Wellbore: 25/2-13 - 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.	25/2-13
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).	APPRAISAL
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.	HUGIN
Discovery Name of the discovery the wellbore is related to.	25/2-5 Lille Frøy
Well name Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.	25/2-13
Seismic location Position of spud location on seismic survey lines. SP: shotpoint.	EL 8801 RAD 367 & KOLONNE 483
Production licence Official designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion).	026
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.	Elf Petroleum 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.	617-L
Drilling facility Norwegian Offshore Directorate's name of the facility which the wellbore was drilled from.	WEST VANGUARD
Drilling days Number of days from wellbore entry to wellbore completion.	142
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,	06.09.1989
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.	25.01.1990
Plugged and abondon date Date when the P&A-operations of the wellbore was finished, as reported by the operator to the Norwegian Offshore Directorate throught DDRS (Daily Drilling Reporting System). Only applied once pr. wellhead/surface location.	06.08.2015
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.	25.01.1992
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.	15.08.2008
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/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.	NO
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.	HUGIN 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.	SLEIPNER 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 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.	STATFJORD GP
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.	117.0
Total depth (MD) [m RKB] Total measured length of wellbore from kelly bushing to total depth (driller's depth).	3908.0
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).	3903.0
Maximum inclination [°] Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.	6.2
Bottom hole temperature [°C] Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.	128
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 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.	SMITH BANK FM
Geodetic datum Reference system for coordinates. Example of legal values: ED50.	ED50
NS degrees Geographic coordinate of the wellhead, north-south degrees.	59° 47' 37.69'' N
EW degrees Geographic coordinate of the wellhead, east-west degrees.	2° 27' 12.52'' E
NS UTM [m] Universal Transverse Mercator coordinate of the wellhead, north-south.	6628728.80
EW UTM [m] Universal Transverse Mercator coordinate of the wellhead, east-west.	469325.46
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.	1459

Well 25/2-13 was drilled in the central part of the Viking Graben, east of the Frigg area. The block straddles the eastern flank of the graben and the north-western part of the Utsira High. It was the first appraisal well on the 25/2-5 discovery, which discovered oil in different reservoirs of the Vestland Group and the Statfjord Formation. The structure is a north-south trending horst, which is located on a terrace in the southern part of the block. Well 25/2-13 was drilled close to a major normal fault bounding the structure. The main objective was to evaluate the western panel. The well should test the fluid columns in both the Vestland Group and the Statfjord Formation, obtain data for fluid characterisation and productivity, and try to define the hydrocarbon contacts of the reservoirs.

Operations and results

Appraisal well 25/2-13 was spudded 6 June 1989 by the semi-submersible installation West Vanguard drilled to TD at 3909 m in the Triassic Smith Bank Formation. The well was drilled to 13" 3/8 casing point (2043 m) without problems, but at 2178 m the bit got stuck and a sidetrack was needed. The sidetrack was kicked off from 2070 m. The first attempt failed, but the second was successful. During coring of the Vestland Group, the core barrel was lost in hole and a second sidetrack was decided after unsuccessful fishing. This sidetrack was kicked off from 3306. The mud that was used in the Jurassic section (3318 - 3887 m) was an FCL type mud which was based on fresh water with added bentonite, polymers, lignosulfonate and barite.

Top Vestland Group came in at 3342 m as prognosed, and with mobile hydrocarbons in two layers; oil in the top ca 40 - 60 m of the reservoir with an unclear OWC in the interval 3382 - 3415 m, and with oil shows down to 3423 m; and gas-condensate in an isolated layer in the Lower Vestland Group with a gross thickness = 33 m. However, the reservoir properties in the Vestland Group were not as good as in 25/2-5. Top Statfjord came in at 3695.5 m, 50 m deeper than prognosed with thickness as expected, but with mobile oil only in a thin zone at the very top. A very tentative OWC was placed at 3709 m, based on RFT pressure data logs, and some moveable oil in DST 2A. Fair shows were recorded down to 3729 m.

A total of 19 cores were cut in this well. Cores 1 and 2 were cut in the original hole from 3340 to 3394.5 m, while cores 3 to 19 were cut in the sidetracked hole from 3387 to 3468.5 m. The core to log depth shifts for cores #1 to #7 are in the range 2.75 to 7.75 m. The core to log depth shifts for cores #11 to #19 are in the range 4.2 to 5.5 m. RFT samples were taken at 3696.5 m (mud filtrate with traces of oil very little gas) and 3727.5 m (mud filtrate with very little gas).

The well was suspended 25 January 1990 as an oil / gas / condensate appraisal.

Testing

Seven drill stem tests were conducted in this well (DST 1,2A & 2B, 3A & 3B, 4, 5). Tests 1 and 2 were conducted in the Statfjord Formation while tests 3, 4 and 5 were conducted in the Vestland Group.

DST #l tested the interval 3759 - 3785 m and produced a total of 42.5 m3 formation water. The final shut-in temperature was 124.4 deg C.

DST #2A tested the interval 3706 - 3713 m, which produced no formation fluids to surface.

DST #2B tested the interval 3695 - 3698 m in addition to the DST2 #A interval. The test flowed 69 sm3 oil and 29400 Sm3 gas /day on a 16/64" choke with a WHP of 85 bar and GOR of 425 sm3/sm3. The oil density was 0.821 g/cm3. The final shut-in temperature was 122.8 deg C.

DST #3A tested the interval 3480 - 3491. This zone was very tight and flowed 154 litres only. Due to the low rates the movable formation fluid could not be identified. The test confirmed that the zone was in a separate and higher pressure regime than the Vestland Group hydrocarbon reservoirs above it.

DST #3B tested the intervals 3437 - 3447 plus 3449.8 - 3460 in addition to the DST #3A interval. The test flowed 242000 sm3 gas-condensate /day with a GOR of 1115 sm3/sm3 and WHP of 170 bar on a 32/64" choke. The condensate density was 0.789 g/cm3. The final shut-in temperature was 115 deg C.

DST #4 tested the interval 3411.5 - 3423 and produced a total of 2856 litres Formation water. The final shut-in temperature was 112.8 deg C.

DST #5 tested the intervals 3343 - 3370 plus 3376.5 - 3382. The test flowed 651 sm3 oil and 213600 Sm3 gas /day on a 40/64" choke with a WHP of 125 bar and GOR of 328 sm3/sm3. The oil density was 0.825 g/cm3 and the gas gravity was 0.816 (air = 1). The final shut-in temperature was 111.8 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]
205.00	3907.50

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	3340.0	3341.8	[m ]
2	3367.0	3394.8	[m ]
3	3387.0	3406.0	[m ]
4	3405.0	3423.0	[m ]
5	3429.0	3441.0	[m ]
6	3441.0	3469.0	[m ]
7	3459.0	3468.6	[m ]
8	3649.0	3667.1	[m ]
9	3667.1	3669.7	[m ]
11	3709.0	3726.3	[m ]
12	3727.0	3744.7	[m ]
13	3745.0	3763.0	[m ]
14	3763.0	3781.5	[m ]
15	3781.5	3792.0	[m ]
16	3792.0	3810.6	[m ]
17	3810.5	3828.8	[m ]
18	3829.0	3847.0	[m ]
19	3847.0	3854.2	[m ]

Cores at the Norwegian Offshore Directorate
Total core sample length [m]	280.8

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

Core photos

Core photos

3340-3345m	3345-3350m	3350-3355m	3355-3360m	3360-3361m

3367-3372m	3372-3377m	3377-3382m	3382-3387m	3387-3392m

3392-3394m	3387-3392m	3392-3397m	3397-3402m	3402-3405m

3405-3410m	3410-3415m	3415-3420m	3420-3423m	3423-3428m

3428-3433m	3433-3438m	3438-3441m	3441-3446m	3446-3451m

3451-3456m	3456-3459m	3459-3464m	3464-3468m	3709-3714m

3714-3719m	3719-3724m	3724-3726m	3727-3732m	3732-3737m

3737-3742m	3742-3744m	3745-3750m	3750-3755m	3755-3760m

3760-3763m	3763-3768m	3768-3773m	3737-3778m	3778-3781m

3781-3786m	3786-3791m	3791-3792m	3792-3797m	3797-3802m

3802-3807m	3807-3810m	3810-3815m	3815-3820m	3820-3825m

3825-3828m	3829-3834m	3834-3839m	3839-3844m	3844-3847m

3847-3852m	3852-3854m

Palynological slides at the Norwegian Offshore Directorate

Palynological slides at the Norwegian Offshore Directorate
Sample depth	Depth unit	Sample type	Laboratory
3341.0	[m]	C	APT
3341.5	[m]	C	APT
3342.3	[m]	C	APT
3344.6	[m]	C	APT
3345.7	[m]	C	APT
3353.3	[m]	C	APT
3357.5	[m]	C	APT
3367.6	[m]	C	APT
3369.6	[m]	C	APT
3371.6	[m]	C	APT
3378.7	[m]	C	APT
3379.6	[m]	C	APT
3381.9	[m]	C	APT
3397.5	[m]	C	APT
3399.6	[m]	C	APT
3404.7	[m]	C	APT
3405.7	[m]	C	APT
3410.4	[m]	C	APT
3414.9	[m]	C	APT
3418.0	[m]	C	APT
3420.8	[m]	C	APT
3422.7	[m]	C	APT
3423.7	[m]	C	APT
3426.2	[m]	C	APT
3427.2	[m]	C	APT
3433.0	[m]	C	APT
3433.3	[m]	C	APT
3439.3	[m]	C	APT
3439.8	[m]	C	APT
3444.2	[m]	C	APT
3445.6	[m]	C	APT
3446.0	[m]	C	APT
3447.8	[m]	C	APT
3450.9	[m]	C	APT
3452.6	[m]	C	APT
3457.4	[m]	C	APT
3459.8	[m]	C	APT
3460.1	[m]	C	APT
3465.0	[m]	C	APT
3465.0	[m]	C	APT
3465.1	[m]	C	APT
3468.5	[m]	C	APT
3469.3	[m]	C	APT
3469.6	[m]	C	APT

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		2252.00	0.00		14.02.1986 - 00:00	NO
DST	DST2B	2706.00	2713.00		20.12.1989 - 00:00	YES
DST	DST3B	3396.96	0.00	WATER	01.01.1990 - 00:00	NO
DST	DST4	3403.00	3411.00	WATER	07.01.1990 - 15:43	YES
DST	DST5	3343.00	3382.00	WATER	15.01.1990 - 00:00	YES
DST	DST5	3343.00	3382.00		15.01.1990 - 00:00	YES
DST	DST5	3343.00	3382.00		15.01.1990 - 00:00	YES

Lithostratigraphy

Lithostratigraphy
Top depth [mMD RKB]	Lithostrat. unit
139	NORDLAND GP
437	UTSIRA FM
1067	HORDALAND GP
2170	ROGALAND GP
2170	BALDER FM
2240	HERMOD FM
2400	LISTA FM
2586	TY FM
2651	VÅLE FM
2706	SHETLAND GP
2706	HARDRÅDE FM
3032	KYRRE FM
3187	TRYGGVASON FM
3268	BLODØKS FM
3286	SVARTE FM
3318	VIKING GP
3318	DRAUPNE FM
3329	HEATHER FM
3342	VESTLAND GP
3342	HUGIN FM
3409	SLEIPNER FM
3491	DUNLIN GP
3491	DRAKE FM
3565	COOK FM
3645	AMUNDSEN FM
3696	STATFJORD GP
3887	NO GROUP DEFINED
3887	SMITH BANK FM

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]
1459_01_WDSS_General_Information	pdf	0.26
1459_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]
1459_25_2_13_COMPLETION_REPORT_AND_LOG	pdf	34.10

Drill stem tests (DST)

Drill stem tests (DST)
Test number	From depth MD [m]	To depth MD [m]	Choke size [mm]
1.0	3785	3774	4.7
2.0	3713	3706	0.0
2.3	3713	3695	6.3
3.1	3460	3437	12.5
5.0	3382	3343	15.8

Drill stem tests (DST)
Test number	Final shut-in pressure [MPa]	Final flow pressure [MPa]	Downhole temperature [°C]
1.0	10.000	10.000	124
2.0
2.3	8.500		123
3.1	16.000		115
5.0	12.500		112

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
2.3	69	29400	0.823	0.880	425
3.1	210	242000	0.800	0.800	1120
5.0	650	213600	0.829	0.818	330

Logs

Logs
Log type	Log top depth [m]	Log bottom depth [m]
CBL CCL GR	1575	3300
CBL VDL GR	1330	2044
DIL BHC LDL GR	700	2022
DIL LSS GR	3300	3903
DIL MSFL GR AMS SP	3300	3529
DIL SLS LDL GR	2044	3319
DLL MSFL GR	3675	3900
FMS GR	3299	3700
FMS GR	3650	3812
LDL CNL NGL	3300	3529
LDL CNL NGT	3476	3901
MWD - GR RES DIR	202	3908
RFT	3346	3418
RFT	3354	3489
RFT	3482	3886
RFT	3696	3696
SHDT GR	2044	3312

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	199.0	36	201.0	0.00	LOT
INTERM.	20	700.0	26	714.0	1.20	LOT
INTERM.	13 3/8	2043.0	17 1/2	2057.0	1.72	LOT
INTERM.	9 5/8	3301.0	12 1/4	3315.0	1.90	LOT
LINER	7	3903.0	8 1/2	3908.0	0.00	LOT

Drilling mud

Drilling mud
Depth MD [m]	Mud weight [g/cm3]	Visc. [mPa.s]	Yield point [Pa]	Mud type	Date measured
1314	1.16	20.0	6.8	WATER BASED	18.09.1989
1331	1.17	24.0	7.8	WATER BASED	18.09.1989
1631	1.17	22.0	5.8	WATER BASED	18.09.1989
1747	1.17	27.0	8.8	WATER BASED	19.09.1989
2036	1.17	20.0	5.8	WATER BASED	20.09.1989
2057	1.18	24.0	7.8	WATER BASED	21.09.1989
2188	1.20	26.0	11.7	WATER BASED	25.09.1989
2238	1.27	39.0	14.2	WATER BASED	04.10.1989
2301	1.27	36.0	13.2	WATER BASED	05.10.1989
2502	1.27	32.0	11.7	WATER BASED	09.10.1989
2502	1.27	32.0	10.7	WATER BASED	06.10.1989
2739	1.27	31.0	11.2	WATER BASED	09.10.1989
2807	1.27	33.0	12.2	WATER BASED	10.10.1989
2875	1.27	33.0	13.2	WATER BASED	12.10.1989
2938	1.27	34.0	12.2	WATER BASED	12.10.1989
3009	1.27	33.0	11.7	WATER BASED	13.10.1989
3159	1.20	37.0	10.7	WATER BASED	07.11.1989
3201	1.27	32.0	11.2	WATER BASED	16.10.1989
3215	1.27	33.0	11.2	WATER BASED	17.10.1989
3282	1.27	34.0	12.2	WATER BASED	18.10.1989
3315	1.27	32.0	10.7	WATER BASED	19.10.1989
3340	1.27	33.0	11.7	WATER BASED	27.10.1989
3395	1.27	30.0	8.8	WATER BASED	27.10.1989
3423	1.20	39.0	13.2	WATER BASED	07.11.1989
3525	1.20	34.0	10.2	WATER BASED	08.11.1989
3799	1.20	36.0	7.3	WATER BASED	21.11.1989
3811	1.20	38.0	8.3	WATER BASED	22.11.1989
3847	1.20	38.0	8.8	WATER BASED	22.11.1989
3856	1.21	38.0	9.8	WATER BASED	23.11.1989
3908	1.20	36.0	13.7	WATER BASED	24.11.1989

Thin sections at the Norwegian Offshore Directorate

Thin sections at the Norwegian Offshore Directorate
Depth	Unit
3340.10	[m ]
3360.25	[m ]
3405.24	[m ]
3367.42	[m ]
3421.10	[m ]
3404.10	[m ]
3394.67	[m ]
3887.10	[m ]
3441.05	[m ]
3440.45	[m ]
3424.20	[m ]
3468.00	[m ]
3459.30	[m ]
3458.10	[m ]

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]
1459_Formation_pressure_(Formasjonstrykk)	pdf	0.23

25/2-13