Wellbore: 676-L - 2/1-9 - 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.	2/1-9
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.	GYDA
Discovery Name of the discovery the wellbore is related to.	2/1-9 Gyda Sør
Well name Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.	2/1-9
Seismic location Position of spud location on seismic survey lines. SP: shotpoint.	X-OVER 3D LINE 560 AND X-LINE 570
Production licence Official designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion).	019 B
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.	BP Norway Limited U.A.
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.	676-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.	83
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,	15.04.1991
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.	06.07.1991
Plugged date Date when plugging operations was finished, as reported by the operator to the Norwegian Offshore Directorate through DDRS (Daily Drilling Reporting System).	06.07.1991
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.	06.07.1993
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.	16.10.2007
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.	APPRAISAL
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 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.	ULA FM
Kelly bushing elevation [m] Elevation of the rotary kelly bushing (RKB) above mean sea level.	23.0
Water depth [m] Depth in metres betweem mean sea level and sea floor.	66.0
Total depth (MD) [m RKB] Total measured length of wellbore from kelly bushing to total depth (driller's depth).	4298.0
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).	4298.0
Maximum inclination [°] Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.	2.2
Bottom hole temperature [°C] Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.	160
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.	LATE 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.	ZECHSTEIN GP
Geodetic datum Reference system for coordinates. Example of legal values: ED50.	ED50
NS degrees Geographic coordinate of the wellhead, north-south degrees.	56° 51' 37.77'' N
EW degrees Geographic coordinate of the wellhead, east-west degrees.	3° 5' 4.77'' E
NS UTM [m] Universal Transverse Mercator coordinate of the wellhead, north-south.	6302000.77
EW UTM [m] Universal Transverse Mercator coordinate of the wellhead, east-west.	505162.30
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.	1667

Well 2/1-9 was drilled on the Gyda South structure, a fault/dip closure in the Late Jurassic fairway on the eastern flank of the Central Graben, 6 km south of the Gyda Field. The main objective of the well was to test the Late Jurassic "Gyda sandstone" (Ula Formation) target and prove a volume of oil that was commercial as a tie back development to the Gyda platform. Secondary reservoir potential existed in both the Middle Jurassic and in the uppermost part of the Triassic. Estimated TD was 4275 m TVD RKB.

Operations and results

Appraisal well 2/1-9 was spudded with the semi submersible rig Ross Isle 15 March 1991 and drilled to TD at 4298 m in the late Permian Zechstein Group. No significant problems were encountered in the operations. No shallow gas was detected. The well was drilled with seawater and high viscosity slugs down to 900 m, and with Aquamul ether-based invert emulsion mud system from 900 m to TD.

A 59 m Forties Formation sandstone sequence was encountered at 2923 m in the Late Paleocene and another ca 30 m thick sandstone sequence at 3025 m within the Lista Formation. Top Mandal Formation was encountered at 4013.5 m, 10.5m deeper than predicted. Top Ula Formation was encountered hydrocarbon bearing from 4048 to 4209 m, which was 111 m thicker than expected. The OWC was interpreted from logs to be at 4137.0 m, while the cores taken had good oil shows all through the cored section, i.e. down to 4153 m. No reservoir sections were encountered in the Middle Jurassic. No Triassic sediments were penetrated by the well.

Five cores were cut continuously from 4019 m to 4153 m with 100% recovery. Core 1 covered the lower part of the Mandal, Farsund, and the upper part of the Ula Formation. Cores 2, 3, 4 and 5 were cut in the Ula Formation. Good oil shows was observed throughout the cored section of the Ula sandstone. RFT fluid samples were taken at 4088.7 m (oil), 4137.0 m (oil), 4151 (water), and 4177 m (water).

Well 2/1-9 was considered a potential water injector for the Gyda South discovery, and to be sidetracked up-dip as a producer. A full evaluation of the DST and PVT data would be performed together with a geological remapping and evaluation of the discovery. The well was thus suspended on 6 July 1991, as an oil discovery. It would be re-entered later, after the above evaluations had been completed.

Testing

One DST was run in the interval 4078 - 4108 m and resulted in an oil rate of 166 Sm3 oil/day through a 32/64" choke. The gas rate was 91180 Sm3/day and the water rate was 120 Sm3/day. The GOR was 548 Sm3/Sm3 and the oil gravity was 43 deg API. Due to the presence of H2S the lower part of the Ula Formation was not tested.

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	4019.0	4046.0	[m ]
2	4046.0	4074.0	[m ]
3	4074.0	4102.0	[m ]
4	4102.0	4124.5	[m ]
5	4125.0	4153.0	[m ]

Cores at the Norwegian Offshore Directorate
Total core sample length [m]	133.5

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

Core photos

Core photos

4019-4024m	4024-4029m	4039-4034m	4034-4039m	4039-4044m

4044-4046m	4046-4051m	4051-4056m	4056-4061m	4061-4066m

4066-4071m	4071-4074m	4074-4079m	4079-4084m	4084-4089m

4089-4094m	4094-4099m	4099-4102m	4102-4107m	4107-4112m

4112-4117m	4117-4122m	4122-4124m	4125-4130m	4130-4135m

4135-4140m	4140-4145m	4145-4150m	4150-4152m

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		0.00	0.00			YES
DST	DST1	4108.00	4078.00		14.06.1991 - 00:00	YES

Lithostratigraphy

Lithostratigraphy
Top depth [mMD RKB]	Lithostrat. unit
89	NORDLAND GP
1814	HORDALAND GP
2898	ROGALAND GP
2898	BALDER FM
2915	SELE FM
2923	FORTIES FM
2982	LISTA FM
3055	VIDAR FM
3143	LISTA FM
3158	VÅLE FM
3168	SHETLAND GP
3168	EKOFISK FM
3256	TOR FM
3617	HOD FM
3765	BLODØKS FM
3783	HIDRA FM
3800	CROMER KNOLL GP
3800	RØDBY FM
3838	SOLA FM
3852	TUXEN FM
3867	ÅSGARD FM
4014	TYNE GP
4014	MANDAL FM
4034	FARSUND FM
4048	VESTLAND GP
4048	ULA FM
4257	BRYNE FM
4289	ZECHSTEIN GP

Composite logs

Composite logs
Document name	Document format	Document size [MB]
1667	pdf	0.50

Geochemical information

Geochemical information
Document name	Document format	Document size [MB]
1667_1	pdf	0.33
1667_2	pdf	0.97

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]
1667_01_WDSS_General_Information	pdf	1.46
1667_02_WDSS_completion_log	pdf	0.22

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]
1667_2_1_9_COMPLETION_LOG	pdf	1.76
1667_2_1_9_COMPLETION_REPORT	pdf	11.33

Drill stem tests (DST)

Drill stem tests (DST)
Test number	From depth MD [m]	To depth MD [m]	Choke size [mm]
1.0	4078	4108	17.4

Drill stem tests (DST)
Test number	Final shut-in pressure [MPa]	Final flow pressure [MPa]	Bottom hole pressure [MPa]	Downhole temperature [°C]
1.0	7.000		23.600	160

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	165	90577			549

Logs

Logs
Log type	Log top depth [m]	Log bottom depth [m]
CBL VDL CCL GR	2040	2895
CBL VDL CCL GR	3761	4249
CST GR	3500	3947
CST GR	3957	4288
DIL LLS GR	0	3954
DIL SDT GR	3945	4298
ENERJET CCL	4078	4093
ENERJET CCL	4093	4108
GR CCL	2700	2700
GR CCL	4003	4003
GR CCL	4150	4150
JUNK BASKET CCL	3980	3980
JUNK BASKET CCL	4250	4250
LDL CNL NGT	3945	4298
MWD - RWD	88	4289
OBDT GR	3945	4298
PERM PACKER	4003	4003
RFT GR SAMPLE	4049	4243
RFT SAMPLE	4088	4088
RFT SAMPLE	4151	4151
RFT SAMPLE	4177	4177
VELOCITY	500	4213

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	164.0	36	166.0	0.00	LOT
INTERM.	20	895.0	26	897.0	1.74	LOT
INTERM.	13 3/8	2893.0	17 1/2	2896.0	2.03	LOT
INTERM.	9 5/8	3938.0	12 1/4	3940.0	2.15	LOT
LINER	7	4275.0	8 1/2	4289.0	0.00	LOT

Drilling mud

Drilling mud
Depth MD [m]	Mud weight [g/cm3]	Visc. [mPa.s]	Mud type
415	0.00		OIL BASED
426	1.57	42.0	OIL BASED
900	1.04		WATER BASED
961	1.20	31.0	WATER BASED
1583	1.39	49.0	WATER BASED
2153	1.60	72.0	WATER BASED
2474	1.60	64.0	WATER BASED
2529	1.60	74.0	WATER BASED
2682	1.60	73.0	WATER BASED
2874	1.60	71.0	WATER BASED
2901	1.60	77.0	WATER BASED
3018	1.60	69.0	WATER BASED
3114	1.60	68.0	WATER BASED
3173	1.60	7.7	WATER BASED
3193	1.60	57.0	WATER BASED
3243	1.60	60.0	WATER BASED
3253	1.60	68.0	WATER BASED
3318	1.60	76.0	WATER BASED
3413	1.60	79.0	WATER BASED
3610	1.60	80.0	WATER BASED
3775	1.73	85.0	WATER BASED
3847	1.73	77.0	WATER BASED
3910	1.73	82.0	OIL BASED
3947	1.73	91.0	OIL BASED
3967	1.72	82.0	OIL BASED
4019	1.62	51.0	OIL BASED
4039	1.56	49.0	OIL BASED
4074	1.56	47.0	OIL BASED
4102	1.57	53.0	OIL BASED
4125	0.14	53.0	OIL BASED
4153	1.57	53.0	OIL BASED
4240	1.58	56.0	OIL BASED
4289	1.59	72.0	OIL BASED

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]
1667_Formation_pressure_(Formasjonstrykk)	PDF	0.21

2/1-9