General information Attribute Value Wellbore nameOfficial name of wellbore based on NPD guidelines for designation of wells and wellbores.6407/7-1 S TypeWellbore type. Legal values: EXPLORATION, DEVELOPMENT, OTHER (see 'Purpose' for more information)EXPLORATION PurposeFinal 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
StatusStatus 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 NPD.
INJECTING: It was injected to the wellbore at the time of the operators last monthly report to the NPD.
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&AFactmaps in new window
Main areaName of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.NORWEGIAN SEA FieldName of the field the wellbore is related to. DiscoveryName of the discovery the wellbore is related to. Well nameOfficial name of the parent well for the wellbore based on NPD guidelines for designation of wells and wellbores.6407/7-1 Seismic locationPosition of spud location on seismic survey lines. SP: shotpoint.HBGS 83 - 424 SP. 1568 Production licenceOfficial designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion). Drilling operatorName 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 permitThe drilling permit number together with the version of the drilling permit as stated in the drilling permit granted by the NPD.486-L Drilling facilityNPD's name of the facility which the wellbore was drilled from. Drilling daysNumber of days from wellbore entry to wellbore completion.171 Entered dateThe date when he wellbore was spudded. For sidetracks: The date when new formation was drilled by kicking off from the mother-wellbore,19.10.1985 Completed dateExploration 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.
Release dateDate 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.07.04.1988 Publication dateDate 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.09.03.2009 Purpose - plannedPre-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 ReentryStatus 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 ContentFor exploration wellbores, status of discovery.
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.
WATER, CUTTINGS, NOT AVAILABLE, OIL, GAS/CONDENSATE, OIL/GAS, CO2, GAS, WATER/GAS, NOT APPLICABLE.OIL/GAS
Discovery wellboreIndicator 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, ageAge of lithostratigraphic unit, 1st level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE. See also NPD bulletins.MIDDLE JURASSIC 1st level with HC, formationName 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 NPD bulletins.ILE FM 2nd level with HC, ageAge 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, formationName 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.TILJE 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.328.0 Total depth (MD) [m RKB]Total measured length of wellbore from kelly bushing to total depth (driller's depth).3950.0 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).3925.0 Maximum inclination [°]Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.9.8 Bottom hole temperature [°C]Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.138 Oldest penetrated ageAge (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 formationName 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.RED BEDS (INFORMAL) Geodetic datumReference system for coordinates. Example of legal values: ED50.ED50 NS degreesGeographic coordinate of the wellhead, north-south degrees.64° 16' 31.49'' N EW degreesGeographic coordinate of the wellhead, east-west degrees.7° 12' 21.12'' E NS UTM [m]Universal Transverse Mercator coordinate of the wellhead, north-south.7129107.11 EW UTM [m]Universal Transverse Mercator coordinate of the wellhead, east-west.413114.25 UTM zoneUniversal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.32 NPDID wellboreNPD's unique id for the wellbore.474
Wellbore historyGeneralWell 6407/7-1 S is located ca 30 km west of the Draugen field on the Njord A-structure in the southern part of the Halten Terrace. The apex of the A-structure is at about 2600 m MSL. The structure has a complex geology with dense faulting. The objective was to test for hydrocarbons in the structure, with the Middle and Early Jurassic as the primary and secondary targets. In addition, the well should obtain reservoir data from the Middle and Early Jurassic reservoir sandstones and establish a better stratigraphical, sedimentological, and structural knowledge of the area. The well should penetrate a deep reflector interpreted to be the "Top Middle Triassic Evaporite reflector". The prognosed total depth was 4025 m.Operations and resultsWildcat well 6407/7 1 S was spudded with the semi-submersible installation Polar Pioneer 19 October 1985 and was drilled to TD at 3950 m in Triassic rocks. Ca 30 days (17%) of the rig time was down time. Major causes for this were sub sea problems with orienting the temporary guide base, bad weather, and fishing for various objects and stuck tools. In addition the section from ca 746 to 1177 m required wiper trips and a lot of reaming to clean the hole. This added several days to the drilling time. The well was vertical down to 1177 m, it built deviation angle up to maximum 9.8 deg at 1460 m, and had a deviation between 9.8 and 3.0 deg from there to TD. The well was drilled with spud mud down to 1172 m, with KCl/polymer mud from 1172 m to 2710 m, with gel/polymer mud from 2710 m to 3601 m, and with gel/lignosulphonate mud from 3610 m to TD.The top of the reservoir came in at 2759 m, 70.5 m higher than prognosed. Oil was discovered in three separate reservoir units. The upper reservoir (2759 - 2783.5 m) consisted of sandstones belonging to the Fangst Group and Ror Formation. Relative pressure in this unit was 1.35 g/cc. The main reservoir (2839 -2988 m) consisted of sandstones belonging to the Tilje Formation. Relative pressure was 1.40 g/cc. This reservoir tested 730 and 711 Sm3 oil /day in two tests with a maximum rate of 1400 Sm3 oil /day. The oil was found to be under saturated. The lower reservoir (3017 - 3038 m) consisted of sandstones belonging to the Åre Formation. Total net pay in the reservoirs using porosity > 13%, volume of shale <40%, and < 60% water saturation was 130 m. The OWC was estimated to be at 3045 m.Oil shows of poor quality were observed on sand/sandstone (1-10 % of cuttings) in the Shetland Group from 2090 to 2165 m. Oil shows of poor to moderate quality were observed on siltstones recovered from CST run in the Viking Group at 2699 to 2711 m. Oil shows of poor to moderate quality restricted to porous sandstone only were observed in the Garn Formation from 2756 to 2780 m. Fair to good shows on porous coarse sandstone were observed in the Tilje/Åre Formations at 2837 to 3032 m. Shows of poor quality, again restricted to predominantly porous, coarse sandstone were observed in the Åre Formation at 3047 to 3082 m. The oil/water contact was defined from the logs to be between 3003 and 3082.5 m, while RFT data showed an oil/water contact between 3016 and 3045 m. The structural closure with estimated OWC at 3045 m was approximately 49 km2.The deep seismic reflector interpreted as "Top middle Triassic Evaporite reflector", was caused by two lithological sequences at 3828 m in the Red Beds, which created a composite strong seismic signal.16 cores were cut in the interval 2713 to 3118 m. Core 1 was cut in the Melke Formation, core 2 in the Garn Formation, while the remaining cores were cut in the Båt Group. An RFT segregated sample was taken at 2959.5 m (2945.2 m TVD RKB). It contained oil and gas with GOR = 241.7 Sm3/m3, BOB = 1.8358, stock tank oil density = 835.4 kg/m3, and gas gravity = 0.841 (air = 1).The well was permanently abandoned on 7 April 1986 as an oil and gas discovery.TestingFive drill stem tests were performed.DST 1 tested the interval 3099.5 - 3113.5 m in the Åre Formation. It produced 4.4 m3 water /day through a 25.4 mm choke. Maximum bottom-hole temperature was 114.8 deg C.DST 2 tested the interval 3022.9 - 3034.4 m in the uppermost Åre Formation. It produced 85 Sm3 oil /day through a 25.4 mm choke. GOR was 229 Sm3/Sm3, oil density was 0.832 g/cm3, and gas gravity was 0.800 (air = 1). Maximum bottom-hole temperature was 111.5 deg C.DST 3 tested the interval 2946.5 - 2973.0 m in the Tilje Formation. It produced 711 Sm3 oil /day through a 12.7 mm choke. GOR was 202 Sm3/Sm3, oil density was 0.825 g/cm3, and gas gravity was 0.700 (air = 1) . Maximum bottom-hole temperature was 114.7 deg C.DST 4 tested the interval 2840 - 2886 m in the uppermost Tilje Formation. It produced 730 Sm3 oil /day through a 12.7 mm choke. GOR was 202 Sm3/Sm3, oil density was 0.825 g/cm3, and gas gravity was 0.693 (air = 1). Maximum bottom-hole temperature was 113 deg C.DST 5 tested the interval 2758 - 2781 m in the Garn and upper Ror Formations. It produced 818 Sm3 oil /day through a 25.4 mm choke. GOR was 220 Sm3/Sm3 oil density was 0.823 g/cm3, and gas gravity was 0.732 (air = 1). Maximum bottom-hole temperature was 109.3 deg C.
Cuttings at the NPD
Cuttings at the NPDCuttings available for sampling?YES Cuttings at the NPDCutting sample, top depth [m]Cutting samples, bottom depth [m]420.003950.00
Cores at the NPD
Cores at the NPDCore sample numberCore sample - top depthCore sample - bottom depthCore sample depth - uom12713.02726.1[m ]22760.02770.7[m ]32772.02781.3[m ]42783.02801.9[m ]52804.02832.7[m ]62844.02854.8[m ]72871.02892.5[m ]82895.02922.8[m ]92923.02951.0[m ]102951.02970.0[m ]112970.02988.7[m ]122988.73013.3[m ]133013.53040.9[m ]143052.03060.2[m ]153063.03083.7[m ]163090.53118.0[m ] Cores at the NPDTotal core sample length [m]314.6 Cores at the NPDCores available for sampling?YES
Palynological slides at the NPD
Oil samples at the NPD
Oil samples at the NPDTest typeBottle numberTop depth
MD [m]Bottom depth
MD [m]Fluid typeTest timeSamples availableDSTDST23022.903034.40OIL08.03.1986 - 00:00YESDSTDST32946.502973.00OIL16.03.1986 - 00:00YESDSTDST42840.002886.0023.03.1986 - 00:00YESDSTDST52758.002781.0030.03.1986 - 00:00YES
LithostratigraphyTop depth [m]Lithostrat. unit35335310811739173919712682269626962706272127592759277327732839301731833277
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 nameDocument formatDocument size [MB]15.864.83
Drill stem tests (DST)
Drill stem tests (DST)Test numberFrom depth MD
[m]To depth MD
Drill stem tests (DST)Test numberFinal shut-in pressure
[MPa]Final flow pressure
[MPa]Bottom hole pressure
Drill stem tests (DST)Test numberOil
[g/cm3]Gas grav. rel.airGOR
LogsLog typeLog top depth [m]Log bottom depth [m]CBL VDL5001892CBL VDL16002703CBL VDL24003733CET24003733CST11901898CST19002336CST23562711CST27043750CST37623901CST37623941DIS LSS GR SP3533951DLL MSFL GR SP18513748LDL CNL CAL GR4203936RFT20022708RFT27602989RFT29083234S MDT GR18883940VSP6873750
Casing and leak–off tests
Casing and leak–off testsCasing typeCasing diam.
[m]LOT/FIT mud eqv.
[g/cm3]Formation test typeCONDUCTOR30441.036443.00.00LOTSURF.COND.201130.0261172.00.00LOTINTERM.13 3/81890.017 1/21917.00.00LOTINTERM.9 5/82700.012 1/42710.00.00LOTINTERM.73729.08 3/83756.00.00LOTOPEN HOLE3950.063950.00.00LOT
Drilling mudDepth MD [m]Mud weight [g/cm3]Visc. [mPa.s]Yield point [Pa]Mud typeDate measured3751.04WATER BASED20.10.19853801.0799.099.0XXX07.04.19863801.0799.099.0XXXX07.04.19864431.04WATER BASED27.10.19854431.04WATER BASED20.10.19854431.04WATER BASED21.10.19854431.04WATER BASED22.10.19854431.04WATER BASED24.10.19855941.10WATER BASED29.10.19859451.06WATER BASED29.10.198511721.07WATER BASED31.10.198511721.07WATER BASED03.11.198511721.10WATER BASED05.11.198511721.16WATER BASED10.11.198511721.16WATER BASED12.11.198511721.2020.013.0WATER BASED13.11.198511721.07WATER BASED04.11.198511721.2020.013.0WATER BASED17.11.198511791.2118.010.0WATER BASED17.11.198512001.2111.010.0WATER BASED17.11.198513681.2122.014.0WATER BASED18.11.198514031.3022.011.0WATER BASED19.11.198514111.3022.012.0WATER BASED20.11.198516521.6032.015.0WATER BASED25.11.198516521.6525.014.0WATER BASED25.11.198516521.6530.015.0WATER BASED25.11.198516871.6530.015.0WATER BASED25.11.198519171.6837.012.0WATER BASED26.11.198519171.6835.014.0WATER BASED27.11.198519171.6831.012.0WATER BASED28.11.198519171.6831.012.0WATER BASED01.12.198519171.7135.011.0WATER BASED01.12.198519651.7136.08.0WATER BASED04.12.198521271.7140.013.0WATER BASED04.12.198521491.7130.09.0WATER BASED03.12.198522721.7131.010.0WATER BASED05.12.198522841.7130.09.0WATER BASED08.12.198522951.6326.07.0WATER BASED08.12.198523881.6334.010.0WATER BASED08.12.198525061.6528.08.0WATER BASED10.12.198525281.6529.08.0WATER BASED11.12.198526051.6526.09.0WATER BASED12.12.198526831.6526.010.0WATER BASED15.12.198527101.6525.011.0WATER BASED15.12.198527101.6525.010.0WATER BASED18.12.198527101.6528.07.0WATER BASED19.12.198527101.6528.07.0WATER BASED22.12.198527101.6525.010.0WATER BASED15.12.198527131.4419.07.0WATER BASED22.12.198527271.3817.07.0WATER BASED22.12.198527281.4728.016.0WATER BASED03.04.198627281.4612.010.0WATER BASED07.04.198627601.3818.08.0WATER BASED23.12.198527721.3818.07.0WATER BASED26.12.198527831.3816.07.0WATER BASED26.12.198528111.3818.08.0WATER BASED26.12.198528321.3817.09.0WATER BASED29.12.198528331.495.01.0BRINE02.04.198628331.545.01.0BRINE25.03.198628361.3816.08.0WATER BASED29.12.198528441.5519.08.0WATER BASED29.12.198528711.5520.09.0WATER BASED30.12.198528951.5521.07.0WATER BASED01.01.198629231.5518.06.0WATER BASED01.01.198629351.545.01.0BRINE21.03.198629351.545.01.0BRINE24.03.198629351.545.01.0BRINE24.03.198629351.545.01.0BRINE26.03.198629351.545.01.0BRINE25.03.198629511.5523.010.0WATER BASED02.01.198629881.5521.09.0WATER BASED05.01.198629881.5522.08.0WATER BASED05.01.198630131.5520.09.0WATER BASED05.01.198630131.5520.09.0WATER BASED05.01.198630131.5522.08.0WATER BASED07.01.198630131.5518.07.0WATER BASED08.01.198630161.555.01.0BRINE17.03.198630161.565.01.0BRINE19.03.198630161.545.01.0BRINE17.03.198630411.5519.07.0WATER BASED09.01.198630521.5518.08.0WATER BASED13.01.198630631.5519.08.0WATER BASED13.01.198630901.5519.08.0WATER BASED13.01.198630941.495.01.0BRINE03.03.198630941.585.01.0BRINE05.03.198630941.575.01.0BRINE06.03.198630941.575.01.0BRINE07.03.198630941.575.01.0BRINE11.03.198630941.585.01.0BRINE08.03.198630941.565.01.0BRINE12.03.198630941.565.01.0BRINE13.03.198630941.555.01.0BRINE14.03.198630941.585.01.0BRINE04.03.198631181.5124.08.0WATER BASED13.01.198631351.4921.08.0WATER BASED15.01.198631571.49WATER BASED24.02.198631571.495.01.0BRINE25.02.198631571.495.01.0BRINE26.02.198631571.495.01.0BRINE27.02.198631571.495.01.0BRINE28.02.198631571.495.01.0BRINE03.03.198631571.4916.06.0WATER BASED24.02.198632181.4924.011.0WATER BASED15.01.198632341.4921.010.0WATER BASED19.01.198632341.4922.011.0WATER BASED19.01.198633181.4923.011.0WATER BASED19.01.198633671.4922.09.0WATER BASED19.01.198633671.4921.08.0WATER BASED19.01.198633891.4919.08.0WATER BASED22.01.198634001.4922.09.0WATER BASED29.01.198634041.4922.010.0WATER BASED03.02.198634091.4923.09.0WATER BASED03.02.198635501.4923.012.0WATER BASED03.02.198636011.4923.012.0WATER BASED03.02.198636481.4915.06.0WATER BASED19.02.198636541.4920.013.0WATER BASED03.02.198637111.4915.07.0WATER BASED28.01.198637111.4915.07.0WATER BASED03.02.198637501.4916.06.0WATER BASED28.01.198637501.4916.06.0WATER BASED30.01.198637501.4916.06.0WATER BASED04.02.198637551.4916.06.0WATER BASED05.02.198637551.5016.05.0WATER BASED07.02.198637551.5016.06.0WATER BASED11.02.198637551.5015.06.0WATER BASED11.02.198637551.4916.06.0WATER BASED06.02.198637551.4916.05.0WATER BASED11.02.198637561.4915.08.0WATER BASED12.02.198637561.4913.07.0WATER BASED13.02.198637581.4913.06.0WATER BASED21.02.198637711.4918.08.0WATER BASED13.02.198637871.4915.08.0WATER BASED17.02.198638891.4915.07.0WATER BASED17.02.198639501.4916.06.0WATER BASED17.02.198639501.4916.06.0WATER BASED18.02.1986
Pressure plotsThe 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 plotsDocument nameDocument formatDocument size [MB]0.29