General information Attribute Value Wellbore nameOfficial name of wellbore based on NPD guidelines for designation of wells and wellbores.33/9-9 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).APPRAISAL
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.NORTH 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.33/9-9 Seismic locationPosition of spud location on seismic survey lines. SP: shotpoint. 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.Mobil Exploration Norway INC Drill permitThe drilling permit number together with the version of the drilling permit as stated in the drilling permit granted by the NPD.179-L Drilling facilityNPD's name of the facility which the wellbore was drilled from. Drilling daysNumber of days from wellbore entry to wellbore completion.114 Entered dateThe 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 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.17.11.1979 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.03.10.2011 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.APPRAISAL 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.NO 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.BRENT GP 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.DUNLIN GP 3rd level with HC, ageAge 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, formationName 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 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.STATFJORD GP Geodetic datumReference system for coordinates. Example of legal values: ED50.ED50 NS degreesGeographic coordinate of the wellhead, north-south degrees.61° 17' 10.19'' N EW degreesGeographic 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 zoneUniversal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.31 NPDID wellboreNPD's unique id for the wellbore.414
Wellbore historyGeneralWell 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 resultsAppraisal 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.TestingSix 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 NPD
Cuttings at the NPDCuttings available for sampling?YES Cuttings at the NPDCutting sample, top depth [m]Cutting samples, bottom depth [m]254.003101.00
Cores at the NPD
Cores at the NPDCore sample numberCore sample - top depthCore sample - bottom depthCore sample depth - uom12414.02421.9[m ]22432.32444.3[m ]32444.32444.8[m ]42446.32455.3[m ]52455.32468.3[m ]62468.32482.3[m ]72482.32500.6[m ]82500.62517.8[m ]92719.02722.3[m ]102722.32732.3[m ]112732.32740.3[m ]122740.32754.8[m ]132754.82768.6[m ]142768.82774.3[m ]152774.32786.6[m ]162786.62793.0[m ]172793.02807.5[m ]182807.52818.4[m ]192818.42826.2[m ]202826.22837.5[m ]212837.52853.5[m ]222853.52866.0[m ]232866.02876.5[m ] Cores at the NPDTotal core sample length [m]258.7 Cores at the NPDCores available for sampling?YES
Palynological slides at the NPD
Palynological slides at the NPDSample depthDepth unitSample typeLaboratory2420.3[m]CLAP2420.3[m]COD2431.1[m]COD2431.1[m]CLAP2433.8[m]CLAP2433.8[m]COD2434.4[m]COD2434.4[m]CLAP2436.1[m]CLAP2436.1[m]COD2436.5[m]COD2436.5[m]CLAP2437.2[m]CLAP2437.2[m]COD2437.8[m]COD2437.8[m]CLAP2438.6[m]CLAP2438.6[m]COD2438.7[m]COD2438.7[m]CLAP2440.9[m]CLAP2440.9[m]COD2442.8[m]COD2442.8[m]CLAP2443.0[m]CLAP2443.0[m]COD2443.0[m]COD2443.0[m]CLAP2443.5[m]CLAP2443.5[m]COD2444.5[m]COD2444.5[m]CLAP2446.3[m]CLAP2446.3[m]COD2446.9[m]CLAP2448.6[m]CLAP2448.6[m]COD2448.8[m]COD2448.8[m]CLAP2448.9[m]CLAP2448.9[m]COD2450.3[m]COD2450.3[m]CLAP2451.8[m]CLAP2451.8[m]COD2453.3[m]COD2453.3[m]CLAP2455.0[m]CLAP2455.0[m]COD2455.3[m]COD2455.3[m]CLAP2456.6[m]CLAP2456.6[m]COD2459.3[m]COD2459.3[m]CLAP2469.3[m]CLAP2469.3[m]COD2486.0[m]CLAP2489.0[m]CLAP2494.0[m]CLAP2497.0[m]CLAP2500.0[m]CLAP2502.0[m]CLAP2503.0[m]CLAP2504.0[m]CLAP2507.0[m]CLAP2512.0[m]CLAP2516.0[m]CLAP
LithostratigraphyTop depth [m]Lithostrat. unit17099716601660169318482396241325042504252825582715
Geochemical informationDocument nameDocument formatDocument size [MB]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 nameDocument formatDocument size [MB]2.470.982.331.802.950.8210.656.731.312.950.590.530.8710.4712.443.036.891.640.133.67
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]DLL23503100FDC CNL4753100GR SPECTRO23503100HDT23003100ISF SONIC2453100LS SONIC19903098RFT00VSP3552955
Casing and leak–off tests
Casing and leak–off testsCasing typeCasing diam.
[m]LOT/FIT mud eqv.
[g/cm3]Formation test typeCONDUCTOR30244.036249.00.00LOTSURF.COND.20475.026486.00.00LOTINTERM.13 3/81984.017 1/21993.00.00LOTINTERM.9 5/83068.012 1/43100.00.00LOT
Drilling mudDepth MD [m]Mud weight [g/cm3]Visc. [mPa.s]Yield point [Pa]Mud typeDate measured2491.07waterbased7601.14waterbased11371.16waterbased15681.25waterbased19931.37waterbased24211.72waterbased
Thin sections at the NPD
Thin sections at the NPDDepthUnit2748.45[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 ]
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]0.22