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.
15/9-12 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.
Den norske stats oljeselskap a.s
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.
309-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.
33
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,
29.03.1982
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.
27.04.1982
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.
27.04.1982
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.
27.04.1984
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.
28.03.2014
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/PLUGGING
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.
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.
HUGIN FM
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.
110.0
Total depth (MD) [m RKB]
Total measured length of wellbore from kelly bushing to total depth (driller's depth).
3740.0
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).
3739.0
Maximum inclination [°]
Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
4.2
Bottom hole temperature [°C]
Estimated temperature at final total depth of the wellbore. Shown only for released wells.
See discription.
124
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.
MIDDLE 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.
SLEIPNER FM
Geodetic datum
Reference system for coordinates. Example of legal values: ED50.
ED50
NS degrees
Geographic coordinate of the wellhead, north-south degrees.
58° 27' 23.17'' N
EW degrees
Geographic coordinate of the wellhead, east-west degrees.
1° 43' 4.01'' E
NS UTM [m]
Universal Transverse Mercator coordinate of the wellhead, north-south.
6480390.26
EW UTM [m]
Universal Transverse Mercator coordinate of the wellhead, east-west.
Well 15/9-12 R is a re-entry of well 15/9-12, which was drilled as an appraisal well on the saddle area between the Alpha and Beta structures on the Sleipner Vest field in the North Sea. Due to technical problems with the rig the final testing was not done in the primary well. The purpose of the re-entry was testing and plugging.
Operations and results
Well 15/9-12 was re-entered on 29 March 1982 with the semi-submersible installation Deepsea Saga.
After testing the well was permanently abandoned on 27 April 1982 as a gas-condensate appraisal well.
Testing
Three Drill Stem Tests were conducted. DST 1A tested the interval 3585 m 3595 m. This test was aborted due to bad weather after flowing the well for 150 minutes. The interval was retested a few days later in DST 1B.
DST 1B flowed 252 Sm3 condensate and 771600 Sm3 gas /day through a 64/64" choke. The condensate/gas ratio (CGR) was 3056 Sm3/Sm3, the condensate density was 0.793 g/cm3, and the gas gravity was 0.772 (air = 1) with ca 8% CO2. The DST temperature was 121 deg C at gauge depth 3561.8 m.
DST 2 tested the interval 3512 m to 3522 m. It flowed 231 Sm3 condensate and 808500 Sm3 gas /day through a 64/64" choke. The CGR was 3495 Sm3/Sm3, the condensate density was 0.793 g/cm3, and the gas gravity was 0.765 (air = 1) with ca 7% CO2. The DST temperature was 119 deg C at gauge depth 3499 m.
Eight gas samples and six condensate samples were taken at the separator during DST 1. Eight gas and eight condensate samples were taken at the separator during DST 2. Neither test experienced sand production nor was H2S detected.
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.
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