Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
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6406/9-1

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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.
    6406/9-1
    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).
    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
    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
    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.
    6406/9-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    HWE95m:inline 4340 & xline 1541.6
    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.
    A/S Norske Shell
    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.
    1077-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.
    353
    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,
    15.06.2004
    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.
    02.06.2005
    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.
    02.06.2007
    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.
    21.12.2007
    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.
    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.
    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.
    ILE 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.
    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.
    TOFTE FM
    3rd level with HC, age
    Age of lithostratigraphic unit, 3rd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    EARLY JURASSIC
    3rd level with HC, formation
    Name of lithostartigraphic unit, 3rd 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.
    TILJE FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.5
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    308.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    5080.0
    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).
    5077.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    7
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    184
    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.
    64° 26' 46.85'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    6° 48' 55.23'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7148739.49
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    394862.07
    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.
    4927

  • Wellbore history
    General
    Well 6406/9-1 is located in the southern Haltenbanken area, offshore Mid Norway. The well was drilled near the crest of the prospect structure, a rotated fault block. The primary objective of well 6406/9-1 was to test the hydrocarbon potential in the Middle to Early Jurassic reservoirs of the Garn, Ile, Ror/Tofte and Tilje Formations, and to production test possible hydrocarbon occurrences.
    Operations and results
    Wildcat well 6406/9-1 was spudded with the semi-submersible installation Transocean Leader on 15 June 2004 and drilled to TD at 5080 m in Early Jurassic sediments of the Åre Formation. The well was a high temperature / high pressure well, with a formation temperature of ca 184 deg C at TD, according to DST and wire line measurements. The well was drilled with seawater and bentonite sweeps down to 1375 m, with Glydril mud from 1375 m to 2893 m, and with Paratherm oil based (paraffin base) mud from 2893 m to TD. Shallow gas was neither predicted nor encountered. Due to labour disputes and bad weather the well was not terminated until 2 June 2005.
    The Jurassic Ile, Tofte, Tilje and Åre Formations were all found to be entirely gas bearing. The Garn Formation, a reservoir interval in some of the neighbouring wells, was found to be shaled out here. The presence of hydrocarbons was confirmed by RCI samples in the Ile, Tofte and Tilje. The discovery appeared to be a stacked reservoir sequence with up to 5 different compartments with small pressure differences between the formations. All reservoirs were intersected in Gas-Down-To situations. The total hydrocarbon column in-well was 492.5 m. The gas was significantly drier than expected when compared to other accumulations in the area. Reservoir quality was very variable with large sections of low/medium permeability, but also two distinct sands of exceedingly high quality.
    A total of four cores were taken from the Early and Middle Jurassic intervals. The first core was taken from the upper part of the Ile Formation and is 13.44 m long. Operations were cut short because of jamming of the core, possibly due to junk in the hole. The second core was taken from the lower part of the Ile Formation and is 27.7 m long. A 26 m core was taken from the Tofte Formation as well as a 28.47 m core from the Lower Ror Formation. The RCI fluid samples sampled gas from four depths: 4625.5 m (Ile), 4682.1 m (Tofte), 4908.5 m (upper Tilje), and 5021.9 m (Tilje).
    The well was permanently abandoned on 2 June 2005 as a gas discovery.
    Testing
    Two full well tests were performed aimed at the most promising Formations: the lower Tilje and the lower Ile. The perforation intervals were limited and selected to include the two high quality sands.
    DST 1 tested the interval 4989.2 - 5029.75 m in the lower Tilje Formation. It produced gas at a rate of 1410000 Sm3/day and with a condensate/gas ratio of less than 1.0E-6 Sm3/Sm3 (GOR > 1000000 Sm3/Sm3). The CO2 content was 7-8% (vol) and the H2S content was 20 - 30 ppm on average. DST 2 tested the interval 4619 - 4633.7 m in the lower Ile Formation. It produced gas at a rate of 770000 Sm3/day and with a condensate/gas ratio of ca 25E-6 Sm3/Sm3 (GOR ca 40000 Sm3/Sm3). The CO2 content was 7-8% (vol), and the H2S content was 15-18 ppm on average.
    Maximum temperatures recorded were 182 and 172 deg C in DST 1 and DST 2, respectively.

  • 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]
    1390.00
    5079.00

  • 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
    4546.5
    4559.9
    [m ]
    2
    4591.0
    4618.8
    [m ]
    3
    4684.0
    4710.1
    [m ]
    4
    4784.0
    4812.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    95.8
    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
    1390.0
    [m]
    DC
    ICHRON
    1430.0
    [m]
    DC
    ICHRON
    1490.0
    [m]
    DC
    ICHRON
    1530.0
    [m]
    DC
    ICHRON
    1560.0
    [m]
    DC
    ICHRON
    1600.0
    [m]
    DC
    ICHRON
    1660.0
    [m]
    DC
    ICHRON
    1680.0
    [m]
    DC
    ICHRON
    1720.0
    [m]
    DC
    ICHRON
    1780.0
    [m]
    DC
    ICHRON
    1800.0
    [m]
    DC
    ICHRON
    1840.0
    [m]
    DC
    ICHRON
    1880.0
    [m]
    DC
    ICHRON
    1910.0
    [m]
    DC
    ICHRON
    1940.0
    [m]
    DC
    ICHRON
    1990.0
    [m]
    DC
    ICHRON
    2020.0
    [m]
    DC
    ICHRON
    2050.0
    [m]
    DC
    ICHRON
    2080.0
    [m]
    DC
    ICHRON
    2110.0
    [m]
    DC
    ICHRON
    2140.0
    [m]
    DC
    ICHRON
    2180.0
    [m]
    DC
    ICHRON
    2200.0
    [m]
    DC
    ICHRON
    2220.0
    [m]
    DC
    ICHRON
    2250.0
    [m]
    DC
    ICHRON
    2265.0
    [m]
    DC
    ICHRON
    2275.0
    [m]
    DC
    ICHRON
    2280.0
    [m]
    DC
    ICHRON
    2295.0
    [m]
    DC
    ICHRON
    2305.0
    [m]
    DC
    ICHRON
    2315.0
    [m]
    DC
    ICHRON
    2320.0
    [m]
    DC
    ICHRON
    2325.0
    [m]
    DC
    ICHRON
    2335.0
    [m]
    DC
    ICHRON
    2340.0
    [m]
    DC
    ICHRON
    2350.0
    [m]
    DC
    ICHRON
    2360.0
    [m]
    DC
    ICHRON
    2365.0
    [m]
    DC
    ICHRON
    2370.0
    [m]
    DC
    ICHRON
    2375.0
    [m]
    DC
    ICHRON
    2380.0
    [m]
    DC
    ICHRON
    2385.0
    [m]
    DC
    ICHRON
    2390.0
    [m]
    DC
    ICHRON
    2395.0
    [m]
    DC
    ICHRON
    2400.0
    [m]
    DC
    ICHRON
    3155.0
    [m]
    DC
    ICHRON
    3180.0
    [m]
    DC
    ICHRON
    3285.0
    [m]
    DC
    ICHRON
    3320.0
    [m]
    DC
    ICHRON
    3330.0
    [m]
    DC
    ICHRON
    3350.0
    [m]
    DC
    ICHRON
    3400.0
    [m]
    DC
    ICHRON
    3420.0
    [m]
    DC
    ICHRON
    3460.0
    [m]
    DC
    ICHRON
    3490.0
    [m]
    DC
    ICHRON
    3530.0
    [m]
    DC
    ICHRON
    3550.0
    [m]
    DC
    ICHRON
    3570.0
    [m]
    DC
    ICHRON
    3780.0
    [m]
    DC
    ICHRON
    3790.0
    [m]
    DC
    ICHRON
    3805.0
    [m]
    DC
    ICHRON
    3820.0
    [m]
    DC
    ICHRON
    3850.0
    [m]
    DC
    ICHRON
    3865.0
    [m]
    DC
    ICHRON
    3875.0
    [m]
    DC
    ICHRON
    3890.0
    [m]
    DC
    ICHRON
    3905.0
    [m]
    DC
    ICHRON
    3930.0
    [m]
    DC
    ICHRON
    3940.0
    [m]
    DC
    ICHRON
    4068.0
    [m]
    DC
    ICHRON
    4071.0
    [m]
    DC
    ICHRON
    4080.0
    [m]
    DC
    ICHRON
    4095.0
    [m]
    DC
    ICHRON
    4107.0
    [m]
    DC
    ICHRON
    4125.0
    [m]
    DC
    ICHRON
    4131.0
    [m]
    DC
    ICHRON
    4137.0
    [m]
    DC
    ICHRON
    4143.0
    [m]
    DC
    ICHRON
    4155.0
    [m]
    DC
    ICHRON
    4161.0
    [m]
    DC
    ICHRON
    4173.0
    [m]
    DC
    ICHRON
    4185.0
    [m]
    DC
    ICHRON
    4197.0
    [m]
    DC
    ICHRON
    4203.0
    [m]
    DC
    ICHRON
    4209.0
    [m]
    DC
    ICHRON
    4215.0
    [m]
    DC
    ICHRON
    4221.0
    [m]
    DC
    ICHRON
    4227.0
    [m]
    DC
    ICHRON
    4233.0
    [m]
    DC
    ICHRON
    4239.0
    [m]
    DC
    ICHRON
    4242.0
    [m]
    DC
    ICHRON
    4248.0
    [m]
    DC
    ICHRON
    4251.0
    [m]
    DC
    ICHRON
    4254.0
    [m]
    DC
    ICHRON
    4263.0
    [m]
    DC
    ICHRON
    4266.0
    [m]
    DC
    ICHRON
    4269.0
    [m]
    DC
    ICHRON
    4272.0
    [m]
    DC
    ICHRON
    4281.0
    [m]
    DC
    ICHRON
    4290.0
    [m]
    DC
    ICHRON
    4296.0
    [m]
    DC
    ICHRON
    4335.0
    [m]
    DC
    ICHRON
    4374.0
    [m]
    DC
    ICHRON
    4398.0
    [m]
    DC
    ICHRON
    4419.0
    [m]
    DC
    ICHRON
    4422.0
    [m]
    DC
    ICHRON
    4428.0
    [m]
    DC
    ICHRON
    4434.0
    [m]
    DC
    ICHRON
    4437.0
    [m]
    DC
    ICHRON
    4443.0
    [m]
    DC
    ICHRON
    4449.0
    [m]
    DC
    ICHRON
    4455.0
    [m]
    DC
    ICHRON
    4461.0
    [m]
    DC
    ICHRON
    4470.0
    [m]
    DC
    ICHRON
    4476.0
    [m]
    DC
    ICHRON
    4488.0
    [m]
    DC
    ICHRON
    4506.0
    [m]
    DC
    ICHRON
    4527.0
    [m]
    DC
    ICHRON
    4536.0
    [m]
    DC
    ICHRON
    4542.0
    [m]
    DC
    ICHRON
    4550.3
    [m]
    C
    ICHRON
    4556.8
    [m]
    C
    ICHRON
    4559.3
    [m]
    C
    ICHRON
    4569.0
    [m]
    DC
    ICHRON
    4579.7
    [m]
    C
    ICHRON
    4591.2
    [m]
    C
    ICHRON
    4595.2
    [m]
    C
    ICHRON
    4601.5
    [m]
    C
    ICHRON
    4605.4
    [m]
    C
    ICHRON
    4608.3
    [m]
    C
    ICHRON
    4614.8
    [m]
    C
    ICHRON
    4685.3
    [m]
    C
    ICHRON
    4692.7
    [m]
    C
    ICHRON
    4698.7
    [m]
    C
    ICHRON
    4702.4
    [m]
    C
    ICHRON
    4706.5
    [m]
    C
    ICHRON
    4785.3
    [m]
    C
    ICHRON
    4788.5
    [m]
    C
    ICHRON
    4792.6
    [m]
    C
    ICHRON
    4794.6
    [m]
    C
    ICHRON
    4798.5
    [m]
    C
    ICHRON
    4803.5
    [m]
    C
    ICHRON
    4807.5
    [m]
    C
    ICHRON
    4808.5
    [m]
    C
    ICHRON
    4812.3
    [m]
    C
    ICHRON

  • 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
    CONDENSATE
    30.04.2005 - 09:00
    YES

  • Lithostratigraphy

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    4964
    5004
    22.0
    2.0
    4619
    4634
    19.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    23.000
    43
    2.0
    28.000
    49
    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
    1410000
    2.0
    1440000

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT DSI IS EMS GR ACTS GPIT
    2777
    4308
    AIT DSI IS EMS GR ACTS GPIT
    4291
    5058
    CBL
    3096
    3813
    CBL
    3510
    5047
    CMR LDS APS ECS HGNS ACTS ECRD
    4291
    5058
    EARTH IMAGER
    4300
    5075
    LDS APS HGNS ACTS ECRD
    2777
    4308
    MFC READ
    326
    4184
    MFC READ
    4100
    5020
    MWD LWD - ARC
    1367
    4291
    MWD LWD - ARC
    4541
    4591
    MWD LWD - ARC
    4865
    5068
    MWD LWD - ARC TST6 STETO
    4289
    4541
    MWD LWD - DVD ECOSCOPE
    4291
    4878
    MWD LWD - GR
    346
    1363
    RCI MINI DST
    4522
    4620
    RCI MINI DST
    4563
    4684
    RCI MINI DST
    4908
    4909
    RCI MINI DST
    5007
    5022
    RCI PRESSURE
    4500
    5024
    RCI SAMPLE
    4625
    5022
    RCOR
    4684
    5023
    VSP
    1500
    5075

  • 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
    417.0
    36
    417.0
    0.00
    LOT
    SURF.COND.
    20
    1375.0
    26
    1375.0
    1.74
    LOT
    INTERM.
    16
    2243.0
    17 1/2
    2244.0
    1.89
    LOT
    INTERM.
    13 3/8
    2873.0
    14 7/8
    2873.0
    1.95
    LOT
    INTERM.
    9 5/8
    4365.0
    12 1/4
    4365.0
    2.13
    LOT
    LINER
    7
    5080.0
    8 1/2
    5080.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    405
    1.05
    SPUD MUD
    644
    1.05
    SPUD MUD
    1381
    1.55
    19.0
    GLYDRIL MUD
    1820
    1.82
    21.0
    GLYDRILL WBM
    2248
    1.70
    30.0
    GLYDRIL MUD
    2793
    1.75
    32.0
    GLYDRIL MUD
    3251
    1.77
    30.0
    PHARATERM
    3544
    1.79
    32.0
    PHARATERM
    4075
    1.87
    40.0
    PARATHERM
    4306
    1.87
    38.0
    PARATHERM
    4546
    1.89
    32.0
    PARATHERM
    4591
    1.88
    36.0
    PARATHERM
    4710
    1.90
    40.0
    PARATHERM
    4718
    1.89
    40.0
    PARATHERM
    4880
    1.88
    40.0
    PARATHERM
    5063
    1.89
    43.0
    PARATHERM
    5080
    1.88
    49.0
    PARATHERM

  • 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