Wellbore: 31/3-1 - 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.	31/3-1
Type Wellbore type. Legal values: EXPLORATION, DEVELOPMENT, OTHER (see 'Purpose' for more information)	EXPLORATION
Purpose Final classification of the wellbore. Legal values for exploration wellbores: WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS. Legal values for development wellbores: OBSERVATION, PRODUCTION, INJECTION, INJECTION-CCS, OBSERVATION-CCS. Legal values for other wellbores: SOIL DRILLING (drilling in connection with track surveys and other subsurface surveys to investigate the soil conditions prior to placement of facilities), SHALLOW GAS (drilling to investigate shallow gas before the first 'real' drilling on the location), PILOT (drilling to investigate the geology and fluid connectors for location of the main wellbore), SCIENTIFIC (drilling according to Law of Scientific research and exploration), STRATIGRAPHIC (driling according to Law of Petroleum activities §2-1).	APPRAISAL
Status Status for the wellbore. Legal values are: BLOWOUT: A blowout has occurred in the well. CLOSED: A development wellbore that has been closed in a shorter or longer periode. Also applies to development wellbores where drilling is completed, but production/injection has not yet been reported. DRILLING: The well is in the drilling phase - can be active drilling, logging, testing or plugging, JUNKED: The drilling operation has been terminated due to technical problems. P&A: Exploration: The well is plugged and abandoned, and can not be reentered for further use. Development wells: The production/injection from/to the well is stopped and the well is plugged. The wellhead is removed or else made unavailable for further well operations. PLUGGED: The wellbore has been plugged, but the upper parts of the wellbore can be re-used. A sidetrack might be drilled at a later stage. PRODUCING: It was produced from the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate. INJECTING: It was injected to the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate. PREDRILLED: The upper part of the well has been drilled, usually as part of a batch-drilling campaign covering several wellbores. RE-CLASS TO DEV: Exploration wellbore that is reclassified to a development wellbore. RE-CLASS TO TEST: Exploration wellbore that is reclassified to test production. SUSPENDED: The drilling operation in the wellbore has been temporarily stopped. The current plan is to continue drilling later on.	P&A
Factmaps in new window	link to map
Main area Name of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.	NORTH SEA
Field Name of the field the wellbore is related to.	TROLL
Discovery Name of the discovery the wellbore is related to.	31/6-1 (Troll Øst)
Well name Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.	31/3-1
Seismic location Position of spud location on seismic survey lines. SP: shotpoint.	ST 8116 - 138 SP 481
Production licence Official designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion).	085
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.	Den norske stats oljeselskap a.s
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.	379-L
Drilling facility Norwegian Offshore Directorate's name of the facility which the wellbore was drilled from.	DEEPSEA BERGEN
Drilling days Number of days from wellbore entry to wellbore completion.	88
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,	17.07.1983
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.	13.10.1983
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.	13.10.1985
Publication date Date quality control of the wellbore information was completed, so it can be published on the internet as a 'Well Data Summary Sheet' wellbore with more information available than other wellbores.	15.02.2006
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
Reentry Status whether the wellbore has been re-entered (YES) or not (NO). Re-entered wellbores are not included in the count when wellbores are presented in statistical overviews.	NO
Content For exploration wellbores, status of discovery. Legal values: DRY, SHOWS (trace amounts of hydrocarbons), GAS, GAS/CONDENSATE, OIL or OIL/GAS. SHOWS (GAS SHOWS, OIL SHOWS or OIL/GAS SHOWS) are detected as fluorescent cut (organic extract), petroleum odour, or visual stain on cuttings or cores, or as increased gas reading on the mud-loggers gas detection equipment. Legal values for WILDCAT-CCS and APPRAISAL-CCS: WATER For development wellbores, type of produced/injected fluid. Legal values: WATER, CUTTINGS, NOT AVAILABLE, OIL, GAS/CONDENSATE, OIL/GAS, CO2, GAS, WATER/GAS, NOT APPLICABLE.	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.	LATE 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.	SOGNEFJORD FM
2nd level with HC, age Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.	MIDDLE JURASSIC
2nd level with HC, formation Name of lithostartigraphic unit, 2nd level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP.	FENSFJORD 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.	334.0
Total depth (MD) [m RKB] Total measured length of wellbore from kelly bushing to total depth (driller's depth).	2374.0
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).	2374.0
Maximum inclination [°] Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.	2.15
Bottom hole temperature [°C] Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.	73
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.	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.	HEGRE GP
Geodetic datum Reference system for coordinates. Example of legal values: ED50.	ED50
NS degrees Geographic coordinate of the wellhead, north-south degrees.	60° 46' 47.86'' N
EW degrees Geographic coordinate of the wellhead, east-west degrees.	3° 44' 3.4'' E
NS UTM [m] Universal Transverse Mercator coordinate of the wellhead, north-south.	6738661.73
EW UTM [m] Universal Transverse Mercator coordinate of the wellhead, east-west.	539989.88
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.	20

The wildcat 31/3-1 was drilled ca 17 km NNE of well 13/6-1 in the Troll East area. The two wells were drilled at the same time and together they established the existence of a Troll East gas field. The objective of 31/3-1 was to test possible gas and oil accumulations in sandstones of Late to Middle Jurassic age. Secondary objective was to test possible hydrocarbon accumulations in Middle to Early Jurassic and Late Triassic.

Operations and results

Wildcat well 31/3-1 was spudded with the semi-submersible installation Deepsea Bergen on 17 July 1983 and drilled to TD at 2374 m in the Triassic Hegre Group. No significant problems occurred during drilling except some technical problems when running the BOP for the 26" section. The well was drilled with spud mud down to 865 m, with KCl/polymer from 865 m to 1300 m, with gel/lignosulphonate from 1300 m to 1833 m, and with lignite/lignosulphonate from 1833 m to TD.

Top reservoir (Sognefjord Formation) was encountered at 1351.5 m. The Sognefjord, Heather, and Fensfjord Formations were found to hold a gas column of ca 220 m gas down to an approximate 4 m oil column. The OWC was at ca 1576m.Geochemical analyses of the reservoir gas show clear signs of biodegradation. Neither the Early Jurassic nor the Late Triassic contained hydrocarbons.

Twelve cores were cut continuously from 1351 m to 1610 m in the Late and Middle Jurassic reservoir sequences. FMT fluid samples were taken at 1374.2 m, 1570 m, 1574.2 m, and 1579.2 m.

The well was permanently abandoned on 13 October 1983 as a gas appraisal well.

Testing

Two DST's were performed, and gas was produced from both. DST 1 was performed from the interval 1519 m to 1529 m and produced 842400 Sm3 gas /day on a 22 mm choke. The gas had a gravity of 0.635 (air = 1). DST2 was performed from the interval 1373 m to 1383 m and produced 733500 Sm3 gas /day on a 19 mm choke. The gas had a gravity of 0.635 (air = 1). Turbulence was a problem during the tests. Although stable static bottom hole temperatures were not obtained the data indicated a reservoir temperature of 54.8 deg C at 1353 m. With a seafloor temperature of 4 deg C this correspond to a linear temperature gradient of 51 deg C/km from top reservoir to the sea floor.

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]
430.00	2374.00

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	1351.0	1362.3	[m ]
2	1366.0	1371.5	[m ]
3	1372.0	1390.7	[m ]
4	1391.0	1405.2	[m ]
5	1407.0	1424.0	[m ]
6	1424.3	1442.3	[m ]
7	1442.6	1461.3	[m ]
8	1461.0	1480.0	[m ]
9	1480.0	1498.0	[m ]
10	1498.1	1516.8	[m ]
11	1516.0	1535.4	[m ]
12	1535.4	1553.6	[m ]
13	1553.9	1572.6	[m ]
14	1572.6	1578.6	[m ]
15	1591.3	1610.0	[m ]

Cores at the Norwegian Offshore Directorate
Total core sample length [m]	240.0

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

Core photos

Core photos

1351-1356m	1356-1361m	1361-1362m	1366-1371m	1371-1372m

1372-1377m	1377-1382m	1382-1387m	1387-1390m	1391-1396m

1396-1401m	1401-1405m	1406-1411m	1411-1416m	1416-1421m

1421-1424m	1424-1429m	1429-1434m	1434-1439m	1439-1442m

1442-1447m	1447-1452m	1452-1457m	1457-1461m	1461-1466m

1466-1471m	1471-1476m	1476-1480m	1480-1485m	1485-1490m

1490-1495m	1495-1498m	1498-1503m	1503-1508m	1508-1513m

1513-1516m	1516-1521m	1521-1526m	1526-1531m	1531-1535m

1535-1540m	1540-1545m	1545-1550m	1550-1553m	1553-1558m

1558-1563m	1563-1568m	1568-1572m	1572-1577m	1577-1581m

1582-1587m	1587-1590m	1591-1596m	1596-1601m	1601-1605m

1606-1610m

Palynological slides at the Norwegian Offshore Directorate

Palynological slides at the Norwegian Offshore Directorate
Sample depth	Depth unit	Sample type	Laboratory
610.0	[m]	DC	GEOCH
640.0	[m]	DC	GEOCH
670.0	[m]	DC	GEOCH
700.0	[m]	DC	GEOCH
730.0	[m]	DC	GEOCH
760.0	[m]	DC	GEOCH
790.0	[m]	DC	GEOCH
820.0	[m]	DC	GEOCH
850.0	[m]	DC	GEOCH
880.0	[m]	DC	GEOCH
909.0	[m]	DC	GEOCH
930.0	[m]	SWC	IKU
936.0	[m]	DC	GEOCH
963.0	[m]	DC	GEOCH
990.0	[m]	DC	GEOCH
1017.0	[m]	DC	GEOCH
1026.0	[m]	SWC	IKU
1038.0	[m]	SWC	IKU
1044.0	[m]	DC	GEOCH
1071.0	[m]	DC	GEOCH
1098.0	[m]	DC	GEOCH
1100.0	[m]	SWC	IKU
1125.0	[m]	DC	GEOCH
1152.0	[m]	DC	GEOCH
1157.0	[m]	SWC	IKU
1179.0	[m]	DC	GEOCH
1206.0	[m]	DC	GEOCH
1219.0	[m]	SWC	IKU
1224.0	[m]	DC	GEOCH
1229.0	[m]	SWC	IKU
1233.0	[m]	DC	GEOCH
1251.0	[m]	DC	GEOCH
1282.0	[m]	SWC	IKU
1290.0	[m]	SWC	IKU
1312.0	[m]	SWC	IKU
1317.0	[m]	SWC	IKU
1322.0	[m]	SWC	IKU
1342.0	[m]	SWC	IKU
1612.0	[m]	SWC	IKU
1780.0	[m]	SWC	IKU
1825.0	[m]	SWC	IKU
1845.0	[m]	SWC	IKU
1865.0	[m]	SWC	IKU
1900.0	[m]	SWC	IKU
1920.0	[m]	SWC	IKU
1980.0	[m]	DC	IKU
2040.0	[m]	SWC	IKU

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	TEST1	1519.00	1529.00	OIL	22.09.1983 - 14:50	YES
DST	TEST2	1373.00	1383.00		04.10.1983 - 15:30	YES

Lithostratigraphy

Lithostratigraphy
Top depth [mMD RKB]	Lithostrat. unit
357	NORDLAND GP
531	HORDALAND GP
931	ROGALAND GP
931	BALDER FM
1038	SELE FM
1136	LISTA FM
1225	VÅLE FM
1235	SHETLAND GP
1273	CROMER KNOLL GP
1273	RØDBY FM
1320	VIKING GP
1320	DRAUPNE FM
1352	SOGNEFJORD FM
1497	HEATHER FM
1516	FENSFJORD FM
1668	KROSSFJORD FM
1779	HEATHER FM
1796	BRENT GP
1844	DUNLIN GP
1844	DRAKE FM
1945	COOK FM
1992	AMUNDSEN FM
2001	JOHANSEN FM
2088	AMUNDSEN FM
2105	STATFJORD GP
2160	HEGRE GP

Composite logs

Composite logs
Document name	Document format	Document size [MB]
20	pdf	0.50

Geochemical information

Geochemical information
Document name	Document format	Document size [MB]
20_1	pdf	5.74
20_2	pdf	0.29
20_3	pdf	1.74
20_4	pdf	0.22
20_5	pdf	3.56
20_6	pdf	0.36

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]
20_01_WDSS_General_Information	pdf	0.19
20_02_WDSS_completion_log	pdf	0.25

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]
20_01_31_3_1_Completion_Report_and_Completion_log	PDF	30.93
20_02_31_3_1_Final_well_report_by_Exlog	pdf	5.87
20_03_31_3_1_Final_well_report_encl_01	pdf	2.89
20_04_31_3_1_Final_well_report_encl_02	pdf	0.64
20_05_31_3_1_Final_well_report_encl_03	pdf	0.45
20_06_31_3_1_Final_well_report_encl_04	pdf	0.35
20_31_3_1_Biostratigrafisk_analyse	pdf	7.92
20_31_3_1_Biostratigraphy_by_IKU	pdf	7.34
20_31_3_1_Clay_contrib_to_obs.prod.loss	pdf	4.45
20_31_3_1_Comp.of_reserv_Fluids DST1,2	pdf	0.44
20_31_3_1_Completion_fluids_by_Statoil	pdf	0.78
20_31_3_1_Core_gamma_surface_log	pdf	0.35
20_31_3_1_DST_1-2_pre-post_gravel_pack_by_Otis	pdf	12.58
20_31_3_1_Formation_res.factor_analysis	pdf	0.30
20_31_3_1_Geochem.analyse_TOC	pdf	0.21
20_31_3_1_Geochem.correlation_of_HC	pdf	1.83
20_31_3_1_Geochemistry_source_rock_Evaluation	pdf	3.80
20_31_3_1_Geolog.progn_and_drilling_progr	pdf	2.09
20_31_3_1_Geolog.progn_and_drilling_progr_encl_01	pdf	0.90
20_31_3_1_Geolog.progn_and_drilling_progr_encl_02	pdf	0.16
20_31_3_1_Grain_size_distr.analysi	pdf	3.15
20_31_3_1_Gravel_Pack_Operations	pdf	1.27
20_31_3_1_Gravel_Pack_Operations_encl_01	pdf	0.16
20_31_3_1_Gravel_Pack_Operations_encl_02	pdf	0.14
20_31_3_1_High_ Acc.press.temp.meas	pdf	4.47
20_31_3_1_High_Acc.press.temp.meas	pdf	5.56
20_31_3_1_High_acc.press.temp.meas_encl_01	pdf	0.17
20_31_3_1_High_acc.press.temp.meas_encl_02	pdf	0.03
20_31_3_1_High_acc.press.temp.meas_encl_03	pdf	0.03
20_31_3_1_High_acc.press.temp.meas_encl_04	pdf	0.02
20_31_3_1_High_acc.press.temp.meas_encl_05	pdf	0.02
20_31_3_1_High_acc.press.temp.meas_Flopetrol	pdf	3.04
20_31_3_1_High_acc.press.temp	pdf	2.46
20_31_3_1_High_acc.press.temp_b	pdf	1.33
20_31_3_1_High_acc.press.temp_b_encl_01	pdf	0.39
20_31_3_1_High_acc.press.temp_encl_01	pdf	0.37
20_31_3_1_High_Acc.press.temp_e_encl_01	pdf	0.17
20_31_3_1_High_Acc.press.temp_e_encl_02	pdf	0.06
20_31_3_1_High_Acc.press.temp_e_encl_03	pdf	0.03
20_31_3_1_High_Acc.press.temp_e_encl_04	pdf	0.02
20_31_3_1_High_Acc.press.temp_e_encl_05	pdf	0.03
20_31_3_1_High_Acc.press.temp_e_encl_06	pdf	0.04
20_31_3_1_High_Acc.press.temp_e_encl_07	pdf	0.03
20_31_3_1_High_Acc.press.temp_e_encl_08	pdf	0.02
20_31_3_1_High_Acc.press.temp_e_Flopetrol	pdf	4.52
20_31_3_1_Mon.quality_of_compl.fluids	pdf	3.80
20_31_3_1_Mud_and_Res.gas_Geochemistry	pdf	0.37
20_31_3_1_Multivariat_behandling_by Rogforsk	pdf	0.61
20_31_3_1_Overlagringstrykk	pdf	1.09
20_31_3_1_Palynofacies_and_stratigraphy	pdf	40.84
20_31_3_1_Petrophysical_evaluation	pdf	1.42
20_31_3_1_Petrophysical_evaluation_encl_01	pdf	0.41
20_31_3_1_Petrophysical_evaluation_encl_02	pdf	2.21
20_31_3_1_Point_counting_test	pdf	0.13
20_31_3_1_Press.survey_rep.test1_run1	pdf	1.27
20_31_3_1_Press.survey_rep.test1_run2	pdf	2.18
20_31_3_1_Press.survey_rep.test2_run1	pdf	0.92
20_31_3_1_Press.survey_rep.test2_run3	pdf	1.87
20_31_3_1_Press.survey_rep.test2_run4	pdf	1.25
20_31_3_1_Routine_core_analysis	pdf	4.46
20_31_3_1_Special_core_analysis	pdf	9.10
20_31_3_1_Special_core_analysis_by_Robertson	pdf	2.28
20_31_3_1_Special_core_analysis_rev_report_by_Geco	pdf	6.00
20_31_3_1_TBP_distillation_of_stock_tank	pdf	0.67
20_31_3_1_Tritiated_water_in_the_mud	pdf	0.55
20_31_3_1_Troll_single_well_Geochemical_study	pdf	0.21
20_31_3_1_Use_of_tritiated_water	pdf	2.63
20_31_3_1_Weesite_Gas_Analysis	pdf	0.46
20_31_3_1_Well_test_report_FMT_no.1,2	pdf	5.40
20_31_3_1_Und_av_GravelPack_vaesker	pdf	1.27

Drill stem tests (DST)

Drill stem tests (DST)
Test number	From depth MD [m]	To depth MD [m]	Choke size [mm]
1.0	1519	1529	16.9
2.0	1373	1383	12.7

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		355000
2.0		479000

Logs

Logs
Log type	Log top depth [m]	Log bottom depth [m]
4ARM DIP/STRATDIP	1288	2374
ACBL	355	1285
ACBL	1000	1814
CDL CNL GR CAL	1285	2372
CDL GR CAL	845	1299
DIFL BHC AC	350	866
DIFL BHC AC GR SP CAL	845	2374
DLL MLL GR	1285	1835
FMT	1352	1695
PROLOG	1340	1650
VELOCITY	1110	2375

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	421.0	36	422.0	0.00	LOT
SURF.COND.	20	849.0	26	865.0	1.55	LOT
INTERM.	13 3/8	1285.5	17 1/2	1300.0	1.66	LOT
INTERM.	9 5/8	1815.5	12 1/4	1835.0	1.65	LOT
OPEN HOLE		2374.0	8 1/2	2374.0	0.00	LOT

Drilling mud

Drilling mud
Depth MD [m]	Mud weight [g/cm3]	Visc. [mPa.s]	Mud type
450	1.07	51.0	seawater
1000	1.08	53.0	seawater
1260	1.28	22.0	seawater
1775	1.30	60.0	seawater
1950	1.12	53.0	seawater

Pressure plots

Pressure plots
The pore pressure data is sourced from well logs if no other source is specified. In some wells where pore pressure logs do not exist, information from Drill stem tests and kicks have been used. The data has been reported to the NPD, and further processed and quality controlled by IHS Markit.

Pressure plots
Document name	Document format	Document size [MB]
20_Formation_pressure_(Formasjonstrykk)	pdf	0.20

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