Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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25.11.2024 - 01:30
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34/7-29 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.
    34/7-29 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).
    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
    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.
    34/7-29
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    CMT-94R95: ROW 2038 & COLUMN 993
    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.
    923-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.
    42
    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,
    04.03.1998
    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.
    14.04.1998
    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.
    14.04.2000
    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.
    11.04.2003
    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.
    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.
    24.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    250.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2927.0
    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).
    2846.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    20.7
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    100
    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° 21' 51.69'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 2' 23.37'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6803911.99
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    448662.75
    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.
    3313

  • Wellbore history
    General
    Exploration well 34/7-29 S was drilled in the west central part of block 34/7 on the H-North prospect. The H-North prospect was located SSE of the Vigdis field and NE of the Statfjord East field. The main objective of well 34/7-29 S was to test a northerly extension of the oil bearing Upper Jurassic Top Draupne Sands penetrated in wells 34/7-21, 21 A, 23 S & 23 A. The well was designed to test the presence of reservoir, hydrocarbons and pressure communication with the other H-Area segments. Reservoir presence was considered the primary risk. Seismic interpretation of the reservoir interval indicated communication with the H-West area, and pressure, sample and DST data were considered important to test this interpretation. In addition the well was to test for the presence of sands and possible hydrocarbons in the Middle and Lower Draupne Formation. Secondary objectives were to test the lithology and depositional model of the Palaeocene Lista Formation and tie the Top Brent seismic marker.
    Operations and results
    Exploration well 34/7-29 S was spudded with the semi-submersible installation "Transocean Leader" on 4 March 1998 and drilled and cored to TD at 2927 m (2848 m TVD RKB) in the 8 1/2" hole section 30 m into the Middle Jurassic Brent Group. A 7" liner was set and cemented. The well was drilled with Sea water and bentonite sweeps down to 1211 m and with "AQUACOL D" KCl / Glycol mud from 1211 m to 2558 m, and with "ANTISOL D" PAC mud from 2558 m to TD. Due to the presence of hydrocarbons and the requirement for the rig to go on contract for Norsk Hydro, the well was suspended on 14 April 1998 as an oil discovery. The semi-submersible drilling installation "Deepsea Bergen" re-entered well 34/7-29 S R on 22 February 1999 for testing.
    In the Nordland, Hordaland and Rogaland Groups the well penetrated mainly clay/claystones with some beds of sand. The Heimdal equivalent Member between 1928 -1999 m (1864 -1933 m TVD RKB) contained thick water wet sands. In the Shetland Group claystones and limestone beds were penetrated. The condensed Cromer Knoll Group consisted of marls, limestones and minor claystones. Core point was reached in the Cromer Knoll Group at 2701 m. The first core (2701 - 2718 m) penetrated the top of the Top intra Draupne Sand at 2705 m (2627 m TVD RKB) and contained oil bearing sands at the base. A second core was cut from 2718 to 2726 m from within the intra Draupne Sands and into the Draupne Shale. In total 17,7 m of sands were penetrated. MDT pressure samples acquired during logging indicated that the sands were all oil bearing and oil down to (ODT) of 2723 m (2622 m TVD MSL) was proved. No sands were penetrated within the Draupne Shale. Fluid samples proved the reservoir fluid to be undersaturated oil. The fluid samples were taken during the MDT run, using the Pump-Out module in combination with the Optical Fluid Analyser to limit contamination of mud filtrate. All fluid samples were taken at 2706.5 m. The quality of the samples and analyses was assumed to be good, because no significant differences were observed between the experimental results. Well 34/7-29 S R was permanently abandoned as an oil discovery on 17 March 1999.
    Testing
    One zone in the intra Draupne Sandstone was tested, from 2704 - 2716 m. After clean-up pressure build-up period of 6.2 hours, the well was opened on a 6,4 mm (16/64") adjustable choke, for the main flow, through the heater. The choke size was increased in steps to 17,5 mm (44/64") fixed choke in about 1.5 hours. The flow was directed through the separator 0.75 hours after the well was opened. The main flow had a duration of 72 hours during which the oil rate decreased gradually from 920 Sm3/d to 875 m3/d. The wellhead pressure decreased from 84.0 bars to 80.6 bars during the same period. Final gas rate was 120000 m3/day, giving a GOR of 137 m3/m3. The oil density was 0.842 g/cm3. Bottom hole sampling after flowing was cancelled.

  • 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]
    1220.00
    2927.00

  • 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
    2701.0
    2717.9
    [m ]
    2
    2718.0
    2724.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    23.6
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2701-2706m
    Core photo at depth: 2706-2711m
    Core photo at depth: 2711-2716m
    Core photo at depth: 2716-2718m
    Core photo at depth: 2718-2723m
    2701-2706m
    2706-2711m
    2711-2716m
    2716-2718m
    2718-2723m
    Core photo at depth: 2723-2724m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2723-2724m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1240.0
    [m]
    DC
    RRI
    1280.0
    [m]
    DC
    RRI
    1320.0
    [m]
    DC
    RRI
    1360.0
    [m]
    DC
    RRI
    1400.0
    [m]
    DC
    RRI
    1450.0
    [m]
    DC
    RRI
    1480.0
    [m]
    DC
    RRI
    1520.0
    [m]
    DC
    RRI
    1560.0
    [m]
    DC
    RRI
    1600.0
    [m]
    DC
    RRI
    1640.0
    [m]
    DC
    RRI
    1680.0
    [m]
    DC
    RRI
    1720.0
    [m]
    DC
    RRI
    1760.0
    [m]
    DC
    RRI
    1800.0
    [m]
    DC
    RRI
    1840.0
    [m]
    DC
    RRI
    1920.0
    [m]
    DC
    RRI
    1960.0
    [m]
    DC
    RRI
    2000.0
    [m]
    DC
    RRI
    2040.0
    [m]
    DC
    RRI
    2080.0
    [m]
    DC
    RRI
    2120.0
    [m]
    DC
    RRI
    2130.0
    [m]
    DC
    RRI
    2150.0
    [m]
    DC
    RRI
    2170.0
    [m]
    DC
    RRI
    2190.0
    [m]
    DC
    RRI
    2210.0
    [m]
    DC
    RRI
    2230.0
    [m]
    DC
    RRI
    2250.0
    [m]
    DC
    RRI
    2270.0
    [m]
    DC
    RRI
    2290.0
    [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
    2470.0
    [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
    2609.0
    [m]
    DC
    RRI
    2630.0
    [m]
    DC
    RRI
    2651.0
    [m]
    DC
    RRI
    2669.0
    [m]
    DC
    RRI
    2702.0
    [m]
    C
    RRI
    2703.0
    [m]
    C
    RRI
    2704.0
    [m]
    DC
    RRI
    2705.0
    [m]
    C
    RRI
    2706.0
    [m]
    C
    RRI
    2707.0
    [m]
    C
    RRI
    2708.0
    [m]
    DC
    RRI
    2708.0
    [m]
    C
    RRI
    2709.0
    [m]
    C
    RRI
    2710.0
    [m]
    C
    RRI
    2710.0
    [m]
    C
    RRI
    2711.0
    [m]
    C
    RRI
    2712.0
    [m]
    C
    RRI
    2713.0
    [m]
    C
    RRI
    2714.0
    [m]
    C
    RRI
    2715.0
    [m]
    C
    RRI
    2716.0
    [m]
    C
    RRI
    2718.0
    [m]
    C
    RRI
    2719.0
    [m]
    C
    RRI
    2720.0
    [m]
    C
    RRI
    2721.0
    [m]
    C
    RRI
    2722.0
    [m]
    C
    RRI
    2723.0
    [m]
    C
    RRI
    2724.0
    [m]
    C
    RRI
    2726.0
    [m]
    DC
    RRI
    2729.0
    [m]
    DC
    RRI
    2732.0
    [m]
    DC
    RRI
    2735.0
    [m]
    DC
    RRI
    2738.0
    [m]
    DC
    RRI
    2741.0
    [m]
    DC
    RRI
    2744.0
    [m]
    DC
    RRI
    2750.0
    [m]
    DC
    RRI
    2753.0
    [m]
    DC
    RRI
    2756.0
    [m]
    DC
    RRI
    2759.0
    [m]
    DC
    RRI
    2762.0
    [m]
    DC
    RRI
    2765.0
    [m]
    DC
    RRI
    2768.0
    [m]
    DC
    RRI
    2771.0
    [m]
    DC
    RRI
    2774.0
    [m]
    DC
    RRI
    2777.0
    [m]
    DC
    RRI
    2780.0
    [m]
    DC
    RRI
    2783.0
    [m]
    DC
    RRI
    2786.0
    [m]
    DC
    RRI
    2789.0
    [m]
    DC
    RRI
    2792.0
    [m]
    DC
    RRI
    2795.0
    [m]
    DC
    RRI
    2798.0
    [m]
    DC
    RRI
    2801.0
    [m]
    DC
    RRI
    2804.0
    [m]
    DC
    RRI
    2807.0
    [m]
    DC
    RRI
    2810.0
    [m]
    DC
    RRI
    2813.0
    [m]
    DC
    RRI
    2816.0
    [m]
    DC
    RRI
    2822.0
    [m]
    DC
    RRI
    2825.0
    [m]
    DC
    RRI
    2831.0
    [m]
    DC
    RRI
    2840.0
    [m]
    DC
    RRI
    2843.0
    [m]
    DC
    RRI
    2846.0
    [m]
    DC
    RRI
    2849.0
    [m]
    DC
    RRI
    2852.0
    [m]
    DC
    RRI
    2855.0
    [m]
    DC
    RRI
    2858.0
    [m]
    DC
    RRI
    2861.0
    [m]
    DC
    RRI
    2864.0
    [m]
    DC
    RRI
    2867.0
    [m]
    DC
    RRI
    2870.0
    [m]
    DC
    RRI
    2873.0
    [m]
    DC
    RRI
    2876.0
    [m]
    DC
    RRI
    2879.0
    [m]
    DC
    RRI
    2885.0
    [m]
    DC
    RRI
    2888.0
    [m]
    DC
    RRI
    2891.0
    [m]
    DC
    RRI
    2894.0
    [m]
    DC
    RRI
    2897.0
    [m]
    DC
    RRI
    2900.0
    [m]
    DC
    RRI

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.27

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.81
    pdf
    1.96
    pdf
    0.21

  • 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
    35.13

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DSI NGT
    2547
    2926
    FMI GPIT
    2547
    2931
    HALS PEX CMR
    2547
    2928
    MDT GR
    2706
    2916
    MSCT
    2600
    2920
    MWD - DIR
    274
    322
    MWD - MPR DIR GR
    322
    2927
    VSP
    1180
    2929

  • 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
    321.0
    36
    322.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    1202.0
    17 1/2
    1211.0
    1.69
    LOT
    INTERM.
    9 5/8
    2547.0
    12 1/4
    2558.0
    1.80
    LOT
    LINER
    7
    2927.0
    8 1/2
    2927.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1211
    1.20
    35.0
    WATER BASED
    1475
    1.45
    33.0
    WATER BASED
    2057
    1.56
    32.0
    WATER BASED
    2115
    1.56
    32.0
    WATER BASED
    2272
    1.57
    31.0
    WATER BASED
    2558
    1.57
    28.0
    WATER BASED
    2701
    1.56
    28.0
    WATER BASED
    2718
    1.56
    27.0
    WATER BASED
    2726
    1.56
    26.0
    WATER BASED
    2909
    1.03
    WATER BASED
    2927
    1.56
    39.0
    WATER BASED

  • 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
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