7220/10-1
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Generell informasjon
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Brønnhistorie
GeneralWell 7220/10-1 was drilled on the Salina Prospect in the south-west end of the Loppa High in the Barents Sea area. The primary exploration target for the well was to prove petroleum in Early Cretaceous to Late Jurassic reservoir rocks (Knurr and Hekkingen formations). The secondary target was to prove petroleum in Middle to Early Jurassic reservoir rocks (Stø, Nordmela, Tubåen and Fruholmen formations).Operations and resultsWildcat well 7220/10-1 was spudded with the semi-submersible installation Scarabeo 8 on 13 August 2012 and drilled to TD at 2405 m in Late Triassic Snadd Formation. A 9 7/8" pilot hole was drilled from the seabed to 830 m to check for shallow gas. There was no indication of shallow gas. The well was drilled with seawater and hi-vis pills down to 688 m and with EMS-3100 water based mud (seawater) from 688 m to TD.The well proved the presence of a 134 m reservoir consisting of sandstones and siltstones of Aptian age within the Kolmule Formation. Top of this sandstone was at 1291 m and the upper 36 m was gas bearing and had 20% average porosity and a net/gross of 96%. Extrapolation of MDT pressure gradients placed the gas-water contact at 1327 m. The reservoir quality decreases towards the base of the reservoir. Top Stø Formation was penetrated at 1513.5 m. It consisted of 132 m sandstone with very good reservoir quality. The upper 53 m was gas bearing and had average porosity of 20% and a net/gross of 90%. A clean gas-water contact was found at 1567 m. The gas in both reservoirs had isotopic profiles typical of thermogenic gases. The gas in the Stø Formation had more C2+ components than the gas in the Kolmule Formation.Sandstone reservoirs were also found in Nordmela, Tubåen, Fruholmen and Snadd Formations with average porosity ranging from 17 to 21%. All reservoir levels below the Stø Formation were water bearing. No oil shows were described in the well.Two cores were cut from 1299.5 m to 1355 m in the Kolmule reservoir and two were cut from 1518 m to 1587.5 m in the Stø reservoir. MDT gas samples were taken at 1309.99 m in the Kolmule Formation and at 1520.51 and 1560.49 m in the Stø Formation.The well was permanently abandoned on 16 October 2012 as a gas discovery.TestingNo drill stem test was performed. -
Borekaks i Sokkeldirektoratet
Borekaks i Sokkeldirektoratet Borekaks tilgjengelig for prøvetaking?YESBorekaks i Sokkeldirektoratet Borekaksprøve, topp dybde [m]Borekaksprøve, bunn dybde [m]690.002405.00 -
Borekjerner i Sokkeldirektoratet
Borekjerner i Sokkeldirektoratet Kjerneprøve nummerKjerneprøve - topp dybdeKjerneprøve - bunn dybdeKjerneprøve dybde - enhet11298.51323.9[m ]21326.01353.7[m ]31518.01547.5[m ]41547.51576.2[m ]Borekjerner i Sokkeldirektoratet Total kjerneprøve lengde [m]111.3Borekjerner i Sokkeldirektoratet Kjerner tilgjengelig for prøvetaking?YES -
Litostratigrafi
Litostratigrafi Topp Dyb [mMD RKB]Litostrat. enhet38247447412721272145614841499151315131645183219312303 -
Logger
Logger Type loggTopp dyp for logg [m]Bunn dyp for logg [m]FMI MSIP GR11771451FMI MSIP GR14502405GR NBGR RES ECD SON DIR D N12452405HRLA TLD APS ECS HNGS GR11511451HRLA TLD APS HNGS CMR GR14502405MDT15162363MWD - GR RES ECD DIR362668MWD - GR RES ECD SON DIR6681450PS HY PO IFA MS PC GR13101333USIT DCBL GR00VSP7362340XPT CMR GR12501450 -
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 formasjonstestCONDUCTOR36442.042450.00.00SURF.COND.20682.024688.01.45LOTPILOT HOLE830.09 7/8830.00.00INTERM.13 3/81177.0161186.01.34LOTLINER9 5/81450.012 1/41450.01.40LOTOPEN HOLE2405.08 1/22405.00.00 -
Boreslam
Boreslam Dybde MD [m]Egenvekt, slam [g/cm3]Viskositet, slam [mPa.s]Flytegrense [Pa]Type slamDato, måling3820.001.0waterbased11860.001.1waterbased13440.001.2waterbased15480.001.2waterbased21050.001.2MI-SWACO EMS-310024050.001.2MI-SWACO EMS-3100 -
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]PDF0.21