Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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31.10.2024 - 01:27
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34/8-3 A

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  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    34/8-3 A
    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
    Multilateral
    Indicator telling if the parent well is multilateral, meaning it has more than one branch radiating from the main borehole. Example of legal values: YES, NO. See also Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    NO
    Factmaps in new window
    Main area
    Name of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.
    NORTH SEA
    Field
    Name of the field the wellbore is related to.
    Discovery
    Name of the discovery the wellbore is related to.
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    34/8-3
    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.
    589-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.
    48
    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,
    14.09.1988
    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.
    31.10.1988
    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.
    31.10.1990
    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.
    21.12.2012
    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
    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.
    BRENT GP
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    382.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3230.0
    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).
    3091.2
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    25.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    116
    Oldest penetrated age
    Age (according to Geologic Time Scale 2004 by F. M. Gradstein, et al. (2004)) of the oldest penetrated formation. May differ from age at TD for example in deviated wellbores. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EARLY PERMIAN, EARLY TRIASSIC, EOCENE.
    EARLY JURASSIC
    Oldest penetrated formation
    Name of the oldest lithostratigraphic unit penetrated by the wellbore. Shown only for released wells. In most wellbores this is formation or group at total depth. May differ from formation or group at TD for example in wellbores drilled with high deviation or through faults. Examples of legal values: AMUNDSEN FM, BALDER FM, BASEMENT, BLODØKS FM, BRYNE FM, BURTON FM, COOK FM, DRAKE FM, DRAUPNE FM, EKOFISK FM, DUNLIN GP.
    COOK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 24' 28.04'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 32' 45.06'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6808456.80
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    475751.35
    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.
    1338

  • Wellbore history
    General
    Well 34/8-3 A is a sidetrack to well 34/8-3 on the A-structure on the Visund Field. Well 34/8-3 found oil and gas in the Brent Group without encountering the OWC. Well 34/8-3 A was sidetracked down flanks on the structure to establish the OWC and to test if the A-North could be in communication with the 34/8-1 A-South Discovery.
    Operations and results
    Appraisal well 34/8-3 A was kicked off at 944 m in the primary well on 14 November 1988. It was drilled with the semi-submersible installation Polar Pioneer to TD at 3230 m (3091 m TVD) in the Early Jurassic Cook Formation. During logging before setting of 9 5/8", the tool got stuck at 1284 m. The string was cut, and the instrument was fished. The well was drilled with KCl/polymer mud from kick-off to TD.
    Spotted hydrocarbon shows were described on cuttings in the interval 2550 to 2660 m in the Kyrre Formation. Top Draupne Formation was encountered at 3003 m. Under Draupne, the sidetrack penetrated a 19 m thick Heather Formation sequence that was not present in the primary well bore. The Brent Group, Tarbert Formation was encountered at 3031 m (2900 m TVD), deeper than prognosed due to the unexpected Heather. The Brent Formation contained gas down to a gas/oil contact at 3059 m (2927 m TVD and oil down to a clear oil/water contact at 3099.5 m (2966 m TVD). Oil shows continued down to 3162 m. The Cook Formation was found water bearing. The RFT pressures in both the primary well and the sidetrack proved higher pressure in the hydrocarbon zone than on the A-South compartment, but with pressure communication in the water zone.
    Five cores were cut in the interval 3034 to 3148.5 m. The drill string got stuck during cutting of the 5th core and further coring was abandoned.  RFT fluid samples were taken at 3073.2 m (0.4 Sm3 gas and 2.6 litres oil in 2 3/4 gallon chamber), and 3093.0 (1 Sm3 gas and 7 litres oil 2 3/4 gallon chamber).
    The well was permanently abandoned on 31 October 1988 as an oil and gas appraisal well.
    Testing
    Two drill stem test was performed in the oil zone in the Ness Formation.
    DST 1A tested the interval 3087 - 3093 m. It produced 746 Sm3 oil and 152640 Sm3 gas /day through a 12.7 mm (32/64") choke. The GOR was 205 Sm3/Sm3, the oil density was 0.850 g/cm3, and the gas gravity was 0.646 (air = 1) with 2 % CO2 and 1ppm H2S. The bottom hole temperature was 108.7 deg C, measured at 3020 m.
    DST 1B tested the intervals 3071.6 - 3078.6 m plus 3081.7 - 3093.0 m. It produced 782 Sm3 oil and 155620 Sm3 gas /day through a 12.7 mm (32/64") choke. The GOR was 199 Sm3/Sm3, the oil density was 0.850 g/cm3, and the gas gravity was 0.650 (air = 1) with 2 % CO2 and 1.2 ppm H2S. The bottom hole temperature was 109.6 deg C, measured at 3020 m.

  • 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]
    1000.00
    3230.00

  • 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
    3034.0
    3061.9
    [m ]
    2
    3062.0
    3079.9
    [m ]
    3
    3081.0
    3101.8
    [m ]
    4
    3103.0
    3130.9
    [m ]
    5
    3131.0
    3148.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    111.9
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3034-3039m
    Core photo at depth: 3039-3044m
    Core photo at depth: 3044-3049m
    Core photo at depth: 3049-3054m
    Core photo at depth: 3054-3059m
    3034-3039m
    3039-3044m
    3044-3049m
    3049-3054m
    3054-3059m
    Core photo at depth: 3059-3061m
    Core photo at depth: 3062-3067m
    Core photo at depth: 3067-3072m
    Core photo at depth: 3072-3077m
    Core photo at depth: 3077-3079m
    3059-3061m
    3062-3067m
    3067-3072m
    3072-3077m
    3077-3079m
    Core photo at depth: 3081-3086m
    Core photo at depth: 3086-3091m
    Core photo at depth: 3091-3096m
    Core photo at depth: 3096-3101m
    Core photo at depth: 3101-3106m
    3081-3086m
    3086-3091m
    3091-3096m
    3096-3101m
    3101-3106m
    Core photo at depth: 3106-3111m
    Core photo at depth: 3111-3116m
    Core photo at depth: 3116-3121m
    Core photo at depth: 3121-3126m
    Core photo at depth: 3126-3130m
    3106-3111m
    3111-3116m
    3116-3121m
    3121-3126m
    3126-3130m
    Core photo at depth: 3126-3130m
    Core photo at depth: 3131-3136m
    Core photo at depth: 3136-3141m
    Core photo at depth: 3141-3146m
    Core photo at depth: 3146-3148m
    3126-3130m
    3131-3136m
    3136-3141m
    3141-3146m
    3146-3148m
    Core photo at depth: 3078-3078m
    Core photo at depth: 3078-3078m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3078-3078m
    3078-3078m

  • 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
    3071.00
    3093.00
    20.10.1988 - 00:00
    YES
    DST
    DST1B
    3071.50
    3078.50
    23.10.1988 - 00:00
    YES

  • 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
    491.0
    36
    0.0
    0.00
    LOT
    INTERM.
    13 3/8
    944.0
    17 1/2
    1475.0
    1.67
    LOT
    INTERM.
    13 3/8
    944.0
    17 1/2
    1475.0
    1.67
    LOT
    INTERM.
    9 5/8
    2442.0
    12 1/4
    2486.0
    1.84
    LOT
    INTERM.
    9 5/8
    2442.0
    12 1/4
    2486.0
    1.84
    LOT
    LINER
    7
    3227.0
    8 1/2
    3230.0
    0.00
    LOT
    LINER
    7
    3230.0
    8 1/2
    3230.0
    0.00
    LOT

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3087
    3093
    12.7
    1.1
    3072
    3093
    12.7
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    1.1
    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
    746
    153000
    0.850
    0.646
    205
    1.1
    782
    156000
    0.850
    0.650
    199

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    1875
    3165
    CST GR
    2525
    3031
    DIL LSS GR SP
    405
    3229
    DLL MSFL GR SP
    3000
    3182
    LDT CNL
    2443
    3195
    MWD
    945
    3034
    MWD FE WD
    3062
    3230
    NGT AMS
    2443
    3186
    RFT GR AMS
    3034
    3162
    VSP
    1000
    3160

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.25
    pdf
    9.20

  • Documents – reported by the production licence (period for duty of secrecy expired)
    Documents – reported by the production licence (period for duty of secrecy expired)
    Document name
    Document format
    Document size [MB]
    pdf
    2.62
    pdf
    16.59

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    944
    1.53
    20.0
    8.0
    WATER BASED
    19.09.1988
    949
    1.40
    21.0
    11.0
    WATER BASED
    20.09.1988
    951
    1.52
    22.0
    11.0
    WATER BASED
    19.09.1988
    966
    1.52
    23.0
    10.0
    WATER BASED
    19.09.1988
    989
    1.40
    22.0
    11.0
    WATER BASED
    22.09.1988
    1152
    1.40
    23.0
    11.0
    WATER BASED
    22.09.1988
    1255
    1.40
    21.0
    9.0
    WATER BASED
    19.09.1988
    1475
    1.40
    24.0
    10.0
    WATER BASED
    23.09.1988
    1795
    1.41
    24.0
    9.0
    WATER BASED
    27.09.1988
    2045
    1.40
    24.0
    8.0
    WATER BASED
    27.09.1988
    2390
    1.50
    24.0
    8.0
    WATER BASED
    27.09.1988
    2400
    1.40
    20.0
    7.0
    WATER BASED
    27.09.1988
    2486
    1.52
    18.0
    11.0
    WATER BASED
    28.09.1988
    2486
    1.52
    20.0
    12.0
    WATER BASED
    29.09.1988
    2486
    1.52
    22.0
    8.0
    WATER BASED
    30.09.1988
    2486
    1.52
    24.0
    7.0
    WATER BASED
    03.10.1988
    2489
    1.52
    23.0
    7.0
    WATER BASED
    03.10.1988
    2591
    1.52
    23.0
    8.0
    WATER BASED
    03.10.1988
    2674
    1.52
    21.0
    8.0
    WATER BASED
    04.10.1988
    2954
    1.55
    22.0
    8.0
    WATER BASED
    11.10.1988
    3034
    1.60
    24.0
    8.0
    WATER BASED
    11.10.1988
    3034
    1.60
    22.0
    8.0
    WATER BASED
    11.10.1988
    3103
    1.60
    25.0
    7.0
    WATER BASED
    11.10.1988
    3131
    1.60
    23.0
    6.0
    WATER BASED
    11.10.1988
    3148
    1.60
    24.0
    8.0
    WATER BASED
    12.10.1988
    3175
    1.70
    26.0
    10.0
    WATER BASED
    18.10.1988
    3175
    1.70
    26.0
    12.0
    WATER BASED
    17.10.1988
    3177
    1.70
    28.0
    7.0
    WATER BASED
    24.10.1988
    3177
    1.70
    27.0
    6.0
    WATER BASED
    25.10.1988
    3177
    1.70
    28.0
    6.0
    WATER BASED
    26.10.1988
    3177
    1.70
    29.0
    7.0
    WATER BASED
    19.10.1988
    3177
    1.70
    29.0
    7.0
    WATER BASED
    20.10.1988
    3177
    1.70
    29.0
    7.0
    WATER BASED
    24.10.1988
    3177
    1.70
    27.0
    6.0
    WATER BASED
    24.10.1988
    3177
    1.71
    30.0
    7.0
    WATER BASED
    27.10.1988
    3177
    1.71
    30.0
    7.0
    WATER BASED
    31.10.1988
    3177
    1.50
    15.0
    5.0
    WATER BASED
    31.10.1988
    3230
    1.60
    26.0
    8.0
    WATER BASED
    17.10.1988
    3230
    1.60
    26.0
    9.0
    WATER BASED
    14.10.1988
    3230
    1.60
    26.0
    8.0
    WATER BASED
    14.10.1988
    3230
    1.60
    24.0
    5.0
    WATER BASED
    17.10.1988

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2665.0
    [m]
    SWC
    HYDRO
    2760.0
    [m]
    SWC
    HYDRO
    2885.0
    [m]
    SWC
    HYDRO
    2978.5
    [m]
    SWC
    HYDRO
    2981.0
    [m]
    SWC
    HYDRO
    2990.0
    [m]
    SWC
    HYDRO
    3005.0
    [m]
    SWC
    HYDRO
    3007.5
    [m]
    SWC
    HYDRO
    3008.0
    [m]
    SWC
    HYDRO
    3011.0
    [m]
    SWC
    HYDRO
    3016.0
    [m]
    SWC
    HYDRO
    3018.0
    [m]
    SWC
    HYDRO
    3023.0
    [m]
    SWC
    HYDRO
    3025.0
    [m]
    SWC
    HYDRO
    3029.5
    [m]
    SWC
    HYDRO
    3035.8
    [m]
    CC
    HYDRO
    3043.6
    [m]
    CC
    HYDRO
    3053.9
    [m]
    CC
    HYDRO
    3057.0
    [m]
    DC
    RRI
    3057.9
    [m]
    CC
    HYDRO
    3059.0
    [m]
    DC
    RRI
    3061.0
    [m]
    DC
    RRI
    3063.0
    [m]
    DC
    RRI
    3063.2
    [m]
    CC
    HYDRO
    3064.0
    [m]
    DC
    RRI
    3065.0
    [m]
    DC
    RRI
    3068.0
    [m]
    DC
    RRI
    3069.0
    [m]
    DC
    RRI
    3069.7
    [m]
    CC
    HYDRO
    3070.0
    [m]
    DC
    RRI
    3074.0
    [m]
    DC
    RRI
    3075.0
    [m]
    CC
    HYDRO
    3075.0
    [m]
    DC
    RRI
    3076.0
    [m]
    DC
    RRI
    3077.5
    [m]
    CC
    HYDRO
    3078.0
    [m]
    DC
    RRI
    3082.0
    [m]
    DC
    RRI
    3082.3
    [m]
    CC
    HYDRO
    3084.0
    [m]
    DC
    RRI
    3084.7
    [m]
    CC
    HYDRO
    3094.0
    [m]
    DC
    RRI
    3094.5
    [m]
    CC
    HYDRO
    3095.0
    [m]
    DC
    RRI
    3095.5
    [m]
    CC
    HYDRO
    3098.2
    [m]
    CC
    HYDRO
    3112.5
    [m]
    CC
    HYDRO
    3120.7
    [m]
    CC
    HYDRO
    3126.0
    [m]
    DC
    RRI
    3126.5
    [m]
    CC
    HYDRO
    3128.0
    [m]
    DC
    RRI
    3129.0
    [m]
    DC
    RRI
    3129.9
    [m]
    CC
    HYDRO
    3130.0
    [m]
    DC
    RRI
    3132.8
    [m]
    CC
    HYDRO
    3136.8
    [m]
    CC
    HYDRO
    3146.8
    [m]
    CC
    HYDRO