Wellbore: 6407/7-6 - 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.	6407/7-6
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
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.	NORWEGIAN SEA
Field Name of the field the wellbore is related to.	NJORD
Discovery Name of the discovery the wellbore is related to.	6407/7-6
Well name Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.	6407/7-6
Production licence Official designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion).	107
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.	985-L
Drilling facility Norwegian Offshore Directorate's name of the facility which the wellbore was drilled from.	SCARABEO 6
Drilling days Number of days from wellbore entry to wellbore completion.	60
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,	18.10.2000
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.	16.12.2000
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.	16.12.2002
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.	18.12.2002
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.	GAS/CONDENSATE
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.	EARLY 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.	TILJE FM
Kelly bushing elevation [m] Elevation of the rotary kelly bushing (RKB) above mean sea level.	26.0
Water depth [m] Depth in metres betweem mean sea level and sea floor.	336.0
Total depth (MD) [m RKB] Total measured length of wellbore from kelly bushing to total depth (driller's depth).	3975.0
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).	3971.0
Maximum inclination [°] Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.	9.58
Bottom hole temperature [°C] Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.	148
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.	EARLY JURASSIC
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.	ÅRE FM
Geodetic datum Reference system for coordinates. Example of legal values: ED50.	ED50
NS degrees Geographic coordinate of the wellhead, north-south degrees.	64° 17' 40.66'' N
EW degrees Geographic coordinate of the wellhead, east-west degrees.	7° 6' 16.31'' E
NS UTM [m] Universal Transverse Mercator coordinate of the wellhead, north-south.	7131389.98
EW UTM [m] Universal Transverse Mercator coordinate of the wellhead, east-west.	408271.69
UTM zone Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.	32
NPDID wellbore Norwegian Offshore Directorate's unique id for the wellbore.	4172

Well 6407/7-6 is located within Njord Unit on the western flank of the Njord Field. The northwest flank structure consists of five fault blocks defined by faults trending south-southwest and north-northeast, with throw towards west. The objective for the well 6407/7-6 was to test the hydrocarbon potential of the "B-segment" on the northwest flank of the Njord field. The primary target was to test the hydrocarbon potential of the Tilje formation of the Båt Group, while the hydrocarbon potential of the Ile Formation of the Fangst Group was a secondary target. There existed also a possibility of hydrocarbons in the Upper Jurassic Melke formation of the Viking Group, and in the Lower Cretaceous Lange Formation of the Cromer Knoll Group.

Operations and results

Wildcat well 6407/7-6 was spudded with the semi-submersible installation "Scarabeo 6" on 18 October 2000. First spud failed due to boulders and high angle in the hole. After a second spud on October 19 the well was first drilled to TD at 3930 m in the Early Jurassic Åre Formation. The TD was later extended to 3975 m to get space for test equipment. The extended TD was not logged. Shallow gas was not encountered. The well was drilled with water based bentonite mud down 1231 m and with oil based mud (Versavert) from 1231 m to TD. The main result of the well was the discovery of gas-condensate in the Tilje Formation as proven by a DST and by MDT fluid samples. The well penetrated 127 m Late Jurassic, 111 m Ile Formation, and 197 m Tilje Formation. The sands encountered in the Lange Formation, the Viking Group, and the Ile Formation were water bearing, but hydrocarbon shows were observed in the approximate 20 m net Lange sandstone and increasing amounts of background gas was measured while drilling in the upper part of the Ile Formation. The Tilje Formation was saturated with a heavy gas-condensate from 3693 m down to a Gas/Water Contact at 3777 m, determined from the resistivity log. Six cores were cut in the Tilje Formation with a recovery of 98% giving a total of 129m. Horizontal Klinkenberg corrected permeability in the range of 0.02 - 12.2 mD was measured in the cores. The core porosity seldom exceeded 20%. Pressure measurements from both the Ile and the Tilje Formations indicate an approximate overpressure of 160-170 bar on the B-segment compared to the Njord East flank. MDT fluid sampling was attempted in the Tilje, Lange and the Ile formations. No samples could be taken in Lange and Ile formations due to tight formations. In the Tilje Formation five samples were retrieved from 3748 m. The short clean-up time prior to sampling caused the samples to be highly contaminated with base oil from the drilling mud (30 % & 60 % base oil). The well was plugged and abandoned as an oil discovery on 16 December 2000.

Testing

The well was production tested with a perforation interval between 3686-3770 m in the Tilje Formation. With 24 hours production the flow rate was measured to 155 000 Sm3/D gas and 220 Sm3/D oil. The GOR was 705 Sm3/Sm3.

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]
1240.00	3930.00

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	3701.0	3707.6	[m ]
2	3743.0	3769.0	[m ]
3	3770.5	3785.7	[m ]
4	3786.0	3808.7	[m ]
5	3809.0	3837.3	[m ]
6	3837.4	3864.9	[m ]

Cores at the Norwegian Offshore Directorate
Total core sample length [m]	126.2

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

Core photos

Core photos

3701-3706m	3706-3746m	3746-3751m	3751-3756m	3756-3761m

3761-3766m	3766-3771m	3771-3776m	3776-3781m	3781-3785m

3786-3791m	3791-3796m	3796-3801m	3801-3806m	3806-3811m

3811-3816m	3816-3821m	3821-3826m	3826-3831m	3831-3836m

3836-3840m	3840-3845m	3845-3850m	3850-3855m	3855-3860m

3860-3865m

Oil samples at the Norwegian Offshore Directorate

Oil samples at the Norwegian Offshore Directorate
Test type	Bottle number	Top depth MD [m]	Bottom depth MD [m]	Fluid type	Test time	Samples available
DST	DST 1	3726.00	0.00		01.12.2000 - 00:00	YES

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	446.5	36	449.0	0.00	LOT
SURF.COND.	20	1224.0	26	1229.0	1.80	LOT
INTERM.	9 5/8	3094.0	12 1/4	3100.0	1.76	LOT
OPEN HOLE		3975.0	8 1/2	3975.0	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	3686	3770	16.0

Drill stem tests (DST)
Test number	Final shut-in pressure [MPa]	Final flow pressure [MPa]	Bottom hole pressure [MPa]	Downhole temperature [°C]
1.0		52.450		136

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	220	155000	0.815		705

Logs

Logs
Log type	Log top depth [m]	Log bottom depth [m]
AIT IPLT /LDS APS HNGS	3093	3930
CMR ESC VSP	2900	3913
CMR+	3440	3882
CST	3125	3900
MDT	3880	3925
MSCT	0	0
MWD - CDR GR RES PWD DIR	365	3100
MWD - RAB CDR GR RES DEN PWD	3100	3930
UBI DSI	2900	3925

Lithostratigraphy

Lithostratigraphy
Top depth [mMD RKB]	Lithostrat. unit
362	NORDLAND GP
362	NAUST FM
1169	HORDALAND GP
1169	BRYGGE FM
1840	ROGALAND GP
1840	TARE FM
1922	TANG FM
2105	SHETLAND GP
2105	SPRINGAR FM
2142	NISE FM
2352	KVITNOS FM
2747	CROMER KNOLL GP
2747	LANGE FM
3338	VIKING GP
3338	SPEKK FM
3351	MELKE FM
3407	FANGST GP
3407	NOT FM
3448	ILE FM
3558	BÅT GP
3558	ROR FM
3684	TILJE FM
3882	ÅRE FM

Composite logs

Composite logs
Document name	Document format	Document size [MB]
4172	pdf	0.46

Geochemical information

Geochemical information
Document name	Document format	Document size [MB]
4172_1	pdf	1.88
4172_2	pdf	1.67

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]
4172_6407_7_6_COMPLETION_LOG	.PDF	1.52
4172_6407_7_6_COMPLETION_REPORT	.PDF	9.52
4172_6407_7_6_COMPLETION_REPORT_ENCL1	.PDF	3.38
4172_6407_7_6_COMPLETION_REPORT_ENCL2	.PDF	3.77
4172_6407_7_6_COMPLETION_REPORT_ENCL3	.PDF	0.67
4172_6407_7_6_COMPLETION_REPORT_ENCL4	.PDF	0.56

Drilling mud

Drilling mud
Depth MD [m]	Mud weight [g/cm3]	Visc. [mPa.s]	Mud type
386	1.05		WATER BASED
392	0.00		WATER BASED
900	0.00		OIL BASED
1232	1.60	72.0	OIL BASED
2541	1.60	38.0	OIL BASED
2900	1.61	50.0	OIL BASED
3083	1.60	44.0	OIL BASED
3100	1.60	45.0	OIL BASED
3205	1.60	44.0	OIL BASED
3377	1.61	42.0	OIL BASED
3558	1.60	33.0	OIL BASED
3700	1.60	33.0	OIL BASED
3709	1.62	33.0	OIL BASED
3720	1.60	34.0	OIL BASED
3743	1.61	34.0	OIL BASED
3771	1.61	33.0	OIL BASED
3786	1.61	37.0	OIL BASED
3809	1.61	36.0	OIL BASED
3852	1.61	36.0	OIL BASED
3864	1.61	34.0	OIL BASED
3975	1.61	46.0	OIL BASED

6407/7-6