Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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6406/2-3

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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.
    6406/2-3
    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.
    6406/2-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    HWM94-row 2802 & col 1022
    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.
    Saga Petroleum ASA
    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.
    851-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.
    235
    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,
    24.08.1996
    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.
    15.04.1997
    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.
    15.04.1999
    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.
    29.05.2002
    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/CONDENSATE
    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.
    24.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    372.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    5258.0
    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).
    5255.9
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    6.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    188
    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° 58' 40.8'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    6° 24' 37.71'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7208685.60
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    377806.71
    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.
    2849

  • Wellbore history
    General
    The main objective of well 6406/2-3 was to test the hydrocarbon potential of the Kristin structure with respect to Middle and Lower Jurassic sandstones, and to test the reservoir qualities at great depths (prognosed TD 5600 m). The secondary target for the well was the seismically prognosed Aptian sandstone, which was interpreted to form either a stratigraphic trap or a structural closure above the crest of the Kristin structure. The Kristin structure is a fault bounded horst block, somewhat eroded in the western part, with only minor internal faulting. The Kristin structure extends into PL 134 area, and the well location was agreed between PL 199 and PL 134. PL 134 contributed with 20% of the expenses to the joint well. Hydrocarbon leakage due to the prognosed high pore pressure in the Kristin structure was regarded the primary risk for the trap, knowing that all high pressured wells drilled in this area had been dry.
    Operations and results
    Wildcat well 6406/2-3 was spudded 24 August 1996 with the semi-submersible rig "Transocean Arctic", and reached TD 47 m into the Åre Formation at 5258 m on 26 January 1997. Due to well control problems starting 23 September a technical side-track was started 23 October from the 13 3/8" casing shoe at 2834 m, and the suffix T2 was added to the well designation (6406/2-3T2). During intermediate logging in 8 1/2" section a FMT tool got stuck, and a second sidetrack had to be done from the 9 5/8" casing shoe at 4538 m. The second sidetrack, 6406/2-3T3, was started 6 December 1996. Shallow gas caused no operational problems. The well was drilled with seawater swept with high viscosity mud down to 1413 m. ANCO 2000 water based mud with ANCO 208 glycol additive was used from 1413 to 2848 m, while ANCOVERT oil based mud was used from 2848 m to TD.

    The main result of well 6406/2-3 was the discovery of gas/condensate in Garn and Ile Formations as proven by production tests, fluid samples, cores and logs. Both Garn and Ile Formations were filled with gas/condensate throughout the units in the well position. Tofte, Tilje and Åre Formations were water bearing, except for a possible hydrocarbon-water transition zone in the uppermost parts of the Tofte Formation. The prognosed Lower Cretaceous Aptian sandstone was not encountered in the well. The well also penetrated Cretaceous sandstones (Lysing and Lange sandstones) that were interpreted to be water bearing with some shows and with poor reservoir qualities.

    Reservoir qualities of the Middle Jurassic sandstones of the Garn and Ile Formations are in general very good, ranging from fair to excellent. The reservoir properties of the Garn Formation are best in the upper part, with porosities up to 20% and permeabilities up to 1 Darcy. The properties of the Ile Formation are best in the lower part and in one central zone of the unit, with porosities up to 30% and permeabilities up to 12 Darcy. The reservoir qualities of the Tofte, Tilje and Åre Formations are more variable, with Tofte Formation ranging from fair to good, Tilje Formation ranging from poor to good, and Åre Formation having poor reservoir qualities.

    Pore pressures of the Jurassic units were very high, reaching a maximum gradient of 1.97 g/cc EMW in upper part of the Garn Formation.

    Ten cores were cut from Lange, Garn, Ile, Tofte and Tilje Formations, totaling 202.95 m, with a recovery of 198.35 m. Two cores were cut in the Cretaceous Lange Formation. Fluid samples containing gas and condensate were collected in the Garn and Ile Formations, whilst water samples were collected in the Tofte, Tilje and Åre Formations. The well was plugged and abandoned as a gas/condensate discovery.
    Testing
    Two zones in the well were successfully production tested. Test # 1 in lower Ile Formation (4806 - 4832 m) produced 892 000 Sm3/D gas and 890 Sm3/D condensate (GOR: 1003 Sm3/Sm3). Test # 2 in upper Garn Formation (4629 - 4654.4 m) produced 777 000 Sm3/D gas and 1048 Sm3/D condensate (GOR: 744 Sm3/Sm3).

  • 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]
    1420.00
    5256.00

  • 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
    4380.0
    4401.5
    [m ]
    2
    4402.0
    4425.5
    [m ]
    3
    4633.0
    4639.0
    [m ]
    4
    4642.0
    4650.8
    [m ]
    5
    4651.5
    4661.5
    [m ]
    6
    4661.5
    4671.0
    [m ]
    7
    4671.0
    4699.4
    [m ]
    8
    4699.3
    4727.8
    [m ]
    9
    4754.0
    4777.5
    [m ]
    10
    4777.5
    4806.1
    [m ]
    11
    4898.0
    4925.4
    [m ]
    12
    5038.0
    5064.9
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    242.6
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 4380-4385m
    Core photo at depth: 4385-4390m
    Core photo at depth: 4390-4395m
    Core photo at depth: 4395-4400m
    Core photo at depth: 4400-4401m
    4380-4385m
    4385-4390m
    4390-4395m
    4395-4400m
    4400-4401m
    Core photo at depth: 4402-4407m
    Core photo at depth: 4407-4412m
    Core photo at depth: 4412-4417m
    Core photo at depth: 4417-4422m
    Core photo at depth: 4422-4423m
    4402-4407m
    4407-4412m
    4412-4417m
    4417-4422m
    4422-4423m
    Core photo at depth: 4633-4638m
    Core photo at depth: 4638-4640m
    Core photo at depth: 4642-4647m
    Core photo at depth: 4647-4650m
    Core photo at depth: 4651-4656m
    4633-4638m
    4638-4640m
    4642-4647m
    4647-4650m
    4651-4656m
    Core photo at depth: 4656-4661m
    Core photo at depth: 4661-4662m
    Core photo at depth: 4661-4666m
    Core photo at depth: 4666-4671m
    Core photo at depth: 4676-4681m
    4656-4661m
    4661-4662m
    4661-4666m
    4666-4671m
    4676-4681m
    Core photo at depth: 4681-4686m
    Core photo at depth: 4686-4691m
    Core photo at depth: 4691-4696m
    Core photo at depth: 4696-4699m
    Core photo at depth: 4699-4704m
    4681-4686m
    4686-4691m
    4691-4696m
    4696-4699m
    4699-4704m
    Core photo at depth: 4704-4709m
    Core photo at depth: 4709-4714m
    Core photo at depth: 4714-4719m
    Core photo at depth: 4719-4724m
    Core photo at depth: 4724-4727m
    4704-4709m
    4709-4714m
    4714-4719m
    4719-4724m
    4724-4727m
    Core photo at depth: 4754-4759m
    Core photo at depth: 4759-4764m
    Core photo at depth: 4764-4769m
    Core photo at depth: 4769-4774m
    Core photo at depth: 4774-4777m
    4754-4759m
    4759-4764m
    4764-4769m
    4769-4774m
    4774-4777m
    Core photo at depth: 4777-4782m
    Core photo at depth: 4782-4787m
    Core photo at depth: 4787-4792m
    Core photo at depth: 4792-4797m
    Core photo at depth: 4797-4802m
    4777-4782m
    4782-4787m
    4787-4792m
    4792-4797m
    4797-4802m
    Core photo at depth: 4802-4806m
    Core photo at depth: 4898-4903m
    Core photo at depth: 4903-4908m
    Core photo at depth: 4908-4913m
    Core photo at depth: 4913-4918m
    4802-4806m
    4898-4903m
    4903-4908m
    4908-4913m
    4913-4918m
    Core photo at depth: 4918-4923m
    Core photo at depth: 4923-4925m
    Core photo at depth: 5038-5043m
    Core photo at depth: 5043-5048m
    Core photo at depth: 5048-5053m
    4918-4923m
    4923-4925m
    5038-5043m
    5043-5048m
    5048-5053m
    Core photo at depth: 5053-5058m
    Core photo at depth: 5058-5063m
    Core photo at depth: 5063-5065m
    Core photo at depth:  
    Core photo at depth:  
    5053-5058m
    5058-5063m
    5063-5065m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1430.0
    [m]
    DC
    STRAT
    1450.0
    [m]
    DC
    STRAT
    1470.0
    [m]
    DC
    STRAT
    1490.0
    [m]
    DC
    STRAT
    1510.0
    [m]
    DC
    STRAT
    1530.0
    [m]
    DC
    STRAT
    1550.0
    [m]
    DC
    STRAT
    1570.0
    [m]
    DC
    STRAT
    1590.0
    [m]
    DC
    STRAT
    1610.0
    [m]
    DC
    STRAT
    1630.0
    [m]
    DC
    STRAT
    1650.0
    [m]
    DC
    STRAT
    1670.0
    [m]
    DC
    STRAT
    1690.0
    [m]
    DC
    STRAT
    1710.0
    [m]
    DC
    STRAT
    1730.0
    [m]
    DC
    STRAT
    1750.0
    [m]
    DC
    STRAT
    1770.0
    [m]
    DC
    STRAT
    1790.0
    [m]
    DC
    STRAT
    1810.0
    [m]
    DC
    STRAT
    1830.0
    [m]
    DC
    STRAT
    1850.0
    [m]
    DC
    STRAT
    1870.0
    [m]
    DC
    STRAT
    1890.0
    [m]
    DC
    STRAT
    1910.0
    [m]
    DC
    STRAT
    1930.0
    [m]
    DC
    STRAT
    1950.0
    [m]
    DC
    STRAT
    1970.0
    [m]
    DC
    STRAT
    1990.0
    [m]
    DC
    STRAT
    2010.0
    [m]
    DC
    STRAT
    2030.0
    [m]
    DC
    STRAT
    2050.0
    [m]
    DC
    STRAT
    2070.0
    [m]
    DC
    STRAT
    2090.0
    [m]
    DC
    STRAT
    2110.0
    [m]
    DC
    STRAT
    2130.0
    [m]
    DC
    STRAT
    2150.0
    [m]
    DC
    STRAT
    2170.0
    [m]
    DC
    STRAT
    2270.0
    [m]
    DC
    STRAT
    2290.0
    [m]
    DC
    STRAT
    2310.0
    [m]
    DC
    STRAT
    2330.0
    [m]
    DC
    STRAT
    2350.0
    [m]
    DC
    STRAT
    2370.0
    [m]
    DC
    STRAT
    2410.0
    [m]
    DC
    STRAT
    2430.0
    [m]
    DC
    STRAT
    2470.0
    [m]
    DC
    STRAT
    2510.0
    [m]
    DC
    STRAT
    2530.0
    [m]
    DC
    STRAT
    2550.0
    [m]
    DC
    STRAT
    2570.0
    [m]
    DC
    STRAT
    2590.0
    [m]
    DC
    STRAT
    2610.0
    [m]
    DC
    STRAT
    2630.0
    [m]
    DC
    STRAT
    2650.0
    [m]
    DC
    STRAT
    2670.0
    [m]
    DC
    STRAT
    2690.0
    [m]
    DC
    STRAT
    2710.0
    [m]
    DC
    STRAT
    2730.0
    [m]
    DC
    STRAT
    2750.0
    [m]
    DC
    STRAT
    2770.0
    [m]
    DC
    STRAT
    2790.0
    [m]
    DC
    STRAT
    2810.0
    [m]
    DC
    STRAT
    2830.0
    [m]
    DC
    STRAT
    2850.0
    [m]
    DC
    STRAT
    2870.0
    [m]
    DC
    STRAT
    2900.0
    [m]
    DC
    STRAT
    3000.0
    [m]
    DC
    STRAT
    3100.0
    [m]
    DC
    STRAT
    3200.0
    [m]
    DC
    STRAT
    3300.0
    [m]
    DC
    STRAT
    3400.0
    [m]
    DC
    STRAT
    3500.0
    [m]
    DC
    STRAT
    3600.0
    [m]
    DC
    STRAT
    3700.0
    [m]
    DC
    STRAT
    3800.0
    [m]
    DC
    STRAT
    3900.0
    [m]
    DC
    STRAT
    4000.0
    [m]
    DC
    STRAT
    4099.0
    [m]
    DC
    STRAT
    4201.0
    [m]
    DC
    STRAT
    4300.0
    [m]
    DC
    STRAT
    4399.0
    [m]
    DC
    STRAT
    4501.0
    [m]
    DC
    STRAT
    4575.0
    [m]
    DC
    STRAT
    4635.0
    [m]
    DC
    STRAT

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.77

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.68
    pdf
    0.98
    pdf
    1.94
    pdf
    1.99
    pdf
    1.88
    pdf
    1.91
    pdf
    1.87
    pdf
    1.88
    pdf
    1.78
    pdf
    1.46

  • 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
    11.09
    pdf
    47.22

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    4832
    4806
    17.0
    2.0
    4654
    4629
    17.5
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    90.000
    89.000
    91.000
    167
    2.0
    88.000
    81.000
    89.000
    166
    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
    890
    892000
    0.791
    0.720
    1003
    2.0
    1048
    777000
    0.792
    0.720
    744

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DPIL MAC DSL
    4537
    4928
    DPIL MAC GR
    2833
    4545
    DPIL MAC GR
    4875
    5255
    DPIL MAC ZDL GR
    1405
    2845
    DPIL ZDL GR
    4512
    4654
    FMT GR
    3430
    4405
    FMT GR
    4626
    5257
    HEXDIP CBIL GR
    4537
    5243
    MRIL GR
    4550
    5255
    MWD - DIR
    395
    487
    MWD - GR RES DIR
    487
    5258
    RCOR GR
    3430
    4504
    SWC GR
    4578
    4957
    ZDL CN DSL
    4537
    5257
    ZDL CN GR
    2833
    4926

  • 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
    482.0
    36
    484.0
    0.00
    LOT
    INTERM.
    18 5/8
    1405.0
    20
    1407.0
    1.80
    LOT
    INTERM.
    13 3/8
    2834.0
    17 1/2
    2835.0
    1.96
    LOT
    INTERM.
    9 5/8
    4538.0
    12 1/4
    4540.0
    2.20
    LOT
    LINER
    7
    5258.0
    8 1/2
    5258.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    680
    1.03
    16.0
    SPUD MUD
    900
    1.03
    16.0
    SPUD MUD
    1413
    1.20
    18.0
    SPUD MUD
    1549
    1.30
    20.0
    KCL MUD
    2060
    1.45
    27.0
    KCL MUD
    2525
    1.72
    38.0
    KCL MUD
    2570
    1.72
    46.0
    KCL MUD
    2848
    1.72
    44.0
    KCL MUD
    2860
    1.82
    53.0
    OIL BASED
    2872
    1.82
    51.0
    OIL BASED
    3170
    1.80
    47.0
    OIL BASED
    3389
    1.50
    44.0
    OIL BASED
    3490
    1.80
    45.0
    OIL BASED
    3580
    1.57
    41.0
    OIL BASED
    3591
    1.80
    43.0
    OIL BASED
    3689
    1.57
    47.0
    OIL BASED
    3753
    1.80
    41.0
    OIL BASED
    3802
    1.82
    53.0
    OIL BASED
    3971
    1.64
    55.0
    OIL BASED
    3975
    1.67
    54.0
    OIL BASED
    4017
    1.67
    50.0
    OIL BASED
    4050
    1.67
    45.0
    OIL BASED
    4054
    1.67
    55.0
    OIL BASED
    4070
    1.67
    44.0
    OIL BASED
    4080
    1.80
    47.0
    OIL BASED
    4087
    1.81
    43.0
    OIL BASED
    4180
    1.78
    54.0
    OIL BASED
    4276
    1.80
    45.0
    OIL BASED
    4378
    1.80
    50.0
    OIL BASED
    4402
    1.80
    51.0
    OIL BASED
    4424
    1.80
    50.0
    OIL BASED
    4448
    1.81
    48.0
    OIL BASED
    4460
    1.78
    54.0
    OIL BASED
    4527
    1.81
    50.0
    OIL BASED
    4550
    1.81
    48.0
    OIL BASED
    4554
    1.89
    52.0
    OIL BASED
    4580
    2.00
    66.0
    OIL BASED
    4593
    1.82
    55.0
    OIL BASED
    4596
    1.82
    67.0
    OIL BASED
    4597
    2.00
    61.0
    OIL BASED
    4598
    2.00
    64.0
    OIL BASED
    4603
    2.00
    65.0
    OIL BASED
    4614
    2.00
    66.0
    OIL BASED
    4626
    2.06
    80.0
    OIL BASED
    4632
    2.00
    64.0
    OIL BASED
    4634
    2.00
    59.0
    OIL BASED
    4635
    2.00
    69.0
    OIL BASED
    4661
    2.00
    57.0
    OIL BASED
    4662
    2.06
    65.0
    OIL BASED
    4671
    2.06
    69.0
    OIL BASED
    4699
    2.06
    62.0
    OIL BASED
    4719
    2.06
    65.0
    OIL BASED
    4728
    2.06
    66.0
    OIL BASED
    4742
    2.06
    65.0
    OIL BASED
    4754
    2.06
    65.0
    OIL BASED
    4777
    2.06
    66.0
    OIL BASED
    4778
    2.06
    66.0
    OIL BASED
    4806
    2.06
    66.0
    OIL BASED
    4806
    2.06
    65.0
    OIL BASED
    4843
    2.06
    64.0
    OIL BASED
    4897
    2.06
    67.0
    OIL BASED
    4926
    2.06
    65.0
    OIL BASED
    4976
    2.06
    63.0
    OIL BASED
    5000
    2.06
    64.0
    OIL BASED
    5020
    2.06
    63.0
    OIL BASED
    5038
    2.06
    65.0
    OIL BASED
    5063
    2.06
    63.0
    OIL BASED
    5066
    2.06
    65.0
    OIL BASED
    5081
    2.06
    63.0
    OIL BASED
    5123
    2.06
    63.0
    OIL BASED
    5169
    2.06
    71.0
    OIL BASED
    5258
    2.06
    66.0
    OIL BASED
    5258
    2.06
    76.0
    OIL 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
    PDF
    0.27