6507/2-2

hide details Export:  PDF

• 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]	Yield point [Pa]	Mud type	Date measured
  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 ]