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.
34/8-7 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).
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.
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.
Norsk Hydro Produksjon 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.
725-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.
84
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,
19.11.1992
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.
10.02.1993
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.
10.02.1993
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.
10.02.1995
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.
24.09.2003
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.
WILDCAT
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.
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.
BRENT 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.
COOK FM
3rd level with HC, age
Age of lithostratigraphic unit, 3rd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
EARLY JURASSIC
3rd level with HC, formation
Name of lithostartigraphic unit, 3rd 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.
STATFJORD GP
Kelly bushing elevation [m]
Elevation of the rotary kelly bushing (RKB) above mean sea level.
23.0
Water depth [m]
Depth in metres betweem mean sea level and sea floor.
334.0
Total depth (MD) [m RKB]
Total measured length of wellbore from kelly bushing to total depth (driller's depth).
5460.0
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).
5441.4
Maximum inclination [°]
Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
12.8
Bottom hole temperature [°C]
Estimated temperature at final total depth of the wellbore. Shown only for released wells.
See discription.
181
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.
61° 19' 9.07'' N
EW degrees
Geographic coordinate of the wellhead, east-west degrees.
2° 33' 32.15'' E
NS UTM [m]
Universal Transverse Mercator coordinate of the wellhead, north-south.
6798582.22
EW UTM [m]
Universal Transverse Mercator coordinate of the wellhead, east-west.
Well 34/8-7 is located on the western flank of the Tampen Spur and is situated approximately 7.4 kilometres due east of well 34/8-4S, in the Visund prospect. This was the third exploration well to be drilled in the licence area. The primary objective of well 34/8-7 was to test the Jurassic Brent Group and Statfjord Formation in the hanging wall of the Visund Fault. The secondary objectives were to establish a good seismic to well correlation and to fulfil licence obligations.
Operations and results
Exploration well 34/8-7 was spudded with the semi-submersible rig "Polar Pioneer" on 21 March 1992 and drilled to TD at 5460 m in the Triassic Hegre Group. The well was drilled with spud mud down to 1444 m and with KCl/PHPA/Polymer mud from 1444 m to 3288 m. From 3288 m the mud system was gradually changed to a HTHP (high temperature stable polymers) mud. Still, towards TD of the well it was evident that some of the chemical/polymers was decomposing and forming carbonates.
Conglomeratic density flow deposits (Intra Draupne Formation sandstone) were found in the upper part of the Draupne Formation. From a gross thickness of 134.5m, 5.75m of net sand were identified of which 5.25m were regarded as net pay. An average porosity value 9.4% and average Sw of 50.1% were computed for the pay section. A core cut in the Intra Draupne sandstone gave 5.2 % core porosity on average.
The primary objective Brent Group was encountered at 4632.5 m. The entire Brent Group was interpreted as being gas bearing. From a gross thickness of 134.5m, 36.5m of net sand were recognised with 36.5m of net pay. An average porosity of 9.8% and average Sw of 30.4% were determined. A core cut in the Brent Group, gave an average porosity of 9.9 %. The sandy member of Cook Formation was found to be gas bearing, but poor reservoir properties reduced the net pay to only 2.0 m with an average porosity of 8.3 % and average Sw of 36.1 %.
No net pay was identified in the Amundsen sand.
The Statfjord Formation came in at 5118 m. It was 88.5 m thick of which 22.5 m was net sand and 18.75 m was identified as net gas bearing pay. Cores cut in the Statfjord Formation gave an average core porosity of 7.1 % porosity.
A total of five cores were cut in isolated intervals throughout the well. Core number 1 was cut in the Intra Draupne Sandstone, core number 2 was cut in the Tarbert and Ness Formations, cores number 3 and 4 were cut in the Statfjord Formation, while core number 5 was cut in the Hegre Group. Attempts to take RFT pre-test in the Draupne equivalent conglomerate proved to be unsuccessful due to the tight nature of the Formation. Because of hole washouts and high down hole temperature and pressure anomalies, no RFT pressure measurements could be obtained in the Brent Group and Statfjord Formations.
After running the liner as part of preparing for drill stem testing, "Polar Pioneer" had to be released for other purposes. The well was therefore suspended on 16 July 1992 with the provision that testing of the reservoir zones would be performed at a later date. The well was re-entered (34/8-7 R) with the semi-submersible installation "Polar Pioneer" on 19 November 1992 for testing. It was permanently abandoned as a gas discovery on 10 February 1993.
Testing
Well 34/8-7 R was tested in two intervals. In Test 1 in the Statfjord Formation (5117.8 m ? 5210.0 m) no production was achieved. Test 2 in the Brent Group (4671.7 m ? 4731.0 m) produced gas.
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