Give whole or part of name of wellbore, licence, field, company, discovery etc. E.g. Aker, Statfjord, 24/12, ABP21014. The main content is not searched.
Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
6507/5-9 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.
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.
PGNiG Upstream Norway 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.
1790-L
Drilling facility
Norwegian Offshore Directorate's name of the facility which the wellbore was drilled from.
Number of days from wellbore entry to wellbore completion.
18
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,
28.09.2019
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.
15.10.2019
Plugged and abondon date
Date when the P&A-operations of the wellbore was finished, as reported by the operator to the Norwegian Offshore Directorate throught DDRS (Daily Drilling Reporting System). Only applied once pr. wellhead/surface location.
15.10.2019
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.
15.10.2021
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.
10.11.2021
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.
FANGST GP
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.
BÅT GP
Kelly bushing elevation [m]
Elevation of the rotary kelly bushing (RKB) above mean sea level.
32.5
Water depth [m]
Depth in metres betweem mean sea level and sea floor.
358.0
Total depth (MD) [m RKB]
Total measured length of wellbore from kelly bushing to total depth (driller's depth).
2230.0
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).
2167.0
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.
BÅT GP
Geodetic datum
Reference system for coordinates. Example of legal values: ED50.
ED50
NS degrees
Geographic coordinate of the wellhead, north-south degrees.
65° 39' 35.84'' N
EW degrees
Geographic coordinate of the wellhead, east-west degrees.
7° 38' 50.85'' E
NS UTM [m]
Universal Transverse Mercator coordinate of the wellhead, north-south.
7282861.20
EW UTM [m]
Universal Transverse Mercator coordinate of the wellhead, east-west.
Well 6507/5-9 A is located approximately 5 km south of the Skarv Field in the Norwegian Sea. The main objectives of the well were to appraise the 6507/5-9 S (Shrek) discovery in the western downfaulted segment of the structure, prove additional commercial volumes in Fangst Group sandstones and secure necessary data to enable a full evaluation of the discovery.
Operations and results
Well 6507/5-9 A was entered with the semi-submersible rig Deepsea Nordkapp. The mainbore well 6507/5-9 S (Shrek) was drilled deviated to a depth of 2317 m in the Båt group and plugged back. The well 6507/5-9 A well was then side-tracked from below the 13 3/8`` casing at a depth of 1106 m on 28 September 2019 and drilled to TD at 2230 (2166 m TVD) in the Early Jurassic Åre Formation. The mainbore well was drilled down to 456.5 m with seawater and sweeps and from 456.5 to 1103 m with seawater, hi-vis, and KCl/Glycol water-based mud. The side-tracked was drilled with Innovert oil-based mud down to TD.
The well 6507/5-9 A encountered the top of Fangst Group, Garn Formation, at 2108 m (2011.9 m TVD MSL)where the Garn Formation consists of sandstone. The Not Formation was penetrated at 2148 m (2051.8 m TVD MSL) and consists of sandstone and claystone, in parts silty. The Båt Group was encountered at 2156 m (2059.8 m TVD MSL) and comprises of the Tilje (2156 m, 2059.8 m TVD MSL) and Åre formations (2169 m, 2072.8 m TVD MSL) where both formations consist of sandstone with a thin coal layer. A 62.7 m hydrocarbon column was proved in the Fangst and Båt groups, 23.7 m of gas column was found in the Garn Formation and 39 m column of oil in the Garn, Not, Tilje and Åre formations. Forty-five meters of the column was in sandstone with mainly good to very good reservoir quality. The gas-oil contact (GOC) was determined from pressure gradient analysis at 2130.7 m (2034.6 m TVD MSL) and the oil-water contact (OWC) calculated from the pressure plot to be at 2169.7 m (2073.6 m TVD MSL). Both contacts came in at equivalent depth as in the discovery well. The Net-to-Gross ratio of the HC zone is calculated to be at 77.8 %. MDT fluid samples were taken at 2119 m (2022.9 m TVD MSL, gas), 2141.5 m (2045.3 m TVD MSL, oil) and 2186 m (2089.9 m TVD MSL, water). No cores were taken in the side-track, but 3 cores were cut from the primary target Garn in the mainbore.
The well was permanently plugged and abandoned on 15 October 2019 as an oil and gas appraisal well.
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