Wellbore: 30/3-2 R - Factpages - Norwegian Offshore Directorate

General information

General information
Attribute	Value
Wellbore name Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.	30/3-2 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).	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.	P&A
Multilateral Indicator telling if the parent well is multilateral, meaning it has more than one branch radiating from the main borehole. Example of legal values: YES, NO. See also Norwegian Offshore Directorate guidelines for designation of wells and wellbores.	NO
Factmaps in new window	link
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.	VESLEFRIKK
Discovery Name of the discovery the wellbore is related to.	30/3-2 Veslefrikk
Well name Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.	30/3-2
Production licence Official designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion).	052
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.	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.	256-L2
Drilling facility Norwegian Offshore Directorate's name of the facility which the wellbore was drilled from.	DEEPSEA SAGA
Drilling days Number of days from wellbore entry to wellbore completion.	168
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,	02.09.1980
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.	16.02.1981
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.	16.02.1983
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.	16.02.1981
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.	17.10.2007
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
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.	YES
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
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.	186.0
Total depth (MD) [m RKB] Total measured length of wellbore from kelly bushing to total depth (driller's depth).	3567.0
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).	3566.0
Maximum inclination [°] Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.	2.75
Bottom hole temperature [°C] Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.	125
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° 47' 49.23'' N
EW degrees Geographic coordinate of the wellhead, east-west degrees.	2° 55' 18.06'' E
NS UTM [m] Universal Transverse Mercator coordinate of the wellhead, north-south.	6740339.45
EW UTM [m] Universal Transverse Mercator coordinate of the wellhead, east-west.	495736.96
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.	508

Well 30/3-2 R is a re-entry of well 30/3-2, which was suspended at 955 m in Miocene sediments due to a strike. It is located ca 7 km north of the Oseberg Field in the Northern North Sea. The primary objective of the well was to test sandstones belonging to the Brent and Dunlin group. Secondary objective was sandstones in the Statfjord formation.

Operations and results

Wildcat well 30/3-2 was re-entered with the semi-submersible installation Deepsea Bergen on 2 September 1980 and drilled to TD at 3567 m in the Triassic Lunde Formation. The re-entry well track was drilled first with gel/lignosulphonate in 12 1/4" pilot hole from 955 m to 2350. Severe problems were experienced when opening up the pilot hole to 17 1/2". The mud system was changed, and a gypsum system was chosen. This change made it possible to complete the 17 1/2" section, but several days were lost due to hole problems and problems with the draw-works control circuits. The rest of the well was drilled with a gypsum/lignosulphonate mud and proceeded according to the program.

The Brent group was encountered at 2825 m and consisted of the Ness Formation down to 2878 m and the Etive Formation from 2878 m to top Dunlin Group at 2949.5 m. The Statfjord Formation was encountered at 3228 m. The Brent Group contained two separate hydrocarbon-bearing reservoirs with one oil/water contact at 2839 m in the Ness formation, and another at 2932 m in the Oseberg Formation. RFT data also indicated a light hydrocarbon gradient (0.433 g/cc) in a 7 m thick Intra Dunlin (Cook) sand at 3071 m. The character of the fluorescence seen on this sand indicated gas. Frequent but discontinuous oil shows on limestone and claystone were observed beginning at 1930 m and down through Paleocene, Cretaceous and Late Jurassic to top reservoir in the Brent Group. Below OWC shows on sandstones were observed down to 3339 m.

A total of 148 m core was recovered in 12 cores in the interval 2828 m to 3306.5 m in the Brent and Dunlin Groups and the Nansen Member of the Statfjord Formatoion. Three RFT segregated samples were taken in the Brent Group at 2833.5 m (mud filtrate and traces of oil and gas), 2872 m (mud filtrate, oil and some gas), and 2897.5 m (mud filtrate, 37 deg API oil and some gas). A fourth RFT segregated sample was taken in the upper Statfjord Formation, Nansen Member, at 3229.5 m (mud filtrate and gas). An FIT fluid sample was taken in the Dunlin Group at 3078 m (only mud filtrate and sand).

The well was permanently abandoned on 16 February 1981 as an oil and gas discovery.

Testing

Three drill stem tests were attempted in the Brent Group reservoir, two of which were successful.

DST 1 tested the interval 2916 - 2923 m in the Oseberg Formation. It produced 324 Sm3 oil and 26335 Sm3 gas /day through a 12.7 mm choke. The GOR was 81 Sm3/Sm3, the oil gravity was 38.8 deg API, and the gas gravity was 0.714 (air = 1). The DST temperature was 125.6 deg C.

DST 2 tested the interval 2870 - 2874 m in the Ness Formation. It produced 370 Sm3 oil and 30865 Sm3 gas /day through a 12.7 mm choke. The GOR was 85.9 Sm3/Sm3, the oil gravity was 39.8 deg API, and the gas gravity was 0.710 (air = 1). The DST temperature was 122.2 deg C.

DST 3 at 2832 - 2837 m in the Ness Formation failed for technical reasons.

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
1	2828.0	2833.8	[m ]
2	2834.5	2842.0	[m ]
3	2860.0	2864.4	[m ]
4	2879.0	2893.5	[m ]
5	2897.0	2898.4	[m ]
6	2898.5	2916.0	[m ]
7	2916.0	2934.6	[m ]
8	2934.6	2951.2	[m ]
9	3073.0	3082.5	[m ]
10	3083.7	3102.0	[m ]
11	3102.0	3121.4	[m ]
12	3295.0	3306.6	[m ]

Cores at the Norwegian Offshore Directorate
Total core sample length [m]	144.8

Cores at the Norwegian Offshore Directorate
Cores available for sampling?	YES

Core photos

Core photos

2828-2830m	2830-2833m	2833-2834m	2834-2837m	2837-2839m

2839-2842m	2860-2862m	2862-2864m	2879-2882m	2881-2884m

2884-2887m	2887-2889m	2889-2892m	2892-2895m	2895-2896m

2897-2898m	2898-2901m	2901-2903m	2903-2906m	2906-2909m

2909-2912m	2912-2914m	2914-2915m	2916-2918m	2918-2921m

2921-2924m	2924-2926m	2926-2929m	2929-2932m	2932-2934m

2934-2937m	2937-2940m	2940-2942m	2942-2945m	2945-2948m

2948-2950m	2950-2951m	3073-3075m	3075-3078m	3078-3081m

3081-3082m	3083-3086m	3086-3089m	3089-3091m	3091-3094m

3094-3097m	3097-3099m	3099-3102m	3102-3104m	3104-3107m

3107-3110m	3110-3112m	3112-3115m	3115-3118m	3118-3120m

3120-3121m	3295-3297m	3297-3300m	3300-3303m	3303-3305m

3305-3306m

Casing and leak–off tests

Casing and leak–off tests
Casing type	Casing diam. [inch]	Casing depth [m]	Hole diam. [inch]	Hole depth [m]	LOT/FIT mud eqv. [g/cm3]	Formation test type
CONDUCTOR	30	260.0	36	261.0	0.00	LOT
SURF.COND.	20	940.0	26	955.0	1.72	LOT
INTERM.	13 3/8	2332.0	17 1/2	2355.0	1.89	LOT
INTERM.	9 5/8	3057.0	12 1/4	3060.0	1.80	LOT
LINER	7	3564.0	8 1/2	3567.0	0.00	LOT

Drill stem tests (DST)

Drill stem tests (DST)
Test number	From depth MD [m]	To depth MD [m]	Choke size [mm]
1.0	2916	2923	12.7
2.0	2870	2874	12.7
3.0	2832	2837	0.0

Drill stem tests (DST)
Test number	Final shut-in pressure [MPa]	Final flow pressure [MPa]
1.0	32.000	23.000
2.0	31.000	23.000
3.0

Drill stem tests (DST)
Test number	Oil [Sm3/day]	Gas [Sm3/day]	Oil density [g/cm3]	Gas grav. rel.air	GOR [m3/m3]
1.0	325	27000	0.831	0.714	86
2.0	369	32000	0.826	0.710	86
3.0

Logs

Logs
Log type	Log top depth [m]	Log bottom depth [m]
CBL CCL GR	1675	3569
CBL VDL GR	2639	3051
DLL MSFL GR	2332	3562
FDC CNL GR CAL	940	3567
GEODIP	2800	3125
HDT	2332	3567
ISF SONIC GR SP	259	3567
LDT CNT GR	2332	3059
LDT GR CAL	3051	3567
VELOCITY	1900	2500

Lithostratigraphy

Lithostratigraphy
Top depth [mMD RKB]	Lithostrat. unit
211	NORDLAND GP
753	UTSIRA FM
894	HORDALAND GP
1954	ROGALAND GP
1954	BALDER FM
2002	SELE FM
2032	LISTA FM
2203	SHETLAND GP
2714	VIKING GP
2714	DRAUPNE FM
2731	HEATHER FM
2825	BRENT GP
2825	NESS FM
2879	ETIVE FM
2882	RANNOCH FM
2891	OSEBERG FM
2950	DUNLIN GP
2950	DRAKE FM
2982	COOK FM
3121	BURTON FM
3228	STATFJORD GP
3228	NANSEN FM
3298	LUNDE FM
3308	EIRIKSSON FM
3394	RAUDE FM

Geochemical information

Geochemical information
Document name	Document format	Document size [MB]
508_1	pdf	0.33
508_2	pdf	0.91
508_3	pdf	3.19
508_4	pdf	0.24
508_5	pdf	5.49

Documents – older Norwegian Offshore Directorate WDSS reports and other related documents

Documents – older Norwegian Offshore Directorate WDSS reports and other related documents
Document name	Document format	Document size [MB]
508_01_WDSS_General_Information	pdf	0.12
508_02_WDSS_completion_log	pdf	0.27

Drilling mud

Drilling mud
Depth MD [m]	Mud weight [g/cm3]	Visc. [mPa.s]	Mud type
600	1.10	50.0	waterbased
1250	1.20	50.0	waterbased
1530	1.30	54.0	waterbased
2020	1.40	57.0	waterbased
3050	1.25	56.0	waterbased
3400	1.25	57.0	waterbased

Palynological slides at the Norwegian Offshore Directorate

Palynological slides at the Norwegian Offshore Directorate
Sample depth	Depth unit	Sample type	Laboratory
340.0	[m]	DC	RRI
640.0	[m]	DC	RRI
1140.0	[m]	DC	RRI
1840.0	[m]	DC	RRI
1940.0	[m]	DC	RRI
2031.0	[m]	DC	RRI
2331.0	[m]	DC	RRI
2655.0	[m]	DC	RRI
2721.0	[m]	DC	RRI
2724.0	[m]	DC	FUGRO
2748.0	[m]	DC	FUGRO
2772.0	[m]	DC	FUGRO
2790.0	[m]	DC	FUGRO
2820.0	[m]	DC	FUGRO
2826.0	[m]	DC	FUGRO
2947.9	[m]	C	RRI
2958.0	[m]	DC	FUGRO
2976.0	[m]	DC	FUGRO
2982.0	[m]	DC	FUGRO
3006.0	[m]	DC	FUGRO
3018.0	[m]	DC	FUGRO
3036.0	[m]	DC	FUGRO
3054.0	[m]	DC	RRI
3054.0	[m]	DC	FUGRO
3114.0	[m]	DC	FUGRO
3132.0	[m]	DC	FUGRO
3168.0	[m]	DC	FUGRO
3204.0	[m]	DC	RRI
3204.0	[m]	DC	FUGRO
3210.0	[m]	DC	FUGRO
3222.0	[m]	DC	FUGRO
3423.0	[m]	DC	RRI

Thin sections at the Norwegian Offshore Directorate

Thin sections at the Norwegian Offshore Directorate
Depth	Unit
2895.00	[m ]
3073.70	[m ]
3078.00	[m ]
3081.80	[m ]
3098.00	[m ]
3121.00	[m ]
3295.45	[m ]
3304.70	[m ]
3306.10	[m ]

30/3-2 R