25/8-19 A
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General information
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Wellbore history
GeneralWell 25/8-19 A was drilled as an appraisal well on the 25/8-19 S Evra discovery on the southern part of the Heimdal Terrace in the North Sea. Well 25/8-19 S found oil and gas in several intervals from Paleocene to Basement. The primary objective was to investigate the hydrocarbon bearing intervals encountered in well 25/8-19 S, find the oil-water contact and to perform a well test in the Skagerrak Formation.Operations and resultsAppraisal well 25/8-19 A was kicked off from 1017 m in well 25/8-19 S on 31 December 2019. It was drilled with the semi-submersible installation Deepsea Bergen to 2950 m (2636.9 m TVD) in Basement rock. Hole problems led to plug back and drilling of a side-track for the planned well test. The side-track 25/8-19 A T2 was kicked off at 1960 m on 2 February 2020 and drilled to final TD at 2975 m (2567.8 m TVD) in Basement rock. The well was drilled with RheGuard oil-based mud from kick-off to TD.The well encountered thin gas and oil-bearing sandstone injectite layers totalling 8 metres from 1760 to 1810 m in the lowermost Hordaland Group and in the Balder Formation at 1818 m. Thin, oil-bearing sandstones were encountered also throughout the Heimdal Formation. The Upper and Middle-Lower Statfjord units came in with water-bearing sandstones of about 50 and 30 metres, respectively. A total of 18 metres of gas and oil-filled sandstone layers were encountered in the Skagerrak Formation between 2615 and 2806 m. No oil/water contact was proven in the Skagerrak Formation. The well confirmed oil-bearing basement. No oil/water contact was proven in basement.In addition to the hydrocarbon-bearing intervals, oil shows with direct and cut fluorescence were observed in the lower Ty Formation as well as in the lower - middle Statfjord Group.Four cores were cut in the 25/8-19 A wellbore. Core 1 was cut from 2001 to 2029 m in the Heimdal Formation with 100% recovery. Core 2 was cut from 2373 to 2390 m in the lower Statfjord Group with 99.24% recovery. Cores 3 and 4 were cut in succession from 2798 to 2823.1 m in the Skagerrak Formation and Basement with 100 % and 94.63% recoveries, respectively. In wellbore 25/8-19 A MDT fluid samples were taken in the Eocene at 1770 m (gas) and 1801.51 m (oil). In the side-track wellbore 25/8-19 A T2 an MDT sample was taken at 2654 m in the Skagerrak Formation (oil).Metrol pressure and temperature gauges were installed at 2625 mm with repeaters at 1454 m and 625 m, as part of the plugging. The well was permanently abandoned on 19 March 2020 as an oil and gas appraisal well.TestingOne DST was performed in the interval 2651 to 2697 m in the Skagerrak Formation. The test was performed in the 25/8-19 A T2 wellbore. The test produced in the high flow period 475 Sm3 oil/day with an average GOR of 175 Sm3/Sm3 through a 32/64-inch choke. Based on downhole measurements during the test the temperature at mid perforations was 95.6 °C. -
Cuttings at the Norwegian Offshore Directorate
Cuttings at the Norwegian Offshore Directorate Cuttings available for sampling?YESCuttings at the Norwegian Offshore Directorate Cutting sample, top depth [m]Cutting samples, bottom depth [m]1020.002974.00 -
Cores at the Norwegian Offshore Directorate
Cores at the Norwegian Offshore Directorate Core sample numberCore sample - top depthCore sample - bottom depthCore sample depth - uom12001.02029.0[m ]22373.02389.5[m ]32798.02812.5[m ]42812.52822.5[m ]Cores at the Norwegian Offshore Directorate Total core sample length [m]69.0Cores at the Norwegian Offshore Directorate Cores available for sampling?YES -
Oil samples at the Norwegian Offshore Directorate
Oil samples at the Norwegian Offshore Directorate Test typeBottle numberTop depth
MD [m]Bottom depth
MD [m]Fluid typeTest timeSamples availableDST0.000.00YESDST0.000.00OIL05.03.2020 - 15:15YESMDT1801.510.00OIL06.01.2020 - 00:00YESMDT2654.000.00OIL09.02.2020 - 00:00YES -
Casing and leak–off tests
Casing and leak–off tests Casing typeCasing diam.
[inch]Casing depth
[m]Hole diam.
[inch]Hole depth
[m]LOT/FIT mud eqv.
[g/cm3]Formation test typeSURF.COND.13 3/81009.517 1/21009.51.74FITINTERM.9 5/81883.012 1/41883.01.61LOTOPEN HOLE2637.08 1/22637.00.00 -
Drill stem tests (DST)
Drill stem tests (DST) Test numberFrom depth MD
[m]To depth MD
[m]Choke size
[mm]1.02651269712.7Drill stem tests (DST) Test numberFinal shut-in pressure
[MPa]Final flow pressure
[MPa]Bottom hole pressure
[MPa]Downhole temperature
[°C]1.095Drill stem tests (DST) Test numberOil
[Sm3/day]Gas
[Sm3/day]Oil density
[g/cm3]Gas grav. rel.airGOR
[m3/m3]1.0475175 -
Logs
Logs Log typeLog top depth [m]Log bottom depth [m]AIT TLD HNGS18102446GR CMR MDT17111912LWD - DIR PWD GR DEN NEU RES SON10171923LWD - RES GR DIR PWD DEN NEU19232949NGI MAST 2PPC10102446NGI MAST 3PPC ROBN02446ROBN PPC MDT NEXT NGI GR19152408XL ROCK GR17051915 -
Lithostratigraphy
Lithostratigraphy Top depth [mMD RKB]Lithostrat. unit149149488679679998112311531810181018971957198620192051207121872187221122112286248324832806 -
Thin sections at the Norwegian Offshore Directorate
Thin sections at the Norwegian Offshore Directorate DepthUnit1892.30[m ]1888.50[m ]1886.20[m ]1884.00[m ]1862.00[m ]1845.40[m ]1843.50[m ]1834.00[m ]1819.00[m ]1815.40[m ]1804.70[m ]1803.50[m ]1801.50[m ]1787.50[m ]1776.20[m ]1770.00[m ]1762.50[m ]1752.50[m ]1757.50[m ]1739.20[m ]1705.00[m ]2822.44[m ]2820.60[m ]2820.08[m ]2819.30[m ]2818.60[m ]2817.41[m ]2816.23[m ]2815.49[m ]2814.24[m ]2814.04[m ]2813.27[m ]2812.68[m ]2812.08[m ]2811.75[m ]2810.57[m ]2809.86[m ]2808.42[m ]2807.25[m ]2806.95[m ]2806.25[m ]2805.50[m ]2805.02[m ]2804.75[m ]2804.25[m ]2804.02[m ]2802.50[m ]2802.02[m ]2801.75[m ]2801.30[m ]2800.86[m ]2799.24[m ]2799.02[m ]2798.35[m ]2383.63[m ]2382.73[m ]2302.50[m ]2382.05[m ]2831.35[m ]2380.50[m ]2380.11[m ]2379.34[m ]2376.80[m ]2376.26[m ]2375.80[m ]2375.15[m ]2374.22[m ]2373.78[m ]2373.03[m ]2028.40[m ]2023.61[m ]2022.14[m ]2021.87[m ]2021.45[m ]2020.62[m ]2018.08[m ]2017.18[m ]2013.50[m ]2012.20[m ]2010.75[m ]2010.53[m ]2009.82[m ]2008.22[m ]2007.90[m ]2006.28[m ]2005.70[m ]2004.03[m ]2003.28[m ]2001.42[m ]