25/7-5
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Generell informasjon
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Brønnhistorie
GeneralWell 25/7-5 was the first exploration well drilled in PL203 and was designed to test the hydrocarbon potential of a sand prospect within the Sele Formation in the northwest corner of block 25/7. This prospect was a stratigraphic trap with structural elements formed by the pinch out of the Hermod T80 sand. Oil was prognosed to be encountered within the Hermod T80 sand. A very small closure in the top of the underlying Heimdal sand was also expected to contain hydrocarbons, but this closure was not defined as a secondary target due to the small volumes expected within the structure. The well commitment was to drill to a total depth of 2735 m within the Shetland Group. The objectives of the well were to test commercial oil volumes within the Hermod T80 sand, to test the geological and geophysical models for the presence of the Hermod T80 sand, and to test the model for hydrocarbon migration within the license area.Operations and resultsThe semi-submersible drilling rig "West Vanguard" was used to drill wildcat well 25/7-5. The well was spudded 16 July 1997 and reached a total depth of 2736m on the 7 August 1997 in the Early Paleocene Våle Formation The well was drilled water based with spud mud to 1338 m and with the ANCO 2000 mud system from 1338 m to TD. Total rig time for the well, including testing, was 46.7 days.
Oil was encountered within the Hermod T80 sands between 2044 - 2052 m. There was 3.5 m of net reservoir within the interval (N/G 0,4372) with an average porosity of 0.25 and an excellent permeability of up to 6 Darcy. The rest of the non-reservoir sand was tightly cemented with calcite. No Oil-Water contact was seen in these sands.
The Heimdal formation was penetrated at 2126 m and contained approximately 1m of oil in the top of the reservoir (0.85 gm/cc density). The reservoir quality of these sands is excellent with an average porosity of 0.234 and permeabilities in the low Darcy range. Approximately 6m of residual hydrocarbons were found under the Oil-Water contact at 2127m. The well was cored (11 cores) from 1976m in the top of the Balder Formation tuffaceous clay stone unit and down through the Sele, Hermod and Lista formations and into the Heimdal sands. Coring was stopped at 2150m, 24m into the Heimdal Formation. Core recovery was generally excellent. MDT oil samples were taken at 2045.4 m and 2116.4 m. MDT samples containing both water and oil were taken at 2126.3 m and 2126.6 m, while MDT samples containing only water was taken at 2127.1 m
The well was permanently plugged and abandoned as an oil discovery on 30 August 1997.TestingOne Drill Stem test was performed over the Hermod T80 sands (perforation 2043 - 2052 m) with a stable flow rate of 900 Sm3 oil/day through a 48/64"choke. The GOR was 88 Sm3 /Sm3 and the oil gravity was 0.870 gm/cc. Traces of produced sand and water were found in the oil. -
Borekaks i Sokkeldirektoratet
Borekaks i Sokkeldirektoratet Borekaks tilgjengelig for prøvetaking?YESBorekaks i Sokkeldirektoratet Borekaksprøve, topp dybde [m]Borekaksprøve, bunn dybde [m]1350.002737.00 -
Borekjerner i Sokkeldirektoratet
Borekjerner i Sokkeldirektoratet Kjerneprøve nummerKjerneprøve - topp dybdeKjerneprøve - bunn dybdeKjerneprøve dybde - enhet21977.01983.0[m ]31983.02002.8[m ]42003.02031.5[m ]52031.52048.0[m ]62048.02057.5[m ]72058.02059.7[m ]82060.02076.1[m ]92078.02084.7[m ]102093.02122.0[m ]112122.02149.8[m ]Borekjerner i Sokkeldirektoratet Total kjerneprøve lengde [m]161.4Borekjerner i Sokkeldirektoratet Kjerner tilgjengelig for prøvetaking?YES -
Kjernebilder
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Palynologiske preparater i Sokkeldirektoratet
Palynologiske preparater i Sokkeldirektoratet Prøve dybdeDybde enhetPrøve typeLaboratorie1350.0[m]DCRRI1370.0[m]DCRRI1390.0[m]DCRRI1410.0[m]DCRRI1430.0[m]DCRRI1460.0[m]DCRRI1470.0[m]DCRRI1490.0[m]DCRRI1510.0[m]DCRRI1530.0[m]DCRRI1550.0[m]DCRRI1570.0[m]DCRRI1590.0[m]DCRRI1610.0[m]DCRRI1630.0[m]DCRRI1650.0[m]DCRRI1670.0[m]DCRRI1690.0[m]DCRRI1710.0[m]DCRRI1730.0[m]DCRRI1750.0[m]DCRRI1770.0[m]DCRRI1790.0[m]DCRRI1810.0[m]DCRRI1830.0[m]SWCRRI1850.0[m]SWCRRI1860.0[m]SWCRRI1870.0[m]DCRRI1870.0[m]SWCRRI1875.0[m]SWCRRI1880.0[m]DCRRI1890.0[m]DCRRI1890.0[m]SWCRRI1900.0[m]DCRRI1901.0[m]SWCRRI1907.0[m]DCRRI1914.0[m]SWCRRI1927.0[m]DCRRI1937.0[m]DCRRI1947.0[m]DCRRI1951.0[m]SWCRRI1957.0[m]DCRRI1977.0[m]CRRI1982.0[m]CRRI1988.0[m]CRRI1994.0[m]CRRI1999.0[m]CRRI2005.0[m]CRRI2012.0[m]CRRI2018.0[m]CRRI2019.0[m]CRRI2020.0[m]CRRI2023.0[m]CRRI2028.0[m]CRRI2033.0[m]CRRI2038.0[m]CRRI2044.0[m]CRRI2046.0[m]CRRI2050.0[m]CRRI2052.0[m]CRRI2054.0[m]CRRI2056.0[m]CRRI2057.0[m]CRRI2059.0[m]CRRI2061.0[m]CRRI2063.0[m]CRRI2067.0[m]CRRI2068.0[m]CRRI2072.0[m]CRRI2075.0[m]DCRRI2078.0[m]CRRI2084.0[m]CRRI2093.0[m]CRRI2096.0[m]CRRI2102.0[m]CRRI2108.0[m]CRRI2114.0[m]CRRI2120.0[m]CRRI2125.0[m]CRRI2127.0[m]CRRI2137.0[m]CRRI2141.0[m]CRRI2147.0[m]CRRI2160.0[m]DCRRI2170.0[m]DCRRI2180.0[m]DCRRI2190.0[m]DCRRI2196.0[m]SWCRRI2210.0[m]DCRRI2222.0[m]DCRRI2226.0[m]SWCRRI2240.0[m]DCRRI2250.0[m]DCRRI2260.0[m]DCRRI2270.0[m]DCRRI2275.0[m]SWCRRI2280.0[m]SWCRRI2290.0[m]DCRRI2300.0[m]DCRRI2310.0[m]DCRRI2320.0[m]DCRRI2330.0[m]DCRRI2340.0[m]DCRRI2350.0[m]DCRRI2360.0[m]DCRRI2370.0[m]DCRRI2380.0[m]DCRRI2390.0[m]DCRRI2400.0[m]DCRRI2410.0[m]DCRRI2420.0[m]DCRRI2430.0[m]DCRRI2440.0[m]DCRRI2460.0[m]DCRRI2470.0[m]DCRRI2480.0[m]DCRRI2490.0[m]DCRRI2500.0[m]DCRRI2510.0[m]DCRRI2520.0[m]DCRRI2535.0[m]DCRRI2545.0[m]DCRRI2555.0[m]DCRRI2565.0[m]DCRRI2609.0[m]SWCRRI2648.0[m]SWCRRI2661.0[m]SWCRRI -
Oljeprøver i Sokkeldirektoratet
Oljeprøver i Sokkeldirektoratet Test typeFlaske nummerTopp dyp
MD [m]Bunn dyp
MD [m]Væske typeTest tidspunktPrøver tilgjengeligDSTDST12043.002052.0018.08.1997 - 06:32YES -
Litostratigrafi
Litostratigrafi Topp Dyb [mMD RKB]Litostrat. enhet146410702118413241915191520172044206120712126249025262688 -
Spleisede logger
Spleisede logger Dokument navnDokument formatDokumentstørrelse [MB]pdf0.34 -
Geokjemisk informasjon
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Dokumenter – rapportert av utvinningstillatelsen (frigitt ihht til regelverk)
Dokumenter – rapportert av utvinningstillatelsen (frigitt ihht til regelverk) Dokument navnDokument formatDokumentstørrelse [MB]pdf8.98pdf15.94 -
Borestrengtester (DST)
Borestrengtester (DST) Test nummerFra dybde MD
[m]Til dybde MD
[m]Reduksjonsventil størrelse
[mm]1.02043205217.5Borestrengtester (DST) Test nummerEndelig avstengningstrykk
[MPa]Endelig strømningstrykk
[MPa]Bunnhullstrykk
[MPa]Borehullstemperatur
[°C]1.07.0005.26018.98167Borestrengtester (DST) Test nummerOlje produksjon
[Sm3/dag]Gass produksjon
[Sm3/dag]Oljetetthet
[g/cm3]Gasstyngde rel. luftGOR
[m3/m3]1.0900780000.8700.67188 -
Logger
Logger Type loggTopp dyp for logg [m]Bunn dyp for logg [m]CBL VDL AMS GR12051876CST AMS GR18702704FMI DSI AMS GR18102730MDT ACTS GR20442625MWD DPR GR-DIR1462736PEX NGT18102732VSP14002730 -
Foringsrør og formasjonsstyrketester
Foringsrør og formasjonsstyrketester Type utforingUtforing diam.
[tommer]Utforing dybde
[m]Brønnbane diam.
[tommer]Brønnbane dyp
[m]LOT/FIT slam eqv.
[g/cm3]Type formasjonstestCONDUCTOR30207.536209.00.00LOTINTERM.13 3/81332.017 1/21338.00.00LOTINTERM.9 5/81860.012 1/41866.00.00LOTLINER72736.08 1/22736.00.00LOT -
Boreslam
Boreslam Dybde MD [m]Egenvekt, slam [g/cm3]Viskositet, slam [mPa.s]Flytegrense [Pa]Type slamDato, måling2091.06WATER BASED3501.2717.0WATER BASED6711.06WATER BASED7021.06WATER BASED8501.2717.0WATER BASED12211.06WATER BASED13381.4529.0WATER BASED13411.4523.0WATER BASED18001.2115.0WATER BASED18861.4526.0WATER BASED19861.2017.0WATER BASED20581.2019.0WATER BASED20601.2318.0WATER BASED20931.2519.0WATER BASED21441.2117.0WATER BASED21481.2519.0WATER BASED21481.2118.0WATER BASED24911.2317.0WATER BASED -
Trykkplott
Trykkplott Porertrykksdataene kommer fra logging i brønnen hvis ingen annen kilde er oppgitt. I noen brønner der trykk ikke er logget, er det brukt informasjon fra formasjonstester eller brønnspark. Trykkdataene er rapportert inn til Oljedirektoratet og videre prosessert og kvalitetssikret av IHS Markit.Trykkplott Dokument navnDokument formatDokumentstørrelse [MB]pdf0.22