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.
31/5-2 R
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.
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.
391-L2
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.
79
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,
13.06.1984
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.
30.08.1984
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.
30.08.1984
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.
30.08.1986
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.
18.12.2008
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
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.
YES
Reentry activity
Reason for reentry of the wellbore. Only relevant for exploration wellbores. Example of legal values: DRILLING, DRILLING/PLUGGING, LOGGING, PLUGGING, TESTING, TESTING/PLUGGING.
TESTING
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.
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.
SOGNEFJORD FM
Kelly bushing elevation [m]
Elevation of the rotary kelly bushing (RKB) above mean sea level.
26.0
Water depth [m]
Depth in metres betweem mean sea level and sea floor.
316.0
Total depth (MD) [m RKB]
Total measured length of wellbore from kelly bushing to total depth (driller's depth).
2500.0
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).
2500.0
Maximum inclination [°]
Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
2
Bottom hole temperature [°C]
Estimated temperature at final total depth of the wellbore. Shown only for released wells.
See discription.
87
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.
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.
HEGRE GP
Geodetic datum
Reference system for coordinates. Example of legal values: ED50.
ED50
NS degrees
Geographic coordinate of the wellhead, north-south degrees.
60° 43' 33.29'' N
EW degrees
Geographic coordinate of the wellhead, east-west degrees.
3° 32' 52.74'' E
NS UTM [m]
Universal Transverse Mercator coordinate of the wellhead, north-south.
6732542.72
EW UTM [m]
Universal Transverse Mercator coordinate of the wellhead, east-west.
Well 31/5-2 R is a re-entry of well 31/5-2. The overall purpose of these wells was to test the reservoir quality, the oil/gas columns, and the hydrocarbon/water contact in the area. The objective of the re-entry was to undertake drill stem testing of the reservoir.
Operations and results
Appraisal well 31/5-2 was re-entered (31/5-2 R) with the semi-submersible installation Treasure Saga. The rig arrived location on 10 June 1984 but due to problems with anchor handling, and on establishing 4 guidelines to well head before running BOP on riser the well was not re-entered before 13 June. After the bridge plug was retrieved at 642 m the hole was circulated with seawater and finally displaced with CaCl brine. Due to the complexity of the tests, equipment failures and an unplanned third test, the duration of the testing period was 67 days, 42 days longer than prognosed.
After testing the well was permanently abandoned on 30 August 1984 as an oil and gas appraisal.
Testing
Three drill stem tests were performed.
DST 1 tested the interval 1577 - 1581 m and produced maximum 1000 m3 oil + water /day trough a 25.4 mm choke. The GOR was 53 Sm3 /Sm3 at 10.3 bar and 60 deg C throughout the test. The corresponding WHP was 22 bar with a nitrogen injection rate of 11.5 m/min. The water production started in the beginning and increased continuously through the test. The final water cut was 62%. The oil density was 0.896 g/cm3 and the gas gravity (air = 1) was 0.66.
DST 2 tested the interval 1574 - 1576 m and produced maximum 1290 m3 oil + water/day through 44.5 + 23.8 mm choke. The GOR was 53 Sm3 /Sm3 with separator conditions of 3.8 bar and 29degC. The corresponding WHP was 15 bar. The water production started after 50 hours of flow and the water cut increased to 34%. The oil density was 0.89 g/cm3 and the gas gravity (air = 1) was 0.66.
DST 3 tested the interval 1546.5 - 1554.5 m produced 1200000 Sm3 of gas / day trough a 44.5 mm choke. The gas/condensate ratio was 41700 Sm3/Sm3 at separator conditions of 32 bar and 12 deg C. The corresponding WHP was 70 bars. The liquid (condensate) density was 0.78 g/cm3 and the gas gravity (air = 1) was 0.61.
The maximum temperatures recorded during the tests were 68.3 deg C in DST 1, 73.8 deg C in DST 2, and 68.3 deg C in DST3. The reported reservoir pressure was 157.6 bar at 1575 m in the oil zone and 157.9 bars at 1550.5 m in the gas zone.
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