35/11-22 S
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Generell informasjon
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Brønnhistorie
GeneralWell 35/11-22 S was drilled to test the Bergand prospect in on the Lomre Terrace about 10 kilometres west of the Fram field in the North Sea. The primary exploration objective for well 35/11-22 S was to prove oil in Middle to Early Jurassic reservoir rocks of the Brent Group and the Cook Formation (Dunlin Group). The secondary exploration objective was to prove oil in the Statfjord Group in the Early Jurassic.Operations and resultsWildcat well 35/11-22 S was spudded with the semi-submersible installation Deepsea Bergen on 12 December 2018 and drilled to TD at 3882 m (3866 m TVD) in the Early Jurassic Statfjord Group. Drilling at 2503 m there was a gas influx, believed to come from a thin sandstone in the Shetland Group. The gain was killed by raising the mud weight from 1.25 to 1.32 sg. Otherwise operations proceeded without significant problems. The well was drilled with seawater and hi-vis pills down to 429 m, with KCl mud from 429 m to 1207 m, and with Innovert oil-based mud from 1207 m to TD.A 30 m thick Oxfordian to Early Kimmeridgian age Intra Heather sandstone was encountered at 3030 m (3026 m TVD), directly underlying the Draupne Formation. Fluid sampling indicated oil all through this sandstone. No oil/water contact was established. In the primary exploration target, the well encountered the Brent Group with a thickness of about 190 metres, of which 90 metres of effective reservoir rocks with moderate reservoir quality. The thickness of the Cook Formation is about 70 metres, of which 50 metres of effective reservoir rocks with poor to moderate reservoir quality. Both primary targets are water-bearing. The secondary exploration target, in the Statfjord group, has a thickness of about 130 metres, of which 60 metres of water-bearing reservoir rocks with poor reservoir quality. A thin sandstone at 3264 to 3271 m in the Ness Formation had oil shows in the form of direct and cut fluorescence and residue fluorescence.An open hole side-track 35/11-22 ST2 was drilled to acquire a bypass core over the intra-Heather sandstone interval. The core was cut from 3027.37 to 3077.37 m. No logs were acquired in this side-track. MDT fluid samples were taken in the main bore at 3042 m (oil), 3052 m (?oil), 3058 m (oil), and 3311.5 m (water).The well was permanently abandoned on 2 February as an oil 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]720.003882.00 -
Borekjerner i Sokkeldirektoratet
Borekjerner i Sokkeldirektoratet Kjerneprøve nummerKjerneprøve - topp dybdeKjerneprøve - bunn dybdeKjerneprøve dybde - enhet13026.03074.1[m ]Borekjerner i Sokkeldirektoratet Total kjerneprøve lengde [m]48.1Borekjerner i Sokkeldirektoratet Kjerner tilgjengelig for prøvetaking?YES -
Litostratigrafi
Litostratigrafi Topp Dyb [mMD RKB]Litostrat. enhet379776858172317231779179518842069206922232639265626632704270427492756278327833030303030603250325032593335335333773417341734953565365736763738 -
Logger
Logger Type loggTopp dyp for logg [m]Bunn dyp for logg [m]AIT PEX XPT25423884MDT30423311MSIP18003542MSIP NGI18103884MWD LWD - GR RES4293882VSP12083475XLR31563836 -
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 formasjonstestCONDUCTOR30429.136429.10.00INTERM.13 3/81198.817 1/21207.01.52FITINTERM.9 5/82542.012 1/42553.01.70FITOPEN HOLE3882.08 1/23882.00.00 -
Boreslam
Boreslam Dybde MD [m]Egenvekt, slam [g/cm3]Viskositet, slam [mPa.s]Flytegrense [Pa]Type slamDato, måling4291.3512.0KCl/Polymer/GEM4291.3914.0KCl/Polymer/GEM8771.3516.0KCl/Polymer/GEM8771.3618.0KCl/Polymer/GEM8901.3518.0KCl/Polymer/GEM10701.3421.0Innovert12071.2313.0Innovert12071.3523.0KCl/Polymer/GEM12101.2414.0Innovert12201.3421.0Innovert12201.3520.0Innovert13501.3415.0Innovert16061.2515.0Innovert21901.2515.0Innovert22811.3415.0Innovert22811.4930.0Innovert25031.2516.0Innovert25031.3018.0Innovert25141.3218.0Innovert25461.4927.0Innovert25531.5217.0Innovert25531.3317.0Innovert25561.5217.0Innovert26901.4921.0Innovert26971.5218.0Innovert27291.4826.0Innovert28241.5218.0Innovert29651.4823.0Innovert30261.4827.0Innovert30901.5219.0Innovert38821.4928.0Innovert38821.5223.0Innovert