Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.11.2024 - 09:09
Time of last synchronization with Norwegian Offshore Directorate's internal systems

29/6-1

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.
    29/6-1
    Type
    Wellbore type. Legal values: EXPLORATION, DEVELOPMENT, OTHER (see 'Purpose' for more information)
    EXPLORATION
    Purpose
    Final classification of the wellbore.

    Legal values for exploration wellbores:
    WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS.

    Legal values for development wellbores:
    OBSERVATION, PRODUCTION, INJECTION, INJECTION-CCS, OBSERVATION-CCS.

    Legal values for other wellbores:
    SOIL DRILLING (drilling in connection with track surveys and other subsurface surveys to investigate the soil conditions prior to placement of facilities),
    SHALLOW GAS (drilling to investigate shallow gas before the first 'real' drilling on the location),
    PILOT (drilling to investigate the geology and fluid connectors for location of the main wellbore),
    SCIENTIFIC (drilling according to Law of Scientific research and exploration),
    STRATIGRAPHIC (driling according to Law of Petroleum activities §2-1).
    WILDCAT
    Status
    Status for the wellbore. Legal values are:

    BLOWOUT: A blowout has occurred in the well.
    CLOSED: A development wellbore that has been closed in a shorter or longer periode. Also applies to development wellbores where drilling is completed, but production/injection has not yet been reported.
    DRILLING: The well is in the drilling phase - can be active drilling, logging, testing or plugging,
    JUNKED: The drilling operation has been terminated due to technical problems.
    P&A: Exploration: The well is plugged and abandoned, and can not be reentered for further use. Development wells: The production/injection from/to the well is stopped and the well is plugged. The wellhead is removed or else made unavailable for further well operations.
    PLUGGED: The wellbore has been plugged, but the upper parts of the wellbore can be re-used. A sidetrack might be drilled at a later stage.
    PRODUCING: It was produced from the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    INJECTING: It was injected to the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    PREDRILLED: The upper part of the well has been drilled, usually as part of a batch-drilling campaign covering several wellbores.
    RE-CLASS TO DEV: Exploration wellbore that is reclassified to a development wellbore.
    RE-CLASS TO TEST: Exploration wellbore that is reclassified to test production.
    SUSPENDED: The drilling operation in the wellbore has been temporarily stopped. The current plan is to continue drilling later on.
    P&A
    Factmaps in new window
    Main area
    Name of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.
    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.
    29/6-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    BP 80 - 021 SP 302
    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.
    BP Norway Limited U.A.
    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.
    307-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.
    210
    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,
    12.10.1981
    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.
    09.05.1982
    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.
    09.05.1984
    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.
    01.08.2010
    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.
    GAS/CONDENSATE
    Discovery wellbore
    Indicator which tells if the wellbore made a new discovery. Legal values: YES, NO. Prior to press-release or other information regarding drilling results, the indicator will be “NO” as a default.
    YES
    1st level with HC, age
    Age of lithostratigraphic unit, 1st level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE. See also Norwegian Offshore Directorate bulletins.
    MIDDLE JURASSIC
    1st level with HC, formation
    Name of lithostartigraphic unit, 1st level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP. See also Norwegian Offshore Directorate bulletins.
    BRENT GP
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    24.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    124.7
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4832.0
    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).
    4785.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    25.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    166
    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 TRIASSIC
    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.
    LUNDE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 32' 17.94'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 59' 24.05'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6711948.14
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    444581.73
    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.
    375

  • Wellbore history
    General
    Well 29/6-1 was drilled ca 2 km west of the UK border on the eastern margin of the East Shetland Basin. The primary objective was the Brent Group in a fault block separate from the Hild structure some few km to the southwest. The secondary objective was the Statfjord formation.
    Operations and results
    Wildcat well 29/6-1 was spudded with the semi-submersible installation SEDCO 707 on and drilled to TD at 4832 m.
    The well was spudded by "Sedco 707" on 12.10.81. When drilling the 17 1/2" pilot hole (with 1.1 sg mud) in the 24" section, mud losses occurred at 870 m. The hole was displaced to seawater and operations continued down to 1205 m where the 24" casing was set. Further drilling went with increasing mud weights due to tight hole problems, to a point where the overbalance considerably reduced penetration rate. Due to high deviation the pipe became differentially stuck at 4664 m. The well was planned to be vertical, but ended up severely deviated. From 3973 m to 4097 m hole inclination increased from 5 degrees to 10.5 degrees, increasing to 15.5 degrees by 4155 m, as a result of the increased dip of the bedding planes. At 4155 m a pendulum drill assembly was used but the hole inclination continued to increase to 19.5 degrees. By 4211 m the angle had reduced to 17 degrees but again increased to a maximum of 21 degrees by 4457 m, and then decreased to 20.25 degrees by 4570 m. Below this depth, surveys were not possible due to the hole conditions with overpull and stuck pipe on the connections and tight hole on trips. Keyseating, washout in the sandstones and the swelling nature of the clays in the Dunlin formation added to the problem caused by hole angle. At TD Schlumberger HDT log was run and the hole angle had built up to 25.25 degrees, and it was estimated that TVD was 47 m less than MD. The well was drilled with gel/seawater/Drispac down to 294 m, with gel/seawater/Lost circulation material from 294 m to 1205 m, with gypsum/Lignosulphonate/CMC from 1205 m to 2552 m, with Lignosulphonate/CMC from 2552 m to 3783 m, and with Lignosulphonate from 3783 m to TD.
    The Base Cretaceous Unconformity was penetrated at 3807 m where a thick section of Late Jurassic mudstones including 110 m Draupne Formation was encountered. The Brent Group clastic sediments were reached at 4204.5 m and found to be gas/condensate bearing. The sandstones were highly overpressured and 15 m of net pay was proved. The GWC was estimated at 4230 m (4195.1 m TVD MSL) using RFT data. The Statfjord Formation was water bearing.
    Methane gas with a weak oil show was observed on sandstone at 1830 m in Paleocene. There were further weak shows (yellow natural fluorescence with colourless cut) in the Shetland Group from 3610 to 3805 m, and there were similar weak shows throughout the Brent Group ("Dull yellow fluorescence becoming very dull orange yellow downhole, fast yellow to milky white cut fluorescence becoming very slow downhole, no natural cut colour"). Similar weak shows were seen also in the Amundsen Formation sands at 4664 to 4729 m and a further 10 m into the underlying Statfjord Formation.
    Seven cores were taken in the interval 4219 to 4340 m in the 8 3/8" section in the Tarbert and Ness Formations. RFT water samples were taken at 4235.5 m and at 4289.7 m (mud filtrate only).
    The well was permanently abandoned on 9 May 1982 as a gas/condensate discovery.
    Testing
    Three drill stem tests were performed in the Tarbert Formation of the Bren Group. The upper DST produced gas and condensate; the two deeper produced only water.
    DST 1 perforated the interval 4287 to 4301 m. It consisted of a 5 minutes initial flow period and a 34 minutes initial shut in. The well then flowed formation water with small quantities of gas containing 11% CO2 for 642 minutes before being shut in for 796 minutes. The final flow rate was 192 m3 water/day through a 4/64" choke. Samples were taken both at the wellhead and at the separator throughout the test. Water salinity was 71000 ppm NaCl. The maximum temperature recording taken at gauge depth 4285.66 m was 151.2 deg C.
    DST 2 perforated the interval 4256 to 4260 m. It consisted of a flow period of 1065 minutes (no hydrocarbons observed) and a build up period of 973 minutes. The final flow rate was 44 m3 water/day through a 4/64" choke. The maximum temperature recording taken at gauge depth 4254,98 m was 150.9 deg C.
    DST 3 perforated the interval 4208.5 to 4218.3 m in the uppermost Tarbert Formation. It consisted of 5 minutes initial flow followed by a 63 minutes build up and a main flow of gas and condensate (439 minutes). The final flow rate was 305822 Sm3 gas (10.8 MMft3) with 2% CO2. H2S was not detected during the test. The condensate gas ratio was 138 STB/MM ft3 (GOR = 1291 Sm3/Sm3), condensate gravity was 44 deg API, and the separator gas gravity was 0.71 (air = 1). The maximum temperature recording taken at gauge depth 4203.14 m was 152.2 deg C.

  • 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]
    290.00
    4818.00

  • 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
    4219.5
    4238.0
    [m ]
    2
    4238.0
    4256.0
    [m ]
    3
    4256.0
    4274.0
    [m ]
    4
    4274.0
    4292.0
    [m ]
    5
    4292.0
    4310.0
    [m ]
    6
    4310.0
    4328.2
    [m ]
    7
    4328.2
    4339.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    120.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 4219-4225m
    Core photo at depth: 4225-4231m
    Core photo at depth: 4231-4237m
    Core photo at depth: 4237-4237m
    Core photo at depth: 4238-4244m
    4219-4225m
    4225-4231m
    4231-4237m
    4237-4237m
    4238-4244m
    Core photo at depth: 4244-4250m
    Core photo at depth: 4250-4356m
    Core photo at depth: 4256-4262m
    Core photo at depth: 4262-4268m
    Core photo at depth: 4268-4274m
    4244-4250m
    4250-4356m
    4256-4262m
    4262-4268m
    4268-4274m
    Core photo at depth: 4274-4280m
    Core photo at depth: 4280-4286m
    Core photo at depth: 4286-4292m
    Core photo at depth: 4292-4298m
    Core photo at depth: 4298-4309m
    4274-4280m
    4280-4286m
    4286-4292m
    4292-4298m
    4298-4309m
    Core photo at depth: 4304-4310m
    Core photo at depth: 4310-4316m
    Core photo at depth: 4316-4322m
    Core photo at depth: 4322-4328m
    Core photo at depth: 4328-4328m
    4304-4310m
    4310-4316m
    4316-4322m
    4322-4328m
    4328-4328m
    Core photo at depth: 4328-4334m
    Core photo at depth: 4334-4339m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    4328-4334m
    4334-4339m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    4512.0
    [m]
    DC
    FUGRO
    4542.0
    [m]
    DC
    FUGRO
    4572.0
    [m]
    DC
    FUGRO
    4602.0
    [m]
    DC
    FUGRO
    4629.0
    [m]
    DC
    FUGRO
    4659.0
    [m]
    DC
    FUGRO
    4692.0
    [m]
    DC
    FUGRO
    4719.0
    [m]
    DC
    FUGRO
    4728.0
    [m]
    DC
    FUGRO
    4797.0
    [m]
    DC
    FUGRO

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.76

  • 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
    12.90
    PDF
    4.05
    PDF
    3.01
    PDF
    3.45
    PDF
    7.85
    PDF
    6.88
    PDF
    19.48
    PDF
    2.13
    PDF
    1.07
    pdf
    6.96
    PDF
    1.04
    PDF
    2.15
    PDF
    0.80
    PDF
    6.20

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    4287
    4301
    0.0
    2.0
    4256
    4260
    0.0
    3.0
    4208
    4218
    3.2
    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
    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
    3.0
    220
    300000
    0.808
    0.705
    1363

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CALI
    3775
    4832
    CBL VDL GR
    3500
    4338
    CBL VDL GR
    3570
    3228
    CBL VDL GR
    3570
    4338
    CBL VDL GR
    4150
    4280
    CYBERDIP
    3775
    4832
    CYBERLOOK
    4150
    4457
    DLL MSFL GR SP CAL
    4100
    4433
    FDC CNL GR CAL
    4300
    4831
    HDT
    3775
    4832
    HRT CCL
    10
    981
    HRT CCL
    10
    2385
    ISF BHC GR CAL
    4100
    4413
    ISF BHC GR SP
    149
    1190
    ISF BHC GR SP
    2336
    3778
    ISF BHC GR SP
    3775
    4232
    ISF MSFL BHC GR SP
    1182
    2550
    ISF MSFL BHC GR SP CAL
    4350
    4832
    LDL CNL GR CAL
    4140
    4416
    LDL CNL GR CAL
    4300
    4830
    NGT
    3775
    4830
    RFT GR
    3772
    4457
    RFT GR
    3772
    4236
    RFT GR
    3772
    4832
    RFT GR
    3772
    4832
    V5
    530
    4832

  • 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
    287.0
    36
    294.0
    0.00
    LOT
    SURF.COND.
    18 5/8
    1183.0
    24
    1205.0
    1.76
    LOT
    INTERM.
    13 3/8
    2541.0
    17 1/2
    2557.0
    1.85
    LOT
    INTERM.
    9 5/8
    3772.0
    12 1/4
    3783.0
    2.15
    LOT
    LINER
    7
    4375.0
    8 3/8
    4832.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    400
    1.09
    85.0
    waterbased
    1200
    1.10
    40.0
    waterbased
    1570
    1.26
    43.0
    waterbased
    2100
    1.33
    60.0
    waterbased
    3000
    1.38
    46.0
    waterbased
    3950
    2.00
    56.0
    waterbased
    4460
    1.97
    55.0
    waterbased
    4750
    1.94
    60.0
    waterbased

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    4328.50
    [m ]
    4323.10
    [m ]
    4317.80
    [m ]
    4312.70
    [m ]
    4303.20
    [m ]
    4299.00
    [m ]
    4294.00
    [m ]
    4289.20
    [m ]
    4281.30
    [m ]
    4275.00
    [m ]
    4271.00
    [m ]
    4259.20
    [m ]
    4237.00
    [m ]
    4231.90
    [m ]
    4228.50
    [m ]
    4225.00
    [m ]
    4222.08
    [m ]
    4219.90
    [m ]
    4249.50
    [m ]
    4230.00
    [m ]
    4257.40
    [m ]
    4220.20
    [m ]
    42661.90
    [m ]
    4261.90
    [m ]

  • 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