This study investigates the depositional environment, source area, sandstone composition, diagenetic properties, reservoir quality and palaeogeography of the Middle–Upper Cretaceous strata at the Unity and Heglig Fields in the SE Muglad Rift Basin, Sudan. In this study, the subsurface Cretaceous sediments were investigated essentially by seven sedimentological techniques. These included subsurface facies analysis, which was based on 1500 cutting samples and seven conventional cores description as well as on wire line logs and three seismic section analyses, petrographic analyses that included heavy mineral analysis, thin sections and scanning electron microscopic investigations, clay mineral as well as geochemical analyses. The facies description and the analysis of conventional cores from the Bentiu, Aradeiba, and Zarga Formations in the Unity and Heglig Field revealed the presence of nine major lithofacies types, all of them are siliciclastic sediments. They can be interpreted as deposits of fluvial, deltaic and lacustrine environments. Moreover, based on wire line logs, cores and cutting sample descriptions and analyses and also on seismic section analyses, the Middle–Upper Cretaceous strata in Unity and Heglig Fields can be classified into three different units of first-order sequences, i.e. fluvial-dominated unit, lacustrine-dominated unit and deltaic-dominated unit. These depositional units most probably testify to environmental change in response to main tectonic pulses during the Turonian – Late Senonian second rifting phase. The seismic analysis revealed that the maximum thickness of the Cretaceous sediments in the study area reaches about 6000 m in the NW part of the Heglig Field. Moreover, the seismic interpretation has revealed three seismic facies reflection patterns: parallel and subparallel reflection patterns (uniform rates of deposition), divergent reflection pattern (differential subsidence rates) and hummocky clinoform pattern (clinoform lobes of delta). The thin section investigations of the core samples revealed that feldspar accounts for 13.5 – 22 %, that of the quartz and the lithic fragments are ranging between 75.7 – 85.2 % and 0.0 7.3 % respectively. Consequently, the sandstones of the study area are classified as subarkoses. Moreover, the modal analysis of the sandstones revealed, that they stem generally from a continental provenance, transitional between the stable interior of a craton and a basement uplift, which is a basement area of relatively high relief along rifts. This allows the detrital components to be recycled and transported for rather long distances and to be deposited in extensional and pull-apart basins. The reservoir quality of the Bentiu and Aradeiba Formations in general is better than that of the Zarga Formation. The porosity of the Bentiu and Aradeiba Formations ranges between 16.7 – 30.0 % and 18.6 – 25.3 %, respectively, whereas the porosity of the Zarga Formation ranges between 16.3 – 23.7 %. Moreover, the thin section investigations and the scanning electron microscope (SEM) analysis for the sandstones of the study area revealed that their reservoir quality was affected positively and negatively by several diagenetic processes. These processes include: mechanical compaction factors (grain slippage and crushing of the ductile grains), quartz overgrowths, precipitation of siderite and calcite, feldspar and clay mineral authigenesis, dissolution of carbonate and of the labile detrital grains and clay infiltration. Furthermore, the reservoir quality of the study intervals was not only affected by the above mentioned diagenetic processes, but also in a large-scale by the type of depositional environment. The study of the heavy minerals revealed that the amounts of the heavy minerals kyanite and garnet supersede those of zircon, tourmaline and rutile. This indicates a metamorphic source rock of originally granitic and/or granodioritic composition for the sediments of the study area. Three heavy mineral assemblage zones with obvious lateral and vertical continuity were identified: a zircon-rutile zone (ZR), a sillimanite-epidote-hornblende zone (SEH) and a kyanite-staurolite-andalusite-garnet zone (KStAnG). On the basis of the ZTR (zircon-tourmaline-rutile) index as well as on the SEH (sillimanite-epidote-hornblende) index, four major maturation levels were constructed: immature, moderately mature, mature and overmature. The clay mineral analysis allowed the subdivision of the Middle–Upper Cretaceous strata into three to two clay mineral zones, which reflect mainly different environmental and diagenetic conditions. The lower clay mineral zone consists of kaolinite, illite/smectite mixed layer, illite, smectite and chlorite. Whereas, the middle zone consists of kaolinite, smectite, illite/smectite mixed layer, illite and chlorite. The upper zone comprises kaolinite, illite, illite/smectite mixed layer, chlorite and smectite. The lower and the upper clay mineral zones contain higher values of kaolinite in comparison to the middle clay mineral zone, whereas the middle zone contains a higher value of smectite in comparison to the lower and the upper clay mineral zones. The higher amount of the kaolinite in the lower and in the upper zones suggest most probably the intensity of chemical weathering and leaching processes under warm humid climate. The marked presence of smectite in the middle zone suggest that the warm humid climate was interrupted by dry seasons. Moreover, the lower clay mineral zone, which shows an increase of illite, chlorite, mixed layer illite/smectite and a higher illite crystallinity, indicates mixed and transitional influences from environmental/tectonic to burial diagenetic controls. Geochemical investigations revealed preferential enrichment and depletion of certain chemical elements in the lacustrine/fluvial/deltaic environments. For instance, the less mobile elements Ti, Ga, Cr and Zr remained in higher amounts in the proximal facies (i.e. in the fluvial channel bar deposits and in the deltaic mouth bar deposits). In contrast, the more mobile elements Mg, Ca, K and Rb occur in higher concentrations in the distal facies (i.e. in the lacustrine deposits, deltaic distal bar deposits and floodplain sediment).

Techn. Universiẗat, Diss., 2003--Berlin.

University, Diss., 2003--Tübingen.

This study investigates the depositional environment, source area, sandstone composition, diagenetic properties, reservoir quality and palaeogeography of the Middle–Upper Cretaceous strata at the Unity and Heglig Fields in the SE Muglad Rift Basin, Sudan. In this study, the subsurface Cretaceous sediments were investigated essentially by seven sedimentological techniques. These included subsurface facies analysis, which was based on 1500 cutting samples and seven conventional cores description as well as on wire line logs and three seismic section analyses, petrographic analyses that included heavy mineral analysis, thin sections and scanning electron microscopic investigations, clay mineral as well as geochemical analyses. The facies description and the analysis of conventional cores from the Bentiu, Aradeiba, and Zarga Formations in the Unity and Heglig Field revealed the presence of nine major lithofacies types, all of them are siliciclastic sediments. They can be interpreted as deposits of fluvial, deltaic and lacustrine environments. Moreover, based on wire line logs, cores and cutting sample descriptions and analyses and also on seismic section analyses, the Middle–Upper Cretaceous strata in Unity and Heglig Fields can be classified into three different units of first-order sequences, i.e. fluvial-dominated unit, lacustrine-dominated unit and deltaic-dominated unit. These depositional units most probably testify to environmental change in response to main tectonic pulses during the Turonian – Late Senonian second rifting phase. The seismic analysis revealed that the maximum thickness of the Cretaceous sediments in the study area reaches about 6000 m in the NW part of the Heglig Field. Moreover, the seismic interpretation has revealed three seismic facies reflection patterns: parallel and subparallel reflection patterns (uniform rates of deposition), divergent reflection pattern (differential subsidence rates) and hummocky clinoform pattern (clinoform lobes of delta). The thin section investigations of the core samples revealed that feldspar accounts for 13.5 – 22 %, that of the quartz and the lithic fragments are ranging between 75.7 – 85.2 % and 0.0 7.3 % respectively. Consequently, the sandstones of the study area are classified as subarkoses. Moreover, the modal analysis of the sandstones revealed, that they stem generally from a continental provenance, transitional between the stable interior of a craton and a basement uplift, which is a basement area of relatively high relief along rifts. This allows the detrital components to be recycled and transported for rather long distances and to be deposited in extensional and pull-apart basins. The reservoir quality of the Bentiu and Aradeiba Formations in general is better than that of the Zarga Formation. The porosity of the Bentiu and Aradeiba Formations ranges between 16.7 – 30.0 % and 18.6 – 25.3 %, respectively, whereas the porosity of the Zarga Formation ranges between 16.3 – 23.7 %. Moreover, the thin section investigations and the scanning electron microscope (SEM) analysis for the sandstones of the study area revealed that their reservoir quality was affected positively and negatively by several diagenetic processes. These processes include: mechanical compaction factors (grain slippage and crushing of the ductile grains), quartz overgrowths, precipitation of siderite and calcite, feldspar and clay mineral authigenesis, dissolution of carbonate and of the labile detrital grains and clay infiltration. Furthermore, the reservoir quality of the study intervals was not only affected by the above mentioned diagenetic processes, but also in a large-scale by the type of depositional environment. The study of the heavy minerals revealed that the amounts of the heavy minerals kyanite and garnet supersede those of zircon, tourmaline and rutile. This indicates a metamorphic source rock of originally granitic and/or granodioritic composition for the sediments of the study area. Three heavy mineral assemblage zones with obvious lateral and vertical continuity were identified: a zircon-rutile zone (ZR), a sillimanite-epidote-hornblende zone (SEH) and a kyanite-staurolite-andalusite-garnet zone (KStAnG). On the basis of the ZTR (zircon-tourmaline-rutile) index as well as on the SEH (sillimanite-epidote-hornblende) index, four major maturation levels were constructed: immature, moderately mature, mature and overmature. The clay mineral analysis allowed the subdivision of the Middle–Upper Cretaceous strata into three to two clay mineral zones, which reflect mainly different environmental and diagenetic conditions. The lower clay mineral zone consists of kaolinite, illite/smectite mixed layer, illite, smectite and chlorite. Whereas, the middle zone consists of kaolinite, smectite, illite/smectite mixed layer, illite and chlorite. The upper zone comprises kaolinite, illite, illite/smectite mixed layer, chlorite and smectite. The lower and the upper clay mineral zones contain higher values of kaolinite in comparison to the middle clay mineral zone, whereas the middle zone contains a higher value of smectite in comparison to the lower and the upper clay mineral zones. The higher amount of the kaolinite in the lower and in the upper zones suggest most probably the intensity of chemical weathering and leaching processes under warm humid climate. The marked presence of smectite in the middle zone suggest that the warm humid climate was interrupted by dry seasons. Moreover, the lower clay mineral zone, which shows an increase of illite, chlorite, mixed layer illite/smectite and a higher illite crystallinity, indicates mixed and transitional influences from environmental/tectonic to burial diagenetic controls. Geochemical investigations revealed preferential enrichment and depletion of certain chemical elements in the lacustrine/fluvial/deltaic environments. For instance, the less mobile elements Ti, Ga, Cr and Zr remained in higher amounts in the proximal facies (i.e. in the fluvial channel bar deposits and in the deltaic mouth bar deposits). In contrast, the more mobile elements Mg, Ca, K and Rb occur in higher concentrations in the distal facies (i.e. in the lacustrine deposits, deltaic distal bar deposits and floodplain sediment).

Most of the old oil fields in China have reached high water cut stage, in order to meet the booming energy demanding, oil production rate must be kept in the near future with corresponding IOR (Improving Oil Recovery) methods. Z106 oilfield lies in Shengli Oilfields Area at the Yellow River delta. It was put into development in 1988. Since the oil belongs to heavy oil, the oil-water mobility ratio is so unfavourable that water cut increases very quickly. Especially for reservoir Ng21, the sand rock is sediment from river channel, the permeability heterogeneity and heavy oil properties together lead to extremely poor water flooding efficiency. In order to improve the oil recovery, IOR methods are needed urgently. Considering all practical situations for this reservoir and present technique level, polymer flooding method has been selected as an IOR test with numerical simulation. For polymer flooding, since polymer resolution has the capability of enlarging water viscosity, it controls the mobility of water phase and at the same time improves the driving efficiency. During polymer flooding simulation, many factors must be taken into account for the construction of mathematical model, such as inaccessible pore volume, polymer shear thinning effect, polymer adsorption, relative permeability reduction factors, etc. All simulations were done with black oil model with polymer option in ECLIPSE. Simulation results for a theoretical river channel reservoir with serious permeability heterogeneity and heavy oil, and simulation results for practical reservoir Ng21, both have shown that polymer flooding is a feasible method for IOR. For reservoir Ng21, with polymer slug size of 0.235 PV, polymer concentration at 1.5 kg/m3, the final oil recovery after polymer flooding could reach 12.8%, the enhanced oil recovery is about 5%. If only the developable oil reserve being taken into account, the final oil recovery is about 34%, and enhanced oil recovery from polymer flooding is more than 12%. For such heavy oil river channel reservoir to reach such a final oil recovery, it could be concluded as a great success. Since there are still many such oil reservoirs in Shengli Oilfields Area, polymer flooding will be of great importance for improving oil recovery in this area in the near future.

Most of the old oil fields in China have reached high water cut stage, in order to meet the booming energy demanding, oil production rate must be kept in the near future with corresponding IOR (Improving Oil Recovery) methods. Z106 oilfield lies in Shengli Oilfields Area at the Yellow River delta. It was put into development in 1988. Since the oil belongs to heavy oil, the oil-water mobility ratio is so unfavourable that water cut increases very quickly. Especially for reservoir Ng21, the sand rock is sediment from river channel, the permeability heterogeneity and heavy oil properties together lead to extremely poor water flooding efficiency. In order to improve the oil recovery, IOR methods are needed urgently. Considering all practical situations for this reservoir and present technique level, polymer flooding method has been selected as an IOR test with numerical simulation. For polymer flooding, since polymer resolution has the capability of enlarging water viscosity, it controls the mobility of water phase and at the same time improves the driving efficiency. During polymer flooding simulation, many factors must be taken into account for the construction of mathematical model, such as inaccessible pore volume, polymer shear thinning effect, polymer adsorption, relative permeability reduction factors, etc. All simulations were done with black oil model with polymer option in ECLIPSE. Simulation results for a theoretical river channel reservoir with serious permeability heterogeneity and heavy oil, and simulation results for practical reservoir Ng21, both have shown that polymer flooding is a feasible method for IOR. For reservoir Ng21, with polymer slug size of 0.235 PV, polymer concentration at 1.5 kg/m3, the final oil recovery after polymer flooding could reach 12.8%, the enhanced oil recovery is about 5%. If only the developable oil reserve being taken into account, the final oil recovery is about 34%, and enhanced oil recovery from polymer flooding is more than 12%. For such heavy oil river channel reservoir to reach such a final oil recovery, it could be concluded as a great success. Since there are still many such oil reservoirs in Shengli Oilfields Area, polymer flooding will be of great importance for improving oil recovery in this area in the near future.

Gas injection into saturated porous media has a high practical relevance. It is applied in groundwater remediation (air sparging), in CO2 sequestration into saline aquifers, and in enhanced oil recovery of petroleum reservoirs. This wide range of application necessitates a comprehensive understanding of gas flow patterns that may develop within the porous media and required modeling of multi-phase flow. There is an ongoing controversy in literature, if continuum models are able to describe the complex flow pattern observed in heterogeneous porous media, especially the channelized stochastic flow pattern. Based on Selker’s stochastic hypothesis, a gas channel is caused by a Brownian-motion process during gas injection. Therefore, the pore-scale heterogeneity will determine the shape of the single stochastic gas channels. On the other hand there are many studies on air sparging, which are based on continuum modeling. Up to date it is not clear under which conditions a continuum model can describe the essential features of the complex gas flow pattern. The aim of this study is to investigate the gas flow pattern on bench-scale and field scale using the continuum model TOUGH2. Based on a comprehensive data set of bench-scale experiments and field-scale experiments, we conduct for the first time a systematic study and evaluate the prediction ability of the continuum model. A second focus of this study is the development of a “real world”-continuum model, since on all scales – pore-scale, bench scale, field scale – heterogeneity is a key driver for the stochastic gas flow pattern. Therefore, we use different geostatistical programs to include stochastic conditioned and unconditioned parameter fields. Our main conclusion from bench-scale experiments is that a continuum model, which is calibrated by different independent measurements, has excellent prediction ability for the average flow behavior (e.g. the gas volume-injection rate relation). Moreover, we investigate the impact of both weak and strong heterogeneous parameter fields (permeability and capillary pressure) on gas flow pattern. The results show that a continuum model with weak stochastic heterogeneity cannot represent the essential features of the experimental gas flow pattern (e.g., the single stochastic gas channels). Contrary, applying a strong heterogeneity the continuum model can represent the channelized flow. This observation supports Stauffer’s statement that a so-called subscale continuum model with strong heterogeneity is able to describe the channelized flow behavior. On the other hand, we compare the theoretical integral gas volumes with our experiments and found that strong heterogeneity always yields too large gas volumes. At field-scale the 3D continuum model is used to design and optimize the direct gas injection technology. The field-scale study is based on the working hypotheses that the key parameters are the same as at bench-scale. Therefore, we assume that grain size and injection rate will determine whether coherent channelized flow or incoherent bubbly flow will develop at field-scale. The results of four different injection regimes were compared with the data of the corresponding field experiments. The main conclusion is that because of the buoyancy driven gas flow the vertical permeability has a crucial impact. Hence, the vertical and horizontal permeability should be implemented independently in numerical modeling by conditioned parameter fields.

Gas injection into saturated porous media has a high practical relevance. It is applied in groundwater remediation (air sparging), in CO2 sequestration into saline aquifers, and in enhanced oil recovery of petroleum reservoirs. This wide range of application necessitates a comprehensive understanding of gas flow patterns that may develop within the porous media and required modeling of multi-phase flow. There is an ongoing controversy in literature, if continuum models are able to describe the complex flow pattern observed in heterogeneous porous media, especially the channelized stochastic flow pattern. Based on Selker’s stochastic hypothesis, a gas channel is caused by a Brownian-motion process during gas injection. Therefore, the pore-scale heterogeneity will determine the shape of the single stochastic gas channels. On the other hand there are many studies on air sparging, which are based on continuum modeling. Up to date it is not clear under which conditions a continuum model can describe the essential features of the complex gas flow pattern. The aim of this study is to investigate the gas flow pattern on bench-scale and field scale using the continuum model TOUGH2. Based on a comprehensive data set of bench-scale experiments and field-scale experiments, we conduct for the first time a systematic study and evaluate the prediction ability of the continuum model. A second focus of this study is the development of a “real world”-continuum model, since on all scales – pore-scale, bench scale, field scale – heterogeneity is a key driver for the stochastic gas flow pattern. Therefore, we use different geostatistical programs to include stochastic conditioned and unconditioned parameter fields. Our main conclusion from bench-scale experiments is that a continuum model, which is calibrated by different independent measurements, has excellent prediction ability for the average flow behavior (e.g. the gas volume-injection rate relation). Moreover, we investigate the impact of both weak and strong heterogeneous parameter fields (permeability and capillary pressure) on gas flow pattern. The results show that a continuum model with weak stochastic heterogeneity cannot represent the essential features of the experimental gas flow pattern (e.g., the single stochastic gas channels). Contrary, applying a strong heterogeneity the continuum model can represent the channelized flow. This observation supports Stauffer’s statement that a so-called subscale continuum model with strong heterogeneity is able to describe the channelized flow behavior. On the other hand, we compare the theoretical integral gas volumes with our experiments and found that strong heterogeneity always yields too large gas volumes. At field-scale the 3D continuum model is used to design and optimize the direct gas injection technology. The field-scale study is based on the working hypotheses that the key parameters are the same as at bench-scale. Therefore, we assume that grain size and injection rate will determine whether coherent channelized flow or incoherent bubbly flow will develop at field-scale. The results of four different injection regimes were compared with the data of the corresponding field experiments. The main conclusion is that because of the buoyancy driven gas flow the vertical permeability has a crucial impact. Hence, the vertical and horizontal permeability should be implemented independently in numerical modeling by conditioned parameter fields.

This thesis provides a feasibility study on the determination of formation anisotropy parameters from logging-while-drilling (LWD) borehole acoustic measurements. For this reason, the wave propagation in fluid-filled boreholes surrounded by transverse isotropic (TI) formations is investigated in great detail using the finite-difference method. While the focus is put on quadrupole waves, the sensitivities of monopole and flexural waves are evaluated as well. All three wave types are considered with/without the presence of an LWD tool. Moreover, anisotropy-induced mode contaminants are discussed for various TI configurations. In addition, the well-known plane wave Alford rotation has been generalized to cylindrical borehole waves of any order, except for the monopole. This formulation has been extended to allow for non-orthogonal multipole firings, and associated inversion methods have been developed to compute formation shear principal velocities and accompanying polarization directions, utilizing various LWD (cross-) quadrupole measurements.:1 Introduction 1.1 Borehole acoustic configurations 1.2 Wave propagation in a fluid-filled borehole in the absence of a logging tool 1.3 Wave propagation in a fluid-filled borehole in the presence of a logging tool 1.4 Anisotropy 2 Theory 2.1 Stiffness and compliance tensor 2.1.1 Triclinic symmetry 2.1.2 Monoclinic symmetry 2.1.3 Orthotropic symmetry 2.1.4 Transverse isotropic (TI) symmetry 2.1.5 Isotropy 2.2 Reference frames 2.3 Seismic wave equations for a linear elastic, anisotropic medium 2.3.1 Basic equations 2.3.2 Integral transforms 2.3.3 Christoffel equation 2.3.4 Phase slowness surfaces 2.3.5 Group velocity 2.4 Solution in cylindrical coordinates for the borehole geometry 2.4.1 Special case: vertical transverse isotropy (VTI) 2.4.2 General case: triclinic symmetry 3 Finite-difference modeling of wave propagation in anisotropic media 3.1 Finite-difference method 3.2 Spatial finite-difference grids 3.2.1 Standard staggered grid 3.2.2 Lebedev grid 3.3 Heterogeneous media 3.4 Finite-difference properties and grid dispersion 3.5 Initial conditions 3.6 Boundary conditions 3.7 Parallelization 3.8 Finite-difference parameters 4 Wave propagation in fluid-filled boreholes surrounded by TI media 4.1 Vertical transverse isotropy (VTI) 4.1.1 Monopole excitation 4.1.2 Dipole excitation 4.1.3 Quadrupole excitation 4.1.4 Summary 4.2 Horizontal transverse isotropy (HTI) 4.2.1 Monopole excitation 4.2.2 Theory of cross-multipole shear wave splitting 4.2.3 Dipole excitation 4.2.4 Quadrupole excitation 4.2.5 Hexapole waves 4.2.6 Summary 4.3 Tilted transverse isotropy (TTI) 4.3.1 Monopole excitation 4.3.2 Dipole excitation 4.3.3 Quadrupole excitation 4.3.4 Summary 4.4 Anisotropy-induced mode contaminants 4.4.1 Vertical transverse isotropy (VTI) 4.4.2 Horizontal transverse isotropy (HTI) 4.4.3 Tilted transverse isotropy (TTI) 4.4.4 Summary 5 Inversion methods 5.1 Vertical transverse isotropy (VTI) 5.2 Horizontal transverse isotropy (HTI) 5.2.1 Inverse generalized Alford rotation 5.2.2 Inversion method based on dipole excitations 5.2.3 Inversion method based on quadrupole excitations 5.3 Tilted transverse isotropy (TTI) 5.4 Challenges in real measurements 5.4.1 Signal-to-noise ratio (SNR) 5.4.2 Tool eccentricity 6 Conclusions References List of Abbreviations and Symbols List of Figures List of Tables A Integral transforms A.1 Laplace transform A.2 Spatial Fourier transform A.3 Azimuthal Fourier transform A.4 Meijer transform B Stiffness and compliance tensor B.1 Rotation between reference frames B.2 Cylindrical coordinates C Christoffel equation C.1 Cartesian coordinates C.2 Cylindrical coordinates D Processing of borehole acoustic waveform array data D.1 Time-domain methods D.2 Frequency-domain methods D.2.1 Weighted spectral semblance method D.2.2 Modified matrix pencil method

Erdöl und Erdgas liegen als flüssige Kohlenwasserstoffe in porösen Sedimentgesteinen im geologischen Untergrund vor. Um diese Kohlenwasserstoffe zu gewinnen, wird der Untergrund durch Tiefbohrungen zur Förderung erschlossen. Anschließend erfolgt die Förderung des Erdöls in drei Phasen: der Primär-, Sekundär- und Tertiärförderung. In der primären Phase wird Erdöl durch den Druck in der Lagerstätte gewonnen, in der sekundären Phase durch künstliche Aufrechterhaltung des Drucks und in der tertiären Phase durch technische Beeinflussung der strömungsmechanischen und thermodynamischen Eigenschaften des Erdöls. Dennoch verbleibt insbesondere bei Schweröllagerstätten ein Anteil von 45 bis 90 % des ursprünglich in der Lagerstätte vorhandenen Erdöls in der Lagerstätte. Aufgrund strömungsmechanischer und thermodynamischer Einschränkungen ist eine Gewinnung dieses Anteils technisch und/oder wirtschaftlich nicht möglich. Meist wird die Lagerstätte nach Abschluss der Förderung verfüllt und die übertägigen Anlagen zurückgebaut. Zugleich steigt weltweit der Bedarf an Energiequellen, insbesondere an solchen, die für die Dekarbonisierung und Umstellung auf umweltschonende Energien benötigt werden. Wasserstoff wird voraussichtlich als chemischer Energieträger der zukünftige Schlüsselrohstoff für die Energiewende sein. Diese Forschungsarbeit untersucht die Weiternutzung bzw. Erschließung ausgeförderter Erdöllagerstätten zur Wasserstoffgewinnungmittels thermischer Verfahren. Diese Verfahren orientieren sich an bereits etablierten Methoden für die übertägige Verfahrenstechnik. Durch das Verfahren wird die Lagerstätte mithilfe der Verbrennung des in dieser vorhandenen Restöls erhitzt und das entstehende Koks durch eine Wasserinjektion in Synthesegas umzuwandeln. Durch die hohen Temperaturen entsteht in der Lagerstätte eine Atmosphäre aus Wasserdampf, die zur Vergasung des Kokses führt. Das Gas wird durch die Wasserfront aus der Lagerstätte in die Produktionsbohrungen verdrängt und kann anschließend an der Oberfläche aufbereitet werden. Im Kontext der Lagerstättenprozesse entsteht nicht nur Wasserstoff, sondern auch weitere Verbrennungsprodukte wie Kohlenstoffmonoxid, Kohlenstoffdioxid, Sauergase und Kohlenwasserstoffgase. Diese werden verfahrenstechnisch aufbereitet und dampfreformiert in den obertägigen Anlagen. Zur Erfüllung der Anforderungen an blauen Wasserstoff ist die Reinjektion von Kohlenstoffdioxid erforderlich. In der Dissertation wird ein numerisches Berechnungsschema eingeführt und ausführlich getestet, um die lagerstättentechnische Simulation der thermischen Wasserstoffgewinnung durchzuführen. Anhand von Modelllagerstätten werden mithilfe dieses Schemas relevante Prozessparameter ermittelt und für die Übertragung auf die konkrete Lagerstättensimulation aufbereitet. Das Verfahren zur Wasserstoffförderung wird an einer antiklinalen Lagerstätte mit geostatistischer Heterogenität simuliert. Die Ergebnisse werden zur weiteren Auswertung bezüglich Integritätsfragen, Übertageanlagen sowie wirtschaftlicher und strategischer Aspekte herangezogen.