Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
11.11.2024 - 01:26
Time of last synchronization with Norwegian Offshore Directorate's internal systems

6507/7-2

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.
    6507/7-2
    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).
    WILDCAT
    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.
    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.
    6507/7-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    BP 83 - 307 SP. 910
    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.
    454-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.
    106
    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,
    25.02.1985
    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.
    10.06.1985
    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.
    10.06.1987
    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.
    18.12.2008
    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.
    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/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.
    YES
    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.
    FANGST GP
    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.
    EARLY 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.
    BÅT 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.
    351.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3262.0
    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).
    3260.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    7.8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    113
    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.
    LATE TRIASSIC
    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° 20' 12.37'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 18' 34.52'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7247224.93
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    421294.24
    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.
    464

  • Wellbore history
    General
    The well 6507/7-2 was drilled in the northern part of the Haltenbanken area, some 190 km west of the Norwegian coast. It was drilled to evaluate the "B" prospect in the intensely faulted zone that lies at the intersection of the Nordland Ridge in the northeast and the Halten Terrace in the south. The prospect was in a southward plunging horst block formed by a Late Jurassic tensional fault system. The main reservoir interval was anticipated to be the Lower Jurassic sandstone of the Aldra (Tilje) Formation.
    Operations and results
    Wildcat well 6507/7-2 was spudded with the semi-submersible installation Nortrym on 25 February 1985 and drilled to TD at 3262 m in Late Triassic sediments of the Åre Formation. No significant problems occurred during drilling operations, which went very much according to schedule. The seven-test program was however delayed approximately two weeks due to a premature firing of the Baker Tubing-Conveyed Perforating Guns while running in for DST 4. This necessitated the running of a protective string of 7" casing to cover the perforations (1062.5m to 1072.5m) and enable the testing program to be completed. Additional time was lost due to pulling and repairing the BOP stack after running the protective casing string. The well was drilled with sea water down to 1030 m and with gypsum mud from 1030 m to TD.
    Shetland Group sediments were resting directly on the Fangst Group, confirming heavy erosion at the crest of the structure as prognosed. The oldest dating of the Shetland Group was Santonian age, in sediments ca 5 m above top Fangst Group, while the youngest Fangst Group sediments were dated Toarcian-?Aalenian. At 2198 meters gas levels rose, indicating the top of the Jurassic sediments. Associated with the gas show was a rare dull-gold fluorescence on cuttings; however, no cut or staining was evident. The MWD gave little indication of sand through the Fangst Group and very little sand was seen in samples. The Ror Formation claystones separated the Fangst Group from the underlying Tilje formation.
    The Fangst and Båt groups were found hydrocarbon-bearing. Using gradients established from electric logs, RFT data, and fluid analysis the gas/oil contact was estimated to be at 2317.5 m. The oil/water contact was not as clear-cut. From logs it was placed at 2455, while the RFT data indicated an OWC between 2476 and 2482 m.
    Fourteen cores were cut in the Tilje Formation from 2283.5m to 2448.5m with an 84% recovery. The coring point was picked on the basis of prognosed depths, two earlier drilling breaks in claystones having been circulated out. Good oil shows were observed. There was good fluorescence to 2317m though little or no visible staining and cut was apparent. Visible oil with a good cut was apparent to 2439 meters, but the quality of show declined from this depth, with no fluorescence recorded below 2470 meters. Analysis of cores and logs indicated very good sandstone porosities and permeabilities throughout the interval. The low gas values through the reservoir were thought to reflect an overbalance of 3.5 - 4.5ppg which combined with increasing permeability caused flushing of the formation ahead of the bit.
    Four segregated RFT samples were taken at 2220.5 m (gas + water, mud and small amount of light coloured oil/condensate), 2303 m (gas + water, mud and small amount of light coloured oil/condensate), 2331.5 m (2.5 litres 29.8 deg API gravity oil with some gas) and 2382.7 m (9 litres of 22 deg API gravity oil with some water and gas).
    The well was permanently abandoned on 10 June 1985 as an oil and gas discovery.
    Testing
    Seven drill stem tests were undertaken. DST 1 was performed in the water zone within the Tilje Formation from 2521 to 2529 m. Four further tests were performed in the Tilje Formation with DST 2 (2417 - 2439 m), 3 (2356.5 - 2376 m) and 4A (2330 - 2340 m) flowing oil and DST 5 (2290 - 2310 m) gas/condensate. DST 6 (2232 - 2245 m) in the Ror Formation produced gas/condensate, and DST 7 in the Fangst Group, 2203 to 2222 m, produced predominantly gas. At stabilized conditions using various chokes sizes the cumulative peak production of oil was 2095 Sm3/day. Oil gravity ranged from 0.922 g/cm3 (22 deg API) to 0.876 g/cm3 (30 deg API). Cumulative peak gas production was 21100000 Sm3/day. Average gas gravity with respect to air was 0.65. Condensate produced in conjunction with the gas tests totalled 185 standard cubic meters per day (1166 BCPD) with an average gravity of 0.75 g/cm3(57 API). The average temperatures measured at the gauge carriers were: 83.4 (DST 1), 82.8 (DST 2), 80.9 (DST 3), 80.8 (DST 4A), 77.2 (DST 5), 72.4 (DST 6), and 75.5 (DST 7).

  • 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]
    480.00
    3262.20

  • 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
    2283.5
    2295.7
    [m ]
    2
    2300.5
    2310.7
    [m ]
    3
    2316.0
    2318.5
    [m ]
    4
    2320.0
    2325.1
    [m ]
    5
    2327.0
    2342.0
    [m ]
    6
    2345.0
    2362.0
    [m ]
    7
    2363.5
    2378.1
    [m ]
    8
    2379.0
    2392.0
    [m ]
    9
    2394.0
    2408.6
    [m ]
    10
    2410.0
    2420.1
    [m ]
    11
    2422.0
    2427.2
    [m ]
    12
    2431.0
    2435.0
    [m ]
    13
    2436.0
    2443.5
    [m ]
    14
    2444.0
    2448.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    135.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2000.0
    [m]
    DC
    OD
    2021.0
    [m]
    DC
    OD
    2042.0
    [m]
    DC
    OD
    2060.0
    [m]
    DC
    OD
    2081.0
    [m]
    DC
    OD
    2099.0
    [m]
    DC
    OD
    2108.0
    [m]
    DC
    OD
    2120.0
    [m]
    DC
    OD
    2129.0
    [m]
    DC
    OD
    2141.0
    [m]
    DC
    OD
    2150.0
    [m]
    DC
    OD
    2162.0
    [m]
    DC
    OD
    2171.0
    [m]
    DC
    OD
    2180.0
    [m]
    DC
    OD
    2192.0
    [m]
    DC
    OD
    2199.0
    [m]
    DC
    OD
    2210.0
    [m]
    DC
    OD
    2219.0
    [m]
    DC
    OD
    2231.0
    [m]
    DC
    OD
    2243.0
    [m]
    DC
    OD
    2249.0
    [m]
    DC
    OD
    2261.0
    [m]
    DC
    OD
    2273.0
    [m]
    DC
    OD
    2282.0
    [m]
    DC
    OD
    2294.0
    [m]
    DC
    OD
    2318.0
    [m]
    DC
    OD
    2330.0
    [m]
    DC
    OD
    2345.0
    [m]
    DC
    OD
    2363.0
    [m]
    DC
    OD
    2381.0
    [m]
    DC
    OD
    2405.0
    [m]
    DC
    OD
    2426.0
    [m]
    DC
    OD
    2435.0
    [m]
    DC
    OD
    2444.0
    [m]
    DC
    OD
    2450.0
    [m]
    DC
    OD
    2462.0
    [m]
    DC
    OD
    2474.0
    [m]
    DC
    OD
    2486.0
    [m]
    DC
    OD
    2495.0
    [m]
    DC
    OD
    2528.0
    [m]
    DC
    OD
    2555.0
    [m]
    DC
    OD
    2585.0
    [m]
    DC
    OD
    2615.0
    [m]
    DC
    OD
    2645.0
    [m]
    DC
    OD
    2675.0
    [m]
    DC
    OD
    2705.0
    [m]
    DC
    OD
    2735.0
    [m]
    DC
    OD
    2765.0
    [m]
    DC
    OD
    2795.0
    [m]
    DC
    OD
    2825.0
    [m]
    DC
    OD
    2855.0
    [m]
    DC
    OD
    2885.0
    [m]
    DC
    OD
    2915.0
    [m]
    DC
    OD
    2945.0
    [m]
    DC
    OD
    2975.0
    [m]
    DC
    OD
    2999.0
    [m]
    DC
    OD

  • 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
    2417.00
    2439.00
    29.04.1985 - 00:00
    YES
    DST
    DST2
    2365.00
    2376.00
    30.04.1985 - 00:00
    YES
    DST
    DST4A
    2330.00
    2340.00
    24.05.1985 - 00:00
    YES
    DST
    DST5
    2290.00
    2310.00
    29.05.1985 - 00:00
    YES
    DST
    DST6
    2232.00
    2245.00
    01.06.1985 - 00:00
    YES
    DST
    DST7
    2203.00
    2222.00
    05.06.1985 - 00:00
    YES

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    376
    376
    1454
    1863
    1863
    1944
    1944
    1977
    2042
    2203
    2217
    2217
    2285
    2482

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.72
    pdf
    0.17
    pdf
    0.36

  • 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
    20.53
    pdf
    2.39

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2521
    2529
    6.1
    2.0
    2417
    2439
    25.4
    2.1
    2417
    2439
    9.5
    2.2
    2417
    2439
    9.5
    2.3
    2417
    2439
    25.4
    3.0
    2357
    2376
    25.4
    4.0
    2330
    2340
    22.2
    5.0
    2290
    2310
    19.1
    6.0
    2232
    2245
    19.1
    7.0
    2203
    2222
    20.2
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    1.000
    26.000
    2.0
    2.1
    5.000
    2.2
    5.000
    2.3
    6.000
    3.000
    25.000
    3.0
    40.000
    4.0
    4.000
    25.000
    5.0
    12.000
    6.0
    5.000
    7.0
    9.000
    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
    2.0
    704
    34000
    0.922
    0.617
    48
    2.1
    208
    12000
    0.910
    57
    2.2
    208
    12000
    0.910
    57
    2.3
    704
    34000
    0.920
    49
    3.0
    489
    32000
    0.982
    0.668
    65
    4.0
    902
    68000
    0.876
    0.660
    75
    5.0
    73
    724000
    0.754
    0.650
    9965
    6.0
    17
    45000
    0.755
    0.650
    2632
    7.0
    96
    900000
    0.755
    9360

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR CCL
    1900
    2597
    CST
    1940
    2097
    CST
    2115
    2591
    CST
    2610
    3249
    DLL MSFL GR SP
    2100
    2602
    ISF BHC MSFL GR SP
    474
    1028
    ISF LSS MSFL GR SP
    1026
    2109
    ISF LSS MSFL GR SP
    2100
    2605
    ISF LSS MSFL GR SP
    2602
    3250
    LDT CNL GR
    2016
    2110
    LDT CNL GR
    2602
    3250
    LDT CNL NGS
    2100
    2606
    MWD - GYRO MULTISHOT
    474
    3262
    RFT
    2205
    2574
    SHDT GR
    1026
    2110
    SHDT GR
    2100
    2606
    SHDT GR
    2602
    3250
    TEMP
    500
    2025
    TEMP
    998
    2551
    VSP
    474
    3250

  • 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
    474.0
    36
    476.0
    0.00
    LOT
    SURF.COND.
    20
    1025.8
    26
    1030.0
    1.52
    LOT
    INTERM.
    13 3/8
    2100.0
    17 1/2
    2110.0
    1.76
    LOT
    INTERM.
    9 5/8
    2599.7
    12 1/4
    2610.0
    1.81
    LOT
    INTERM.
    9 5/8
    2600.2
    12 1/4
    2610.0
    1.81
    LOT
    OPEN HOLE
    3262.0
    8 1/2
    3262.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    383
    0.00
    WATER BASED
    25.02.1985
    426
    1.02
    180.0
    WATER BASED
    27.02.1985
    476
    1.06
    180.0
    WATER BASED
    27.02.1985
    476
    1.02
    180.0
    WATER BASED
    01.03.1985
    476
    1.02
    180.0
    WATER BASED
    01.03.1985
    836
    1.12
    5.0
    77.0
    WATER BASED
    03.03.1985
    1030
    1.12
    6.0
    148.0
    WATER BASED
    03.03.1985
    1030
    1.02
    7.0
    115.0
    WATER BASED
    03.03.1985
    1030
    1.26
    9.0
    124.5
    WATER BASED
    04.03.1985
    1030
    1.02
    7.0
    115.0
    WATER BASED
    03.03.1985
    1030
    1.26
    9.0
    124.5
    WATER BASED
    04.03.1985
    1070
    1.08
    23.0
    76.6
    WATER BASED
    10.03.1985
    1486
    1.35
    21.0
    57.5
    WATER BASED
    10.03.1985
    1646
    1.39
    11.0
    86.2
    WATER BASED
    11.03.1985
    1862
    1.43
    11.0
    91.0
    WATER BASED
    12.03.1985
    2052
    1.45
    14.0
    115.0
    WATER BASED
    13.03.1985
    2110
    1.48
    14.0
    124.0
    WATER BASED
    14.03.1985
    2110
    1.47
    14.0
    110.0
    WATER BASED
    17.03.1985
    2110
    1.47
    14.0
    110.0
    WATER BASED
    17.03.1985
    2179
    1.54
    14.0
    119.7
    WATER BASED
    19.03.1985
    2228
    1.56
    14.0
    81.3
    WATER BASED
    20.03.1985
    2284
    1.58
    16.0
    95.7
    WATER BASED
    21.03.1985
    2313
    1.58
    16.0
    95.7
    WATER BASED
    24.03.1985
    2327
    1.58
    16.0
    95.7
    WATER BASED
    24.03.1985
    2403
    1.58
    16.0
    95.8
    WATER BASED
    27.03.1985
    2436
    1.58
    16.0
    65.6
    WATER BASED
    29.03.1985
    2582
    1.58
    16.0
    105.3
    WATER BASED
    01.04.1985
    2605
    1.58
    18.0
    81.4
    WATER BASED
    01.04.1985
    2610
    1.58
    22.0
    71.8
    WATER BASED
    09.04.1985
    2610
    1.58
    23.0
    81.4
    WATER BASED
    09.04.1985
    2610
    1.58
    20.0
    67.0
    WATER BASED
    09.04.1985
    2610
    1.58
    23.0
    86.2
    WATER BASED
    09.04.1985
    2610
    1.58
    23.0
    81.4
    WATER BASED
    09.04.1985
    2610
    1.58
    20.0
    67.0
    WATER BASED
    09.04.1985
    2610
    1.58
    23.0
    86.2
    WATER BASED
    09.04.1985
    2627
    1.50
    13.0
    67.0
    WATER BASED
    09.04.1985
    2645
    1.48
    15.0
    62.2
    WATER BASED
    09.04.1985
    2680
    1.44
    15.0
    62.3
    WATER BASED
    10.04.1985
    2728
    1.42
    16.0
    71.8
    WATER BASED
    11.04.1985
    2810
    1.39
    15.0
    71.8
    WATER BASED
    12.04.1985
    2917
    1.39
    17.0
    62.2
    WATER BASED
    15.04.1985
    2989
    1.39
    15.0
    67.0
    WATER BASED
    15.04.1985
    3135
    1.39
    16.0
    67.0
    WATER BASED
    15.04.1985
    3262
    1.39
    16.0
    76.6
    WATER BASED
    16.04.1985
    3262
    1.39
    16.0
    76.6
    WATER BASED
    17.04.1985
    3262
    1.39
    20.0
    95.6
    WATER BASED
    18.04.1985
    3262
    1.39
    20.0
    95.6
    WATER BASED
    18.04.1985
    3262
    1.39
    16.0
    76.6
    WATER BASED
    17.04.1985

  • 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
    0.28