Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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24.11.2024 - 01:27
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34/10-36

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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.
    34/10-36
    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.
    34/10-36
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 8720-695 & KOLONNE 555
    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.
    Den norske stats oljeselskap a.s
    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.
    723-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.
    77
    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,
    28.04.1992
    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.
    13.07.1992
    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.
    13.07.1994
    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.
    03.12.2014
    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.
    TARBERT FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    136.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3640.0
    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).
    3634.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    10.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    134
    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.
    COOK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 6' 48.49'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 10' 35.15'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6775866.39
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    455614.12
    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.
    1940

  • Wellbore history
    General
    Well 34/10-36 was the sixth well drilled on the Gullfaks Sør structure. The objectives were to test the potential of Intra-Draupne Formation turbiditic sandstone, and to confirm the gas-oil contact, the oil-water contact, and the pressure regime in the Brent Group.
    Operations and results
    Appraisal well 34/10-36 was spudded with the semi-submersible installation Deepsea Bergen on 28 April 1992  and drilled to TD at 3640 m in the Early Jurassic Cook Formation. A 9 7/8” pilot hole was drilled from surface to 859 m to check for shallow gas. The MWD indicated several sands but all were water-filled. The well was drilled with seawater and CMC down to 1071 m, with gypsum/polymer mud from 1071 m to 3010 m, and with Ancotemp/bentonite from 3010 m to TD.
    The Draupne Formation consisted of shale with only traces of sandstone stringers towards the base. The Brent Group, Tarbert Formation was encountered at 3361 m (3355.3 m TVD), 55 m deeper than prognosed. It was oil-bearing down to the OWC at 3377.5 m (3371.9 m TVD). Shows were seen down to 3397 m. The GOC was not penetrated in the well location.
    Three cores were cut in the well. Core 1 was cut from 3029 to 3054 m in the Draupne Formation. Cores 2 and 3 were cut in the Tarbert Formation from 3363 m to 3417 m. The core shifts for cores 1, 2 and 3 were 3.0 m, 2.3 m and 2.3 m, respectively. One segregated sample was taken at 3363.8 m. The 2 3/4 gallon chamber contained 3.5 litres of oil, 3.5 litres of mud filtrate and 0.22 m3 gas. No CO2 or H2S was detected from this sample chamber.
    The well was permanently abandoned on 13 July 1992 as an oil appraisal well.
    Testing
    One drill stem test was performed in the Tarbert Formation, from the interval 3371.2 - 3376.2 m. The well flowed 836 Sm3 oil and 161490 Sm3 gas /day through a 36/64” choke. The GOR was 193 Sm3/Sm3, the oil density was 0.869 g/cm3 and the gas density was 0.695 with 2 % CO2 and 3.5 ppm H2S. The recorded temperature was 126.1 °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]
    1080.00
    3640.00

  • 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
    3029.0
    3053.0
    [m ]
    2
    3363.0
    3390.0
    [m ]
    3
    3390.0
    3417.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    78.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3029-3034m
    Core photo at depth: 3034-3039m
    Core photo at depth: 3039-3044m
    Core photo at depth: 3044-3049m
    Core photo at depth: 3049-3053m
    3029-3034m
    3034-3039m
    3039-3044m
    3044-3049m
    3049-3053m
    Core photo at depth: 3363-3368m
    Core photo at depth: 3368-3373m
    Core photo at depth: 3373-3378m
    Core photo at depth: 3378-3383m
    Core photo at depth: 3383-3388m
    3363-3368m
    3368-3373m
    3373-3378m
    3378-3383m
    3383-3388m
    Core photo at depth: 3388-3390m
    Core photo at depth: 3390-3395m
    Core photo at depth: 3395-3400m
    Core photo at depth: 3400-3405m
    Core photo at depth: 3405-3410m
    3388-3390m
    3390-3395m
    3395-3400m
    3400-3405m
    3405-3410m
    Core photo at depth: 3410-3415m
    Core photo at depth: 3415-3416m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3410-3415m
    3415-3416m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1080.0
    [m]
    DC
    GEOST
    1100.0
    [m]
    DC
    GEOST
    1120.0
    [m]
    DC
    GEOST
    1130.0
    [m]
    DC
    GEOST
    1150.0
    [m]
    DC
    GEOST
    1160.0
    [m]
    DC
    GEOST
    1180.0
    [m]
    DC
    GEOST
    1190.0
    [m]
    DC
    GEOST
    1210.0
    [m]
    DC
    GEOST
    1220.0
    [m]
    DC
    GEOST
    1240.0
    [m]
    DC
    GEOST
    1250.0
    [m]
    DC
    GEOST
    1270.0
    [m]
    DC
    GEOST
    1280.0
    [m]
    DC
    GEOST
    1300.0
    [m]
    DC
    GEOST
    1310.0
    [m]
    DC
    GEOST
    1330.0
    [m]
    DC
    GEOST
    1340.0
    [m]
    DC
    GEOST
    1360.0
    [m]
    DC
    GEOST
    1370.0
    [m]
    DC
    GEOST
    1390.0
    [m]
    DC
    GEOST
    1400.0
    [m]
    DC
    GEOST
    1420.0
    [m]
    DC
    GEOST
    1430.0
    [m]
    DC
    GEOST
    1450.0
    [m]
    DC
    GEOST
    1460.0
    [m]
    DC
    GEOST
    1480.0
    [m]
    DC
    GEOST
    1490.0
    [m]
    DC
    GEOST
    1510.0
    [m]
    DC
    GEOST
    1520.0
    [m]
    DC
    GEOST
    1540.0
    [m]
    DC
    GEOST
    1550.0
    [m]
    DC
    GEOST
    1570.0
    [m]
    DC
    GEOST
    1580.0
    [m]
    DC
    GEOST
    1600.0
    [m]
    DC
    GEOST
    1610.0
    [m]
    DC
    GEOST
    1630.0
    [m]
    DC
    GEOST
    1640.0
    [m]
    DC
    GEOST
    1660.0
    [m]
    DC
    GEOST
    1670.0
    [m]
    DC
    GEOST
    1690.0
    [m]
    DC
    GEOST
    1700.0
    [m]
    DC
    GEOST
    1720.0
    [m]
    DC
    GEOST
    1730.0
    [m]
    DC
    GEOST
    1750.0
    [m]
    DC
    GEOST
    1760.0
    [m]
    DC
    GEOST
    1780.0
    [m]
    DC
    GEOST
    1790.0
    [m]
    DC
    GEOST
    1809.0
    [m]
    DC
    GEOST
    1827.0
    [m]
    DC
    GEOST
    1839.0
    [m]
    DC
    GEOST
    1854.0
    [m]
    DC
    GEOST
    1869.0
    [m]
    DC
    GEOST
    1884.0
    [m]
    DC
    GEOST
    1899.0
    [m]
    DC
    GEOST
    1914.0
    [m]
    DC
    GEOST
    1926.0
    [m]
    DC
    GEOST
    1944.0
    [m]
    DC
    GEOST
    1959.0
    [m]
    DC
    GEOST
    1974.0
    [m]
    DC
    GEOST
    1986.0
    [m]
    DC
    GEOST
    2001.0
    [m]
    DC
    GEOST
    2019.0
    [m]
    DC
    GEOST
    2034.0
    [m]
    DC
    GEOST
    2049.0
    [m]
    DC
    GEOST
    2064.0
    [m]
    DC
    GEOST
    2079.0
    [m]
    DC
    GEOST
    2100.0
    [m]
    DC
    GEOST
    2130.0
    [m]
    DC
    GEOST
    2160.0
    [m]
    DC
    GEOST
    2190.0
    [m]
    DC
    GEOST
    2220.0
    [m]
    DC
    GEOST
    2250.0
    [m]
    DC
    GEOST
    2280.0
    [m]
    DC
    GEOST
    2310.0
    [m]
    DC
    GEOST
    2340.0
    [m]
    DC
    GEOST
    2370.0
    [m]
    DC
    GEOST
    2400.0
    [m]
    DC
    GEOST
    2430.0
    [m]
    DC
    GEOST
    2460.0
    [m]
    DC
    GEOST
    2490.0
    [m]
    DC
    GEOST
    2520.0
    [m]
    DC
    GEOST
    2550.0
    [m]
    DC
    GEOST
    2580.0
    [m]
    DC
    GEOST
    2610.0
    [m]
    DC
    GEOST
    2640.0
    [m]
    DC
    GEOST
    2670.0
    [m]
    DC
    GEOST
    2700.0
    [m]
    DC
    GEOST
    2730.0
    [m]
    DC
    GEOST
    2760.0
    [m]
    DC
    GEOST
    2790.0
    [m]
    DC
    GEOST
    2820.0
    [m]
    DC
    GEOST
    2850.0
    [m]
    DC
    GEOST
    2880.0
    [m]
    DC
    GEOST
    2909.0
    [m]
    DC
    GEOST
    2939.0
    [m]
    DC
    GEOST
    2969.0
    [m]
    DC
    GEOST
    2999.0
    [m]
    DC
    GEOST
    3005.0
    [m]
    DC
    GEOST
    3011.0
    [m]
    DC
    GEOST
    3017.0
    [m]
    DC
    GEOST
    3026.0
    [m]
    DC
    GEOST
    3029.0
    [m]
    C
    GEOST
    3033.0
    [m]
    C
    GEOST
    3038.0
    [m]
    C
    GEOST
    3042.0
    [m]
    C
    GEOST
    3045.9
    [m]
    C
    GEOST
    3050.0
    [m]
    C
    GEOST
    3053.3
    [m]
    C
    GEOST
    3055.0
    [m]
    SWC
    GEOST
    3060.0
    [m]
    SWC
    GEOST
    3070.0
    [m]
    SWC
    GEOST
    3080.0
    [m]
    DC
    GEOST
    3089.0
    [m]
    DC
    GEOST
    3110.0
    [m]
    SWC
    GEOST
    3115.0
    [m]
    SWC
    GEOST
    3120.0
    [m]
    SWC
    GEOST
    3125.0
    [m]
    SWC
    GEOST
    3130.0
    [m]
    SWC
    GEOST
    3140.0
    [m]
    SWC
    GEOST
    3150.0
    [m]
    C
    GEOST
    3160.0
    [m]
    SWC
    GEOST
    3171.0
    [m]
    SWC
    GEOST
    3185.0
    [m]
    SWC
    GEOST
    3194.0
    [m]
    DC
    GEOST
    3203.0
    [m]
    DC
    GEOST
    3212.5
    [m]
    SWC
    GEOST
    3221.0
    [m]
    DC
    GEOST
    3236.0
    [m]
    SWC
    GEOST
    3245.0
    [m]
    DC
    GEOST
    3257.0
    [m]
    DC
    GEOST
    3269.0
    [m]
    DC
    GEOST
    3281.0
    [m]
    DC
    GEOST
    3293.0
    [m]
    DC
    GEOST
    3305.0
    [m]
    DC
    GEOST
    3317.0
    [m]
    DC
    GEOST
    3331.0
    [m]
    SWC
    GEOST
    3341.0
    [m]
    DC
    GEOST
    3355.0
    [m]
    SWC
    GEOST
    3363.8
    [m]
    C
    GEOST
    3364.2
    [m]
    C
    GEOST
    3376.7
    [m]
    C
    GEOST
    3379.3
    [m]
    C
    GEOST
    3382.3
    [m]
    C
    GEOST
    3390.2
    [m]
    C
    GEOST
    3394.3
    [m]
    C
    GEOST
    3398.9
    [m]
    C
    GEOST
    3403.8
    [m]
    C
    GEOST
    3405.5
    [m]
    C
    GEOST
    3408.7
    [m]
    C
    GEOST
    3410.5
    [m]
    C
    GEOST
    3422.0
    [m]
    DC
    GEOST
    3431.0
    [m]
    DC
    GEOST
    3440.0
    [m]
    DC
    GEOST
    3449.0
    [m]
    DC
    GEOST
    3458.0
    [m]
    DC
    GEOST
    3467.0
    [m]
    DC
    GEOST
    3476.0
    [m]
    DC
    GEOST
    3485.0
    [m]
    DC
    GEOST
    3496.0
    [m]
    SWC
    GEOST
    3507.0
    [m]
    SWC
    GEOST
    3515.0
    [m]
    DC
    GEOST
    3524.0
    [m]
    SWC
    GEOST
    3533.0
    [m]
    DC
    GEOST
    3545.0
    [m]
    SWC
    GEOST
    3555.0
    [m]
    SWC
    GEOST
    3557.0
    [m]
    SWC
    GEOST
    3563.0
    [m]
    SWC
    GEOST
    3568.0
    [m]
    SWC
    GEOST
    3573.0
    [m]
    SWC
    GEOST
    3584.0
    [m]
    DC
    GEOST
    3596.0
    [m]
    DC
    GEOST
    3603.0
    [m]
    DC
    STATO
    3610.0
    [m]
    SWC
    GEOST
    3620.0
    [m]
    DC
    GEOST
    3629.0
    [m]
    DC
    STATO
    3635.0
    [m]
    DC
    STATO
    3640.0
    [m]
    DC
    GEOST
    3640.0
    [m]
    DC
    STATO

  • 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
    TEST1
    3371.20
    3373.20
    28.06.1992 - 15:00
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.55
    pdf
    0.60
    pdf
    1.23
    pdf
    1.79
    pdf
    0.28

  • 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
    2.10
    pdf
    21.90

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3371
    0
    14.3
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    14.000
    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
    836
    161490
    0.861
    0.685
    194

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    825
    3574
    CORGUN
    3055
    3634
    DIFL ACL GR
    1056
    2087
    DIFL ACL GR CAL
    2097
    3637
    DIP
    3215
    3637
    DLL MLL GR
    2993
    3637
    FMT GR
    3131
    3553
    MWD
    159
    3640
    VSP
    139
    3570
    ZDL CNL GR
    2993
    3636

  • 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
    220.0
    36
    222.0
    0.00
    LOT
    INTERM.
    20
    1056.0
    26
    1058.0
    1.60
    LOT
    INTERM.
    13 3/8
    2100.0
    17 1/2
    2103.0
    1.76
    LOT
    LINER
    7
    2838.0
    8 1/2
    3625.0
    0.00
    LOT
    INTERM.
    9 5/8
    2994.0
    12 1/4
    2997.0
    1.97
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    826
    1.03
    10.0
    WATER BASED
    947
    1.03
    16.0
    WATER BASED
    1171
    1.30
    20.0
    WATER BASED
    1445
    1.30
    23.0
    WATER BASED
    1737
    1.30
    25.0
    WATER BASED
    1918
    1.30
    27.0
    WATER BASED
    2015
    1.30
    26.0
    WATER BASED
    2115
    1.30
    27.0
    WATER BASED
    2241
    1.35
    27.0
    WATER BASED
    2350
    1.35
    25.0
    WATER BASED
    2396
    1.39
    27.0
    WATER BASED
    2451
    1.39
    27.0
    WATER BASED
    2612
    1.39
    28.0
    WATER BASED
    2661
    1.39
    28.0
    WATER BASED
    2774
    1.39
    29.0
    WATER BASED
    2825
    1.45
    31.0
    WATER BASED
    2880
    1.50
    32.0
    WATER BASED
    3010
    1.54
    27.0
    WATER BASED
    3050
    1.47
    26.0
    WATER BASED
    3359
    1.56
    28.0
    WATER BASED
    3363
    1.47
    22.0
    WATER BASED
    3426
    1.47
    21.0
    WATER BASED
    3586
    1.47
    21.0
    WATER BASED
    3640
    1.56
    31.0
    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
    Document name
    Document format
    Document size [MB]
    pdf
    0.22