Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.11.2024 - 09:09
Time of last synchronization with Norwegian Offshore Directorate's internal systems

29/9-1

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    29/9-1
    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.
    29/9-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    CDP 239276 (NH 8101)
    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.
    Norsk Hydro Produksjon AS
    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.
    390-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.
    155
    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,
    23.09.1983
    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.
    24.02.1984
    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.
    24.02.1986
    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.
    01.08.2010
    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/GAS
    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.
    EOCENE
    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.
    FRIGG 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.
    BRENT GP
    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.
    104.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4703.0
    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).
    4703.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.1
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    147
    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.
    STATFJORD GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 28' 33.19'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 59' 58.95'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6704986.97
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    445007.97
    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.
    31

  • Wellbore history
    General
    Well 29/9-1 is located on the Hild structure ca 1.5 km west of the UK border on the eastern margin of the East Shetland Basin in the North Sea. The well was drilled to appraise the 30/7-2 discovery. The main objectives were to test the hydrocarbon prospectivity and reservoir parameters of the Middle and Early Jurassic sequence. The well was planned to be drilled 50 m into the Statfjord Formation at a total depth of 4640 +/- 200 m.
    Operations and results
    Appraisal well 29/9-1 was spudded with the semi-submersible installation Treasure Seeker on 23 September 1983 and drilled to TD at 4703 m in the Early Jurassic Statfjord Formation. During drilling of the 17 1/2" hole, tight hole problems were experienced. The 9 5/8" casing had to be run twice due to problems with the casing hanger seal. Due to high temperature and lack of circulation the mud in the 7" liner gelled up and had to be replaced several times. This caused difficulties operating the testing tool. The well was drilled with seawater and gel slugs down to 1057 m and with KCl/polymer mud from 1057 m to TD. Mud retort test showed 4-5% oil in the mud from top of the 12 1/4" section at 2752 m, declining to traces at 3732 m.
    The well encountered oil in the Frigg Formation in the interval 1782 to 1787 m (OWC), and gas in the middle Jurassic Brent Group from 4386.5 m to 4421 m (gas down to top Dunlin Group; no hydrocarbon contact was encountered).
    The Frigg Formation (1782-1981 m) consisted of predominantly of fine to coarse grained porous sandstones. The uppermost 2.5 m was tight and calcareous cemented. Net pay was thus 2.5 m with 31% average porosity and 40% average water saturation, based on logs. No RFTs or drill stem tests were performed through this section. The upper part of the Brent Group, the Tarbert and most of the Ness Formation was faulted out. The remaining section of the Ness Formation (4386.5 - 4393.5m) consisted of shales with interbedded coals and stringers of sandstones. Fairly clean fine to coarse grained sandstones made up the underlying Etive Formation (4393.5 - 4405.5 m). The Rannoch Formation (4405.5 - 4415m) was a relatively tight sequence of very fine grained micaceous and silty sandstones. The Broom Formation (4415 - 4421m) constitutes the base of the Brent Group and consisted of fine to coarse grained pebbly sandstones. The net pay for the whole Brent Group was calculated to 10.6m of a gross thickness of 34,5m giving a net to gross ratio of 0.3. The average porosity was calculated from logs to 14.3% with an average water saturation of 53.6%.
    Oil shows in the Frigg Formation became weaker below OWC and died completely at 1844 m. Poor hydrocarbon shows occasionally observed on limestones and marls in the Cretaceous section were not considered significant. Good shows were seen on cores from the Brent reservoir. No shows were recorded below bas Brent Group.
    Three cores were cut in the middle Jurassic sequence from 4386 to 4436 m with 96 to 100% recovery. No RFT pressure recordings or sampling were performed due to badly washed out hole over the reservoir section.
    The well was permanently abandoned on 24 February as a gas as an oil and gas appraisal well.
    Testing
    A drill stem test (DST) was performed over the interval 4394 - 4405 m in the Etive Formation. The well produced at maximum only 9769 Sm3 (0.345 MMft3) gas/day through a 1.27cm (32/64") choke. The gravity of the gas was 0.774 (air=l). Only traces of condensate were produced. Bottom hole temperature measured in the test was 141.1 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]
    220.00
    4703.00

  • 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
    4386.0
    4403.8
    [m ]
    2
    4404.0
    4417.5
    [m ]
    3
    4419.0
    4430.1
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    42.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 4386-4390m
    Core photo at depth: 3290-4394m
    Core photo at depth: 4394-4398m
    Core photo at depth: 4398-4402m
    Core photo at depth: 4402-4406m
    4386-4390m
    3290-4394m
    4394-4398m
    4398-4402m
    4402-4406m
    Core photo at depth: 4406-4410m
    Core photo at depth: 4410-4414m
    Core photo at depth: 4414-4417m
    Core photo at depth: 4418-4422m
    Core photo at depth: 4422-4436m
    4406-4410m
    4410-4414m
    4414-4417m
    4418-4422m
    4422-4436m
    Core photo at depth: 4426-4430m
    Core photo at depth: 4430-4434m
    Core photo at depth: 4434-4436m
    Core photo at depth:  
    Core photo at depth:  
    4426-4430m
    4430-4434m
    4434-4436m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2922.5
    [m]
    SWC
    IKU
    2931.5
    [m]
    SWC
    IKU
    2942.5
    [m]
    SWC
    IKU
    3151.0
    [m]
    SWC
    IKU
    3485.5
    [m]
    SWC
    IKU
    3625.0
    [m]
    SWC
    IKU
    3771.0
    [m]
    SWC
    IKU
    3848.0
    [m]
    SWC
    IKU
    3883.5
    [m]
    SWC
    IKU
    3896.5
    [m]
    SWC
    IKU
    3983.0
    [m]
    SWC
    IKU
    4014.0
    [m]
    SWC
    IKU
    4035.0
    [m]
    SWC
    IKU
    4067.0
    [m]
    SWC
    IKU
    4116.0
    [m]
    SWC
    IKU
    4169.0
    [m]
    SWC
    IKU
    4211.0
    [m]
    SWC
    IKU
    4246.0
    [m]
    SWC
    IKU
    4262.0
    [m]
    SWC
    IKU
    4290.0
    [m]
    SWC
    IKU
    4336.0
    [m]
    SWC
    IKU
    4345.0
    [m]
    SWC
    IKU
    4360.0
    [m]
    SWC
    IKU
    4386.1
    [m]
    C
    IKU
    4417.3
    [m]
    C
    IKU
    4419.4
    [m]
    C
    IKU
    4421.2
    [m]
    C
    IKU
    4428.8
    [m]
    C
    IKU
    4431.1
    [m]
    C
    IKU
    4508.0
    [m]
    SWC
    IKU
    4555.0
    [m]
    SWC
    IKU
    4685.0
    [m]
    SWC
    IKU

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.88

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.73
    pdf
    0.24
    pdf
    0.89
    pdf
    0.94

  • 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
    3.81
    pdf
    19.35

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    4394
    4405
    12.7
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    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
    10000
    0.774

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    1858
    3925
    CST
    2250
    2748
    CST
    2922
    3695
    CST
    3698
    3950
    CST
    3950
    4321
    CST
    4014
    4625
    CST
    4026
    4595
    CST
    4336
    4704
    DLL MSFL
    4200
    4703
    HDT
    1700
    3955
    ISF LSS GR SP
    213
    4703
    LDT CNL GR CAL
    1039
    4703
    SHDT
    3927
    4703
    VSP
    2980
    4705

  • 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
    213.5
    36
    215.0
    0.00
    LOT
    SURF.COND.
    20
    1040.5
    26
    1057.0
    1.54
    LOT
    INTERM.
    13 3/8
    2724.0
    17 1/2
    2751.0
    1.91
    LOT
    INTERM.
    9 5/8
    3927.0
    12 1/4
    3950.0
    2.19
    LOT
    LINER
    7
    4546.0
    8 3/8
    4703.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    250
    1.06
    48.0
    WATER BASED
    450
    1.10
    48.0
    WATER BASED
    565
    1.04
    30.0
    WATER BASED
    905
    1.06
    32.0
    WATER BASED
    1050
    1.11
    47.0
    WATER BASED
    1250
    1.12
    53.0
    WATER BASED
    1550
    1.13
    50.0
    WATER BASED
    1750
    1.14
    47.0
    WATER BASED
    1920
    1.20
    49.0
    WATER BASED
    2000
    1.25
    49.0
    WATER BASED
    2120
    1.26
    46.0
    WATER BASED
    2220
    1.32
    45.0
    WATER BASED
    2250
    1.38
    52.0
    WATER BASED
    2300
    1.39
    52.0
    WATER BASED
    2400
    1.38
    52.0
    WATER BASED
    2750
    1.42
    56.0
    WATER BASED
    3700
    1.50
    45.0
    WATER BASED
    3810
    1.53
    46.0
    WATER BASED
    3860
    1.80
    52.0
    WATER BASED
    3950
    1.97
    47.0
    WATER BASED
    4050
    1.98
    30.0
    WATER BASED
    4150
    2.02
    26.0
    WATER BASED