7120/12-2

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General information

General information
Attribute	Value
Wellbore name Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.	7120/12-2
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
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.	BARENTS SEA
Discovery Name of the discovery the wellbore is related to.	7120/12-2 (Alke Sør)
Well name Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.	7120/12-2
Production licence Official designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion).	061
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.	284-L
Drilling facility Norwegian Offshore Directorate's name of the facility which the wellbore was drilled from.	TREASURE SEEKER
Drilling days Number of days from wellbore entry to wellbore completion.	150
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,	15.04.1981
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.	11.09.1981
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.	11.09.1983
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.	11.02.2005
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.	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.	MIDDLE 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.	SNADD FM
Kelly bushing elevation [m] Elevation of the rotary kelly bushing (RKB) above mean sea level.	25.0
Water depth [m] Depth in metres betweem mean sea level and sea floor.	164.0
Total depth (MD) [m RKB] Total measured length of wellbore from kelly bushing to total depth (driller's depth).	4680.0
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).	4667.0
Maximum inclination [°] Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.	9.25
Bottom hole temperature [°C] Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.	115
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.	PRE-DEVONIAN
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.	BASEMENT
Geodetic datum Reference system for coordinates. Example of legal values: ED50.	ED50
NS degrees Geographic coordinate of the wellhead, north-south degrees.	71° 7' 30.3'' N
EW degrees Geographic coordinate of the wellhead, east-west degrees.	20° 48' 19'' E
NS UTM [m] Universal Transverse Mercator coordinate of the wellhead, north-south.	7891571.43
EW UTM [m] Universal Transverse Mercator coordinate of the wellhead, east-west.	492968.97
UTM zone Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.	34
NPDID wellbore Norwegian Offshore Directorate's unique id for the wellbore.	122

Wellbore history

General

The primary objectives of well 7120/12-2 were to test sandstone reservoirs of Middle to Early Jurassic age in the central compartment of the Alke structure, and a deep seismic marker interpreted to represent top of a possible carbonate reservoir of Permian age. A secondary objective was to test sandstones of Early Triassic age. The well was planned to be drilled to 5000 m or into basement rocks to serve as the deep commitment well on the licence.

Operations and results

Well 7120/12-2 was spudded with the semi-submersible installation Treasure Seeker on 15 April 1981 and drilled to TD at 4680 m in basement rocks. After setting the 20" casing the kill line outlet flange was accidentally damaged and 5 days were spent repairing the BOP. The well was drilled with bentonite/seawater mud down to 515 m and with lignosulphonate (Spersene / XP-20) mud from 515 m to TD. Severe problems were encountered with gumbo type clays during the interval from about 800 m to 1400 m.

A major fault was penetrated at 2410 m in the well, faulting out approximately 400 m of the Triassic section. This is evident from comparing the Triassic sequences penetrated in the well 7120/12-1 and 7120/12-2. Rocks of Permian age were encountered from 3657 m while metamorphic basement was encountered at 4664 m. Hydrocarbon bearing sandstones were encountered in the Middle to Late Jurassic and in the Middle to Late Triassic.

The "Alke Formation" from 1892 m to 2314 m (Stø, Nordmela, Tubåen , and most of the Fruholmen Formation) was found hydrocarbon bearing from 1888 m to the gas/water contact at 1981.5 m. This interval consisted of relatively clean, fine to occasionally coarse grained, homogeneous sandstones separated by thin silty and argillaceous beds. Towards the base, the sandstones were predominantly very fine to fine grained, becoming increasingly argillaceous and micaceous. The net pay was, from wire line logs, calculated to 76 m, with 20% average porosity and an average water saturation of 19%. RFT pressure recordings and sampling were successfully performed over the interval. This gave a clear gas gradient of 0.088 psi/ft with an underlying water gradient of 0.458 psi/ft.

The Middle to Late Triassic hydrocarbon-bearing interval from 2547 m to 2574 m (Snadd Formation) consisted of fine to very fine-grained sandstone beds with stringers and thin beds of limestone and calcareous cemented sandstone. The net pay was calculated to 14 m, with 23% average porosity and an average water saturation of 30 %. Due to hole conditions, no RFT sampling was performed in this sequence. RFT pressure readings were, however, run through the interval and gave a gas gradient of 0.076 psi/ft. Gas shows were also reported in the Late Triassic (2513 m to 2547 m, Snadd Formation ), Early Triassic (2935 m to 3075 m, Kobbe Formation) and in Permian sandstones (3657 m to 3800 m, Ørret Formation). The water saturation in these intervals ranged from 50 - 100% and based on log interpretation, the hydrocarbons were assumed to be non-moveable. Very poor permeabilities were indicated in the Early Triassic and Permian intervals from RFT pressure readings.

Organic geochemical analyses showed rich potential for gas/condensate generation in the Late Jurassic Hekkingen Formation (1630 m to 1859 m), Below this level Early Jurassic to Middle Triassic sequences contained carbonaceous sequences and coal beds with potential for gas and possibly oil. All sediments down to 2500 m to 3000 m are immature. Migrant hydrocarbons were frequently detected all through the well. This could indicate contamination from oil in the mud, although the mud used should be water based.

Six conventional cores were cut in the Middle Jurassic Fuglen, Stø, and Nordmela Formations from 1888 m to 2050 m, and two were cut from 3671 m to 3689 m and 4117 m to 4128 m in Permian sandstones. A final core was cut at TD from 4675 m to 4680.5 m and recovered 5.5 m of gneiss. Two RFT samples at 1978 m and 1943.5 m recovered gas and small volumes of condensate.

The well was permanently abandoned on 11 September as a gas/condensate discovery.

Testing

Three drill stem tests were performed, one on the Triassic and two in the Middle Jurassic.

DST 1 perforated the interval 2562 m to 2568 m in the Middle Triassic Snadd Formation and flowed 417700 Sm3/day gas of gravity 0.62, and 25.1 Sm3/day condensate of gravity 55.92° API, through a 1/2" choke. The GOR was 16630 Sm3/Sm3.

DST 2 perforated the interval 1985 m to 1991 m in the water-zone in the Middle to Late Jurassic reservoir (lower Stø and upper Nordmela Formations) and flowed 160 Sm3 water/day through a 172/64"choke.

A sample labelled DST 2 was submitted to the NPD oil store. Since it contains condensate and not water it is probably a mis-labelled DST 1 or DST 3 sample.

DST 3 perforated the interval 1944 m to 1950 m Stø Formation) and flowed 758000 Sm3/day gas of gravity 0.626, and 52.5 Sm3/day condensate of gravity 64.4° API, through a 60/64" choke. The GOR was 14430 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]
320.00	4680.00

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	1888.0	1903.5	[m ]
2	1960.0	1979.4	[m ]
3	1978.0	1994.9	[m ]
4	1996.0	2013.2	[m ]
5	2013.2	2031.9	[m ]
6	2032.0	2050.0	[m ]
7	3671.0	3688.4	[m ]
8	4117.0	4128.1	[m ]
9	4675.0	4680.5	[m ]

Cores at the Norwegian Offshore Directorate
Total core sample length [m]	139.7

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

Core photos

Core photos

1888-1890m	1890-1893m	1893-1895m	1895-1898m	1899-1901m

1901-1903m	1903-1904m	1960-1962m	1962-1965m	1965-1967m

1967-1970m	1970-1972m	1972-1975m	1975-1977m	1977-1978m

1978-1980m	1980-1983m	1983-1985m	1985-1988m	1988-1981m

1991-1993m	1993-1995m	1996-1998m	1998-2000m	2000-2003m

2003-2006m	2006-2008m	2008-2011m	2011-2014m	2014-2016m

2016-2019m	2019-2022m	2022-2024m	2024-2027m	2027-2030m

2030-2031m	2032-2034m	2034-2037m	2037-2039m	2039-2042m

2042-2045m	2045-2047m	2047-2050m	3671-3676m	3676-3681m

3681-3684m	3684-3688m	4117-4121m	4121-4124m	4124-4128m

4675-4678m	4678-4680m

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		1985.00	1991.00	CONDENSATE	03.09.1981 - 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	312.0	36	313.0	0.00	LOT
SURF.COND.	20	502.0	26	515.0	1.74	LOT
INTERM.	13 3/8	1710.0	17 1/2	1724.0	1.92	LOT
INTERM.	9 5/8	3101.0	12 1/4	3116.0	2.08	LOT
OPEN HOLE		4680.0	8 3/8	4680.0	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	2562	2568	25.1
2.0	1985	1991	68.3
3.0	1944	1950	23.1

Drill stem tests (DST)
Test number	Final shut-in pressure [MPa]	Final flow pressure [MPa]	Bottom hole pressure [MPa]	Downhole temperature [°C]
1.0				77
2.0				66
3.0				66

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	25	418000	0.755	0.620	16624
2.0
3.0	53	758000	0.722	0.630	14425

Logs

Logs
Log type	Log top depth [m]	Log bottom depth [m]
CALI	3096	4675
CBL	1850	2002
CBL VDL	1850	3096
CST	610	1305
CST	1316	1717
CST	1747	2370
CST	2394	3061
CST	2785	3103
CST	3120	3703
CST	3713	4417
CST	3713	4177
CST	3920	4670
CST	4195	4670
CST	4195	4670
CYBERDIP	500	1719
CYBERDIP	2200	3116
CYBERDIP	3096	4675
DLL MSFL GR	1850	2164
DLL MSFL GR	2400	3115
DLL MSFL GR	3525	3913
FIL	2800	3115
HDT	500	4675
ISF BHC GR	500	1721
ISF LSS GR	189	512
ISF LSS GR	1707	4674
LDT CNL GR CAL	500	4675
LDT GR CAL	312	513
NGS	1850	2100
RFT	1888	2148
RFT	2165	3004
RFT	3141	3281
RFT	3555	3859
RFT	3766	3780
VELOCITY	727	4671
WFT	1850	2100

Lithostratigraphy

Lithostratigraphy
Top depth [mMD RKB]	Lithostrat. unit
189	NORDLAND GP
463	SOTBAKKEN GP
463	TORSK FM
701	NYGRUNNEN GP
701	KVITING FM
745	ADVENTDALEN GP
745	KOLMULE FM
1309	KOLJE FM
1455	KNURR FM
1700	HEKKINGEN FM
1875	FUGLEN FM
1892	KAPP TOSCANA GP
1892	STØ FM
1978	NORDMELA FM
2152	TUBÅEN FM
2234	FRUHOLMEN FM
2354	SNADD FM
2927	SASSENDALEN GP
2927	KOBBE FM
3095	KLAPPMYSS FM
3552	HAVERT FM
3657	TEMPELFJORDEN GP
3657	ØRRET FM
3920	RØYE FM
3975	ØRRET FM
4031	RØYE FM
4076	ØRRET FM
4485	RØYE FM
4558	GIPSDALEN GP
4558	UGLE FM
4664	BASEMENT

Composite logs

Composite logs
Document name	Document format	Document size [MB]
122	pdf	0.92

Geochemical information

Geochemical information
Document name	Document format	Document size [MB]
122_1	pdf	6.13
122_2	pdf	2.79

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]
122_01_Completion_Report	pdf	16.22
122_02_Completion_log	pdf	3.33

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]
122_01_WDSS_General_Information	pdf	0.12
122_02_WDSS_completion_log	pdf	0.36

Drilling mud

Drilling mud
Depth MD [m]	Mud weight [g/cm3]	Visc. [mPa.s]	Yield point [Pa]	Mud type
515	1.12	51.0	12.0	WATER BASED
1625	1.18	65.0	20.0	WATER BASED
1888	1.36	46.0	8.0	WATER BASED
2354	1.36	48.0	9.0	WATER BASED
2985	1.40	48.0	4.0	WATER BASED
3117	1.53	60.0	6.0	WATER BASED
3532	1.59	49.0	6.0	WATER BASED
3884	1.89	54.0	8.5	WATER BASED
4103	1.93	54.0	11.0	WATER BASED
4680	1.93	68.0	22.0	WATER BASED

Palynological slides at the Norwegian Offshore Directorate

Palynological slides at the Norwegian Offshore Directorate
Sample depth	Depth unit	Sample type	Laboratory
360.0	[m]	DC	OD
380.0	[m]	DC	OD
450.0	[m]	DC	OD
480.0	[m]	DC	OD
500.0	[m]	DC	OD
530.0	[m]	DC	OD
560.0	[m]	DC	OD
600.0	[m]	DC	OD
610.0	[m]	SWC	IKU
640.0	[m]	DC	OD
680.0	[m]	DC	OD
698.0	[m]	SWC	IKU
702.0	[m]	SWC	IKU
717.0	[m]	SWC	IKU
725.0	[m]	SWC	IKU
728.5	[m]	SWC	IKU
737.0	[m]	SWC	IKU
743.0	[m]	SWC	IKU
750.0	[m]	DC	OD
770.0	[m]	DC	OD
783.0	[m]	SWC	IKU
790.0	[m]	DC	OD
810.0	[m]	DC	OD
830.0	[m]	DC	OD
836.0	[m]	SWC	IKU
850.0	[m]	DC	OD
870.0	[m]	DC	OD
890.0	[m]	DC	OD
910.0	[m]	DC	OD
921.0	[m]	SWC	IKU
930.0	[m]	DC	OD
948.0	[m]	SWC	IKU
980.0	[m]	SWC	IKU
1019.0	[m]	SWC	IKU
1057.0	[m]	SWC	IKU
1091.0	[m]	SWC	IKU
1101.0	[m]	SWC	IKU
1148.0	[m]	SWC	IKU
1165.0	[m]	SWC	IKU
1184.0	[m]	SWC	IKU
1222.0	[m]	SWC	IKU
1256.0	[m]	SWC	IKU
1267.5	[m]	SWC	IKU
1290.0	[m]	SWC	IKU
1305.0	[m]	SWC	IKU
1316.0	[m]	SWC	IKU
1373.0	[m]	SWC	IKU
1415.0	[m]	SWC	IKU
1440.0	[m]	SWC	IKU
1450.0	[m]	SWC	IKU
1460.0	[m]	SWC	IKU
1463.0	[m]	SWC	IKU
1465.0	[m]	SWC	IKU
1490.0	[m]	SWC	IKU
1516.0	[m]	SWC	IKU
1537.0	[m]	SWC	IKU
1557.0	[m]	SWC	IKU
1561.0	[m]	SWC	IKU
1572.5	[m]	SWC	IKU
1615.0	[m]	SWC	IKU
1626.0	[m]	SWC	IKU
1633.0	[m]	SWC	IKU
1637.0	[m]	SWC	IKU
1643.0	[m]	SWC	IKU
1657.4	[m]	SWC	IKU
1665.0	[m]	SWC	IKU
1671.0	[m]	SWC	IKU
1687.0	[m]	SWC	IKU
1705.0	[m]	SWC	IKU
1716.5	[m]	SWC	IKU
1717.0	[m]	SWC	IKU
1764.0	[m]	SWC	IKU
1785.0	[m]	SWC	IKU
1797.0	[m]	SWC	IKU
1820.0	[m]	SWC	IKU
1827.0	[m]	SWC	IKU
1842.5	[m]	SWC	IKU
1895.0	[m]	SWC	IKU
1897.6	[m]	C	IKU
1901.0	[m]	C	ICHRON
1960.5	[m]	C	IKU
1960.5	[m]	C	ICHRON
1963.6	[m]	C	IKU
1966.1	[m]	C	ICHRON
1966.1	[m]	C	IKU
1966.4	[m]	C	IKU
1974.5	[m]	C	IKU
1976.3	[m]	C	IKU
1976.4	[m]	C	ICHRON
1983.9	[m]	C	ICHRON
1984.5	[m]	C	ICHRON
1992.7	[m]	C	ICHRON
1992.7	[m]	C	IKU
1996.6	[m]	C	ICHRON
1998.5	[m]	C	IKU
2001.8	[m]	C	ICHRON
2005.6	[m]	C	ICHRON
2007.0	[m]	C	IKU
2007.8	[m]	C	ICHRON
2010.6	[m]	C	ICHRON
2015.7	[m]	C	ICHRON
2018.5	[m]	C	ICHRON
2018.6	[m]	C	IKU
2020.9	[m]	C	ICHRON
2021.7	[m]	C	IKU
2025.4	[m]	C	ICHRON
2027.2	[m]	C	IKU
2027.4	[m]	C	ICHRON
2031.5	[m]	C	ICHRON
2032.7	[m]	C	ICHRON
2034.4	[m]	C	IKU
2034.4	[m]	C	ICHRON
2038.8	[m]	C	IKU
2038.8	[m]	C	ICHRON
2041.7	[m]	C	IKU
2043.7	[m]	C	ICHRON
2046.7	[m]	C	ICHRON
2046.8	[m]	C	IKU
2048.2	[m]	C	ICHRON
2049.5	[m]	C	ICHRON
2068.0	[m]	C	IKU
2106.0	[m]	C	IKU
2120.9	[m]	C	IKU
2122.5	[m]	C	IKU
2142.0	[m]	C	IKU
2160.0	[m]	C	IKU
2180.0	[m]	C	IKU
2202.0	[m]	C	IKU
2215.0	[m]	C	IKU
2262.0	[m]	C	IKU
2278.0	[m]	C	IKU
2284.5	[m]	C	IKU
2326.0	[m]	SWC	IKU
2348.0	[m]	C	UIB
2350.0	[m]	SWC	IKU
2365.0	[m]	C	UIB
2378.0	[m]	C	UIB
2393.0	[m]	C	UIB
2393.0	[m]	C	UIB
2398.0	[m]	C	UIB
2408.0	[m]	SWC	IKU
2421.0	[m]	SWC	IKU
2425.0	[m]	C	UIB
2443.0	[m]	C	UIB
2468.0	[m]	C	UIB
2476.0	[m]	SWC	IKU
2498.0	[m]	SWC	IKU
2510.0	[m]	C	UIB
2512.0	[m]	SWC	IKU
2515.0	[m]	C	UIB
2523.0	[m]	C	UIB
2533.0	[m]	C	UIB
2547.0	[m]	SWC	IKU
2554.0	[m]	SWC	IKU
2570.0	[m]	C	UIB
2577.0	[m]	SWC	IKU
2587.9	[m]	SWC	IKU
2590.0	[m]	C	UIB
2622.0	[m]	SWC	IKU
2625.0	[m]	C	UIB
2636.0	[m]	SWC	IKU
2645.0	[m]	C	UIB
2647.1	[m]	SWC	IKU
2664.1	[m]	SWC	IKU
2686.0	[m]	SWC	IKU
2703.0	[m]	SWC	IKU
2728.0	[m]	SWC	IKU
2740.0	[m]	SWC	IKU
2785.0	[m]	SWC	IKU
2799.9	[m]	SWC	IKU
2814.9	[m]	SWC	IKU
2830.0	[m]	SWC	IKU
2843.0	[m]	SWC	IKU
2855.0	[m]	SWC	IKU
2867.0	[m]	SWC	IKU
2878.0	[m]	SWC	IKU
2890.0	[m]	SWC	IKU
2912.0	[m]	SWC	IKU
2922.0	[m]	SWC	IKU
2935.0	[m]	SWC	IKU
2943.0	[m]	SWC	IKU
2954.0	[m]	SWC	IKU
2964.0	[m]	SWC	IKU
2981.9	[m]	SWC	IKU
2992.0	[m]	SWC	IKU
3018.0	[m]	SWC	IKU
3026.9	[m]	SWC	IKU
3038.0	[m]	SWC	IKU
3051.9	[m]	SWC	IKU
3061.0	[m]	SWC	IKU
3072.0	[m]	SWC	IKU
3085.0	[m]	SWC	IKU
3103.0	[m]	SWC	IKU
3120.0	[m]	SWC	IKU
3131.0	[m]	SWC	IKU
3157.0	[m]	SWC	IKU
3200.0	[m]	SWC	IKU
3222.0	[m]	SWC	IKU
3234.0	[m]	SWC	IKU
3265.0	[m]	SWC	IKU
3294.0	[m]	SWC	IKU
3319.0	[m]	SWC	IKU
3326.0	[m]	SWC	IKU
3349.0	[m]	SWC	IKU
3367.0	[m]	SWC	IKU
3391.0	[m]	SWC	IKU
3413.0	[m]	SWC	IKU
3432.0	[m]	SWC	IKU
3489.0	[m]	SWC	IKU
3497.0	[m]	SWC	IKU
3532.0	[m]	SWC	IKU
3551.0	[m]	SWC	IKU
3568.0	[m]	SWC	IKU
3591.0	[m]	SWC	IKU
3599.0	[m]	SWC	IKU
3624.0	[m]	SWC	IKU
3648.0	[m]	SWC	IKU
3650.0	[m]	DC
3667.5	[m]	SWC	IKU
3682.3	[m]	C	OD
3682.5	[m]	C	IKU
3700.0	[m]	DC
3703.0	[m]	SWC	IKU
3713.0	[m]	SWC	IKU
3734.0	[m]	SWC	IKU
3750.0	[m]	DC
3750.5	[m]	SWC	IKU
3763.5	[m]	SWC	IKU
3789.0	[m]	SWC	IKU
3828.0	[m]	SWC	IKU
3850.0	[m]	DC
3864.0	[m]	SWC	IKU
3899.5	[m]	SWC	IKU
3900.0	[m]	DC
3982.0	[m]	SWC	IKU
4059.0	[m]	SWC	IKU
4077.5	[m]	SWC	IKU
4104.0	[m]	SWC	IKU
4121.1	[m]	C	IKU
4121.2	[m]	C	IKU
4121.2	[m]	C	OD
4123.8	[m]	C	IKU
4123.9	[m]	C	IKU
4126.8	[m]	C	IKU
4130.0	[m]	SWC	IKU
4141.5	[m]	SWC	IKU
4150.0	[m]	DC
4158.0	[m]	SWC	IKU
4224.0	[m]	SWC	IKU
4250.0	[m]	SWC	IKU
4273.0	[m]	SWC	IKU
4292.5	[m]	SWC	IKU
4300.0	[m]	DC
4310.0	[m]	SWC	IKU
4335.0	[m]	SWC	IKU
4360.5	[m]	SWC	IKU
4398.0	[m]	SWC	IKU
4417.0	[m]	SWC	IKU
4434.0	[m]	SWC	IKU
4448.5	[m]	SWC	IKU
4500.0	[m]	DC
4535.5	[m]	SWC	IKU

Thin sections at the Norwegian Offshore Directorate

Thin sections at the Norwegian Offshore Directorate
Depth	Unit
4679.71	[m ]
4124.00	[m ]
4119.74	[m ]
3684.90	[m ]
3675.60	[m ]
3671.20	[m ]
2048.15	[m ]

7120/12-2

General information

Wellbore history

Cuttings at the Norwegian Offshore Directorate

Cores at the Norwegian Offshore Directorate

Core photos

Oil samples at the Norwegian Offshore Directorate

Casing and leak–off tests

Drill stem tests (DST)

Logs

Lithostratigraphy

Composite logs

Geochemical information

Documents – reported by the production licence (period for duty of secrecy expired)

Documents – older Norwegian Offshore Directorate WDSS reports and other related documents

Drilling mud

Palynological slides at the Norwegian Offshore Directorate

Thin sections at the Norwegian Offshore Directorate