6507/7-4

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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.	6507/7-4
  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.	NORWEGIAN SEA
  Field Name of the field the wellbore is related to.	HEIDRUN
  Discovery Name of the discovery the wellbore is related to.	6507/7-2 Heidrun
  Well name Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.	6507/7-4
  Seismic location Position of spud location on seismic survey lines. SP: shotpoint.	BP 83 - 308 SP. 689
  Production licence Official designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion).	095
  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.	Conoco 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.	490-L
  Drilling facility Norwegian Offshore Directorate's name of the facility which the wellbore was drilled from.	NORTRYM
  Drilling days Number of days from wellbore entry to wellbore completion.	69
  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,	06.11.1985
  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.	13.01.1986
  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.	13.01.1988
  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.	18.12.2008
  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
  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.	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.	ILE FM
  Kelly bushing elevation [m] Elevation of the rotary kelly bushing (RKB) above mean sea level.	25.0
  Water depth [m] Depth in metres betweem mean sea level and sea floor.	345.0
  Total depth (MD) [m RKB] Total measured length of wellbore from kelly bushing to total depth (driller's depth).	2850.0
  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).	2850.0
  Maximum inclination [°] Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.	2.8
  Bottom hole temperature [°C] Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.	98
  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.	TILJE FM
  Geodetic datum Reference system for coordinates. Example of legal values: ED50.	ED50
  NS degrees Geographic coordinate of the wellhead, north-south degrees.	65° 19' 11.56'' N
  EW degrees Geographic coordinate of the wellhead, east-west degrees.	7° 15' 44.99'' E
  NS UTM [m] Universal Transverse Mercator coordinate of the wellhead, north-south.	7245402.39
  EW UTM [m] Universal Transverse Mercator coordinate of the wellhead, east-west.	419050.20
  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.	853

• Wellbore history

  Wellbore history

  General

  Appraisal well 6507/7-4 was drilled in the northern part of the Haltenbanken area, some 190 km west of the Norwegian coast. It was drilled to evaluate the "B" prospect in the intensely faulted zone that lies at the intersection of the Nordland Ridge in the northeast and the Halten Terrace in the south. The prospect was in a southward plunging horst block formed by a Late Jurassic tensional fault system. Well 6507/7-4 was drilled in a down dip position relative to discovery well 6507/7-2 and the prime objective was to establish the oil/water contact in sandstones of the Middle Jurassic Tomma Formation.

  Operations and results

  Well 6507/7-4 was spudded with the semi-submersible installation Nortrym on 6 November 1985 and drilled to TD at 2850 m in the Early Jurassic Tilje Formation. Due to adverse weather conditions in the first week of operations spudding of the well was made difficult, and 4.5 days were lost as WOW in this phase. Swelling clays (gumbo) caused some problems in the 17 1/2" section. The upper part of the core barrel in core no 3 ruptured, unfortunately exactly in the section around OWC. Otherwise operations proceeded without significant problems. The well was drilled with sea water and gel sweeps down to 1021 m and with gypsum/polymer mud from 1021 m to TD.

  The Tomma Formation sandstones (Garn Formation) was prognosed at 2455 m, and encountered at 2449 m. The Garn Formation was found oil bearing. Oil shows were observed on core no 1 from 2444.5 m (driller's depth) down to 2490.7 m. It was described as a uniform strong yellow show with even white cut down to 2463 m when the show became more patchy with streaming cut. When retrieving core no 3 the upper part from 2491 to 2503.6 m of the core barrel ruptured so that the amount and sequence of recovery in this section was made uncertain. But shows were seen in this section and was confirmed by electric logs, DST and very good RFT pressure data, which gave an O/W contact at 2498 m. No oil show was seen below 2503.6 m driller's depth (2509.1 m logger's depth).

  Twelve cores were cut from 2435 m down to 2766.40 m with 98.2% recovery. A water sample was taken on wire line at 2525 m.

  The well was permanently abandoned on 13 January 1986 as an oil and gas appraisal well.

  Testing

  Three drill stem tests were undertaken, all of them testing the oil-bearing sands of the Tomma Formation (Garn Formation). The intervals perforated were 2494-2499 m (DST 1), 2470-2477 m (DST 2) and 2449-2465 m (DST 3). At stabilized conditions with a 152/64 inch choke the maximum production was 6504 BOPD (1032 Sm3 oil/day) with an oil gravity of 29 deg API. Associated gas production was 3217 MCFGPD (91100 Sm3 gas/day) with a gravity of 0.696 at 60 deg F. The average DST temperatures at mid perforation were: 88.6 deg C (DST 1), 87.7 deg C (DST 2), and 87.2 deg C (DST 3).

• 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]
  470.00	2846.00

• 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	2435.0	2461.0	[m ]
  2	2463.0	2490.7	[m ]
  3	2491.0	2518.5	[m ]
  4	2518.5	2546.0	[m ]
  5	2546.0	2573.5	[m ]
  6	2573.0	2601.1	[m ]
  7	2601.5	2629.4	[m ]
  8	2629.0	2656.8	[m ]
  9	2657.0	2684.8	[m ]
  10	2684.0	2712.1	[m ]
  11	2712.0	2739.6	[m ]
  12	2739.5	2766.7	[m ]

  Cores at the Norwegian Offshore Directorate

  Total core sample length [m]	330.6

  Cores at the Norwegian Offshore Directorate

  Cores available for sampling?	YES

• Core photos

  Core photos

  2435-2461m	2435-2461m	2435-2461m	2435-2461m	2435-2461m
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• Palynological slides at the Norwegian Offshore Directorate

  Palynological slides at the Norwegian Offshore Directorate

  Sample depth	Depth unit	Sample type	Laboratory
  2003.0	[m]	DC	OD
  2021.0	[m]	DC	OD
  2039.0	[m]	DC	OD
  2063.0	[m]	DC	OD
  2081.0	[m]	DC	OD
  2099.0	[m]	DC	OD
  2123.0	[m]	DC	OD
  2141.0	[m]	DC	OD
  2159.0	[m]	DC	OD
  2180.0	[m]	DC	OD
  2198.0	[m]	DC	OD
  2219.0	[m]	DC	OD
  2240.0	[m]	DC	OD
  2261.0	[m]	DC	OD
  2279.0	[m]	DC	OD
  2300.0	[m]	DC	OD
  2321.0	[m]	DC	OD
  2339.0	[m]	DC	OD
  2360.0	[m]	DC	OD
  2381.0	[m]	DC	OD
  2399.0	[m]	DC	OD
  2420.0	[m]	DC	OD
  2435.0	[m]	C	OD
  2435.5	[m]	C	OD
  2435.9	[m]	C	OD
  2436.5	[m]	C	OD
  2437.0	[m]	C	OD
  2437.1	[m]	C	OD
  2437.8	[m]	C	OD
  2438.0	[m]	C	OD
  2438.0	[m]	DC	OD
  2438.3	[m]	C	OD
  2438.3	[m]	C	OD
  2439.5	[m]	C	OD
  2440.3	[m]	C	OD
  2441.0	[m]	C	OD
  2441.5	[m]	C	OD
  2444.2	[m]	C	OD
  2552.0	[m]	DC	OD
  2603.0	[m]	DC	OD
  2684.0	[m]	DC	OD
  2750.0	[m]	DC	OD
  2801.0	[m]	DC	OD
  2840.0	[m]	DC	OD

• 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	DST1	2494.00	2499.00		18.12.1985 - 00:00	YES
  DST	DST2	2470.00	2477.00		24.12.1985 - 00:00	YES
  DST	DST3	2418.00	2424.00		31.12.1985 - 00:00	YES

• Lithostratigraphy

  Lithostratigraphy

  Top depth [mMD RKB]	Lithostrat. unit
  370	NORDLAND GP
  370	NAUST FM
  1483	KAI FM
  1906	HORDALAND GP
  1906	BRYGGE FM
  2009	ROGALAND GP
  2009	TARE FM
  2036	TANG FM
  2105	SHETLAND GP
  2399	VIKING GP
  2399	MELKE FM
  2449	FANGST GP
  2449	GARN FM
  2500	NOT FM
  2516	ILE FM
  2540	BÅT GP
  2540	ROR FM
  2604	TILJE FM

• Geochemical information

  Geochemical information

  Document name	Document format	Document size [MB]
  853_1	pdf	0.42
  853_2	pdf	0.36
  853_3	pdf	0.73

• 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]
  853_01_WDSS_General_Information	pdf	0.26
  853_02_WDSS_completion_log	pdf	0.29

• 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]
  853_01_6507_7_4_COMPLETION_REPORT	pdf	15.21
  853_02_6507_7_4_COMPLETION_LOG	pdf	3.07

• Drill stem tests (DST)

  Drill stem tests (DST)

  Test number	From depth MD [m]	To depth MD [m]	Choke size [mm]
  1.0	2494	2499	19.1
  2.0	2470	2477	35.8
  3.0	2449	2465	60.3

  Drill stem tests (DST)

  Test number	Final shut-in pressure [MPa]	Final flow pressure [MPa]	Bottom hole pressure [MPa]	Downhole temperature [°C]
  1.0	19.000	5.000	26.000
  2.0	6.000	5.000	26.000
  3.0		4.000	25.000

  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	646	51000	0.897	0.685	80
  2.0	875	732000	0.879		84
  3.0	1034	91000	0.897		88

• Logs

  Logs

  Log type	Log top depth [m]	Log bottom depth [m]
  CBL VDL GR CCL	1500	2804
  CBL VDL GR CCL	1690	2810
  DIL BHC GR SP	2368	2576
  DIL SLS GR SP	2368	2843
  DLL MSFL GR SP	2368	2842
  GR CCL	2300	2605
  HRT CCL	365	2345
  ISF BHC MSFL GR	1020	2377
  ISF SLS MSFL GR	368	1020
  LDL CNL GR	1020	2379
  LDL CNL NGL NGT-RATIOS	2368	2847
  MSD DD	2371	2844
  MWD - GYRO MULTISHOT	365	2850
  RFT HP SG	2451	2788
  SHDT HG FC	2368	2844
  VBL VDL GR CCL	2300	2600
  VSP	415	2819

• 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	469.5	36	951.0	0.00	LOT
  SURF.COND.	20	1021.0	26	1030.0	1.51	LOT
  INTERM.	13 3/8	2371.0	17 1/2	2388.0	1.79	LOT
  INTERM.	9 5/8	2832.0	12 1/4	2850.0	0.00	LOT

• Drilling mud

  Drilling mud

  Depth MD [m]	Mud weight [g/cm3]	Visc. [mPa.s]	Yield point [Pa]	Mud type	Date measured
  402	1.07			WATER BASED	11.11.1985
  410	1.07			WATER BASED	11.11.1985
  470	1.07			WATER BASED	11.11.1985
  470	1.20			WATER BASED	12.11.1985
  470	1.04	10.0	15.0	WATER BASED	18.11.1985
  470	1.07			WATER BASED	05.11.1985
  470	1.07			WATER BASED	07.11.1985
  951	1.13	5.0	30.0	WATER BASED	18.11.1985
  1025	1.18	6.0	23.0	WATERBASED	18.11.1985
  1025	1.04	2.0	2.0	WATER BASED	18.11.1985
  1030	1.15			WATER BASED	18.11.1985
  1349	1.16	20.0	100.0	WATER BASED	25.11.1985
  1759	1.31	24.0	110.0	WATER BASED	25.11.1985
  1928	1.32	24.0	110.0	WATER BASED	25.11.1985
  2230	1.32	22.0	125.0	WATER BASED	25.11.1985
  2377	1.34	8.0	105.3	WATER BASED	27.11.1985
  2377	1.40	8.0	106.0	WATER BASED	27.11.1985
  2377	1.43	8.0	106.0	WATER BASED	29.11.1985
  2377	1.25	18.0	66.9	WATER BASED	28.11.1985
  2388	1.20	8.0	86.0	WATER BASED	28.11.1985
  2463	1.20	13.0	86.2	WATER BASED	01.12.1985
  2654	1.20	14.0	81.4	WATER BASED	09.12.1985
  2685	1.20	15.0	91.0	WATER BASED	09.12.1985
  2740	1.20	15.0	86.1	WATER BASED	09.12.1985
  2812	1.20	16.0	91.0	WATER BASED	10.12.1985
  2850	1.20	9.0	86.2	WATER BASED	11.12.1985
  2850	1.21	12.0	478.8	WATER BASED	13.01.1986
  2850	1.20	9.0	91.0	WATER BASED	10.12.1985

• 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]
  853_Formation_pressure_(Formasjonstrykk)	pdf	0.27