34/4-16 S
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Generell informasjon
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Brønnhistorie
GeneralWell 34/4-16 S was drilled to appraise the 34/4-15 S Dugong discovery in the boarder between the Marulk Basin and Tampen Spur in the North Sea. The primary objective was to prove commercial hydrocarbons in the Middle Jurassic Rannoch Formation, locate the Oil-Water Contact and perform a Drill Stem Test if sufficient oil column.Operations and resultsAppraisal well 34/4-16 S was spudded with the semi-submersible installation Deepsea Yantai on 27 February 2021 and drilled to TD at 3603 m (3583 m TVD) m in the Early-Middle Jurassic Drake Formation. The well was drilled S-shaped with vertical sections above ca 1825 m and below ca 3010 m. Operations proceeded without significant problems. The well was drilled with Glydril mud, seawater and hi-vis sweeps down to 1207 m, with Versatec oil-based mud from 1207 m to 3334 m, and with Rheguard oil-based mud from 3334 m TD.Brent Group sandstones were penetrated at 3457 m (3437 m TVD): The Brent Group includes an 11 m thick Tarbert Fm sandstone on top and Rannoch Formation sandstones below down to top Drake Formation at 3553 m (3532.6 m TVD) Both Tarbert and Rannoch were found oil-bearing. The upper Tarbert oil column gradient lie on a ca 1 bar higher pressured gradient than the Rannoch oil column. Moveable hydrocarbons was seen down to 3489 m (3469 m TVD)The only shows above OBM was in the oil-bearing Brent Group.Two cores were cut in succession over the Heather-Tarbert-Rannoch sequence from 3449 to 3503.8 m. Fluid samples were taken at 3476.2 m (oil) and 3497.4 m (water).The well was suspended on 31 March 2021 and then re-entered on 1 September same year for testing. Deepsea Yantai was used both for drilling and testing. The well was permanently abandoned on 23 September 2021 as an oil appraisal well.TestingA DST was performed in the interval 3470.2 to 3482.2 m in the Rannoch Formation. The maximum flow rate achieved was during the clean-up flow; ca. 400 Sm3/day, GOR of 185 Sm3/Sm3 on a 32/64" adjustable choke with a FWHP of 74 barg. The production declined during the following flow periods due to near-well bore geometry. The flow data are thus not representative for what will be achieved in a production well. Oil density was 0.827 g/cm3 and the oil produced with 2.2% CO2 and 2.5 ppm H2S. For long term monitoring of the reservoir pressure, two Metrol pressure gauge stations were installed above and across the perforations on a 7" EZSV plug set at 3449.2 m. -
Borekaks i Sokkeldirektoratet
Borekaks i Sokkeldirektoratet Borekaks tilgjengelig for prøvetaking?YESBorekaks i Sokkeldirektoratet Borekaksprøve, topp dybde [m]Borekaksprøve, bunn dybde [m]380.003604.00 -
Borekjerner i Sokkeldirektoratet
Borekjerner i Sokkeldirektoratet Kjerneprøve nummerKjerneprøve - topp dybdeKjerneprøve - bunn dybdeKjerneprøve dybde - enhet13449.03503.9[m ]23503.93553.3[m ]Borekjerner i Sokkeldirektoratet Total kjerneprøve lengde [m]104.3Borekjerner i Sokkeldirektoratet Kjerner tilgjengelig for prøvetaking?YES -
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 formasjonstestPILOT HOLE30370.49 7/8510.00.00INTERM.201206.0261214.00.00INTERM.9 5/83334.812 1/43340.01.75LOTLINER73602.08 1/23603.02.05LOT -
Logger
Logger Type loggTopp dyp for logg [m]Bunn dyp for logg [m]AIT QGEO PPC MSIP PEX EMA JAR3353605LWD - PWD RES GR DI445510LWD - PWD RES GR DI NE DN SON SV34493603LWD - PWD RES GR DI NEU DEN SON12183449LWD - PWD RES GR DI SON358445LWD - PWD RES GR DI SON5101218MDT JAR33353565NEXT HNGS CMR XPT EMA JAR33353565 -
Litostratigrafi
Litostratigrafi Topp Dyb [mMD RKB]Litostrat. enhet35835810921138113812991723172317621773192019351935222131503386338633983398340534273457345734683553 -
Boreslam
Boreslam Dybde MD [m]Egenvekt, slam [g/cm3]Viskositet, slam [mPa.s]Flytegrense [Pa]Type slamDato, måling4441.2010.0Water6791.329.0Water12141.3911.0Water12181.4610.5Synthetic23931.5212.9Synthetic31461.525.2Oil31461.03Water33401.5811.4Synthetic33401.527.6Synthetic34491.525.7Synthetic34951.525.2Oil36031.51Brine36031.525.7Oil