. The main objective was to test for Top Draupne Sandstone reservoir presence within the Top Draupne Sequence of Portlandian and Ryazanian age and to test for an oil water contact. Secondary objective was to test for reservoir presence and hydrocarbons in a seismic wedge in the middle Draupne Sequence. Additional targets were lowermost Late Cretaceous and intra Oxfordian (Intra-Heather Formation) sandstones.
    Operations and results
    Well 34/7-23 A was kicked off from well 34/7-23 S on April 8, 1994. The kick off point was at 2358 m (1968.5 m TVD) in the upper part of the Shetland Group. The well was drilled westward deviated to TD at 3412 m (2769 m TVD) using the semi-submersible installation Vildkat Explorer. Drilling went without problem. During logging operations the FMT tool got stuck at 3220 m and 60 hrs were spent fishing for it. The well was drilled with KCl mud with a polyalkyleneglycol additive (BP DCP 208) m from kick-off to TD.
    In the Shetland Group claystones with limestone beds were penetrated. The condensed Cromer Knoll Group consisted of marls, limestones and minor claystones. The Viking Group was encountered at 3202.9 m (2619 m TVD). The topmost section was oil bearing Intra Draupne Formation sandstone from 3202.9 to 3246 m (2619 - 2649.1 TVD, 30.1 m gross). This sandstone interval, which was the only sandstone interval encountered within the Draupne Formation, proved an ODT at 3246 m (2649.1 m TVD). No OWC was identified on the logs or with the FMT-measurements. The Intra Draupne Formation Sandstone reservoir had an estimated average log porosity of 22.4% and an estimated average water saturation of 11.4%. The net gross ratio was 0.93. Below the reservoir, the Draupne Formation consisted of siltstones and claystones. The Middle to Late Jurassic Heather Formation penetrated by the well consisted of sandy silty claystones with only minor limestone and sandstone beds.
    Five cores were cut with a 90 ft core barrel from 3199 to 3291 m in the Intra Draupne Formation Sandstone and into the Draupne Formation. H2S was present when recovering core No 1 and 2 (200 and 300 ppm H2S, respectively). No H2S was measured in the three lowermost cores. Due to the FMT problems no fluid samples were taken.
    The well was permanently abandoned on 20 May as an oil appraisal.
    Testing
    The interval 3205.0-3225.0 m (2622-2635 m TVD) in the Intra-Draupne Formation sand was perforated and tested. The oil rate at the end of the multi-rate flow was measured to 1085 Sm3/day through a 19.1 mm choke, with a corresponding wellhead pressure of 97.5 bar and a GOR of 106 Sm3/Sm3 at separator conditions of 42.9 bar and 58.9 deg C. The dead oil density was 0.848 g/cm3 and the gas gravity was 0.71 (air = 1). A maximum H2S concentration of 0.8 ppm was measured. Maximum bottom hole temperature measured
  • 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]
    2360.00
    3412.00
  • 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
    3199.0
    3222.7
    [m ]
    2
    3223.0
    3251.0
    [m ]
    3
    3251.0
    3267.0
    [m ]
    4
    3267.0
    3278.2
    [m ]
    5
    3279.0
    3291.1
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    91.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 3199-3204m
    Core photo at depth: 3204-3209m
    Core photo at depth: 3209-3214m
    Core photo at depth: 3214-3219m
    Core photo at depth: 3219-3222m
    3199-3204m
    3204-3209m
    3209-3214m
    3214-3219m
    3219-3222m
    Core photo at depth: 3223-3228m
    Core photo at depth: 3228-3233m
    Core photo at depth: 3233-3238m
    Core photo at depth: 3238-3243m
    Core photo at depth: 3243-3248m
    3223-3228m
    3228-3233m
    3233-3238m
    3238-3243m
    3243-3248m
    Core photo at depth: 3248-3251m
    Core photo at depth: 3251-3258m
    Core photo at depth: 3256-3261m
    Core photo at depth: 3261-3266m
    Core photo at depth: 3266-3267m
    3248-3251m
    3251-3258m
    3256-3261m
    3261-3266m
    3266-3267m
    Core photo at depth: 3267-3272m
    Core photo at depth: 3272-3277m
    Core photo at depth: 3277-3278m
    Core photo at depth: 3279-3284m
    Core photo at depth: 3284-3289m
    3267-3272m
    3272-3277m
    3277-3278m
    3279-3284m
    3284-3289m
    Core photo at depth: 3289-3291m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3289-3291m
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3203.8
    [m]
    C
    BIOSTRAT
    3205.8
    [m]
    C
    BIOSTR
    3208.1
    [m]
    C
    BIOSTR
    3209.6
    [m]
    C
    BIOSTR
    3212.5
    [m]
    C
    BIOSTR
    3216.6
    [m]
    C
    BIOSTR
    3219.5
    [m]
    C
    BIOSTR
    3221.6
    [m]
    C
    BIOSTR
    3224.5
    [m]
    C
    BIOSTR
    3226.8
    [m]
    C
    BIOSTR
    3228.5
    [m]
    C
    BIOSTR
    3230.4
    [m]
    C
    BIOSTR
    3231.6
    [m]
    C
    BIOSTR
    3232.5
    [m]
    C
    BIOSTR
    3234.6
    [m]
    C
    BIOSTR
    3235.3
    [m]
    C
    BIOSTR
    3237.9
    [m]
    C
    BIOSTR
    3238.6
    [m]
    C
    BIOSTR
    3240.7
    [m]
    C
    BIOSTR
    3241.1
    [m]
    C
    BIOSTR
    3242.8
    [m]
    C
    BIOSTR
    3243.9
    [m]
    C
    BIOSTR
    3244.9
    [m]
    C
    BIOSTR
    3245.3
    [m]
    C
    BIOSTR
    3246.6
    [m]
    C
    BIOSTR
    3247.3
    [m]
    C
    BIOSTR
    3248.5
    [m]
    C
    BIOSTR
    3249.7
    [m]
    C
    BIOSTR
    3250.6
    [m]
    C
    BIOSTR
    3251.8
    [m]
    C
    BIOSTR
    3252.5
    [m]
    C
    BIOSTR
    3254.2
    [m]
    C
    BIOSTR
    3255.6
    [m]
    C
    BIOSTR
    3257.5
    [m]
    C
    BIOSTR
    3259.3
    [m]
    C
    BIOSTR
    3261.0
    [m]
    C
    BIOSTR
    3284.7
    [m]
    C
    BIOSTR
  • Lithostratigraphy

  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.20
    pdf
    3.02
    pdf
    0.86
  • 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
    157.42
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DLL MLL GR
    3180
    3297
    DPIL MAC ZDL CN DSL
    2319
    3409
    FMT GR
    3204
    3258
    HDIP CBIL GR
    2319
    3409
    MWD EWR - GR RES DIR
    2358
    3412
    SWC OFC
    3179
    3389
    VELOCITY
    2100
    3295
  • 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
    INTERM.
    9 5/8
    2320.0
    12 1/4
    2323.0
    0.00
    LOT
    LINER
    7
    3358.0
    8 1/2
    3409.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    2320
    1.60
    26.0
    19.0
    DUMMY
    05.04.1994
    2320
    1.60
    25.0
    19.0
    DUMMY
    06.04.1994
    2320
    1.60
    25.0
    19.0
    DUMMY
    07.04.1994
    2320
    1.60
    25.0
    20.0
    DUMMY
    08.04.1994
    2370
    1.60
    17.0
    13.0
    DUMMY
    11.04.1994
    2510
    1.60
    34.0
    19.0
    DUMMY
    11.04.1994
    2545
    1.60
    29.0
    17.0
    DUMMY
    11.04.1994
    2728
    1.60
    37.0
    29.0
    DUMMY
    12.04.1994
    2792
    1.60
    90.0
    25.0
    DUMMY
    13.04.1994
    2792
    1.60
    90.0
    25.0
    DUMMY
    14.04.1994
    2960
    1.60
    31.0
    29.0
    DUMMY
    14.04.1994
    3040
    1.60
    30.0
    28.0
    DUMMY
    18.04.1994
    3105
    1.60
    28.0
    24.0
    DUMMY
    18.04.1994
    3190
    1.60
    30.0
    30.0
    DUMMY
    18.04.1994
    3223
    1.60
    30.0
    30.0
    DUMMY
    18.04.1994
    3251
    1.60
    32.0
    28.0
    DUMMY
    19.04.1994
    3267
    1.60
    32.0
    24.0
    DUMMY
    21.04.1994
    3291
    1.60
    25.0
    23.0
    DUMMY
    21.04.1994
    3318
    1.60
    27.0
    24.0
    DUMMY
    22.04.1994
    3343
    1.60
    28.0
    26.0
    DUMMY
    25.04.1994
    3383
    1.60
    24.0
    20.0
    DUMMY
    25.04.1994
    3412
    1.60
    28.0
    20.0
    DUMMY
    25.04.1994
    3412
    1.60
    25.0
    22.0
    DUMMY
    26.04.1994
    3412
    1.60
    25.0
    15.0
    DUMMY
    27.04.1994
    3412
    1.60
    29.0
    18.0
    DUMMY
    28.04.1994
    3412
    1.60
    27.0
    18.0
    DUMMY
    29.04.1994
    3412
    1.60
    27.0
    18.0
    DUMMY
    02.05.1994
    3412
    1.60
    26.0
    19.0
    DUMMY
    02.05.1994
    3412
    1.60
    26.0
    19.0
    DUMMY
    02.05.1994
    3412
    1.60
    26.0
    18.0
    DUMMY
    03.05.1994
    3412
    1.60
    26.0
    26.0
    DUMMY
    04.05.1994
    3412
    1.60
    26.0
    26.0
    DUMMY
    05.05.1994
    3412
    1.60
    26.0
    26.0
    DUMMY
    09.05.1994
    3412
    1.60
    27.0
    17.0
    DUMMY
    09.05.1994
    3412
    1.60
    27.0
    17.0
    DUMMY
    09.05.1994
    3412
    1.60
    26.0
    26.0
    DUMMY
    09.05.1994
    3412
    1.60
    27.0
    17.0
    DUMMY
    10.05.1994
    3412
    1.60
    27.0
    17.0
    DUMMY
    16.05.1994
    3412
    1.60
    27.0
    17.0
    DUMMY
    16.05.1994
    3412
    1.60
    25.0
    20.0
    DUMMY
    18.05.1994
    3412
    1.60
    25.0
    20.0
    DUMMY
    18.05.1994
    3412
    1.60
    30.0
    17.0
    DUMMY
    19.05.1994
    3412
    1.60
    28.0
    18.0
    DUMMY
    19.05.1994
    3412
    1.20
    15.0
    15.0
    DUMMY
    19.05.1994
    3412
    1.20
    15.0
    15.0
    DUMMY
    24.05.1994
    3412
    1.20
    DUMMY
    24.05.1994
    3412
    1.60
    28.0
    18.0
    DUMMY
    18.05.1994
  • Thin sections at the Norwegian Offshore Directorate

    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    3203.20
    [m ]
    3203.60
    [m ]
    3221.50
    [m ]
    3220.25
    [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
    0.22