Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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25.11.2024 - 01:30
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6506/12-11 S

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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.
    6506/12-11 S
    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.
    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.
    6506/12-11
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    3 D HWM-94: INLINE 4188 & CROSSLINE 1678
    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.
    849-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.
    92
    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,
    08.06.1996
    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.
    07.09.1996
    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.
    07.09.1998
    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.
    24.09.2002
    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.
    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.
    EARLY 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.
    TILJE 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.
    ÅRE FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    22.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    289.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    5268.0
    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).
    4843.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    33.2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    167
    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.
    65° 5' 7.2'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    6° 40' 54.75'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7220144.87
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    391047.42
    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.
    2795

  • Wellbore history
    General
    The well 6506/12-11 S was planned to be completed as a future producer. The main objectives of the well were to collect data on reservoir quality and fluid distribution, perform a long-term test to evaluate the continuity of the reservoir in the Tilje Formation, carry out an interference test between this well and an adjacent gas injector, 6506/11-5 S, and to investigate the effect of stimulation by fracturing on well productivity.
    Operations and results
    The deviated appraisal well 6506/12-11 S was spudded on 8 June 1996 with the semi-submersible installation "Transocean Searcher" and drilled to a TD of 5268 m (4842.5 m TVD), approximately 60 m into the Åre Formation. Drilling was interrupted for 11 days by a labour conflict. The well was drilled with seawater and high viscosity pills down to 621 m, Anco 2000 mud with glycol from 621 to 2242 m, and with oil based Anco vert from 2242 m to TD. The well penetrated the top of the Tilje Formation and the Åre Formation, respectively, 18 m and 9.5 m shallower than prognosed. Both the Tilje and the Åre Formations were hydrocarbon bearing. Two tests were performed, one in Åre and one in Tilje. In addition, a minifrac test was performed in the Åre Formation. Six cores (196 m, 187 m recovered) were cut in the Tilje and Åre Formations. Three MDT wireline samples were taken in the well, one from each of the formations Åre, Tilje, and Garn. The samples from the Tilje and Åre Formations contained oil and gas, while the sample from the Garn Formation, contained formation water. A 7" liner was run and cemented on 9 August 1996. After testing, well 6506/12-11 S was suspended on 7 September 1996 as an oil appraisal well. The well was re-entered (6506/12-11 SR) on 11 November 1996 for an extended test. Well 6506/12-11 SR was suspended as an oil appraisal well on 1 February 1997 and re-classed to development well 6506/12-I-4 H.
    Testing
    Test 1 in 6506/12-11 S was carried out over the interval 5226 - 5235.5 m in Åre and flowed with a rate of 685 Sm3/day oil and 453000 Sm3/day gas. Test 2 in 6506/12-11 S was carried out over the interval 5197.5 - 5206.5 m in Tilje and flowed with a rate of 470 Sm3/day oil and 173900 Sm3/day gas. The testing in 6506/12-11 SR consisted of a prefrac test in Tilje 1.1 followed by a massiv hydraulic stimulation and clean up with coiled tubing prior to start the extended well test. Most of the produced oil during the well test was recovered by the floating production, storage and testing vessel "Crystal Sea". When offloading Crystal Sea at Mongstad, the oil was burnt off at the installation.

  • 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]
    3640.00
    5267.00

  • 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
    5041.0
    5054.7
    [m ]
    2
    5063.0
    5116.8
    [m ]
    3
    5117.0
    5146.0
    [m ]
    4
    5146.0
    5166.8
    [m ]
    5
    5167.0
    5212.7
    [m ]
    6
    5212.7
    5237.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    187.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 5041-5046m
    Core photo at depth: 5046-5051m
    Core photo at depth: 5051-5054m
    Core photo at depth: 5063-5068m
    Core photo at depth: 5068-5073m
    5041-5046m
    5046-5051m
    5051-5054m
    5063-5068m
    5068-5073m
    Core photo at depth: 5073-5078m
    Core photo at depth: 5078-5083m
    Core photo at depth: 5083-5088m
    Core photo at depth: 5088-5093m
    Core photo at depth: 5093-5098m
    5073-5078m
    5078-5083m
    5083-5088m
    5088-5093m
    5093-5098m
    Core photo at depth: 5098-5103m
    Core photo at depth: 5103-5108m
    Core photo at depth: 5108-5113m
    Core photo at depth: 5113-5117m
    Core photo at depth: 5117-5122m
    5098-5103m
    5103-5108m
    5108-5113m
    5113-5117m
    5117-5122m
    Core photo at depth: 5122-5127m
    Core photo at depth: 5127-5132m
    Core photo at depth: 5132-5137m
    Core photo at depth: 5137-5142m
    Core photo at depth: 5142-5146m
    5122-5127m
    5127-5132m
    5132-5137m
    5137-5142m
    5142-5146m
    Core photo at depth: 5146-5151m
    Core photo at depth: 5151-5156m
    Core photo at depth: 5156-5161m
    Core photo at depth: 5161-5166m
    Core photo at depth: 5166-5167m
    5146-5151m
    5151-5156m
    5156-5161m
    5161-5166m
    5166-5167m
    Core photo at depth: 5167-5172m
    Core photo at depth: 5172-5177m
    Core photo at depth: 5177-5182m
    Core photo at depth: 5182-5187m
    Core photo at depth: 5187-5192m
    5167-5172m
    5172-5177m
    5177-5182m
    5182-5187m
    5187-5192m
    Core photo at depth: 5192-5197m
    Core photo at depth: 5197-5202m
    Core photo at depth: 5202-5207m
    Core photo at depth: 5207-5212m
    Core photo at depth: 5212-5213m
    5192-5197m
    5197-5202m
    5202-5207m
    5207-5212m
    5212-5213m
    Core photo at depth: 5213-5217m
    Core photo at depth: 5217-5222m
    Core photo at depth: 5222-5227m
    Core photo at depth: 5227-5232m
    Core photo at depth: 5232-5237m
    5213-5217m
    5217-5222m
    5222-5227m
    5227-5232m
    5232-5237m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3640.0
    [m]
    DC
    RRI
    3660.0
    [m]
    DC
    RRI
    3680.0
    [m]
    DC
    RRI
    3690.0
    [m]
    DC
    RRI
    3710.0
    [m]
    DC
    RRI
    3720.0
    [m]
    DC
    RRI
    3750.0
    [m]
    DC
    RRI
    3760.0
    [m]
    DC
    RRI
    3780.0
    [m]
    DC
    RRI
    3790.0
    [m]
    DC
    RRI
    3810.0
    [m]
    DC
    RRI
    3830.0
    [m]
    DC
    RRI
    3840.0
    [m]
    DC
    RRI
    3860.0
    [m]
    DC
    RRI
    3870.0
    [m]
    DC
    RRI
    3890.0
    [m]
    DC
    RRI
    3900.0
    [m]
    DC
    RRI
    3920.0
    [m]
    DC
    RRI
    3930.0
    [m]
    DC
    RRI
    3950.0
    [m]
    DC
    RRI
    3970.0
    [m]
    DC
    RRI
    3980.0
    [m]
    DC
    RRI
    4000.0
    [m]
    DC
    RRI
    4020.0
    [m]
    DC
    RRI
    4030.0
    [m]
    DC
    RRI
    4050.0
    [m]
    DC
    RRI
    4060.0
    [m]
    DC
    RRI
    4080.0
    [m]
    DC
    RRI
    4090.0
    [m]
    DC
    RRI
    4110.0
    [m]
    DC
    RRI
    4120.0
    [m]
    DC
    RRI
    4140.0
    [m]
    DC
    RRI
    4150.0
    [m]
    DC
    RRI
    4170.0
    [m]
    DC
    RRI
    4185.0
    [m]
    DC
    RRI
    4200.0
    [m]
    DC
    RRI
    4215.0
    [m]
    DC
    RRI
    4230.0
    [m]
    DC
    RRI
    4250.0
    [m]
    DC
    RRI
    4265.0
    [m]
    DC
    RRI
    4280.0
    [m]
    DC
    RRI
    4335.0
    [m]
    DC
    RRI
    4350.0
    [m]
    DC
    RRI
    4365.0
    [m]
    DC
    RRI
    4380.0
    [m]
    DC
    RRI
    4395.0
    [m]
    DC
    RRI
    4410.0
    [m]
    DC
    RRI
    4425.0
    [m]
    DC
    RRI
    4440.0
    [m]
    DC
    RRI
    4455.0
    [m]
    DC
    RRI
    4470.0
    [m]
    DC
    RRI
    4485.0
    [m]
    DC
    RRI
    4500.0
    [m]
    DC
    RRI
    4515.0
    [m]
    DC
    RRI
    4530.0
    [m]
    DC
    RRI
    4545.0
    [m]
    DC
    RRI
    4551.0
    [m]
    DC
    RRI
    4560.0
    [m]
    DC
    RRI
    4566.0
    [m]
    DC
    RRI
    4578.0
    [m]
    DC
    RRI
    4584.0
    [m]
    DC
    RRI
    4587.0
    [m]
    DC
    RRI
    4590.0
    [m]
    DC
    RRI
    4596.0
    [m]
    DC
    RRI
    4611.0
    [m]
    DC
    RRI
    4626.0
    [m]
    DC
    RRI
    4644.0
    [m]
    DC
    RRI
    4656.0
    [m]
    DC
    RRI
    4665.0
    [m]
    DC
    RRI
    4674.0
    [m]
    DC
    RRI
    4683.0
    [m]
    DC
    RRI
    4692.0
    [m]
    DC
    RRI
    4704.0
    [m]
    DC
    RRI
    4713.0
    [m]
    DC
    RRI
    4722.0
    [m]
    DC
    RRI
    4731.0
    [m]
    DC
    RRI
    4740.0
    [m]
    DC
    RRI
    4749.0
    [m]
    DC
    RRI
    4761.0
    [m]
    DC
    RRI
    4770.0
    [m]
    DC
    RRI
    4782.0
    [m]
    DC
    RRI
    4791.0
    [m]
    DC
    RRI
    4800.0
    [m]
    DC
    RRI
    4809.0
    [m]
    DC
    RRI
    4818.0
    [m]
    DC
    RRI
    4827.0
    [m]
    DC
    RRI
    4836.0
    [m]
    DC
    RRI
    4845.0
    [m]
    DC
    RRI
    4854.0
    [m]
    DC
    RRI
    4860.0
    [m]
    DC
    RRI
    4869.0
    [m]
    DC
    RRI
    4878.0
    [m]
    DC
    RRI
    4887.0
    [m]
    DC
    RRI
    4896.0
    [m]
    DC
    RRI
    4905.0
    [m]
    DC
    RRI
    4914.0
    [m]
    DC
    RRI
    4922.0
    [m]
    DC
    RRI
    4932.0
    [m]
    DC
    RRI
    4941.0
    [m]
    DC
    RRI
    4950.0
    [m]
    DC
    RRI
    4959.0
    [m]
    DC
    RRI
    4968.0
    [m]
    DC
    RRI
    4977.0
    [m]
    DC
    RRI
    4986.0
    [m]
    DC
    RRI
    4995.0
    [m]
    DC
    RRI
    5001.0
    [m]
    DC
    RRI
    5007.0
    [m]
    DC
    RRI
    5013.0
    [m]
    DC
    RRI
    5019.0
    [m]
    DC
    RRI
    5025.0
    [m]
    DC
    RRI
    5031.0
    [m]
    DC
    RRI
    5037.0
    [m]
    DC
    RRI
    5041.8
    [m]
    C
    RRI
    5050.4
    [m]
    C
    RRI
    5054.5
    [m]
    C
    RRI
    5063.2
    [m]
    C
    RRI
    5065.6
    [m]
    C
    RRI
    5072.1
    [m]
    C
    RRI
    5076.5
    [m]
    C
    RRI
    5082.1
    [m]
    C
    RRI
    5087.7
    [m]
    C
    RRI
    5096.4
    [m]
    C
    RRI
    5096.7
    [m]
    C
    RRI
    5102.8
    [m]
    C
    RRI
    5108.8
    [m]
    C
    RRI
    5116.4
    [m]
    C
    RRI
    5122.5
    [m]
    C
    RRI
    5128.5
    [m]
    C
    RRI
    5134.6
    [m]
    C
    RRI
    5139.4
    [m]
    C
    RRI
    5143.0
    [m]
    C
    RRI
    5146.7
    [m]
    C
    RRI
    5152.7
    [m]
    C
    RRI
    5158.5
    [m]
    C
    RRI
    5163.9
    [m]
    C
    RRI
    5169.4
    [m]
    C
    RRI
    5224.4
    [m]
    C
    RRI
    5229.0
    [m]
    C
    RRI
    5232.6
    [m]
    C
    RRI
    5236.8
    [m]
    C
    RRI

  • 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
    DST1
    0.00
    0.00
    23.08.1996 - 09:30
    YES
    DST
    DST2
    0.00
    0.00
    03.09.1996 - 05:30
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.61

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.00

  • 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
    44.41

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    5236
    5226
    20.6
    2.0
    5207
    5198
    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
    12.000
    162
    2.0
    73.000
    162
    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
    690
    453000
    0.840
    656
    2.0
    470
    173900
    0.831
    0.775
    360

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    6CAL CHT GR
    2207
    4730
    DIFL MAC CHT GR
    4735
    5271
    DPR
    617
    4756
    FMT VPC CHT GR
    3709
    4369
    MAC HXDIP GR
    3600
    5270
    MDT GR
    4768
    5230
    MRIL CHT GR
    4736
    5233
    TRIPLE COMBO
    4756
    5264
    VSP GR
    1825
    5260
    ZDL CN CHT GR
    3590
    5275

  • 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
    370.0
    36
    370.0
    0.00
    LOT
    INTERM.
    20
    617.0
    26
    618.0
    1.40
    LOT
    INTERM.
    13 3/8
    2227.0
    17 1/2
    2230.0
    1.87
    LOT
    INTERM.
    9 5/8
    4739.0
    12 1/4
    4739.0
    0.00
    LOT
    OPEN HOLE
    5268.0
    8 1/2
    5268.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1070
    1.25
    DUMMY
    1720
    1.28
    DUMMY
    2242
    1.36
    18.0
    ANCO 2000
    2340
    1.65
    65.0
    ANCO VERT
    2560
    1.66
    52.0
    ANCO VERT
    3980
    1.76
    59.0
    ANCO VERT
    3986
    1.66
    52.0
    ANCO VERT
    4326
    1.72
    54.0
    ANCO VERT
    4548
    1.76
    56.0
    ANCO VERT
    4619
    1.76
    55.0
    ANCO VERT
    4727
    1.76
    57.0
    ANCO VERT
    4756
    1.76
    56.0
    ANCO VERT
    4790
    1.20
    DUMMY
    4790
    1.20
    18.0
    ANCO VERT
    4802
    1.20
    30.0
    ANCO VERT
    4831
    1.20
    29.0
    ANCO VERT
    4950
    1.20
    DUMMY
    4953
    1.20
    23.0
    ANCO VERT
    4999
    1.20
    25.0
    ANCO VERT
    5041
    1.20
    27.0
    ANCO VERT
    5063
    1.20
    18.0
    ANCO VERT
    5117
    1.20
    DUMMY
    5146
    1.20
    DUMMY
    5212
    1.20
    DUMMY
    5237
    1.20
    DUMMY
    5268
    1.20
    30.0
    ANCO VERT
    5268
    1.20
    DUMMY

  • 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
    0.30