Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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27.04.2024 - 01:34
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6507/5-5

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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.
    6507/5-5
    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
    Press release
    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.
    NORWEGIAN 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.
    6507/5-5
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    bpn00ml Pl 212 xline1765-inline1203
    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.
    BP Amoco Norge 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.
    1021-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.
    79
    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,
    28.11.2001
    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.
    14.02.2002
    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.
    14.02.2004
    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.
    08.03.2004
    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.
    MIDDLE 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.
    GARN FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    18.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    375.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3948.0
    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).
    3948.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    6.6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    155
    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.
    ÅRE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    65° 42' 8.01'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 35' 45.36'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7287623.70
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    435533.04
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    32
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    4428

  • Wellbore history
    General
    The Skarv structure is located in the Nordland II area west of the Nordland Ridge on the Dønna Terrace. The structure consists of three fault segments called A, B, and C. Well 6507/5-5 was drilled on the B-segment. The primary objective of the well was to appraise hydrocarbons in sandstones of the Early to Middle Jurassic Garn, Ile, and Tilje Formations. Secondary objective was to verify significant hydrocarbon columns (> 10 m continuous columns) in the Cretaceous Lange Formation.
    Operations and results
    Appraisal well 6507/5-5 was spudded in the second attempt with the semi-submersible installation West Alpha on 28 November 2002 and drilled to TD at 3950 m in the Early Jurassic Åre Formation. No shallow gas was encountered. While drilling, a leak in the 9 5/8" casing was discovered and repaired. The well was drilled with gel and seawater down to 1051 m, with KCl/Polymer/Glycol mud from 1051 m to 2100 m, with oil based mud (ENVIROMUL NAP) from 2100 to 3642 m, and with KCl/Polymer mud from 3642 m to TD.
    Top Lysing Formation came in at 2735.6 m TVD MSL, top Lange Formation at 2739 m TVD MSL, top Garn Formation at 3629.5 m TVD MSL, top Ile Formation at 3722.5 m TVD MSL, top Tilje Formation at 3811.6 m TVD MSL, and top Åre Formation at 3905.2 m TVD MSL. A 55 m oil column with an oil-down-to contact was encountered in the Garn Formation. Amplitude anomalies showed good structural correlation between the A-, B-, and C -fault segments, but hydrocarbon phase could not be predicted. The Lysing Formation was tight with no shows. Weak and questionable shows (oil based mud) were seen in cuttings from carbonate lithologies in the Lange Formation in the form of visible and UV fluorescent residue. Such shows were observed in the intervals 2951 m to 2985 m, 3022 m to 3030 m, and 3432 m to 3469 m. Shows in the form of visible and UV fluorescent residue were observed also in sandstone cuttings from the interval 3630 m to 3663 m in the Garn Formation.
    One 81 m core was cut from 3655 m to 3736 m from the Garn and into the Not Formation. The full core length was recovered, but the core was ejected at rig floor due to gas expansion and 12.2 m of the core was damaged. The damaged interval was puzzled together onshore, but the interval between 3668.25 m and 3672 m was not submitted to the NPD. Forty-five pressure points were taken. MDT fluid samples recovered oil from 3668 m and 3653 m. The samples appeared to be of good quality and without contamination. The well was permanently abandoned on 14 February 2002 as an oil appraisal.
    Testing
    The Garn Formation was perforated from 3651.5 m to 3706.5 m. The main flow produced oil at a rate of 5880 barrels/day (935 Sm3/day) with a 64/64" choke with a total of 5264 bbl (8364 Sm3) of oil produced in 30 hours. Gas rate was 5.8 mmscf/day (164238 Sm3 gas/day), giving a GOR of 176 Sm3/Sm3 during the main flow. Samples were taken on sample chambers on the test string and from the separator outlet and the wellhead. Mean down-hole temperature (DST temperature) was 132.9°C. Mean oil density was 0.855 g/cm3 and mean gas gravity was 0.735 (air = 1); mean CO2 content in gas was 3.5%.

  • 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]
    1060.00
    3950.00

  • 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
    3654.7
    3736.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    81.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3654-3659m
    Core photo at depth: 3659-3664m
    Core photo at depth: 3664-3667m
    Core photo at depth: 3667-3672m
    Core photo at depth: 3672-3677m
    3654-3659m
    3659-3664m
    3664-3667m
    3667-3672m
    3672-3677m
    Core photo at depth: 3677-3682m
    Core photo at depth: 3682-3687m
    Core photo at depth: 3687-3692m
    Core photo at depth: 3692-3697m
    Core photo at depth: 3697-3702m
    3677-3682m
    3682-3687m
    3687-3692m
    3692-3697m
    3697-3702m
    Core photo at depth: 3702-3707m
    Core photo at depth: 3707-3712m
    Core photo at depth: 3712-3717m
    Core photo at depth: 3717-3722m
    Core photo at depth: 3737-3722m
    3702-3707m
    3707-3712m
    3712-3717m
    3717-3722m
    3737-3722m
    Core photo at depth: 3722-3727m
    Core photo at depth: 3727-3732m
    Core photo at depth: 3732-3736m
    Core photo at depth:  
    Core photo at depth:  
    3722-3727m
    3727-3732m
    3732-3736m

  • Oil samples at the Norwegian Offshore Directorate
    Oil samples at the Norwegian Offshore Directorate
    Test type
    Bottle number
    Top depth
    MD [m]
    Bottom depth
    MD [m]
    Fluid type
    Test time
    Samples available
    DST
    0.00
    0.00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.45

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    3.86

  • 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
    1.84
    .PDF
    0.49
    .PDF
    12.50

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3561
    3706
    25.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    7.400
    133
    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
    940
    164256
    0.855
    0.735
    176

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DSI HRLA GR EMS
    3440
    3946
    DSI IPLT GR
    2100
    3644
    IPLT GR
    3644
    3946
    MDT GR
    3644
    3946
    MDT GR
    3653
    3885
    MWD - LWD DIR
    471
    1060
    MWD - LWD MPR GR
    1060
    3950
    VSI-VSP/CHK
    1322
    3946

  • 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
    466.0
    36
    471.0
    0.00
    LOT
    INTERM.
    20
    1051.0
    26
    1060.0
    1.56
    LOT
    INTERM.
    13 3/8
    2100.0
    17 1/2
    2106.0
    1.90
    LOT
    LINER
    9 5/8
    3642.0
    12 1/4
    3643.0
    0.00
    LOT
    LINER
    7
    3948.0
    8 1/2
    3948.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    393
    0.17
    SPUD MUD
    471
    0.17
    SPUD MUD
    1060
    0.14
    SPUD MUD
    3643
    1.25
    KCL
    3643
    1.25
    WATER/BRINE
    3643
    1.63
    28.0
    KCL

  • 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
    0.29