Wellbore: 02.01.2024 - 6506/12-3 - 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.	6506/12-3
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.	NORWEGIAN SEA
Field Name of the field the wellbore is related to.	ÅSGARD
Discovery Name of the discovery the wellbore is related to.	6506/12-3 Smørbukk Sør
Well name Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.	6506/12-3
Seismic location Position of spud location on seismic survey lines. SP: shotpoint.	ST 8403 - 402 A SP. 1112
Production licence Official designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion).	094
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.	456-L
Drilling facility Norwegian Offshore Directorate's name of the facility which the wellbore was drilled from.	ROSS ISLE
Drilling days Number of days from wellbore entry to wellbore completion.	138
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,	02.03.1985
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.	17.07.1985
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.	17.07.1987
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.	28.06.2007
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
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.	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 CRETACEOUS
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.	LYSING 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.	MIDDLE JURASSIC
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.	FANGST GP
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 JURASSIC
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.	TILJE FM
Kelly bushing elevation [m] Elevation of the rotary kelly bushing (RKB) above mean sea level.	22.0
Water depth [m] Depth in metres betweem mean sea level and sea floor.	301.0
Total depth (MD) [m RKB] Total measured length of wellbore from kelly bushing to total depth (driller's depth).	4360.0
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).	4359.0
Maximum inclination [°] Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.	4.4
Bottom hole temperature [°C] Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.	152
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.	TILJE FM
Geodetic datum Reference system for coordinates. Example of legal values: ED50.	ED50
NS degrees Geographic coordinate of the wellhead, north-south degrees.	65° 1' 31.09'' N
EW degrees Geographic coordinate of the wellhead, east-west degrees.	6° 53' 27.35'' E
NS UTM [m] Universal Transverse Mercator coordinate of the wellhead, north-south.	7213112.80
EW UTM [m] Universal Transverse Mercator coordinate of the wellhead, east-west.	400646.78
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.	468

Wildcat well 6506/12-3 is a replacement well for 6506/12-2, which was abandoned at 955 m due to technical problems. The new well was designed to test the hydrocarbon potential of the Beta structure in the southeast part of the

block. The main object was Middle Jurassic sandstones, secondary targets were possible Cretaceous sands, Early Jurassic sandstones and sandstones within the Coal Beds.

Operations and results

Well 6506/12-3 was spudded with the semi-submersible installation Ross Isle, 47 m from the junked well 6506/12-2. It was spudded on 2 March 1985 and drilled to TD at 4360 m in the Early Jurassic Tilje Formation (formerly called the Aldra Formation). No significant technical problems occurred during the operations. From 0600 hours on 15 June, during the testing phase, the rig was on strike for 13 days. The well was drilled with seawater/gel down to 955 m, with gypsum/lignosulphonate mud from 955 m to 3831 m, and with gel/lignosulphonate mud from 3831 m to TD. The shallow gas present at 572 m in 6506/12-2 was not encountered in 6506/12-3.

Top Middle Jurassic Garn Formation (formerly Tomma Formation) came in at 3822 m, 80 m above the prognosis. The Early Jurassic Tilje Formation sandstone (Aldra Formation) came in at 4147 m. Hydrocarbons were encountered both in the Middle and the Early Jurassic sandstones, with a hydrocarbon/water contact at 4216 m in the Tilje Formation. Late Cretaceous Lysing sandstones at the top of the Cromer Knoll Group (Finnvær Group) was also hydrocarbon bearing. A total of 242 m of hydrocarbon bearing sands was proven. Shows were only recorded in association with the hydrocarbon bearing sections.

A total of 289 m core was recovered in 15 cores from the Garn, Not, Ile, Ror, and Tilje Formations between 3836 and 4269 m. Six RFT runs were completed in the Early - Middle Jurassic section in well 6506/12-3. A total of 47 pressure tests gave reliable results. In addition, segregated fluid samples were collected at 3863 m, 4231 m, 4308.1 m, and 4310.9 m.

The well was permanently abandoned on 17 July as an oil/condensate/gas discovery.

Testing

Six DST tests were performed:

DST 1 at 4222 - 4241 m in the Tilje Formation flowed 742 Sm3 light oil and 373300 Sm3 gas /day through a 22.2 mm choke. The GOR was 503 Sm3/Sm3, the oil density was 0.802 g/cm3 and the gas gravity was 0.847 (air = 1). The DST temperature was 150 deg C.

DST 2 at 4165 - 4170 m in the Tilje Formation flowed 53.8 Sm3 light oil and 66800 Sm3 gas /day through a 25.4 mm choke. The GOR was 1241 Sm3/Sm3, the oil density was 0.820 g/cm3 and the gas gravity was 0.907 (air = 1). The DST temperature was 143.8 deg C.

DST 3 at 3960 - 3980 m in the Ile Formation flowed 328.9 Sm3 condensate and 453100 Sm3 gas /day through a 31.8 mm choke. The GOR was 1378 Sm3/Sm3, the oil density was 0.787 g/cm3 and the gas gravity was 0.745 (air = 1). The DST temperature was 143.4 deg C.

DST 4 at 3880 - 3890 m in the Garn Formation flowed 777.3 Sm3 light oil and 396500 Sm3 gas /day through a 23.8 mm choke. The GOR was 510 Sm3/Sm3, the oil density was 0.820 g/cm3 and the gas gravity was 0.764 (air = 1). The DST temperature was 141.8 deg C.

DST 5 at 3822 - 3836 m in the topmost Garn Formation flowed 156.2 Sm3 oil and 37600 Sm3 gas /day through a 12.7 mm choke. The GOR was 241 Sm3/Sm3, the oil density was 0.830 g/cm3 and the gas gravity was 0.787 (air = 1). The DST temperature was 141 deg C.

DST 6 at 3162 - 3173 m in the Lysing Formation flowed 582.7 Sm3 light oil, 712.2 m3 water, and 109600 Sm3 gas /day through a 19.1 mm choke. The GOR was 188 Sm3/Sm3, the oil density was 0.807 g/cm3 and the gas gravity was 0.780 (air = 1). This was the only test with water production.

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]
950.00	4360.00

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	3836.0	3845.5	[m ]
2	3845.5	3855.0	[m ]
3	3855.0	3864.2	[m ]
4	3864.2	3882.6	[m ]
5	3884.0	3911.2	[m ]
6	3911.2	3926.0	[m ]
7	3949.0	3977.0	[m ]
8	3977.0	4003.0	[m ]
9	4004.0	4017.9	[m ]
10	4116.0	4144.0	[m ]
11	4144.0	4170.0	[m ]
12	4170.0	4197.5	[m ]
13	4197.5	4221.5	[m ]
14	4221.5	4249.5	[m ]
15	4249.5	4268.0	[m ]

Cores at the Norwegian Offshore Directorate
Total core sample length [m]	308.5

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

Core photos

Core photos

3836-3842m	3842-3845m	3845-3851m	3851-3855m	3855-3861m

3861-3864m	3864-3869m	3870-3876m	3878-3882m	3882-3883m

3884-3890m	3890-3896m	3896-3902m	3902-3908m	3908-3917m

3911-3917m	3917-3923m	3923-3925m	3949-3955m	3955-3961m

3961-3967m	3967-3973m	3973-3977m	3977-3983m	3983-3989m

3989-3995m	3995-4001m	4001-4003m	4004-4010m	4010-4016m

4016-4017m	4116-4122m	4122-4128m	4128-4134m	4134-4140m

4140-4144m	4144-4150m	4150-4156m	4156-4162m	4162-4168m

4168-4170m	4170-4176m	4176-4182m	4182-4188m	4188-4194m

4194-4197m	4197-4203m	4203-4209m	4209-4215m	4215-4221m

4221-4222m	4222-4227m	4227-4233m	4233-4239m	4239-4245m

4245-4249m	4249-4255m	4255-4261m	4261-4267m	4267-4268m

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]	Test time	Samples available
DST	DST1	4222.00	4241.00	21.05.1985 - 23:20	YES
DST	DST2	4143.00	4148.00	28.05.1985 - 00:30	YES
DST	DST3	3960.00	3980.00	04.06.1985 - 01:30	YES
DST	DST4	3880.00	3890.00	10.06.1985 - 00:00	YES
DST	DST5	3822.00	3836.00	03.07.1985 - 10:10	YES
DST	DST6	3162.00	3173.00	08.07.1985 - 16:40	YES

Lithostratigraphy

Lithostratigraphy
Top depth [mMD RKB]	Lithostrat. unit
323	NORDLAND GP
323	NAUST FM
1388	KAI FM
1982	HORDALAND GP
1982	BRYGGE FM
2214	ROGALAND GP
2214	TARE FM
2278	TANG FM
2336	SHETLAND GP
3146	CROMER KNOLL GP
3146	LYSING FM
3173	LANGE FM
3709	VIKING GP
3709	SPEKK FM
3721	MELKE FM
3822	FANGST GP
3822	GARN FM
3908	NOT FM
3947	ILE FM
3997	BÅT GP
3997	ROR FM
4147	TILJE FM

Geochemical information

Geochemical information
Document name	Document format	Document size [MB]
468_1	pdf	0.88
468_2	pdf	0.54
468_3	pdf	4.69
468_4	pdf	1.16
468_5	pdf	5.00
468_6	pdf	0.15

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]
468_01_WDSS_General_Information	pdf	0.31
468_02_WDSS_completion_log	pdf	0.31

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]
468_01_6506_12_3_Completion_report	pdf	23.72
468_02_6506_12_3_Completion_log	pdf	2.73

Drill stem tests (DST)

Drill stem tests (DST)
Test number	From depth MD [m]	To depth MD [m]	Choke size [mm]
1.0	4222	4241	25.4
2.0	4165	4170	25.4
3.0	3960	3980	25.4
4.0	3881	3890	28.6
5.0	3822	3836	9.5
6.0	3162	3173	32.0
6.1	3162	3173	15.8

Drill stem tests (DST)
Test number	Final shut-in pressure [MPa]	Final flow pressure [MPa]	Bottom hole pressure [MPa]	Downhole temperature [°C]
1.0		83.000		120
2.0		10.000		120
3.0		7.000		118
4.0		9.000		121
5.0	7.000		23.000	120
6.0		14.000	40.000
6.1		128.000

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	820	372000	0.810	0.803	454
2.0	54	68000	0.820	0.907	1264
3.0	297	445000	0.795	0.755	1500
4.0	790	416000	0.820	0.765	526
5.0	100	29000	0.830	0.797	290
6.0	92	28000	0.785	0.797	304
6.1	329	57000	0.814	0.797	173

Logs

Logs
Log type	Log top depth [m]	Log bottom depth [m]
CBL VDL CCL GR	347	2236
CBL VDL CCL GR	2390	3797
CBL VDL CCL GR	3659	4287
CEQL	3659	4298
CST	2281	3824
CST	4078	4351
DIL LSS GR	3810	4359
DLL MSFL GR SP	3809	4357
ISF LSS MS SP GR	940	3830
LDL CNL NGT GR	2236	4362
LDL GR	940	2249
MWD - GR RES DIR	940	4358
NGS	2236	4362
RFT GR	3840	3961
RFT GR	3863	3863
RFT GR	3865	4335
RFT GR	3961	4208
RFT GR	4302	4306
RFT GR	4309	4343
SHDT GR	2236	4362
VELOCITY	600	4350

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	404.0	36	404.0	0.00	LOT
SURF.COND.	20	940.0	26	955.0	1.65	LOT
INTERM.	13 3/8	2240.0	17 1/2	2280.0	1.87	LOT
INTERM.	9 5/8	3809.0	12 1/4	3831.0	1.83	LOT
LINER	7	4359.0	8 1/2	4360.0	0.00	LOT

Drilling mud

Drilling mud
Depth MD [m]	Mud weight [g/cm3]	Visc. [mPa.s]	Yield point [Pa]	Mud type	Date measured
2043	1.25	11.0	7.5	WATERBASED	19.03.1985
2043	1.25	11.0	7.5	WATER BASED	19.03.1985
2131	1.40	12.0	7.0	WATER BASED	19.03.1985
2131	1.40	12.0	7.0	WATERBASED	19.03.1985
2206	1.48	17.0	10.0	WATERBASED	19.03.1985
2206	1.48	17.0	10.0	WATER BASED	19.03.1985
2250	1.57	17.0	10.0	WATERBASED	19.03.1985
2250	1.57	17.0	10.0	WATER BASED	19.03.1985
3290	1.65	240.0	7.0	WATERBASED	02.04.1985
3290	1.65	240.0	7.0	WATER BASED	02.04.1985
3711	1.70	21.0	6.2	WATER BASED	10.04.1985
3711	1.70	21.0	6.2	WATERBASED	10.04.1985
3822	1.20			WATER BASED	17.04.1985
3830	1.73		24.0	WATERBASED	15.04.1985
3830	1.73		24.0	WATER BASED	15.04.1985
4360	1.12	10.0	9.0	WATER BASED	07.05.1985

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]
468_Formation_pressure_(Formasjonstrykk)	pdf	0.24

6506/12-3