Wellbore: 11.07.1979 - 34/4-1 - 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.	34/4-1
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
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.	SNORRE
Discovery Name of the discovery the wellbore is related to.	34/4-1 Snorre
Well name Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.	34/4-1
Seismic location Position of spud location on seismic survey lines. SP: shotpoint.
Production licence Official designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion).	057
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.	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.	217-L
Drilling facility Norwegian Offshore Directorate's name of the facility which the wellbore was drilled from.	BYFORD DOLPHIN
Drilling days Number of days from wellbore entry to wellbore completion.	159
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,	11.07.1979
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.	16.12.1979
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.	16.12.1981
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.	26.05.2009
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
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.	LATE TRIASSIC
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.	LUNDE 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.	377.0
Total depth (MD) [m RKB] Total measured length of wellbore from kelly bushing to total depth (driller's depth).	2916.0
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).	2912.0
Maximum inclination [°] Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.	8.8
Bottom hole temperature [°C] Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.	103
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 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.	TEIST FM (INFORMAL)
Geodetic datum Reference system for coordinates. Example of legal values: ED50.	ED50
NS degrees Geographic coordinate of the wellhead, north-south degrees.	61° 32' 49.23'' N
EW degrees Geographic coordinate of the wellhead, east-west degrees.	2° 16' 23.66'' E
NS UTM [m] Universal Transverse Mercator coordinate of the wellhead, north-south.	6824096.50
EW UTM [m] Universal Transverse Mercator coordinate of the wellhead, east-west.	461368.88
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.	422

Wildcat well 34/4-1 was drilled on the rotated fault block systems on the Tampen Spur area of the Northern North Sea. The objective of the well was to test the stratigraphic sequence below the Base Cretaceous Unconformity. The primary target was the Intra Triassic "Carnian Sandstone", which was known from two wells in block 33/12 where it constitutes more than 100 m silty, argillaceous, partly calcareous cemented sandstone. The secondary targets were possible reworked Late Jurassic sandstones immediately below the Unconformity, and by possible sands associated with stratigraphically undefined seismic reflectors between Base Cretaceous and Carnian level.

Operations and results

Well 34/4-1 was spudded with the semi-submersible installation Byford Dolphin on 11 July 1979. The well was first drilled to 2961 m. When pulling out of hole to change bit it got stuck. The bit could not be worked free and the drill string was eventually backed off and left in the hole. A sidetrack was made from 2484 m and drilled to final TD at 2916 m in the Triassic Teist Formation. The well was drilled with seawater and viscosity slugs down to 844 m, with Drispac/Unical/gypsum mud from 844 m to 1988 m, and with Drispac/Unical mud from 1988 m to TD, including sidetrack.

The well penetrated Tertiary, Cretaceous and Triassic rocks with a hiatus ranging from Late Triassic to Early Cretaceous

Secondary target for the well was reworked Late Jurassic sediments immediately below Base Cretaceous. Such deposits were not established. The Triassic sandstones (Lunde Formation) were encountered at 2508 m and contained oil over a column of more than 100 m. No definite OWC was seen, but it could be estimated to be at 2618 m. Numerous shows on sandstone stringers were observed in the Cretaceous from ca 2025 m (top Kyrre Formation) and down to top of the Triassic reservoir. No shows were observed below 2622 m.

Eleven cores were cut in the Lunde Formation. Cores 1 and 2 were cut in the primary well bore, and the first of these was a mis-run. The remaining nine cores were cut in the side track. Two RFT segregated fluid samples were taken. The first, at 2541 m, recovered oil, gas and mud filtrate. The second, at 2639.5 m, recovered formation water and mud filtrate.

The well was permanently abandoned on 16 December 1979 as an oil discovery.

Testing

Two drill stem tests were performed in the Lunde Formation.

DST 1 tested the interval 2608 - 2613 m. It produced a total of 1.65 m3 salt water at a rate of approximately 11 m3 /day (79 bbls/day). The BHT in the test was 94.4 deg C

DST 2 tested the interval 2510 - 2536 m. The average rate in the final flow in this test was 238 m3/day of oil through a 1/4" choke. Average GOR was 120 m3/m3, oil Gravity was 0.82 g/cm3 (41.7 deg API) and the gas gravity was 0.712 (air = 1). The BHT in the test was 90.6 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]
530.00	2910.00

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	2509.2	2510.5	[m ]
3	2516.0	2531.8	[m ]
4	2531.8	2539.9	[m ]
5	2541.4	2544.1	[m ]
6	2557.0	2563.5	[m ]
7	2570.8	2589.8	[m ]
8	2589.8	2608.9	[m ]
9	2608.8	2614.7	[m ]
10	2615.3	2617.3	[m ]
11	2665.0	2674.6	[m ]

Cores at the Norwegian Offshore Directorate
Total core sample length [m]	90.0

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

Core photos

Core photos

2509-2510m	2516-2518m	2518-2521m	2521-2524m	2524-2526m

2526-2529m	2529-2531m	2531-2534m	2534-2537m	2537-2539m

2541-2544m	2557-2559m	2559-2562m	2562-2563m	2570-2573m
				$Core photo at depth: 2584-2587m$
2573-2576m	2576-2578m	2578-2581m	2581-2584m	2584-2587m

2587-2589m	2589-2592m	2592-2595m	2595-2597m	2597-2600m

2600-2603m	2603-2606m	2606-2608m	2608-2609m	2608-2611m

2611-2614m	2614-2614m	2615-2617m	2665-2667m	2670-2673m

2673-2674m	2667-2670m

Lithostratigraphy

Lithostratigraphy
Top depth [mMD RKB]	Lithostrat. unit
402	NORDLAND GP
1190	UTSIRA FM
1211	HORDALAND GP
1685	ROGALAND GP
1685	BALDER FM
1715	LISTA FM
1788	SHETLAND GP
1788	JORSALFARE FM
2025	KYRRE FM
2490	CROMER KNOLL GP
2490	RØDBY FM
2494	MIME FM
2508	HEGRE GP
2508	LUNDE FM
2834	LOMVI FM
2894	TEIST FM

Geochemical information

Geochemical information
Document name	Document format	Document size [MB]
422_1	pdf	0.15
422_2	pdf	0.38
422_3	pdf	1.26

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]
422_01_WDSS_General_Information	pdf	0.13
422_02_WDSS_completion_log	pdf	0.18

Documents – reported by the production licence (period for duty of secrecy expired)

Documents – reported by the production licence (period for duty of secrecy expired)
Document name	Document format	Document size [MB]
422_00_34_4_1_Completion_Log	pdf	1.60
422_00_34_4_1_Completion_Report	pdf	3.05

Drill stem tests (DST)

Drill stem tests (DST)
Test number	From depth MD [m]	To depth MD [m]	Choke size [mm]
1.0	2608	2613	0.0
2.0	2510	2536	6.3

Drill stem tests (DST)
Test number	Final shut-in pressure [MPa]	Final flow pressure [MPa]	Bottom hole pressure [MPa]	Downhole temperature [°C]
1.0
2.0	38.100	35.000		94

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
2.0	238	28560	0.820	0.712	120

Logs

Logs
Log type	Log top depth [m]	Log bottom depth [m]
CBL	403	1975
CBL	1950	2499
CST	2480	2521
CST	2677	2915
DLL	2499	2911
FDC CNL GR	2390	2915
HDT	1976	2899
ISF SONIC GR	521	2515
ISF SONIC MSFL SP GR CAL	2499	2914
MSFL	2400	2518
NGT	2499	2915
RFT	2512	2516
RFT	2541	2640
VELOCITY	524	2914

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	521.0	36	521.0	0.00	LOT
SURF.COND.	20	830.0	26	845.0	1.68	LOT
INTERM.	13 3/8	1975.0	17 1/2	1991.0	1.94	LOT
INTERM.	9 5/8	2499.0	12 1/4	2515.0	1.84	LOT
LINER	7	2703.0	8 1/2	2916.0	0.00	LOT

Drilling mud

Drilling mud
Depth MD [m]	Mud weight [g/cm3]	Visc. [mPa.s]	Mud type
860	1.15	42.0	waterbased
1275	1.27	40.0	waterbased
1810	1.48	49.0	waterbased
2080	1.77	46.0	waterbased
2370	1.78	50.0	waterbased
2565	1.77	52.0	waterbased
2900	1.77	59.0	waterbased

Pressure plots

Pressure plots
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.

Pressure plots
Document name	Document format	Document size [MB]
422_Formation_pressure_(Formasjonstrykk)	pdf	0.21

34/4-1