Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
31.12.2024 - 01:26
Time of last synchronization with Norwegian Offshore Directorate's internal systems

30/6-7

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    30/6-7
    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.
    30/6-7
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    8006 - 137 SP 589
    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.
    Norsk Hydro Produksjon AS
    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.
    329-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.
    97
    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,
    20.05.1982
    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.
    24.08.1982
    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.
    24.08.1984
    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.
    26.10.2009
    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/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.
    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
    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.
    MIDDLE 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.
    NESS FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    114.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3236.0
    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).
    3236.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    124
    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.
    STATFJORD GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 38' 39.49'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 45' 21.74'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6723352.60
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    486657.23
    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.
    73

  • Wellbore history
    General
    Well 30/6-7 is an appraisal well on the Oseberg Field, discovered by well 30/6-1 in 1979.The primary objective was to test for hydrocarbon accumulations in the Late Jurassic sandstones of the Brent formation and the Late and Early Jurassic sandstones of the Dunlin and Statfjord formations in the Alpha north structure. Secondary objectives were to establish the type of communication between the Alpha and Alpha North structures and to define the oil/water contact on Alpha North. The well was planned to reach total depth at 3225 +- 50 m, 75 m into the Statfjord Formation.
    The well is Type well for the Oseberg Formation and Reference well for the Amundsen, Cook, Drake, Etive, Ness, and Tarbert Formations.
    Operations and results
    Well 30/6-7 was spudded with the semi-submersible installation Nortrym on 20 May 1982 and drilled to TD at 3236 m in Early Jurassic rocks of the Statfjord Formation. The 26" section was initiated by a 17 1/2" pilot hole. One small pocket of shallow gas was detected at 358 m (5.6% C1). The well was drilled with seawater and hi-vis pills down to 952 m and with KCl/polymer mud from 952 m to 2285 m. At 2285 m the 13 3/8" casing got stuck and a pill of EZY spot and diesel was pumped in the hole, without effect. The drilling fluid used in the 12 1/4" section from 2285 m to 2915 m the well was drilled with a Dextrid/KCl mud. From 2915 m to TD the mud was converted to a dispersed system by adding lignosulfonate.
    The Brent Group was encountered at 2631.5 m. The Brent Group was hydrocarbon bearing with a total gross thickness of 154.5 m and a net sand interval of 106.9 m. The net pay was 50.7 m. Sandstone intervals were also encountered in the Early Jurassic Cook and Statfjord formations but these were both 100% water saturated.
    The Tarbert Formation (2631.5 - 2646.5 m) formed the uppermost interval in the Brent Group. It consisted of very fine to fine grained sandstone which was occasionally medium to coarse grained. Wire line log evaluation gave a net pay of 14.7 m, with an average porosity of 20.7% and an average water saturation of 18.1%. Average permeability (KH, log) was 520 mD.
    The Ness Formation (2646.5 - 2727.5 m) consisted of interbedded sandstones, shales, siltstones and stringers of coal. The sandstones were very fine to medium, occasionally coarse grained and locally very micaceous and carbonaceous. The interval contained 38.7 m of net sand and 36 m of net pay which had an average porosity of 20.5%, average water saturation of 27.7% and an average permeability of 577 mD (KH, log). Measured average permeability (KH, core) was 1163 mD.
    FMT pressure measurements were taken throughout the Brent interval showing that the different sandstone intervals in the Tarbert and Ness Formations have different oil gradients. From log analysis an oil/water contact has been estimated to be at 2723.5 m in the Ness Formation. On the Alpha structure an oil/water contact has been defined at 2731 m from earlier wells and it appears therefore that the southwest - northeast fault separating the Alpha from the Alpha North structure does have some sealing properties.
    The Etive Formation (2727.5 - 2786 m) consists predominantly of a very fine grained to pebbly sandstone with occasional stringers of shale and siltstone. The interval contained 53.5 m of net sand with average porosity of 19.5%. A transition zone of residual hydrocarbons (2727.5 - 2747 m) had an average water saturation of 72%. This agrees with patchy oil shows seen in the cores down to 2755 m (2747 m when depth correction between logger's and driller's depths is applied). The remaining interval of the Etive Formation (2747 - 2786 m) had an average water saturation of 94%. Average permeability of the Etive Formation was 799 mD (KH, log) Measured average permeability from cores was 1670 mD (KH, core).
    Apart from in the hydrocarbon bearing reservoirs as described above, weak shows were described in thin limestone stringers in the Sele Formation and in limestones of the Shetland Group.
    A total of twelve conventional cores were cut from 2648 to 2812.4 m in the 12 1/4" section in the well. A total of 155.1 m (94.3%) was recovered. Cores were cut consecutively from the top of the Ness Formation and down into the Dunlin Group shales. Core depths are approximately 5 m shallower than logger's depths at the top of Core No 1 and 8.5 m shallower at the base of Core No 12. FMT fluid samples were taken at 2633.5 m (gas, oil and water/filtrate), 2643m (gas, oil and water/filtrate), 2666 m (gas, oil and water/filtrate), 2676 m (gas, oil and water/filtrate), 2684 m (gas, oil and trace of water/filtrate), 2713 m (water/filtrate), and 2714 m (water/filtrate).
    The well was permanently abandoned on 24 August 1982 as an oil and gas appraisal well.
    Testing
    Four DTS' were performed in the Brent formation sandstones.
    DST 1 was taken over the interval 2729 -2736 m and produced 770 m3 water/day through an 80/64" choke. Reservoir pressure was 4255.5 psig and the BHT was 110 °C.
    DST 2 was taken over the interval 2711 - 2716 m and produced 1028 SM3/day of 34.9 deg API oil and 116100 Sm3 of 0.72 SG gravity gas through a 56/6 4" choke. Separator GOR was 113 Sm3/Sm3, CO2 content was 0.8%, reservoir pressure was 4250 psig and the BHT was 110 °C.
    DST 3 was taken in the interval 2681 -2684 m and produced 534 Sm3 of 33.9 deg API gravity oil and 65130 Sm3 of 0.702 SG gravity gas through a 32/64" choke. Separator GOR was 122 Sm3/Sm3, CO2 content was 0.2%, and reservoir pressure was extrapolated to be 4222 psig. This test was aborted due to bad weather conditions and no bottom hole samples were obtained.
    DST 4 was taken in the interval 2633 -2636 m and produced 1339 Sm3 of 34.1 deg API oil and 146681 Sm3 of 0.700 SG gravity gas through a 72/64" choke. Separator GOR was 110 Sm3/Sm3, CO2 content was 1.0%, and reservoir pressure was extrapolated to be 4178 psig.

  • 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]
    230.00
    3237.00

  • 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
    2648.0
    2666.1
    [m ]
    2
    2666.1
    2675.0
    [m ]
    3
    2679.5
    2692.2
    [m ]
    4
    2692.2
    2693.7
    [m ]
    5
    2694.0
    2705.0
    [m ]
    6
    2707.0
    2719.4
    [m ]
    7
    2720.0
    2733.1
    [m ]
    8
    2733.1
    2750.0
    [m ]
    9
    2751.0
    2761.4
    [m ]
    10
    2762.0
    2778.8
    [m ]
    11
    2780.0
    2793.9
    [m ]
    12
    2793.9
    2812.4
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    154.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2648-2652m
    Core photo at depth: 2652-2656m
    Core photo at depth: 2656-2660m
    Core photo at depth: 2660-2664m
    Core photo at depth: 2664-2666m
    2648-2652m
    2652-2656m
    2656-2660m
    2660-2664m
    2664-2666m
    Core photo at depth: 2666-2670m
    Core photo at depth: 2670-2674m
    Core photo at depth: 2674-2675m
    Core photo at depth: 2679-2683m
    Core photo at depth: 2683-2687m
    2666-2670m
    2670-2674m
    2674-2675m
    2679-2683m
    2683-2687m
    Core photo at depth: 2687-2691m
    Core photo at depth: 2691-2692m
    Core photo at depth: 2692-2693m
    Core photo at depth: 2694-2698m
    Core photo at depth: 2698-2702m
    2687-2691m
    2691-2692m
    2692-2693m
    2694-2698m
    2698-2702m
    Core photo at depth: 2702-2705m
    Core photo at depth: 2707-2711m
    Core photo at depth: 2711-2715m
    Core photo at depth: 2715-2719m
    Core photo at depth: 2719-2719m
    2702-2705m
    2707-2711m
    2711-2715m
    2715-2719m
    2719-2719m
    Core photo at depth: 2720-2724m
    Core photo at depth: 2724-2728m
    Core photo at depth: 2728-2732m
    Core photo at depth: 2732-2733m
    Core photo at depth: 2733-2737m
    2720-2724m
    2724-2728m
    2728-2732m
    2732-2733m
    2733-2737m
    Core photo at depth: 2737-2741m
    Core photo at depth: 2741-2745m
    Core photo at depth: 2745-2749m
    Core photo at depth: 2749-2750m
    Core photo at depth: 2751-2755m
    2737-2741m
    2741-2745m
    2745-2749m
    2749-2750m
    2751-2755m
    Core photo at depth: 2755-2759m
    Core photo at depth: 2759-2761m
    Core photo at depth: 2762-2766m
    Core photo at depth: 2766-2770m
    Core photo at depth: 2770-2774m
    2755-2759m
    2759-2761m
    2762-2766m
    2766-2770m
    2770-2774m
    Core photo at depth: 2774-2778m
    Core photo at depth: 2778-2779m
    Core photo at depth: 2780-2784m
    Core photo at depth: 2784-2788m
    Core photo at depth: 2788-2792m
    2774-2778m
    2778-2779m
    2780-2784m
    2784-2788m
    2788-2792m
    Core photo at depth: 2792-2793m
    Core photo at depth: 2793-2797m
    Core photo at depth: 2797-2801m
    Core photo at depth: 2801-2805m
    Core photo at depth: 2805-2808m
    2792-2793m
    2793-2797m
    2797-2801m
    2801-2805m
    2805-2808m
    Core photo at depth: 2809-2812m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2809-2812m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2507.0
    [m]
    SWC
    RRI
    2530.0
    [m]
    SWC
    RRI
    2545.0
    [m]
    SWC
    RRI
    2602.0
    [m]
    SWC
    RRI
    2609.5
    [m]
    SWC
    RRI
    2615.0
    [m]
    SWC
    RRI
    2620.0
    [m]
    SWC
    RRI
    2625.0
    [m]
    SWC
    RRI
    2628.0
    [m]
    SWC
    RRI
    2662.0
    [m]
    C
    RRI
    2692.1
    [m]
    C
    RRI
    2693.7
    [m]
    C
    RRI
    2698.0
    [m]
    C
    RRI
    2699.0
    [m]
    C
    RRI
    2705.0
    [m]
    C
    RRI
    2712.4
    [m]
    C
    RRI
    2717.8
    [m]
    C
    RRI
    2726.9
    [m]
    C
    RRI
    2730.8
    [m]
    C
    RRI
    2734.1
    [m]
    C
    RRI
    2745.0
    [m]
    C
    RRI
    2765.1
    [m]
    C
    RRI
    2780.3
    [m]
    C
    RRI
    2795.1
    [m]
    C
    RRI
    2800.5
    [m]
    C
    RRI
    2805.0
    [m]
    C
    RRI
    2807.0
    [m]
    SWC
    RRI
    2810.0
    [m]
    C
    RRI
    2812.0
    [m]
    C
    RRI
    2817.0
    [m]
    SWC
    RRI
    2836.0
    [m]
    SWC
    RRI
    2869.0
    [m]
    SWC
    RRI
    2892.0
    [m]
    SWC
    RRI
    2908.9
    [m]
    SWC
    RRI

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.80
    pdf
    0.51

  • 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
    18.46

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2729
    2736
    31.7
    2.0
    2711
    2716
    22.2
    3.0
    2681
    2684
    12.7
    4.0
    2637
    2639
    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
    2.0
    3.0
    4.0
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    1.0
    2.0
    1028
    116000
    0.850
    0.720
    113
    3.0
    534
    65000
    0.835
    0.700
    122
    4.0
    1339
    146000
    0.853
    0.700
    109

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    825
    2285
    CBL VDL
    2250
    2928
    CCL GR
    130
    2928
    CDL CNL CR CNL
    952
    3233
    CST
    1300
    2433
    CST
    2444
    2908
    CST
    2914
    32132
    DIFL LS BHC GR SP
    137
    3232
    DLL MLL GR CAL
    2600
    2908
    FMT
    2633
    2775
    FMT
    2633
    2633
    FMT
    2643
    2643
    FMT
    2666
    0
    FMT
    2666
    2666
    FMT
    2676
    2676
    FMT
    2684
    2695
    FMT
    2684
    2684
    FMT
    2694
    2714
    FMT
    2713
    2713
    FMT
    2743
    2743
    FMT
    2977
    3188
    HRD
    2000
    3232
    MWD
    2475
    2885
    VELOCITY
    230
    3232

  • 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
    227.0
    36
    227.5
    0.00
    LOT
    SURF.COND.
    20
    952.0
    26
    965.0
    1.62
    LOT
    INTERM.
    13 3/8
    2285.0
    17 1/2
    1787.0
    1.78
    LOT
    INTERM.
    9 5/8
    2900.0
    12 1/4
    2916.0
    1.75
    LOT
    OPEN HOLE
    3236.0
    8 3/8
    3236.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    490
    1.08
    46.0
    waterbased
    970
    1.20
    38.0
    waterbased
    1795
    1.35
    60.0
    waterbased
    2200
    1.43
    69.0
    waterbased
    2450
    1.36
    62.0
    waterbased
    2720
    1.35
    45.0
    waterbased
    3045
    1.26
    49.0
    waterbased
    3120
    1.27
    67.0
    waterbased
    3210
    1.26
    58.0
    waterbased

  • 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