Wellbore: 33/9-9 - Factpages - Norwegian Offshore Directorate

General information

General information
Attribute	Value
Wellbore name Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.	33/9-9
Type Wellbore type. Legal values: EXPLORATION, DEVELOPMENT, OTHER (see 'Purpose' for more information)	EXPLORATION
Purpose Final classification of the wellbore. Legal values for exploration wellbores: WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS. Legal values for development wellbores: OBSERVATION, PRODUCTION, INJECTION, INJECTION-CCS, OBSERVATION-CCS. Legal values for other wellbores: SOIL DRILLING (drilling in connection with track surveys and other subsurface surveys to investigate the soil conditions prior to placement of facilities), SHALLOW GAS (drilling to investigate shallow gas before the first 'real' drilling on the location), PILOT (drilling to investigate the geology and fluid connectors for location of the main wellbore), SCIENTIFIC (drilling according to Law of Scientific research and exploration), STRATIGRAPHIC (driling according to Law of Petroleum activities §2-1).	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
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.	NORTH SEA
Field Name of the field the wellbore is related to.	STATFJORD
Discovery Name of the discovery the wellbore is related to.	33/12-1 Statfjord
Well name Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.	33/9-9
Production licence Official designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion).	037
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.	Mobil Exploration Norway INC
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.	179-L
Drilling facility Norwegian Offshore Directorate's name of the facility which the wellbore was drilled from.	BORGNY DOLPHIN
Drilling days Number of days from wellbore entry to wellbore completion.	114
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,	27.07.1977
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.	17.11.1977
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.	17.11.1979
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.	03.10.2011
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
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.	BRENT GP
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.	EARLY 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.	DUNLIN GP
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.	25.0
Water depth [m] Depth in metres betweem mean sea level and sea floor.	145.0
Total depth (MD) [m RKB] Total measured length of wellbore from kelly bushing to total depth (driller's depth).	3100.0
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).	3098.0
Maximum inclination [°] Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.	5.2
Bottom hole temperature [°C] Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.	96
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.	STATFJORD GP
Geodetic datum Reference system for coordinates. Example of legal values: ED50.	ED50
NS degrees Geographic coordinate of the wellhead, north-south degrees.	61° 17' 10.19'' N
EW degrees Geographic coordinate of the wellhead, east-west degrees.	1° 54' 26.05'' E
NS UTM [m] Universal Transverse Mercator coordinate of the wellhead, north-south.	6795313.86
EW UTM [m] Universal Transverse Mercator coordinate of the wellhead, east-west.	441428.36
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.	414

Well 33/9-9 was drilled in the northern part of the Statfjord field, about 1.6 km southeast of 33/9-3 well on the Tampen Spur in the northern North Sea. The objectives were to provide structural and stratigraphic control on the Brent reservoirs, and to provide stratigraphic control and to establish an oil/water contact for the Statfjord reservoir.

Operations and results

Appraisal well 33/9-9 was spudded with the semi-submersible installation Borgny Dolphin on 27 July 1977 and drilled to TD at 3100 m in Late Triassic sediments in the Statfjord Formation. The well was drilled with seawater down to 486 m and with a seawater/lignosulphonate mud system from 486 m to 1993 m. At 1993 m, TD in the 17 1/2" section, the hole was displaced to a freshwater/Lignosulphonate mud system. At the same point diesel was added to free the 13 3/8" casing which had become differentially stuck. After that the mud contained initially 5% diesel decreasing to traces of diesel at to 2489 m. From 2489 m to final TD the freshwater/Lignosulphonate mud system was without measurable diesel.

No hydrocarbon shows were reported above the Brent Group. The Brent Group was found at 2413 m, 77.5 m deeper than prognosed 44.0 m thinner than anticipated in comparison to 33/9-3. Good oil shows were encountered at the top of the Brent Formation and continued throughout the reservoir down to top Dunlin Group at 2504 m. The entire Brent Group was oil-filled and it was above the field oil/water contact of 2609.1 m (2584.1 MSL). Log calculations showed that of the 87.0 m of gross oil section 84.6 m was net sand with 27.5% average porosity and 13.1% average water saturation. The Dunlin Group came in at 2504 m and log interpretation indicated a 23.2 m gross oil bearing reservoir between 2528.4 and 2551.6 m with 17.9 m net oil sand. The interval had 20.2% average porosity and 34.6% water saturation. Oil shows were reported from ditch samples and side wall cores in the Dunlin sand between 2535 and 2575 m. No OWC was established in the Dunlin Group. It was assumed that Brent and Dunlin had a common OWC at 2609.1 m (2584.1 MSL), outside well position. The Early Jurassic Statfjord Formation was penetrated at 2715.0, only 5.0 m deep to prognosis confirming that the Statfjord seismic reflector is a reliable mapping horizon. Good oil shows were reported from the top down to about 2850.0 m. The lowest potential pay sand indicated on the CPI log occurs between 2847.5 and 2852.5 m, but a test in this interval, DST No. 2, produced water with only trace oil. The anticipated oil/water contact was not found. The lowest-known-oil in the well at 2815.0 m (2790.0 m MSL) is 13.1 m above the lowest-known-oil previously established in the 33/12-2, which falls within a section of tight sands and shales in 33/9-9.

A total of 23 cores were cut in the well. Cores no 1 to 8 were taken through the Brent reservoir and into the shaly top of Dunlin, while cores no 9 to 23 were cut in the Statfjord Formation. A significant error in core depth is noted for the first 16 cores. For these 11.3 m must be added to the registered core depths in order to match with the logger's depth. The last seven cores had core-log mismatch within +/- 2 m.

The well was permanently abandoned on 17 November 1977 as n oil and gas appraisal well.

Testing

Six separate zones were successfully tested, requiring a total of nine attempts. The purpose of the tests was to obtain information from six separate zones in the Brent, Dunlin and Statfjord Sands in order to further evaluate the reservoirs. The tests for the first two zones were designed primarily for production data, bottom hole pressures and formation fluid samples, with sustained sand production expected only if very thin unconsolidated sand stringers were present. The last four zones where sand bonding was weak, as calculated from the well log data, had the additional test requirement of measuring the oil rate at which the formation sand broke down.

DST 1 in the interval 2847.5 to 2852.5 m in the Statfjord Formation was a misrun.

DST 2 in the interval 2847.5 to 2852.5 m in the Statfjord Formation produced 215 Sm3 water and only trace oil /day through a 3/4" choke. The recorded bottom hole temperature was 91.1 deg C. Sand was produced throughout the test, at rates from 1200 to 300 pounds/thousand barrels (ptb)

DST 3 in the interval 2800.0 m to 2803.5 m in the Statfjord Formation produced in the final flow period 254 Sm3 oil /day through a 1/4" choke. The GOR was 82 Sm3/Sm3 and the oil gravity was 39.0 deg API. The recorded bottom hole temperature was 86.1 deg C. After the initial cleanup flow no sand was produced.

DST 4 in the interval 2742.0 m to 2745.0 m in the Statfjord Formation was a misrun.

DST 5 in the interval 2742.0 m to 2745.0 m in the Statfjord Formation produced in the final flow period 513 Sm3 oil /day through a 5/16" choke. The GOR was 93 Sm3/Sm3 and the oil gravity was 38.7 deg API. The recorded bottom hole temperature was 89.4 deg C. Sand was produced after each rate change (20 ptb), but cleaned up rapidly. Sand began producing more or less continuously, in bursts, on 5/8" choke (40 ptb) indicating formation was breaking down.

DST 6 in the interval 2742.0 m to 2745.0 m in the Statfjord Formation produced in the final flow period 299 Sm3 oil /day through a 1/4" choke. The GOR was 129 Sm3/Sm3 and the oil gravity was 38.6 deg API. The recorded bottom hole temperature was 89 deg C.No sand was observed other than a few grains upon initial cleanup on 7/16" choke.

DST 7 in the interval 2531.0 m to 2537.0 m in the Dunlin Group produced in the final flow period 442 Sm3 oil /day through a 23/64" choke. The GOR was 117 Sm3/Sm3 and the oil gravity was 34.4 deg API. The recorded bottom hole temperature was 82.8 deg C. On 1 1/4" choke sand production was observed on a continuous basis at about 120 ptb.

DST 8 in the interval 2458.0 m to 2460.7 m in the Brent Group produced in the final flow period 525 Sm3 oil /day through a 24/64" choke. The GOR was 144 Sm3/Sm3 and the oil gravity was 37.6 deg API (measured in the first flow period). The recorded bottom hole temperature was 80.1 deg C. Only small amounts of sand were produced.

DST 9 in the interval 2426.0 m to 2432.8 m in the Brent Group produced in the final flow period 416 Sm3 oil /day through a 22/64" choke. The GOR was 170 Sm3/Sm3 and the oil gravity was 38.5 deg API (measured in the first flow period). No temperature was recorded due to malfunction in the temperature gauge. Small amounts of sand were produced throughout the test. No measurable sand was produced on the highest flow rate (50/64" adjustable choke).

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]
254.00	3101.00

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	2414.0	2421.9	[m ]
2	2432.3	2444.3	[m ]
3	2444.3	2444.8	[m ]
4	2446.3	2455.3	[m ]
5	2455.3	2468.3	[m ]
6	2468.3	2482.3	[m ]
7	2482.3	2500.6	[m ]
8	2500.6	2517.8	[m ]
9	2719.0	2722.3	[m ]
10	2722.3	2732.3	[m ]
11	2732.3	2740.3	[m ]
12	2740.3	2754.8	[m ]
13	2754.8	2768.6	[m ]
14	2768.8	2774.3	[m ]
15	2774.3	2786.6	[m ]
16	2786.6	2793.0	[m ]
17	2793.0	2807.5	[m ]
18	2807.5	2818.4	[m ]
19	2818.4	2826.2	[m ]
20	2826.2	2837.5	[m ]
21	2837.5	2853.5	[m ]
22	2853.5	2866.0	[m ]
23	2866.0	2876.5	[m ]

Cores at the Norwegian Offshore Directorate
Total core sample length [m]	249.2

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

Core photos

Core photos

24414-2416m	2416-2419m	2419-2421m	2421-2424m	2424-2426m

2426-2429m	2429-2432m	2432-2432m	2432-2434m	2434-2437m

2437-2439m	2439-2443m	2442-2444m	2444-2446m	2446-2448m

2448-2451m	2451-2453m	2453-2455m	2455-2458m	2458-2460m

2460-2463m	2463-2465m	2465-2465m	2468-2470m	2470-2473m

2473-2475m	2475-2478m	2478-2480m	2480-2481m	2481-2484m

2484-2487m	2487-2490m	2490-2492m	2492-2495m	2495-2498m

2498-2500m	2500-2503m	2503-2505m	2505-2508m	2508-2522m

2511-2513m	2513-2516m	2516-2516m	2719-2722m	2722-2725m

2725-2727m	2727-2732m	2732-2734m	2734-2737m	2737-2740m

2740-2742m	2742-2745m	2742-2745m	2745-2748m	2748-2750m

2750-2754m	2754-2757m	2757-2760m	2760-2762m	2762-2765m

2765-2768m	2768-2774m	2774-2776m	2776-2779m	2779-2782m

2782-2784m	2784-2786m	2786-2789m	2789-2791m	2791-2793m

2793-2795m	2795-2798m	2798-2807m	2807-2810m	2810-2812m

2812-2815m	2815-2818m	2818-2821m	2821-2823m	2823-2826m

2826-2828m	2828-2831m	2831-2834m	2834-2837m	2837-2840m

2840-2842m	2842-2845m	2845-2847m	2847-2850m	2850-2853m

2853-2856m	2856-2858m	2861-2863m	2863-2866m	2866-2868m

2868-2871m	2871-2874m	2874-2876m	2858-2861m

Casing and leak–off tests

Casing and leak–off tests
Casing type	Casing diam. [inch]	Casing depth [m]	Hole diam. [inch]	Hole depth [m]	Formation test type
CONDUCTOR	30	244.0	36	249.0	LOT
SURF.COND.	20	475.0	26	486.0	LOT
INTERM.	13 3/8	1984.0	17 1/2	1993.0	LOT
INTERM.	9 5/8	3068.0	12 1/4	3100.0	LOT

Drill stem tests (DST)

Drill stem tests (DST)
Test number	From depth MD [m]	To depth MD [m]	Choke size [mm]
2.0	2848	2853	19.0
3.0	2800	2804	19.0
5.0	2742	2745	15.9
6.0	2742	2745	11.0
7.0	2531	2538	30.0
8.0	2458	2461	19.0
9.0	2426	2433	0.0

Drill stem tests (DST)
Test number	Final shut-in pressure [MPa]	Downhole temperature [°C]
2.0
3.0	30.000
5.0	34.000
6.0	38.000	89
7.0	24.000
8.0	34.000
9.0

Drill stem tests (DST)
Test number	Oil [Sm3/day]	Oil density [g/cm3]	GOR [m3/m3]
2.0
3.0	1438	0.830	412
5.0	1206	0.830	545
6.0	863	0.830	618
7.0	1327	0.830	569
8.0	1468	0.830	1059
9.0

Logs

Logs
Log type	Log top depth [m]	Log bottom depth [m]
DLL	2350	3100
FDC CNL	475	3100
GR SPECTRO	2350	3100
HDT	2300	3100
ISF SONIC	245	3100
LS SONIC	1990	3098
RFT	0	0
VSP	355	2955

Lithostratigraphy

Lithostratigraphy
Top depth [mMD RKB]	Lithostrat. unit
170	NORDLAND GP
997	HORDALAND GP
1660	ROGALAND GP
1660	BALDER FM
1693	LISTA FM
1848	SHETLAND GP
2396	CROMER KNOLL GP
2413	BRENT GP
2504	DUNLIN GP
2504	DRAKE FM
2528	COOK FM
2558	BURTON FM
2715	STATFJORD GP

Geochemical information

Geochemical information
Document name	Document format	Document size [MB]
414_1	pdf	1.24

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]
414_33_9_9_Biostratighraphical_analysis_charts	pdf	2.47
414_33_9_9_Biostratigraphic_correlation	pdf	0.98
414_33_9_9_biostratigraphy_of_the_interval_254m-3100m	pdf	2.33
414_33_9_9_Completion_log	pdf	1.80
414_33_9_9_Completion_Report	pdf	2.95
414_33_9_9_Conventional_core_analysis	pdf	0.82
414_33_9_9_Core_analysis_report	pdf	10.65
414_33_9_9_Core_analysis_report_statfjord	pdf	6.73
414_33_9_9_Drilling_program	pdf	1.31
414_33_9_9_final_geological_report	pdf	2.95
414_33_9_9_Final_geological_report_appraisal	pdf	0.59
414_33_9_9_Paleontological_and_sedimentological_studies	pdf	0.53
414_33_9_9_Palynofacies_studies	pdf	0.87
414_33_9_9_Special_core_analysis	pdf	10.47
414_33_9_9_Special_core_analysis_Final_report	pdf	12.44
414_33_9_9_Special_core_analysis_mobil_exploratoin	pdf	3.03
414_33_9_9_Special_core_analysis_statfjord_field	pdf	6.89
414_33_9_9_Special_core_analysis_study_Core_lab	pdf	1.64
414_33_9_9_Summary_log	pdf	0.13
414_33_9_9_Well_history_operations_report	pdf	3.67

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]
414_01_WDSS_General_Information	pdf	1.90

Drilling mud

Drilling mud
Depth MD [m]	Mud weight [g/cm3]	Mud type
249	1.07	waterbased
760	1.14	waterbased
1137	1.16	waterbased
1568	1.25	waterbased
1993	1.37	waterbased
2421	1.72	waterbased

Palynological slides at the Norwegian Offshore Directorate

Palynological slides at the Norwegian Offshore Directorate
Sample depth	Depth unit	Sample type	Laboratory
2420.3	[m]	C	LAP
2420.3	[m]	C	OD
2431.1	[m]	C	OD
2431.1	[m]	C	LAP
2433.8	[m]	C	LAP
2433.8	[m]	C	OD
2434.4	[m]	C	OD
2434.4	[m]	C	LAP
2436.1	[m]	C	LAP
2436.1	[m]	C	OD
2436.5	[m]	C	OD
2436.5	[m]	C	LAP
2437.2	[m]	C	LAP
2437.2	[m]	C	OD
2437.8	[m]	C	OD
2437.8	[m]	C	LAP
2438.6	[m]	C	LAP
2438.6	[m]	C	OD
2438.7	[m]	C	OD
2438.7	[m]	C	LAP
2440.9	[m]	C	LAP
2440.9	[m]	C	OD
2442.8	[m]	C	OD
2442.8	[m]	C	LAP
2443.0	[m]	C	LAP
2443.0	[m]	C	OD
2443.0	[m]	C	OD
2443.0	[m]	C	LAP
2443.5	[m]	C	LAP
2443.5	[m]	C	OD
2444.5	[m]	C	OD
2444.5	[m]	C	LAP
2446.3	[m]	C	LAP
2446.3	[m]	C	OD
2446.9	[m]	C	LAP
2448.6	[m]	C	LAP
2448.6	[m]	C	OD
2448.8	[m]	C	OD
2448.8	[m]	C	LAP
2448.9	[m]	C	LAP
2448.9	[m]	C	OD
2450.3	[m]	C	OD
2450.3	[m]	C	LAP
2451.8	[m]	C	LAP
2451.8	[m]	C	OD
2453.3	[m]	C	OD
2453.3	[m]	C	LAP
2455.0	[m]	C	LAP
2455.0	[m]	C	OD
2455.3	[m]	C	OD
2455.3	[m]	C	LAP
2456.6	[m]	C	LAP
2456.6	[m]	C	OD
2459.3	[m]	C	OD
2459.3	[m]	C	LAP
2469.3	[m]	C	LAP
2469.3	[m]	C	OD
2486.0	[m]	C	LAP
2489.0	[m]	C	LAP
2494.0	[m]	C	LAP
2497.0	[m]	C	LAP
2500.0	[m]	C	LAP
2502.0	[m]	C	LAP
2503.0	[m]	C	LAP
2504.0	[m]	C	LAP
2507.0	[m]	C	LAP
2512.0	[m]	C	LAP
2516.0	[m]	C	LAP

Thin sections at the Norwegian Offshore Directorate

Thin sections at the Norwegian Offshore Directorate
Depth	Unit
2748.45	[m ]
2751.45	[m ]
2756.30	[m ]
2759.20	[m ]
2764.55	[m ]
2765.88	[m ]
2782.55	[m ]
2799.60	[m ]
2809.30	[m ]
2722.85	[m ]

33/9-9