Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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34/7-26 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.
    34/7-26 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.
    RE-CLASS TO TEST
    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
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    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.
    34/7-26
    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.
    925-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.
    21
    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,
    06.02.1998
    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.
    26.02.1998
    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.
    26.02.2000
    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.
    04.06.2008
    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
    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.
    LATE 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.
    INTRA DRAUPNE FM SS
    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.
    201.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4290.0
    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).
    2573.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    63
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    91
    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.
    LATE 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.
    HEATHER FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 16' 29.35'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 7' 11.74'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6793878.10
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    452810.97
    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.
    3329

  • Wellbore history
    Appraisal well 34/7-26 A was drilled as a sidetrack from well 34/7-26 S in the in the "H-central" prospect in the Tampen area in the Northern North Sea. The H-Central is located between the Gullfaks and the Vigdis Fields. The well had two primary objectives. Firstly, to perform an optimum data collection programme in the Top Intra Draupne sandstone, and possible deeper Intra Draupne sandstone and also in possible base Cretaceous sandstone. Secondly, to perform a long term production test if the well was to encounter at least 20 m with Top Intra Draupne Formation sand. The two previous wells with this objective, 34/7-26 S and re-entry 34/7-26 SR, did not penetrate prognosed Top Intra Draupne sandstone in a position that fulfilled the test criteria.
    Operations and results
    Well 34/7-26A was kicked off from below 13 3/8" casing shoe in well 34/7-26 S, on 6 January 1998. The well was entered through slot J-3 on Tordis Extension Template and drilled deviated with the semi-submersible installation Scarabeo 5 to TD at 4290 m (2573 m TVD) in Late Jurassic sediments of the Heather Formation. Some problems were encountered getting the wire line tools to TD during final log runs, otherwise operations went without significant problems. The well bore was drilled all through to TD with a pseudo oil based mud (Ancotec with Novamul).
    The Top Cromer Knoll Group was penetrated at 4115 m (2429 m TVD) and consisted of the Rødby Formation down to 4123 m, and the Mime Formation from 4123 m to 4129 m (2436 - 2441 m TVD). There were no sandstones in the Cromer Knoll Group.
    The main reservoir interval, the Top Intra Draupne sandstone, came in at 4129 m (2441.1 m TVD) with a thickness of 50 m TVD. The underlying Draupne Formation shale was 20 m TVD thick. The top Intra Draupne Formation reservoir in well 34/7-26 A consisted of coarsening-upwards sandstones, which mostly were structureless, parallel bedded, and less frequent, graded bedded. The upper four meters consisted of medium to coarse grained sands, which were structureless. The lower part of the reservoir was more bioturbated than the upper part. The net-to-gross was 93%, the average porosity 28%, the average permeability 1320 mD, and the average water saturation 7%. In addition to the Top Intra Draupne Formation sandstone, a second Intra Draupne Formation sandstone was encountered at 4204 m (2502 m TVD). This sandstone was 1.6 m thick TVD, and the bottom half was completely tight (carbonate cemented). Faint parallel lamination could be distinguished in the base, otherwise it was structureless. The sandstone was medium grained. The upper part had a net-to-gross of 62%, 29% porosity, 750 mD in permeability (from core), and 19% water saturation.
    No oil water contact was encountered in the well. The deepest oil down-to was observed at 4206 m (2504 m TVD). No shows were observed above or below the Intra Draupne Formation sands. Pressure point measurements in the reservoir section show depletion caused by production from the Tordis field.
    Coring commenced at a depth of 4104 m, circa 20 m MD above estimated Base Cretaceous depth. Four continuous cores were taken to a depth of 4216 m. Two MDT fluid samples were taken. The first was taken in the Top Intra Draupne Formation sand at a depth of 4153 m, and the other in the second Intra Draupne Formation sand at a depth of 4205 m. Laboratory measurements indicated the fluid samples were contaminated by base oil from the mud.
    After two drill stem tests the well was re-classified to development well 34/7-J-3 H for a long term test to the Gullfaks C platform.
    Testing
    Two drill stem tests were conducted in 34/7-26 A.
    DST 1 tested the interval 4203.5 - 4207.5 m (2502.0 - 2405.3 m TVD) in the deepest Intra Draupne Formation Sand. It flowed 31560 Sm3 gas and 346 Sm3 oil on a 20/64" choke in the main flow. The GOR was 91 Sm3/Sm3. The maximum recorded temperature, measured during maximum flow, was 89.6 deg C.
    DST 2 tested the intervals 4161.5-4179.5 m (2467.7-2482.4 m TVD) plus 4140.0-4149.0 m (2450.1-2457.4 m TVD) in the top Intra Draupne Formation Sand. It flowed 99664 Sm3 gas and 1361 Sm3 oil on a 44/64" choke in the main flow. The GOR was 73 Sm3/Sm3. The maximum recorded temperature was 88.4 deg C.
    h

  • 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]
    1400.00
    4289.00

  • Cores at the Norwegian Offshore Directorate
    Cores at the Norwegian Offshore Directorate
    Comments
    Kjerneintervall 4104 - 4144 er ikke tilgjengelig hos OD
    Cores at the Norwegian Offshore Directorate
    Core sample number
    Core sample - top depth
    Core sample - bottom depth
    Core sample depth - uom
    1
    4104.0
    4130.7
    [m ]
    2
    4132.0
    4153.6
    [m ]
    3
    4153.5
    4178.4
    [m ]
    4
    4179.0
    4216.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    110.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 4104-4109m
    Core photo at depth: 4109-4114m
    Core photo at depth: 4114-4119m
    Core photo at depth: 4119-4124m
    Core photo at depth: 4124-4129m
    4104-4109m
    4109-4114m
    4114-4119m
    4119-4124m
    4124-4129m
    Core photo at depth: 4129-4130m
    Core photo at depth: 4132-4137m
    Core photo at depth: 4137-4142m
    Core photo at depth: 4142-4147m
    Core photo at depth: 4147-4152m
    4129-4130m
    4132-4137m
    4137-4142m
    4142-4147m
    4147-4152m
    Core photo at depth: 4152-4153m
    Core photo at depth: 4153-4158m
    Core photo at depth: 4158-4163m
    Core photo at depth: 4163-4168m
    Core photo at depth: 4168-4173m
    4152-4153m
    4153-4158m
    4158-4163m
    4163-4168m
    4168-4173m
    Core photo at depth: 4173-4178m
    Core photo at depth: 4178-4179m
    Core photo at depth: 4179-4184m
    Core photo at depth: 4184-4189m
    Core photo at depth: 4189-4194m
    4173-4178m
    4178-4179m
    4179-4184m
    4184-4189m
    4189-4194m
    Core photo at depth: 4194-4199m
    Core photo at depth: 4199-4204m
    Core photo at depth: 4204-4209m
    Core photo at depth: 4209-4214m
    Core photo at depth: 4214-4216m
    4194-4199m
    4199-4204m
    4204-4209m
    4209-4214m
    4214-4216m

  • 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
    INTERM.
    13 3/8
    1371.0
    17 1/2
    1373.0
    1.60
    LOT
    INTERM.
    9 5/8
    3746.0
    12 1/4
    3750.0
    1.68
    LOT
    LINER
    5 1/2
    4286.0
    8 1/2
    4290.0
    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
    4204
    4208
    17.5
    2.0
    4140
    4180
    0.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    14.000
    30.000
    89
    2.0
    88
    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
    1361
    2.0

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT H PEX GR
    3746
    4289
    MDT CMR GR
    4124
    4206
    MWD - GR RES DIR
    1384
    3750
    MWD - GR RES DIR
    3750
    4290
    RIGS
    1370
    3663
    UBI DSI NGT
    3746
    4281
    VELOCITY
    1523
    4229

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.47
    pdf
    5.06

  • 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
    25.60

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1396
    1.39
    21.0
    PSEUDO OIL BASE
    1708
    1.39
    26.0
    PSEUDO OIL BASE
    3071
    1.45
    32.0
    PSEUDO OIL BASE
    3750
    1.49
    33.0
    PSEUDO OIL BASE
    4104
    1.58
    31.0
    PSEUDO OIL BASE
    4130
    1.58
    29.0
    PSEUDO OIL BASE
    4205
    1.50
    BRINE
    4205
    1.55
    32.0
    PSEUDO OIL BASE
    4290
    1.62
    35.0
    PSEUDO OIL BASE

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    4132.5
    [m]
    C
    BIOSTRAT
    4134.5
    [m]
    C
    BIOSTR
    4135.7
    [m]
    C
    BIOSTR
    4138.3
    [m]
    C
    BIOSTR
    4140.8
    [m]
    C
    BIOSTR
    4142.0
    [m]
    C
    BIOSTR
    4143.3
    [m]
    C
    BIOSTR
    4143.8
    [m]
    C
    BIOSTR
    4144.5
    [m]
    C
    BIOSTR
    4146.4
    [m]
    C
    BIOSTR
    4146.9
    [m]
    C
    BIOSTR

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    4154.40
    [m ]
    4159.90
    [m ]
    4167.28
    [m ]
    4173.50
    [m ]
    4179.80
    [m ]
    4188.94
    [m ]
    4207.20
    [m ]
    4207.87
    [m ]
    4219.58
    [m ]
    4148.70
    [m ]