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3D Lithofacies Model Building of the Rotliegend Sediments of the NE German Basin*
By
Inga Moeck1, Heinz-Gerd Holl1, and Heinz Schandelmeier2
Search and Discovery Article #30039 (2006)
Posted February 1, 2002
*Adapted from an extended abstract prepared for AAPG International Conference, Paris, France, September 11-14, 2005
1GeoForschungs Zentrum Potsdam, Geothermics, Telegrafenberg, D-14473 Potsdam, Germany ([email protected])
2TU Berlin, Exploration Geology, Ernst-Reuter Platz 1, D-10587 Berlin, Germany
Abstract
Static 3D geological models are essential to reservoir characterization and dynamic models. We introduce an approach of combining pre-existing and newly generated data to assess lithofacies distributions and sandstone permeability of a clastic reservoir within the Rotliegend II of the NE German basin. The target is at 4300 m depth and situated north of Berlin (Germany) in the vicinity of a former gas exploration well, drilled in 1990 and currently acting as geothermal in-situ laboratory.
This second-hand well was re-opened in 2000 and deepened in two steps to 4309m TVD. An extensive logging program was performed between various stimulations and hydraulic tests. Porosity/permeability data are available from logging data as well as from abundant porosity (290 samples) and permeability measurements (109) on cores.
A basic 3D
structural geological model of an area of 120 km2
was
calculated using pre-existing well data and 2D seismic profiles. Detailed well
data provided information to develop a 3D lithofacies model, comprising five
lithotypes. The facies grids were calculated with a 3D minimum tension
technique. In this procedure each facies grid was normalized, calculated against
each other, and reconciled by creating a 0-isoenvelop, that clearly defines the
facies-type body. The isoshells were set in each 
fault
block of the structural
model and processed to a comprehensive 3D structural lithofacies model. This
volumetric 3D model allows an assessment of both matrix-driven and
fracture-driven permeability. This approach can be applied to any region, where
detailed structural and sedimentological data are available.
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The well Gross Schönebeck 3/90 (GrSk 3/90; NE of Berlin, Germany; Figure 1) was drilled in 1990 assigned to gas exploration in East Germany. The borehole was been closed due to lack of gas. In 2000 the well was re-opened to use the borehole as in-situ laboratory for geothermal low enthalphy reservoir studies. The geothermal reservoir is situated in Rotliegend II strata in part of the NE German Basin (NEGB). The NEGB is part of an extensive basin system which extends from the North Sea towards Poland. It is bounded in the north by the Baltic Shield and in the south by the Variscan fold belt. Initial basin extension occurred between the latest Carboniferous and the Early Permian and was accompanied by the deposition of volcanic rocks which were subsequently covered by a siliciclastic sequence of alluvial fans, ephemeral stream, playa deposits, and eolian sands (Rieke et al., 2001). Thick cyclic evaporites and carbonates, deposited during the Zechstein, are overlain by a thick section of Mesozoic and Cenozoic sediments. The basic scientific function of the in-situ laboratory consists in the development of hydraulic stimulation techniques in order to enhance the permeability in siliciclastic and volcanic formations of the Rotliegend. In order to assess the permeability of both the sandstone matrix and the fracture porosity, an extensive logging program has been conducted, while the geometry of the reservoir is revealed by 3D structural model building procedures.
MethodsLogging ProgramThe first geophysical logging program was carried out in 1991 to explore a potential gas reservoir in the Rotliegend sediments. Erdöl Erdgas GmbH (EEG) provided logging data in digital format for this project (caliper, spectral gamma ray, resistivity, neutron, density, sonic, and dipmeter). The GeoForschungsZentrum (GFZ) logging operations were performed by the Operational Support Group (OSG) implementing caliper, electric, spectral gamma ray, resistivity, and acoustic measurements. The last logging campaign was executed by Schlumberger during the winter 2003. Two new logging tools were used in addition to the GFZ logging program. The latest porosity measurement was achieved by Reservoir Saturation Tool logs (RST, mark of Schlumberger) and is used for a comparison with laboratory data.
3D Model BuildingThe basic 3D structural model is calculated, based on data of 6 pre-existing, reprocessed 2D seismic sections and 15 wells (locations in Figure 1). This modeling procedure comprises the development of a 3D conceptual model interpreted from a time-thickness map of the Rotliegend II, and the calculation of a final 3D structural model of the reservoir integrating the seismic section and well data with the conceptual model (Figure 2; see also Figure 4, track lithology). The
calculation of grids has been made with an iterative minimum tension
algorithm, the
ResultsFigure 4 shows the lithology distribution and stratigraphic classification of the well Gross Schönebeck 3/90. The volcanic formation of the Lower Rotliegend consists of two different magmatic rock types. The upper series shows higher thorium contents than the lower series and is suggested to be more highly differentiated with a trachydacitic or trachyandesitic character. The lower series is characterized by geochemical properties of a more primitive source and is classified as basaltic andesite. Both of the volcanic rock suites are intersected by a crossbedded tuffaceous or tuffitic layer. The interbedded sediments consist of marls, marly limestones, and mudstones, subordinately interstratified by thin anhydritic evaporite layers. The sandstones and conglomerates of the Havel Subgroup show decreasing gamma ray values attributed to the depletion of mechanically unstable, chemically altered volcanic rock fragments within a fining-upward cycle of the siliciclastic sediments. The nearly clean sandstones of the Lower Dethlingen Formation (4130-4175m/Lower Elbe Subgroup) show the lowest gamma ray emissions of all measured clastic sediments, owing to their low clay content. The gamma ray values increase continuously upward within the interval of interbedded siltstones/sandstones and reach a maximum value in the mudstones of the Upper Elbe Subgroup. The petrophysical properties of the target horizons are important for the characterization of the geothermal reservoir. Figure 4 shows a composite log of the sandstones of interest. We used the neutron porosity measurement from the RST data (track TPHI RST) to estimate permeabilities (calculated permeability/logarithmic scale) using the empirical formula from Pape et al. (1999, eq. 22) and observed permeability values from 0.04 up to 110 mD. We repeated this procedure with porosity data calculated from density and sonic measurements and received transmissibilities in the range from 0.25 to 0.70 Dm for a 80m sandstone interval (4100-4180m). The comparison of logging data (Tphi RST) with measured core porosities as well as a comparison of calculated permeabilities with core permeabilities is shown in tracks 3 and 4 (core porosity: n =290; core permeability: n=109). The results indicate a good correlation between logging data, permeability estimation, and core data. The right-hand track illustrates a borehole temperature measurement representing the current state after the last stimulation experiment. Temperature logs record changes of the temperature field due to injection and production of brines during hydraulic experiments. The bright yellow areas mark the stimulated intervals. Three temperature minima are recognized in identifying productive zones. The upper two temperature signals prove the existence of pay sand horizons. The productivity of the lowermost reservoir horizon indicates a cumulative flow out of porous sandstones (Havel Subgroup) and of the naturally fractured volcanic formation (Lower Rotliegend). The 3D
lithofacies model reveals the spatial distribution of the five
lithofacies types that are part of the Rotliegend II siliciclastics (Figure
5). The conglomerates and the medium-grained sand were only
deposited south of a NW-SE-striking strike-slip The target horizon is in the fine- and medium-grained facies type at an average 4150 m TVD due to its efficient porosity.
ConclusionsRecent investigations on the state of stress in the NEGB have revealed a constant ± N-S trend of the direction of the maximum horizontal stress SH in the area north of Berlin (Röckel and Lempp, 2003). The mean direction of SH was determined in the open-hole section of Gross Schönebeck from borehole breakouts and vertical hydraulically induced fractures to 18.5° ± 3.7° (Holl et al., 2004). Thus only a small acute angle exists between SH and the NNE-trending faults. Röckel and Lempp (2003) have shown that the current state of stress in the NGB is generally a normal-faulting state; however, transitions to strike-slip faulting-states may not be excluded. The
recent stress The combined use of pre-existing and newly generated data sets provides new understanding for the characteristics of the geothermal reservoir in the Lower Rotliegend formation of the North East German Basin. The multidisciplinary approach included implementation of existing well data, reprocessing of pre-existing 2D seismic sections, interpretation of various newly generated well log data, and reconciliation of all data to a coherent 3D geological model. The petrophysical properties of the target, the depositional environment, and the reservoir geometry are now well known. These data are crucial for modeling the thermo-hydraulic conditions within the geothermal reservoir during production. Future work will focus on the use of geostatistical models, combining porosity and permeability distributions with sedimentary facies architecture.
ReferencesBaltrusch, S., and S. Klarner, 1993, Rotliegend-Gräben in NE-Brandenburg: Zeitschrift der deutschen geologischen Gesellschaft, v. 144, p. 173-186. Holl, H.-G., I. Moeck, and H. Schandelmeier, 2004, Geothermal well Großschönebeck 3/90: A low enthalpy reservoir (Rotliegend, NE Germany): Proceedings, 66th EAGE Conference, F032, Paris, France. Pape, H., C. Clauser, and J. Iffland, 1999, Permeability prediction based on fractal pore-space geometry: Geophysics, v. 64, no. 5, p. 1447-1460. Rieke, H., D. Kossow, T. McCann, and C. Krawczyk, 2001, Tectono-sedimentary evolution of the northernmost margin of the NE German Basin between uppermost Carboniferous and Late Permian (Rotliegend): Geological Journal, v. 36, p. 19-38. Röckel, T., and C. Lempp, 2003, Der Spannungszustand im Norddeutschen Becken: Erdöl Erdgas Kohle, v. 119, no. 2, p. 73-80. Ziegler, P.A., 1988, Evolution of the Arctic-North Atlantic and the Western Tethys: AAPG Memoir, v. 43, 198 p. Zoback, M.D., and J.H. Healy, 1992, In-situ measurements to 3.5 km depth in the Cajon Pass scientific research borehole: Journal of Geophysical Research, v. 97, p. 5039-5057.
AcknowledgmentsThis multidisciplinary project is a joint research project of GFZ Potsdam, BGR Hannover, GGA Hannover, TU Berlin, Ruhr University Bochum, University Stuttgart and industrial partners (GTN Neubrandenburg, BWG Neubrandenburg, MeSy Bochum). It is funded by BMWi, BMBF, BMU, MWI and MWFK. The 3D models are processed with EarthVision®, Dynamic Graphics Inc. (DGI). Our thanks are addressed to Erdöl Erdgas GmbH (EEG) for data release, and to DGI (namely P. Luxey) for support and advise . |
