Wellbore: 7225/3-1 - 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.	7225/3-1
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
Press release	link to press release
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.	BARENTS SEA
Discovery Name of the discovery the wellbore is related to.	7225/3-1 (Norvarg)
Well name Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.	7225/3-1
Seismic location Position of spud location on seismic survey lines. SP: shotpoint.	inline 1438 & crossline 1874 BST4 PSTM FINAL
Production licence Official designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion).	535
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.	Total E&P Norge 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.	1350-L
Drilling facility Norwegian Offshore Directorate's name of the facility which the wellbore was drilled from.	WEST PHOENIX
Drilling days Number of days from wellbore entry to wellbore completion.	149
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,	30.04.2011
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.	25.09.2011
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.	25.09.2013
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.	25.09.2013
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.	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.	STØ FM
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.	LATE TRIASSIC
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.	KOBBE 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 TRIASSIC
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.	HAVERT FM
Kelly bushing elevation [m] Elevation of the rotary kelly bushing (RKB) above mean sea level.	39.0
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).	4150.0
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).	4147.0
Maximum inclination [°] Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.	5.1
Bottom hole temperature [°C] Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.	157
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.	PERMIAN
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.	ISBJØRN FM
Geodetic datum Reference system for coordinates. Example of legal values: ED50.	ED50
NS degrees Geographic coordinate of the wellhead, north-south degrees.	72° 54' 58.31'' N
EW degrees Geographic coordinate of the wellhead, east-west degrees.	25° 52' 2.67'' E
NS UTM [m] Universal Transverse Mercator coordinate of the wellhead, north-south.	8091704.90
EW UTM [m] Universal Transverse Mercator coordinate of the wellhead, east-west.	462862.72
UTM zone Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.	35
NPDID wellbore Norwegian Offshore Directorate's unique id for the wellbore.	6587

Well 7225/3-1 was the first well to be drilled on the faulted Norvarg Dome on the Bjarmeland Platform in the Barents Sea. It was drilled fairly close to the crest of the structure. The primary objective was to prove hydrocarbon presence, determine fluid nature and evaluate reservoir characteristics in sandstones of the Late Triassic (Carnian) Lower Snadd Formation and the Early Triassic Kobbe Formation. Secondary objective was to prove hydrocarbons in the Jurassic Stø Formation, the Early Triassic Havert Formation, and the Permian Tempelfjorden and Bjarmeland groups.

Operations and results

Wildcat well 7225/3-1 was spudded with the semi-submersible installation West Phoenix on 30 April 2011 and drilled to TD at 4150 m in the Permian Isbjørn Formation. No major drilling problems were encountered, but P&A in the upper part was subject to extensive delays associated with trying to retrieve casing, failed cement plugs or leak in 20" casing and extra time spent trying to locate the source of a gas leak. The well was drilled with bentonite mud with hiv-vis pills down to 672 m, and with KCl/polymer mud from 672 m to TD.

Gas was proven both in intervals from the Jurassic and the Triassic. The Jurassic Stø Formation was gas bearing from top at 726 m to a likely GWC at 766.5 m. In the Triassic the upper part of the Snadd Formation with top at 804 m was supposed to be gas bearing, but this was not proven by sampling. The best Snadd sands, below 1040 m, could be sampled and they were water bearing. An Intra-Carnian section was penetrated from 1146 m to 1521 m. It contained gas in two zones with GWC's at 1218 m and ca 1250 m, respectively, and in a third thin sandstone from 1347 m to 1357 m. The upper and the lowermost Intra-Carnian gas zone were confirmed by MDT sampling. The Kobbe Formation was encountered at 1521 m. It is 634 m thick with 27.5% net/gross based on petrophysical evaluations. Gas was tested in numerous thin sandstone beds from 1557 m to 1779 m by MDT sampling and by a DST. The Havert Formation with top at 2554 m had only poorly developed reservoir rocks. MDT testing failed, but it was assumed to be gas bearing as well based on logs.

Rig site analyses of fluorescence (oil shows) and by GCMS analyses of up to C7 components in mud gas ("FLAIR analysis") suggested that the Stø and upper Snadd gas zones were oil-associated. The deeper gas zones were practically devoid of liquid components based on these analyses.

Four conventional cores were cut. Core 1 was cut in intra-Carnian sandstone and claystone from 1204-1258 m with 98% recovery. Core 2 was cut in the Kobbe Formation from 1675 to 1695 m with 83.3% recovery (jammed off). Core 3 was cut from 2610 to 2637 m in the Havert Formation with 100% recovery. Core 4 was cut from 4013 to 4016 m in the Isbjørn Formation with 15% recovery (jammed off). During two successful MDT wire line runs a total of 9 sampling stations were performed. Samples were taken at 1090.01 m (Snadd Formation; water+gas), 1121.98 m (Snadd Formation water), 1215.26 m (Intra-Carnian Sandstone; gas), 1279.99 m (Intra-Carnian sandstone; water), 1349.78 m (Intra-Carnian sandstone; gas), 1353.41 m (Intra-Carnian sandstone; gas), 1560.21 m (Kobbe Formation: gas), 1595.97 m (Kobbe Formation: only fluid scanning; no sample), 1778.65 m (Kobbe Formation: gas).

The well was permanently abandoned on 25 September 2011 as a gas discovery.

Testing

The well was perforated from 1557-1570 m,1580-1621 m and 1631 m-1685 m in the Kobbe interval.The test produced 180000 Sm3 gas/day througt a 44/64" choke. The gas gravity 0,618(air=1)

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]
690.00	4149.00

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
1	1204.0	1256.9	[m ]
2	1675.0	1691.7	[m ]
3	2610.0	2637.1	[m ]
4	4013.0	4013.5	[m ]

Cores at the Norwegian Offshore Directorate
Total core sample length [m]	97.1

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

Lithostratigraphy

Lithostratigraphy
Top depth [mMD RKB]	Lithostrat. unit
416	ADVENTDALEN GP
416	KOLMULE FM
636	KNURR FM
670	HEKKINGEN FM
695	FUGLEN FM
727	KAPP TOSCANA GP
727	STØ FM
770	FRUHOLMEN FM
804	SNADD FM
1146	NO FORMAL NAME
1522	SASSENDALEN GP
1522	KOBBE FM
2155	KLAPPMYSS FM
2555	HAVERT FM
3666	TEMPELFJORDEN GP
3666	ØRRET FM
3771	RØYE FM
3931	BJARMELAND GP
3931	ISBJØRN FM

Drill stem tests (DST)

Drill stem tests (DST)
Test number	From depth MD [m]	To depth MD [m]	Choke size [mm]
1.0	1557	1685	17.5

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

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		180000		0.618

Logs

Logs
Log type	Log top depth [m]	Log bottom depth [m]
FMI GR	3750	4150
FMI PPC MSIP PPC	3390	4147
HGNS CMR	3750	4150
IBC DCBL GR	800	2503
LEH EDTC HNGS APS TLD HRLA CMR S	2580	3745
LEH EDTC PPC MSIP PPC FMI	2425	3753
LWD - ADR SWRO GM PWD PCDC	4016	4150
LWD - AFR EWR DGR ALD CTN FTWD P	677	1067
LWD - EWR DGR PWD DI	440	3750
LWD - EWR P4 DGR PWD PCDC	3751	4013
MDT GR	1062	2064
MDT GR	1594	1889
MDT GR	1596	1976
MDT GR	2605	2640
MDT GR	2606	2606
MDT GR	2606	3472
MDT GR	2609	2620
MSCT GR	1090	2309
MSCT GR	1090	1826
MSCT GR	2605	3475
MSIP FMI	1062	2064
SP CMR HRLA TLD APS HNGS	1062	2064
SP GPIT PPC MSIP PPC TLD APS HNG	1062	2514
SP HRLA TLD APS	3750	4150
USIT CBL GR	395	1062
VSP GR	416	2514
VSP GR	2500	4143

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	482.0	36	484.0	0.00	LOT
SURF.COND.	20	665.0	26	672.0	1.50	LOT
PILOT HOLE		681.0	9 7/8	681.0	0.00
INTERM.	13 5/8	1062.0	17 1/2	1070.0	1.82	LOT
INTERM.	9 5/8	2503.0	12 1/4	2514.0	1.85	LOT
LINER	7	3749.0	8 1/2	3750.0	1.90	LOT
OPEN HOLE		4150.0	6	4150.0	0.00	LOT

Drilling mud

Drilling mud
Depth MD [m]	Mud weight [g/cm3]	Visc. [mPa.s]	Mud type
431	1.30	10.0	waterbased
500	1.30	10.0	waterbased
502	1.24	11.0	ManualEntry
511	1.30	10.0	waterbased
540	1.25	13.0	waterbased
552	1.05	16.0	seawater
552	1.25	10.0	waterbased
652	1.30	10.0	waterbased
680	1.05	16.0	waterbased
854	1.25	12.0	waterbased
854	1.37	14.0	waterbased
957	1.35	14.0	waterbased
1070	1.25	17.0	waterbased
1730	1.36	1.0	brine
2014	1.35	19.0	waterbased
2100	1.45	24.0	waterbased
2514	1.35	22.0	waterbased
3750	1.52	22.0	waterbased
4150	1.45	17.0	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]
6587_Formation_pressure_(Formasjonstrykk)	pdf	0.28

7225/3-1