6507/2-2

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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.	6507/2-2
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.	NORWEGIAN SEA
Field Name of the field the wellbore is related to.	MARULK
Discovery Name of the discovery the wellbore is related to.	6507/2-2 Marulk
Well name Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.	6507/2-2
Production licence Official designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion).	122
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.	702-L
Drilling facility Norwegian Offshore Directorate's name of the facility which the wellbore was drilled from.	POLAR PIONEER
Drilling days Number of days from wellbore entry to wellbore completion.	148
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,	21.10.1991
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.	16.03.1992
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.	16.03.1994
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.	19.12.2007
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
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.	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.	LATE CRETACEOUS
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.	LANGE 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.	384.0
Total depth (MD) [m RKB] Total measured length of wellbore from kelly bushing to total depth (driller's depth).	3958.0
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).	3953.0
Maximum inclination [°] Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.	10
Bottom hole temperature [°C] Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.	141
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.	65° 55' 1.69'' N
EW degrees Geographic coordinate of the wellhead, east-west degrees.	7° 30' 54.56'' E
NS UTM [m] Universal Transverse Mercator coordinate of the wellhead, north-south.	7311658.69
EW UTM [m] Universal Transverse Mercator coordinate of the wellhead, east-west.	432391.00
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.	1840

Wellbore history

General

The Dønna Terrace forms a large down faulted block on the western margin of the Trøndelag Platform, situated between the Nordland Ridge and the Vøring Basin. The structure to be tested by 6507/2-2 is situated on the western edge of the Dønna Terrace. This structure was earlier tested by well 6507/2-1, which however left a considerable untested column up-dip from the well position. The main target of the well was the Jurassic reservoirs of Garn, Ile, and Tilje Formation. The secondary objectives were to test the prospectivity of the Cretaceous sands in the Lysing and Lange Formations or at least to obtain stratigraphic information from these formations.

Operations and results

Wildcat well 6507/2-2 was spudded with the semi-submersible installation Polar Pioneer on 21 October 1991 and drilled to TD at 3958 m in Early Jurassic sediments of the Åre Formation. The well had 37% downtime due mainly to repeated occurrences of stuck drill pipe. Drilling went relatively smooth down to setting of the 9 5/8" casing shoe at 2760 m. After having cut two cores in the 8 1/2" section the well was shut in due to an influx at 3336 m. The well was killed with increased mud weight, but the pipe was found to be stuck. The pipe could not be freed and was cut at 3175 m. The well was then plugged back and sidetracked from 2989 m and drilled to 3326 m with minor problems. A 7" liner was run and set with shoe at 3324 m and the 6" section was then drilled to 3737 where parts of the bit sub was lost in the hole. This led to 20 days lost while attempting to recover the fish and sidetrack past the fish. Eventually the fish was partly recovered and drilling commenced to TD. The well was drilled with seawater and hi-vis pills down to 685 m and with a KCl/polymer mud from 685 m to TD.

Oil shows were recorded on sandstone laminae in the interval 2208 ? 2750 m in the Shetland Group. The Cretaceous Lysing Formation was encountered at 2817.5 m, and the Lange Formation at 2831 m. A total of 23 m net sand was interpreted in the Cretaceous interval. Both Lysing and Lange Formation proved to be gas filled and the reservoirs were tested and exhibited fair to good production rates. Top Jurassic was encountered at 3380 m with a 292.5 m thick Melke Formation. Top Garn Formation came in at 3672.5 m. A total of 65.8 m net sand with an average porosity of 14.8% was penetrated in the Early and Middle Jurassic. The Jurassic sands were water filled, but weak to moderate shows were recorded on all cores from the Jurassic.

Six cores were cut in the well. The two first were cut in the first hole from 2822 m to 2849.4 m in the Lysing and top Lange Formation and from 3278 m to 3296 m in the hydrocarbon-bearing Intra-Lange Formation sandstone. Cores 3 to 6 were cut in the sidetrack. Core 3 was cut over a second Intra-Lange sand from 3330 m to 3339.4 m; core 4 was cut from 3685 m to 3700 m in the Middle Jurassic Fangst Group, while core 5 and 6 were cut at 3770 m to 3778.5 m and at 3921 m to 3930 in sandstones of the Early Jurassic Båt Group. RFT fluid samples were taken at 3270.5 m (water and filtrate), 3280 m, 2825 m (water/filtrate and gas), and 3331.6 m (water/filtrate and gas).

The well was permanently abandoned on 16 March 1992 as a gas condensate discovery.

Testing

Two DST tests were performed in the Cretaceous.

DST 1A from the interval 3285.4 m to 3294.4 m in an intra- Lange Formation sandstone flowed 676000 Sm3 gas and 107 Sm3 oil/condensate per day through a 25.4mm choke. The GOR was 4950 Sm3/Sm3, the condensate density was 0.796 g/cm3, the gas gravity (air =1) was 0.63, and the gas contained 0.65 % CO2 and 0.2 ppm H2S. The bottom hole temperature recorded in the test was 118.4 deg C.

DST 2 from 2820 m to 2831 m in the Lysing Formation flowed 865000 Sm3 gas and 80 Sm3 oil/condensate per day through a 25.5 mm choke. The GOR was 10800 Sm3/Sm3, the condensate density was 0.787 g/cm3, the gas gravity (air =1) was 0.645, and the gas contained 0.7 % CO2 and 0.1 ppm H2S. The bottom hole temperature recorded in the test was 99.1 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]
690.00	3957.00

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	2822.0	2849.5	[m ]
2	3273.0	3295.8	[m ]
3	3330.0	3339.3	[m ]
4	3685.4	3700.4	[m ]
5	3770.0	3778.5	[m ]
6	3921.0	3929.3	[m ]

Cores at the Norwegian Offshore Directorate
Total core sample length [m]	91.4

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

Core photos

Core photos

2822-2827m	2827-2832m	2832-2837m	2837-2842m	2842-2847m

2847-2849m	3273-3278m	3278-3283m	3283-3288m	3288-3293m

3293-3295m	3330-3335m	3335-3339m	3685-3690m	3690-3695m

3695-3700m	3700-3701m	3770-3775m	3775-3778m	3921-3926m

3926-3929m

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	TEST1A	3294.00	3285.00	CONDENSATE	16.02.1992 - 23:00	YES
DST	TEST2	2831.00	2820.00		02.03.1992 - 03:57	YES
DST		0.00	0.00	WATER	17.02.1992 - 00:31	YES
DST		0.00	0.00	WATER	02.03.1992 - 02:15	YES
DST		0.00	0.00	CONDENSATE	16.02.1992 - 23:00	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	491.0	36	491.0	0.00	LOT
INTERM.	18 5/8	671.0	24	685.0	1.48	LOT
INTERM.	13 3/8	1399.0	17 1/2	1414.0	1.72	LOT
INTERM.	9 5/8	2761.0	12 1/4	2777.0	2.02	LOT
INTERM.	7	3324.0	8 1/2	3958.0	2.00	LOT

Drill stem tests (DST)

Drill stem tests (DST)
Test number	From depth MD [m]	To depth MD [m]	Choke size [mm]
1.0	3285	3294	25.4
2.0	2820	2831	25.4

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

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	107	676000	0.790	0.630	6317
2.0	80	865000	0.780	0.640	1081

Logs

Logs
Log type	Log top depth [m]	Log bottom depth [m]
CBL VDL GR CCC	1900	2597
CST	1940	2097
CST	2115	2591
CST	2610	3249
DLL MSFL GR SP	2100	2602
ISF BHC MSFL GR SP	474	3250
LDT CNL GR	1026	3250
MWD	474	3262
RFT	2205	2574
SHDT GR	1026	3250
TEMP	500	2025
TEMP	998	2551
VSP	474	3250

Lithostratigraphy

Lithostratigraphy
Top depth [mMD RKB]	Lithostrat. unit
407	NORDLAND GP
407	NAUST FM
1397	KAI FM
1680	HORDALAND GP
1680	BRYGGE FM
1850	ROGALAND GP
1850	TARE FM
1941	TANG FM
1987	SHETLAND GP
2818	CROMER KNOLL GP
2818	LYSING FM
2831	LANGE FM
3380	VIKING GP
3380	MELKE FM
3673	FANGST GP
3673	GARN FM
3698	NOT FM
3703	ILE FM
3720	BÅT GP
3720	ROR FM
3746	TOFTE FM
3770	TILJE FM
3810	ÅRE FM

Geochemical information

Geochemical information
Document name	Document format	Document size [MB]
1840_1	pdf	0.51
1840_2	pdf	1.50
1840_3	pdf	0.67
1840_4	pdf	0.33
1840_5	pdf	2.28
1840_6	pdf	1.35

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]
1840_6507_2_2_COMPLETION_REPORT_AND_LOG	pdf	20.03

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]
1840_01_WDSS_General_Information	pdf	0.89
1840_02_WDSS_completion_log	pdf	0.22

Drilling mud

Drilling mud
Depth MD [m]	Mud weight [g/cm3]	Visc. [mPa.s]	Mud type
407	1.00		WATER BASED
430	1.61	16.0	WATER BASED
491	1.05	18.0	WATER BASED
505	1.05	18.0	WATER BASED
685	1.05	18.0	WATER BASED
1051	1.26	17.0	WATER BASED
1238	1.60	12.0	WATER BASED
1259	1.26	13.0	WATER BASED
1414	1.26	14.0	WATER BASED
1600	1.30	14.0	WATER BASED
1959	1.51	20.0	WATER BASED
2100	1.55	18.0	WATER BASED
2355	1.55	25.0	WATER BASED
2449	1.55	24.0	WATER BASED
2517	1.57	25.0	WATER BASED
2568	1.70	13.0	WATER BASED
2568	1.70	15.0	WATER BASED
2727	1.57	23.0	WATER BASED
2775	1.60	28.0	WATER BASED
2777	1.60	28.0	WATER BASED
2783	1.50	22.0	WATER BASED
2821	1.50	19.0	WATER BASED
2843	1.50	20.0	WATER BASED
2863	1.50	20.0	WATER BASED
2900	1.70	22.0	WATER BASED
2924	1.50	19.0	WATER BASED
2987	1.50	19.0	WATER BASED
2989	1.70	23.0	WATER BASED
3013	1.50	17.0	WATER BASED
3045	1.50	17.0	WATER BASED
3084	1.70	25.0	WATER BASED
3112	1.70	26.0	WATER BASED
3154	1.70	24.0	WATER BASED
3156	1.50	15.0	WATER BASED
3161	1.70	24.0	WATER BASED
3175	1.70	22.0	WATER BASED
3188	1.70	25.0	WATER BASED
3212	1.86	26.0	WATER BASED
3257	1.70	28.0	WATER BASED
3265	1.50	16.0	WATER BASED
3274	1.86	27.0	WATER BASED
3283	1.62	13.0	WATER BASED
3296	1.50	16.0	WATER BASED
3307	1.86	27.0	WATER BASED
3326	1.70	24.0	WATER BASED
3330	1.75	20.0	WATER BASED
3336	1.70	25.0	WATER BASED
3448	1.75	20.0	WATER BASED
3570	1.75	23.0	WATER BASED
3626	1.86	31.0	WATER BASED
3638	1.75	24.0	WATER BASED
3670	1.86	28.0	WATER BASED
3678	1.75	23.0	WATER BASED
3684	1.86	30.0	WATER BASED
3685	1.86	27.0	WATER BASED
3696	1.86	27.0	WATER BASED
3700	1.86	28.0	WATER BASED
3702	1.86	29.0	WATER BASED
3705	1.86	31.0	WATER BASED
3710	1.86	31.0	WATER BASED
3712	1.86	29.0	WATER BASED
3721	1.86	30.0	WATER BASED
3736	1.86	31.0	WATER BASED
3737	1.86	27.0	WATER BASED
3739	1.86	32.0	WATER BASED
3741	1.86	30.0	WATER BASED
3751	1.86	30.0	WATER BASED
3770	1.86	31.0	WATER BASED
3796	1.86	31.0	WATER BASED
3910	1.86	31.0	WATER BASED
3958	1.86	28.0	WATER BASED
3958	1.86	33.0	WATER BASED

Palynological slides at the Norwegian Offshore Directorate

Palynological slides at the Norwegian Offshore Directorate
Sample depth	Depth unit	Sample type	Laboratory
1456.0	[m]	SWC	HYDRO
1530.0	[m]	DC	STRAT
1560.0	[m]	DC	STRAT
1590.0	[m]	DC	STRAT
1600.0	[m]	SWC	HYDRO
1620.0	[m]	DC	STRAT
1650.0	[m]	DC	STRAT
1670.0	[m]	SWC	HYDRO
1680.0	[m]	DC	STRAT
1700.0	[m]	SWC	HYDRO
1710.0	[m]	DC	STRAT
1740.0	[m]	DC	STRAT
1760.0	[m]	SWC	HYDRO
1770.0	[m]	DC	STRAT
1780.0	[m]	DC	STRAT
1790.0	[m]	DC	STRAT
1800.0	[m]	DC	STRAT
1810.0	[m]	DC	STRAT
1820.0	[m]	DC	STRAT
1830.0	[m]	DC	STRAT
1851.0	[m]	SWC	HYDRO
1855.0	[m]	SWC	HYDRO
1860.0	[m]	DC	STRAT
1890.0	[m]	DC	STRAT
1899.0	[m]	SWC	HYDRO
1920.0	[m]	DC	STRAT
1930.0	[m]	SWC	HYDRO
1940.0	[m]	SWC	HYDRO
1980.0	[m]	DC	STRAT
1982.0	[m]	SWC	HYDRO
1992.0	[m]	SWC	HYDRO
2010.0	[m]	DC	STRAT
2040.0	[m]	DC	STRAT
2070.0	[m]	DC	STRAT
2070.0	[m]	SWC	HYDRO
2100.0	[m]	DC	STRAT
2130.0	[m]	DC	STRAT
2140.0	[m]	SWC	HYDRO
2160.0	[m]	DC	STRAT
2190.0	[m]	DC	STRAT
2208.0	[m]	SWC	HYDRO
2220.0	[m]	DC	STRAT
2235.0	[m]	DC	STRAT
2260.0	[m]	DC	STRAT
2280.0	[m]	SWC	HYDRO
2290.0	[m]	DC	STRAT
2320.0	[m]	DC	STRAT
2345.0	[m]	SWC	HYDRO
2350.0	[m]	DC	STRAT
2380.0	[m]	DC	STRAT
2424.0	[m]	SWC	HYDRO
2440.0	[m]	DC	STRAT
2470.0	[m]	DC	STRAT
2555.0	[m]	DC	STRAT
2615.0	[m]	DC	STRAT
2675.0	[m]	DC	STRAT
2700.0	[m]	SWC	HYDRO
2725.0	[m]	DC	STRAT
2750.0	[m]	DC	STRAT
2765.0	[m]	SWC	HYDRO
2775.0	[m]	DC	STRAT
2795.0	[m]	DC	STRAT
2800.0	[m]	DC	STRAT
2810.0	[m]	DC	STRAT
2818.0	[m]	SWC	HYDRO
2820.0	[m]	DC	STRAT
2822.2	[m]	C	OD
2822.6	[m]	C	STRAT
2822.7	[m]	DC	STRAT
2823.1	[m]	C	OD
2823.1	[m]	C	STRAT
2823.6	[m]	C	STRAT
2824.6	[m]	C	STRAT
2827.0	[m]	C	STRAT
2827.3	[m]	C	STRAT
2828.5	[m]	C	STRAT
2828.8	[m]	C	OD
2829.2	[m]	C	STRAT
2831.4	[m]	C	STRAT
2832.0	[m]	C	STRAT
2832.5	[m]	C	STRAT
2832.9	[m]	C	STRAT
2833.0	[m]	C	STRAT
2833.1	[m]	C	STRAT
2833.3	[m]	C	OD
2834.8	[m]	C	STRAT
2836.8	[m]	C	OD
2836.9	[m]	C	STRAT
2839.0	[m]	C	STRAT
2840.0	[m]	DC	STRAT
2840.4	[m]	C	STRAT
2841.8	[m]	C	STRAT
2844.0	[m]	C	STRAT
2845.1	[m]	C	STRAT
2849.0	[m]	C	STRAT
2849.4	[m]	C	STRAT
2860.0	[m]	DC	STRAT
2870.0	[m]	DC	STRAT
2880.0	[m]	DC	STRAT
2890.0	[m]	DC	STRAT
2900.0	[m]	DC	STRAT
2901.0	[m]	SWC	HYDRO
2910.0	[m]	DC	STRAT
2920.0	[m]	SWC	HYDRO
2930.0	[m]	DC	STRAT
2950.0	[m]	SWC	HYDRO
2960.0	[m]	DC	STRAT
2970.0	[m]	SWC	HYDRO
2980.0	[m]	DC	STRAT
3000.0	[m]	DC	STRAT
3020.0	[m]	DC	STRAT
3025.0	[m]	SWC	HYDRO
3030.0	[m]	DC	STRAT
3040.0	[m]	DC	STRAT
3050.0	[m]	DC	STRAT
3060.0	[m]	DC	STRAT
3070.0	[m]	DC	STRAT
3075.0	[m]	SWC	HYDRO
3080.0	[m]	DC	STRAT
3110.0	[m]	DC	STRAT
3122.0	[m]	SWC	HYDRO
3130.0	[m]	DC	STRAT
3140.0	[m]	DC	STRAT
3150.0	[m]	DC	STRAT
3160.0	[m]	DC	STRAT
3163.0	[m]	SWC	HYDRO
3170.0	[m]	DC	STRAT
3173.0	[m]	SWC	HYDRO
3180.0	[m]	DC	STRAT
3190.0	[m]	DC	STRAT
3194.0	[m]	SWC	HYDRO
3210.0	[m]	DC	STRAT
3225.0	[m]	DC	STRAT
3240.0	[m]	DC	STRAT
3251.0	[m]	SWC	HYDR0
3255.0	[m]	DC	STRAT
3260.0	[m]	DC	STRAT
3265.0	[m]	SWC	HYDRO
3270.0	[m]	SWC	HYDRO
3270.0	[m]	DC	STRAT
3273.0	[m]	DC	STRAT
3274.0	[m]	C	STRAT
3275.0	[m]	SWC	HYDRO
3275.0	[m]	C	STRAT
3277.0	[m]	C	STRAT
3279.0	[m]	C	STRAT
3286.9	[m]	C	STRAT
3287.0	[m]	C	STRAT
3288.0	[m]	C	HYDRO
3294.3	[m]	C	STRAT
3294.7	[m]	C	STRAT
3295.0	[m]	SWC	HYDRO
3295.0	[m]	SWC	HYDRO
3300.0	[m]	DC	STRAT
3305.0	[m]	DC	STRAT
3307.0	[m]	DC	STRAT
3310.0	[m]	DC	STRAT
3320.0	[m]	DC	STRAT
3325.0	[m]	SWC	HYDRO
3326.0	[m]	DC	STRAT
3327.0	[m]	DC	STRAT
3329.9	[m]	SWC	HYDRO
3330.1	[m]	C	STRAT
3335.0	[m]	C	STRAT
3335.0	[m]	DC	STRAT
3338.6	[m]	C	STRAT
3345.0	[m]	DC	STRAT
3350.0	[m]	DC	STRAT
3355.0	[m]	DC	STRAT
3360.0	[m]	DC	STRAT
3365.0	[m]	DC	STRAT
3367.3	[m]	SWC	HYDRO
3370.0	[m]	DC	STRAT
3373.0	[m]	SWC	HYDRO
3375.0	[m]	DC	STRAT
3380.0	[m]	DC	STRAT
3383.2	[m]	SWC	HYDRO
3385.0	[m]	DC	STRAT
3395.0	[m]	DC	STRAT
3400.0	[m]	DC	STRAT
3405.0	[m]	DC	STRAT
3410.0	[m]	DC	STRAT
3415.0	[m]	DC	STRAT
3420.0	[m]	DC	STRAT
3425.0	[m]	DC	STRAT
3430.0	[m]	DC	STRAT
3435.0	[m]	DC	STRAT
3440.0	[m]	DC	STRAT
3445.0	[m]	DC	STRAT
3450.0	[m]	DC	STRAT
3455.0	[m]	DC	STRAT
3460.0	[m]	DC	STRAT
3465.0	[m]	DC	STRAT
3470.0	[m]	DC	STRAT
3475.0	[m]	DC	STRAT
3480.0	[m]	DC	STRAT
3485.0	[m]	DC	STRAT
3490.0	[m]	DC	STRAT
3495.0	[m]	DC	STRAT
3500.0	[m]	DC	STRAT
3508.4	[m]	SWC	HYDRO
3510.0	[m]	DC	STRAT
3517.0	[m]	DC	STRAT
3530.0	[m]	DC	STRAT
3540.0	[m]	DC	STRAT
3545.0	[m]	DC	STRAT
3550.0	[m]	DC	STRAT
3555.0	[m]	DC	STRAT
3560.0	[m]	DC	STRAT
3570.0	[m]	DC	STRAT
3580.0	[m]	DC	STRAT
3590.0	[m]	DC	STRAT
3600.0	[m]	DC	STRAT
3610.0	[m]	DC	STRAT
3612.2	[m]	SWC	HYDRO
3620.0	[m]	DC	STRAT
3630.0	[m]	DC	STRAT
3640.0	[m]	DC	STRAT
3650.0	[m]	DC	STRAT
3660.0	[m]	DC	STRAT
3665.0	[m]	DC	STRAT
3670.0	[m]	DC	STRAT
3680.0	[m]	DC	STRAT
3685.0	[m]	DC	STRAT
3685.7	[m]	C	STRAT
3700.0	[m]	DC	STRAT
3700.4	[m]	C	STRAT
3705.0	[m]	DC	STRAT
3710.0	[m]	DC	STRAT
3715.0	[m]	DC	STRAT
3720.0	[m]	DC	STRAT
3725.0	[m]	DC	STRAT
3730.0	[m]	DC	STRAT
3735.0	[m]	DC	STRAT
3737.0	[m]	DC	STRAT
3740.0	[m]	DC	STRAT
3743.2	[m]	SWC	HYDRO
3745.0	[m]	DC	STRAT
3750.0	[m]	DC	STRAT
3760.0	[m]	DC	STRAT
3770.0	[m]	DC	STRAT
3772.8	[m]	C	STRAT
3774.8	[m]	C	STRAT
3778.4	[m]	C	STRAT
3780.0	[m]	DC	STRAT
3784.0	[m]	SWC	HYDRO
3784.0	[m]	SWC	HYDRO
3785.0	[m]	DC	STRAT
3790.0	[m]	DC	STRAT
3795.0	[m]	DC	STRAT
3800.0	[m]	DC	STRAT
3810.0	[m]	DC	STRAT
3820.0	[m]	DC	STRAT
3830.0	[m]	DC	STRAT
3842.0	[m]	DC	STRAT
3851.0	[m]	SWC	HYDRO
3852.0	[m]	DC	STRAT
3862.0	[m]	DC	STRAT
3872.0	[m]	DC	STRAT
3882.0	[m]	DC	STRAT
3892.0	[m]	DC	STRAT
3902.0	[m]	DC	STRAT
3912.0	[m]	DC	STRAT
3920.0	[m]	DC	STRAT
3922.0	[m]	C	STRAT
3923.6	[m]	C	STRAT
3925.0	[m]	C	STRAT
3928.5	[m]	C	STRAT
3929.0	[m]	C	STRAT
3929.4	[m]	C	STRAT
3932.0	[m]	DC	STRAT
3940.0	[m]	DC	STRAT
3950.0	[m]	DC	STRAT
3957.0	[m]	DC	STRAT

Thin sections at the Norwegian Offshore Directorate

Thin sections at the Norwegian Offshore Directorate
Depth	Unit
2824.25	[m ]
2825.00	[m ]
2826.25	[m ]
2828.05	[m ]
2831.25	[m ]
3281.00	[m ]
3282.50	[m ]
3284.00	[m ]
3286.50	[m ]
3287.75	[m ]
3291.75	[m ]
3335.50	[m ]
3337.25	[m ]
3337.50	[m ]
3687.50	[m ]
3690.00	[m ]
3691.65	[m ]
3692.45	[m ]
3694.22	[m ]
3695.50	[m ]
3698.50	[m ]
3698.75	[m ]
3771.25	[m ]
3777.00	[m ]
3275.25	[m ]
3281.01	[m ]
3285.50	[m ]
3286.75	[m ]
3293.00	[m ]
3295.00	[m ]

6507/2-2

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

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