Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

6507/7-5

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.
    6507/7-5
    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
    Multilateral
    Indicator telling if the parent well is multilateral, meaning it has more than one branch radiating from the main borehole. Example of legal values: YES, NO. See also Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    NO
    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.
    6507/7-5
    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.
    Conoco Norway Inc.
    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.
    500-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.
    50
    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,
    16.01.1986
    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.
    06.03.1986
    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.
    06.03.1988
    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.
    17.09.2007
    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
    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.
    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.
    ILE FM
    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.
    331.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2660.0
    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).
    2659.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    92
    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.
    TILJE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    65° 21' 30.27'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 17' 35.08'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7249656.78
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    420590.94
    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.
    879

  • Wellbore history
    General
    Well 6507/7-5 is located on the northern part of the Halten Terrace off shore Mid Norway and was drilled to appraise the northern extension of the 6507/7-2 Heidrun Discovery. The primary objective was Middle and Lower Jurassic sands in a downthrown fault block located NNW of the 6507/7-2 well. Prognosed top Jurassic was at 2308 m.
    Secondary objective was the Båt Group at an expected depth of 2394 m. Based on site survey, shallow gas could appear at 512, 570, 618, 746, and 799 m. Prognosed TD was 2675 m.
    Operations and results
    Appraisal well 6507/7-5 was spudded with the semi-submersible installation Nortrym on 16 January 1986 and drilled to TD at 2660 in the Early Jurassic Tilje Formation. The 26" hole section was drilled without marine riser to 1040 m, first as a 17 1/2" pilot hole with MWD logging, then opening up to 26". No shallow gas was recorded. The MWD quality was good, so no electric logging was performed in this section. Since no riser was used, all returns were to seafloor down to 1040 m. No significant problems were encountered during operations. The well was drilled with seawater and pre-hydrated gel down to 1040 m and with KCl/polymer mud from 1040 m to TD.
    No sandstone of importance was encountered above the Middle Jurassic. A hiatus from Late Cretaceous Turonian to Late Jurassic Oxfordian/Kimmeridgian was observed at 2310 m. Sandstones of the Fangst Group were encountered at 2353 to 2424 m. Analysis of cores and logs indicated good to excellent porosity and permeability in these sandstones, with the best reservoir properties towards the top, in the Garn Formation.
    Poor oil shows were observed in sandstone lenses in core no 1 from the Shetland Group (2255.0 - 2282.5 m), which consisted mainly of claystones. Visible shows of uniform light brown oil were observed on cores from top of the Garn Formation down to 2400 m. Below this depth the shows were occasionally more patchy, until at 2422 m core depth (2427 m loggers depth) where there was no longer any visible oil. The lowermost oil observed on the cores was not believed to represent the true OWC, but a change into impermeable lithologies. One RFT run was carried out in the 12 1/4" hole with the objective of establishing the OWC. Intersection of the oil and water gradients from the RFT pressure data suggested an OWC at ca 2475 m. The Early Jurassic Ti1je Formation of the Båt Group was penetrated at 2473.5 m and proved to be dry without shows.
    Seventeen cores from the Late Cretaceous through to the Early Jurassic were cut from 2255 to 2644.5 m with 89.4 % recovery. Attempts were made to obtain a water sample on RFT at 2485 and 2485.5 m, but these were unsuccessful due to malfunction of the sample chamber.
    The well was permanently abandoned on 6 March 1986 as an oil and gas appraisal.
    Testing
    Three DST tests were performed in this well.
    DST 1 tested the interval 2418 m to 2424 m in the base of the Garn Formation. It produced at maximum rates 751 Sm3 oil and 52358 Sm3 separator gas /day through a 2x1" choke. The separator GOR was 70 Sm3/Sm3, the oil gravity was 27.9 deg API, and the separator gas gravity was 0.65. The gas contained maximum 2% CO2 and no detectable H2S.
    DST 2, was aborted due to a leak in the kill line and was re-tested as DST 2A.
    DST 2A tested the interval 2355 m to 2375 m in the top of the Garn Formation. It produced at maximum rates 982 Sm3 oil and 85630 Sm3 separator gas /day through a 2x1" choke. The separator GOR was 87 Sm3/Sm3, the oil gravity was 31.3 deg API, and the separator gas gravity was 0.68. The gas contained maximum 2% CO2 and no detectable H2S.
    None of the tests produced any bottom sediments or water.
    The DST maximum recorded temperatures from the final flows of DST1 and DST2A were 85.7 deg C at 2421 m, and 82.6 deg C at 2365 m, respectively.
    6

  • 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]
    1050.00
    2660.00

  • 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
    2255.0
    2282.9
    [m ]
    2
    2282.5
    2308.8
    [m ]
    3
    2308.5
    2336.4
    [m ]
    4
    2336.0
    2349.6
    [m ]
    5
    2362.0
    2385.5
    [m ]
    6
    2390.0
    2407.8
    [m ]
    7
    2411.0
    2438.9
    [m ]
    8
    2439.0
    2466.9
    [m ]
    9
    2467.0
    2480.7
    [m ]
    10
    2482.0
    2497.6
    [m ]
    11
    2501.0
    2509.0
    [m ]
    12
    2512.0
    2533.6
    [m ]
    13
    2538.0
    2553.1
    [m ]
    14
    2556.0
    2578.7
    [m ]
    15
    2581.5
    2591.1
    [m ]
    16
    2596.5
    2623.9
    [m ]
    17
    2625.0
    2644.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    345.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • 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
    2418.00
    2424.00
    21.02.1986 - 00:00
    YES
    DST
    TEST1
    0.00
    0.00
    20.01.1987 - 00:00
    YES
    DST
    DST2
    2355.00
    2375.00
    25.02.1986 - 00:00
    YES
    DST
    2355.00
    2375.00
    02.03.1986 - 00:00
    YES
    DST
    TEST2A
    2355.00
    2375.00
    02.03.1986 - 00:00
    YES

  • 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
    455.0
    36
    455.0
    0.00
    LOT
    INTERM.
    20
    1033.0
    26
    1040.0
    1.52
    LOT
    INTERM.
    13 3/8
    2228.0
    17 1/2
    2255.0
    1.79
    LOT
    INTERM.
    9 5/8
    2659.0
    12 1/4
    2660.0
    0.00
    LOT

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2417
    2424
    35.9
    2.0
    2355
    2375
    35.9
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    4.000
    4.000
    25.000
    2.0
    4.000
    5.000
    25.000
    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
    774
    52000
    0.890
    67
    2.0
    953
    85000
    0.868
    89

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR CCL
    2125
    2621
    CYBERDIP
    2228
    2658
    CYBERLOOK
    2228
    2516
    DIL GR SP
    2228
    2516
    DIL SLS GR SP
    2228
    2658
    DLL MSFL GR SP
    2228
    2655
    HRT
    355
    2177
    ISF SLS MSFL GR
    1032
    2232
    LDL CNL GR
    1032
    2233
    LDL CNL GR
    2228
    2516
    LDL CNL NGL
    2228
    2659
    MWD - GR RES DIR
    455
    2240
    NGT RATIOS
    2228
    2659
    RFT GP
    2358
    2637
    RFT HP
    2358
    2637
    RFT SG
    2358
    2637
    SHDT
    2228
    2658
    SONIC WAVEFORM
    2228
    2658
    VELOCITY
    1036
    2654

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    356
    356
    1482
    1904
    1904
    1998
    1998
    2025
    2086
    2310
    2310
    2316
    2353
    2353
    2399
    2409
    2424
    2424
    2474

  • 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
    0.27
    pdf
    0.09
    pdf
    0.19

  • 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
    11.57
    pdf
    2.15

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    426
    1.03
    WATER BASED
    17.01.1986
    1794
    1.38
    WATER BASED
    25.01.1986
    1905
    1.39
    WATER BASED
    25.01.1986
    2075
    1.38
    108.0
    20.0
    WATER BASED
    05.03.1986
    2098
    1.34
    WATER BASED
    25.01.1986
    2238
    1.42
    WATER BASED
    25.01.1986
    2248
    1.42
    WATER BASED
    30.01.1986
    2248
    1.42
    WATER BASED
    31.01.1986
    2248
    1.42
    WATER BASED
    03.02.1986
    2255
    1.21
    WATER BASED
    03.02.1986
    2283
    1.20
    WATER BASED
    03.02.1986
    2309
    1.21
    WATER BASED
    01.02.1986
    2362
    1.22
    WATER BASED
    04.02.1986
    2411
    1.22
    WATER BASED
    06.02.1986
    2451
    1.02
    WATER BASED
    10.02.1986
    2501
    1.20
    WATER BASED
    10.02.1986
    2512
    1.20
    WATER BASED
    10.02.1986
    2538
    1.02
    WATER BASED
    10.02.1986
    2582
    1.20
    24.0
    9.0
    WATER BASED
    10.02.1986
    2660
    1.20
    108.0
    20.0
    WATER BASED
    14.02.1986
    2660
    1.20
    108.0
    20.0
    WATER BASED
    24.02.1986

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2255.0
    [m]
    C
    OD
    2257.0
    [m]
    C
    OD
    2258.0
    [m]
    C
    OD
    2260.0
    [m]
    C
    OD
    2261.0
    [m]
    C
    OD
    2262.0
    [m]
    C
    OD
    2263.5
    [m]
    C
    OD
    2264.4
    [m]
    C
    OD
    2265.6
    [m]
    C
    OD
    2266.5
    [m]
    C
    OD
    2267.5
    [m]
    C
    OD
    2268.5
    [m]
    C
    OD
    2269.5
    [m]
    C
    OD
    2270.5
    [m]
    C
    OD
    2271.5
    [m]
    C
    OD
    2272.5
    [m]
    C
    OD
    2273.5
    [m]
    C
    OD
    2274.5
    [m]
    C
    OD
    2275.5
    [m]
    C
    OD
    2276.5
    [m]
    C
    OD
    2277.5
    [m]
    C
    OD
    2278.5
    [m]
    C
    OD
    2279.5
    [m]
    C
    OD
    2280.5
    [m]
    C
    OD
    2281.5
    [m]
    C
    OD
    2282.5
    [m]
    C
    OD
    2283.5
    [m]
    C
    OD
    2284.5
    [m]
    C
    OD
    2285.5
    [m]
    C
    OD
    2286.5
    [m]
    C
    OD
    2287.5
    [m]
    C
    OD
    2288.5
    [m]
    C
    OD
    2289.5
    [m]
    C
    OD
    2290.5
    [m]
    C
    OD
    2291.5
    [m]
    C
    OD
    2292.5
    [m]
    C
    OD
    2293.5
    [m]
    C
    OD
    2294.5
    [m]
    C
    OD
    2295.5
    [m]
    C
    OD
    2296.5
    [m]
    C
    OD
    2297.5
    [m]
    C
    OD
    2298.5
    [m]
    C
    OD
    2299.5
    [m]
    C
    OD
    2300.5
    [m]
    C
    OD
    2301.5
    [m]
    C
    OD
    2302.5
    [m]
    C
    OD
    2303.6
    [m]
    C
    OD
    2304.5
    [m]
    C
    OD
    2305.5
    [m]
    C
    OD
    2306.5
    [m]
    C
    OD
    2307.5
    [m]
    C
    OD
    2308.7
    [m]
    C
    OD
    2309.0
    [m]
    C
    OD
    2309.5
    [m]
    C
    OD
    2310.5
    [m]
    C
    OD
    2311.5
    [m]
    C
    OD
    2312.5
    [m]
    C
    OD
    2312.5
    [m]
    C
    OD
    2314.5
    [m]
    C
    OD
    2316.5
    [m]
    C
    OD
    2319.5
    [m]
    C
    OD
    2322.5
    [m]
    C
    OD
    2325.5
    [m]
    C
    OD
    2328.5
    [m]
    C
    OD
    2331.5
    [m]
    C
    OD
    2334.5
    [m]
    C
    OD
    2336.6
    [m]
    C
    OD
    2342.5
    [m]
    C
    OD
    2348.0
    [m]
    C
    OD
    2348.6
    [m]
    C
    OD
    2378.7
    [m]
    C
    OD
    2405.8
    [m]
    C
    OD
    2417.0
    [m]
    C
    OD
    2417.3
    [m]
    C
    OD
    2418.7
    [m]
    C
    OD
    2438.5
    [m]
    C
    OD