30/9-3 A

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• General information

  General information

  Attribute	Value
  Wellbore name Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.	30/9-3 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.	P&A
  Factmaps in new window	link to map
  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.	OSEBERG SØR
  Discovery Name of the discovery the wellbore is related to.	30/9-3 Oseberg Sør
  Well name Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.	30/9-3
  Seismic location Position of spud location on seismic survey lines. SP: shotpoint.	NH 82 - 065 SP. 377
  Production licence Official designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion).	079
  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.	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.	406-L
  Drilling facility Norwegian Offshore Directorate's name of the facility which the wellbore was drilled from.	NORTRYM
  Drilling days Number of days from wellbore entry to wellbore completion.	85
  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,	26.02.1984
  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.	20.05.1984
  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.	20.05.1986
  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.	03.10.2011
  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.	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.	NESS 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.	111.0
  Total depth (MD) [m RKB] Total measured length of wellbore from kelly bushing to total depth (driller's depth).	4300.0
  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).	4008.0
  Maximum inclination [°] Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.	35.5
  Bottom hole temperature [°C] Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.	138
  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° 28' 16.33'' N
  EW degrees Geographic coordinate of the wellhead, east-west degrees.	2° 45' 37.55'' E
  NS UTM [m] Universal Transverse Mercator coordinate of the wellhead, north-south.	6704071.58
  EW UTM [m] Universal Transverse Mercator coordinate of the wellhead, east-west.	486827.21
  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.	102

• Wellbore history

  General

  Well 30/9-3 A is a sidetrack to well 30/9-3 on the Gamma West structure on the Oseberg Fault Block in the northern North Sea. The primary objective of 30/9-3 was to find hydrocarbon accumulations in the Middle Jurassic Brent Group. Secondary objective was to find additional hydrocarbon accumulations in the Early Jurassic. Planned TD was ca 75 m below a possible intra Triassic marker to a depth of 4188 +/- 100 m. Well 30/9-3 discovered oil in the Brent Group, but reached only 3113 m in the Drake Formation due to fish in the hole. For the same reason no wire line logs were run below 1713.5 m.

  Sidetrack well 30/9-3 A was drilled to complete the well programme.

  Operations and results

  Well 30/9-3 A was kicked off on 26 February 1984, from a window from 1539 to 1562 m in the 13 3/8" casing. The well was drilled to TD at 4300 m (4008 m TVD) in the Late Triassic Lunde Formation using the semi-submersible installation Nortrym. No significant problem was encountered in the operations. The well was drilled with Invermul/EZmul Oil Based Mud from kick-off to TD.

  The Ness Formation (2853.5 - 3059 m, 2717.3 - 2890 m TVD) was encountered at a horizontal distance of 538 m to the west of the 30/9-3 well. The top of the formation had been subjected to erosion and lacked the sandstone units which were found in the upper part of the 30/9-3 well. The lithology was alternating sandstones, siltstones and shales with beds of coal. The sandstones were generally very fine to fine grained, locally medium grained, and occurred often as normally graded beds.

  The Ness Formation was found oil bearing down to 3000 m (2840m TVD). No oil/water contact could be established in this well due to shaly formation. The oil column extended to the top of the reservoir except for an isolated gas bearing sandstone bed at 2880 - 2886 m. From logs the net pay was calculated to 20.3 m of a gross thickness of 122.7 m giving a net to gross ratio of 0.17. The average porosity was calculated to 20.1% with an average water saturation of 29%. The Etive Formation (3059 - 3133 m, 2890 - 2952.5 m TVD), which consisted of sandstones with a predominantly medium to coarse grain size, was found water bearing. FMT pressure recordings indicated that the hydrocarbon bearing and the water bearing parts of the Brent Group belonged to two different pressure regimes. The Statfjord Formation (3679 - 4161 m, 3431.5-3879 m TVD) was encountered at a distance of 936.5m to the west of the 30/9-3 well and consisted of alternating sandstones, which were very fine to very coarse grained, siltstones and shales. Beds of coal occurred occasionally. The Statfjord Formation was water bearing. Oil shows were recorded in Maastrichtian limestone in the upper part of the Shetland Group.

  Fourteen conventional cores were cut in the well, of which one was cut in the Hordaland Group, twelve were cut in the Ness Formation, and one in the Etive Formation. A segregated oil sample was obtained from the FMT at 2915.5 m in the Ness Formation. Segregated samples taken at 2885.7 m and 2885.5 m in the Nesss Formation contained both oil and gas, while pressure gradients indicated that this sandstone unit (2880 - 2886 m) was gas bearing. Water samples were obtained in the Etive Formation at 3086 m and in the Statfjord Formation at 3692 m.

  The well was permanently abandoned on 20 May 1984 as an oil and gas appraisal well.

  Testing

  One Drill Stem Test was carried out in the well in the oil zone in the Ness Formation. The perforated interval was 2910-2916 m (2764.65 - 2769.7 m TVD). The well flowed 800 Sm3/day of oil with a gravity of 34.3 API and 108000 Sm3 of gas with a gravity of 0.710 (air=l) through a 38.1 mm choke size. GOR was 135 Sm3/Sm3. Maximum recorded temperature in this flow was 109.6 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]
  1545.00	4300.00

• 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
  2	2853.0	2861.0	[m ]
  3	2861.0	2872.3	[m ]
  4	2873.0	2891.2	[m ]
  5	2891.5	2909.0	[m ]
  6	2909.5	2927.3	[m ]
  7	2928.0	2951.0	[m ]
  8	2951.0	2968.0	[m ]
  9	2968.0	2980.3	[m ]
  10	2981.0	2981.8	[m ]
  11	2982.0	3005.0	[m ]
  12	3007.9	3018.0	[m ]
  13	3018.0	3036.5	[m ]
  14	3084.0	3102.5	[m ]

  Cores at the Norwegian Offshore Directorate

  Total core sample length [m]	196.0

  Cores at the Norwegian Offshore Directorate

  Cores available for sampling?	YES

• Core photos

  Core photos

  2853-2861m	2853-2861m	2853-2861m	2853-2861m	2853-2861m
  2853-2861m	2853-2861m	2853-2861m	2853-2861m	2853-2861m
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  2861-2872m	2861-2872m	2861-2872m	2861-2872m	2873-2891m
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  2968-2980m	2968-2980m	2981-2982m	2981-2982m	2982-3003m
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