Layer | Fill | Outline |
---|
Map layers
Theme | Visible | Selectable | Appearance | Zoom Range (now: 0) |
---|
Fill | Stroke |
---|---|
Collaborating Authors
Results
Department of Petroleum Engineering, University of Houston, 2. Metarock Laboratories, 3. Department of Earth and Atmospheric Sciences, University of Houston) 16:00-16:30 Break and Walk to Bizzell Museum 16:30-17:30 Tour: History of Science Collections, Bizzell Memorial Library, The University of Oklahoma 17:30-19:00 Networking Reception: Thurman J. White Forum Building
- North America > United States > Texas (0.51)
- North America > United States > Oklahoma (0.44)
- North America > United States > Colorado (0.31)
- Geology > Geological Subdiscipline > Geomechanics (0.76)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.49)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (0.48)
Petroleum Engineering, University of Houston, 2. Metarock Laboratories, 3. Department of Earth and Atmospheric Sciences, University of Houston) 16:00-16:30 Break and Walk to Bizzell Museum 16:30-17:30 Tour: History of Science Collections, Bizzell Memorial Library, The University of Oklahoma 17:30-19:00 Networking Reception: Thurman J. White Forum Building
- Research Report > New Finding (0.93)
- Overview (0.68)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Mineral (0.72)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.68)
- (2 more...)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (0.93)
- North America > United States > Texas (1.00)
- Europe (0.93)
- Research Report > New Finding (0.93)
- Overview (0.88)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.68)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.47)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (0.93)
Department of Petroleum Engineering, University of Houston, 2. Metarock Laboratories, 3. Department of Earth and Atmospheric Sciences, University of Houston) 16:00-16:30 Break and Walk to Bizzell Museum 16:30-17:30 Tour: History of Science Collections, Bizzell Memorial Library, The University of Oklahoma 17:30-19:00 Networking Reception: Thurman J. White Forum Building
- North America > United States > Texas (0.51)
- North America > United States > Oklahoma (0.43)
- Geology > Geological Subdiscipline > Geomechanics (0.77)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.49)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (0.48)
- North America > United States > Texas (0.51)
- North America > United States > Oklahoma (0.44)
- Geology > Geological Subdiscipline > Geomechanics (0.77)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.49)
Abstract Multi-stage, multi-well completions cause pore-pressures to increase around each stage treated, compound from earlier offset treatment stages, then dissipate as the injected fluid leaks off into the rock formation. Rock stresses change in a dynamic fashion from virgin reservoir stress to an altered stress influencing subsequently treated stages which can restrict slurry propagation from these injections into regions experiencing excess stress. Stress shadows are time-dependent and dissipate over time and return to the virgin stress state. Microseismic focal mechanisms detected from a high-fold wide azimuth surface array can be used to observe and calculate stress changes in the reservoir and constrain the time it takes for stresses to return to the virgin reservoir state. Operators can take advantage of stress changes and contain fractures close to the stages by building stress wedges around subsequently treated stages. After stress dissipates fluid propagates into previously opened fractures leading to poor fracture containment. In this paper, we review the effects of time-dependent stress shadows on multi-well completions in the Wolfcamp Formation in Southeast New Mexico. Then radioactive tracer data from the Niobrara Formation in the Denver-Julsburg basin is analyzed to provide further verification of the time-dependent process. Increased stresses from previous treatments remain elevated for ∼7 days which push fluid injected on neighboring wells away from the stress shadow. Production of well-specific tracer corroborates the hypothesis that local stress-shadows are elevated for ∼7 days which can push fluid from subsequent neighboring wells. After stresses dissipate through the fractures created during the initial stimulation, new tracer on offset wells was produced as much as 3,000 ft away on a neighboring well. Introduction Microseismic monitoring is a proven technology for observing and mapping reservoir response to hydraulic fracture stimulations. The event radiation pattern of the P-wave first arrival reveals advanced characteristics of the fracture describing deformation at the source location when detected using a high-fold wide azimuth surface array. The full-moment tensor can be generally decomposed into the relative percentages of isotropic, double couple and compensated linear vector dipole components (e.g. Aki and Richards, 1980) which fully describes the failure process in terms of volume change, amount of shearing, and other complexities related to deformation. The local stress field can be calculated using a set of focal mechanisms by minimizing the misfit angle between the modeled stress field and the observed focal mechanism slip vectors (Angelier, 1989) where the local stress field extent is defined by the spatial extent of the observed focal mechanisms. The local stress field orientation and relative magnitude can be resolved for a group of microseismic focal mechanisms by minimizing the misfit angle between the modeled stress field and the observed focal mechanism slip vectors for the subsets using a method described by Vavrycuk, 2014.
- North America > United States > New Mexico (0.55)
- North America > United States > Texas (0.35)
- North America > United States > Wyoming (0.34)
- (3 more...)
- North America > United States > Wyoming > Laramie Basin > Niobrara Formation (0.99)
- North America > United States > Wyoming > DJ (Denver-Julesburg) Basin > Niobrara Formation (0.99)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
- (7 more...)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Tracer test analysis (1.00)
Estimating Recovery by Quantifying Mobile Oil and Geochemically Allocating Production in Source Rock Reservoirs
Adams, Jennifer (Stratum Reservoir, Houston) | Flannery, Matt (Stratum Reservoir, Houston) | Ruble, Tim (Stratum Reservoir, Houston) | McCaffrey, Mark A. (Stratum Reservoir, Houston) | Krukowski, Elizabeth (Stratum Reservoir, Houston) | Kolodziejczyk, Daniel (GeoLab Sur S.A., Buenos Aires, Argentina) | Villar, Héctor (GeoLab Sur S.A., Buenos Aires, Argentina)
Abstract Due to highly variable well performance, unconventional reservoir (UR) field development relies heavily on production monitoring to predict total recovery, assess well interference, delineate drained rock volume, and diagnose mechanical issues. Completion design and well spacing decisions depend on accurate recovery estimates from reservoir models, and these can be limited by non-uniqueness in the history matching. Geochemical production allocation can greatly improve operators’ understanding of well performance when integrated with reservoir characterization and in-reservoir P/T monitoring. There are several long-standing challenges in the characterization of UR fluid flow: (i) collecting reservoir samples representative of mobile oil, (ii) accounting for production fractionation over the life of a well, and (iii) determining recoverable original oil in place (OOIP) from contributing zones. Although many metrics and correlations are commonly used, ultimate recovery requires accurate quantification of the provenance of produced fluids and proportion of total OOIP. We have developed a rapid method for quantifying mobile and total oil saturations from water-based mud (WBM) collected, tight cuttings and sidewall core samples using low temperature hydrous pyrolysis (EZ-LTHP). These mobile oils commonly include even the gasoline range compounds, which are the dominant compounds of produced liquids in most mid-continent UR fields, making EZ-LTHP-derived oils representative end-members for geochemical production allocation studies. EUR estimates and production forecasts by zone, are more accurate when calibrated to the mobile oil fraction, rather than to total oil saturation. EZ-LTHP provides this step-change by quantifying the mobile oil fraction in WBM cuttings and, when paired with reservoir volumetrics, allows for better reservoir model calibration and field management. Other industry techniques, such as solvent extraction and vaporization, suffer from the same limitations as log-derived values which are known to overestimate mobile oil in kerogen-rich intervals by incorrectly including kerogen-bound immobile oil. In this paper, we present quantified mobile oil recovery estimates based on integrated geochemical allocation studies from the Vaca Muerta, Neuquén basin, and the Niobrara, Denver basin. In the Vaca Muerta play (Argentina), the organic-rich Cocina and Organico intervals in the Vaca Muerta expelled liquid into intervening good quality reservoir lithologies. However, liquids dominantly are produced from the most organic-rich zones, with evidence of a larger drained rock volume (DRV) during early production. Gas and oil allocations show different DRVs explained by fluid mobility. The Montney play (Canada) shows contribution of liquid from non-target zones. Interbedded zones of indigenous Montney oil mixed with migrated more mature fluid - and major discontinuities in mud gas isotopes - document minimal vertical mixing. Horizontal wells produce gas and oil dominantly from better-quality reservoirs regardless of landing zone, with natural gas bypassing low permeability zones. Accurate estimations of out-of-zone contributions therefore require cuttings/core-based geochemical allocation. A subset of these wells requires additional consideration of production fractionation.
- North America > United States > Texas (1.00)
- North America > United States > Colorado (1.00)
- North America > Canada > British Columbia (1.00)
- (3 more...)
- Geology > Geological Subdiscipline > Geochemistry (1.00)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.35)
- South America > Argentina > Patagonia > Neuquén > Neuquen Basin > Vaca Muerta Shale Formation (0.99)
- North America > United States > Wyoming > Powder River Basin (0.99)
- North America > United States > Wyoming > Laramie Basin > Niobrara Formation (0.99)
- (59 more...)
Abstract As the petroleum industry builds long-term production histories in major liquid-rich unconventional resource (UCR) plays, development geologists and engineers have realized that the production gas oil ratio, petroleum type, and ultimate recoveries do not always match the predictive petroleum system models. Early studies suggested that the UCR petroleum systems require neither traditional petroleum traps nor major migration systems but an organic-rich source within optimal maturity window. Possible explanations for these production discrepancies that were not fully characterized in the initial models include uncertainties in source rock characteristics, primary migration fractionation, fractionation related to storage, and production fractionation. Long-term empirical observations suggest that off-structure migration contribution, trapping mechanisms, and reservoir phase (single versus two) play an important role in the liquid-rich UCR production. If the liquid-rich UCR petroleum system is a well-behaved predominantly local charge system, then the generation product can be estimated with an understanding of the local organic matter type and in situ level of maturity. However, if the UCR play is hybrid with significant migrated down-dip charge contribution, then a more complicated work program will be required to estimate well rates and volumes. The liquid-rich UCR play evaluation should reflect these additional factors, which can greatly impact surface production rate and liquid recovery.
- North America > United States > North Dakota (1.00)
- North America > United States > Texas (0.94)
- Geology > Petroleum Play Type > Unconventional Play (1.00)
- Geology > Geological Subdiscipline > Geochemistry (1.00)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (1.00)
- (2 more...)
- North America > United States > Wyoming > Laramie Basin > Niobrara Formation (0.99)
- North America > United States > Texas > West Gulf Coast Tertiary Basin > Eagle Ford Shale Formation (0.99)
- North America > United States > Texas > Sabinas - Rio Grande Basin > Eagle Ford Shale Formation (0.99)
- (68 more...)
Laboratory Measurements of Permeability and Porosity of the Matrix and Created Fractures: Application to the Pressure Falloff Analysis Following Well Stimulation to Determine Effective Fracture Spacing in Field
Mindygaliyeva, B. (Petroleum Engineering Department, Colorado School of Mines, Golden, Colorado, USA) | Uzun, O. (Petroleum Engineering Department, Colorado School of Mines, Golden, Colorado, USA) | Amini, K. (Petroleum Engineering Department, Colorado School of Mines, Golden, Colorado, USA) | Kazemi, H. (Petroleum Engineering Department, Colorado School of Mines, Golden, Colorado, USA)
Abstract We present an analysis of several multi-rate pressure falloff data following well stimulation in the Utah FORGE enhanced geothermal system (EGS) injection well. The purpose of the analysis was to determine the effective stimulated permeability and representative fracture spacing in the stimulated formation volume. The Utah FORGE geothermal system is a very low-permeability, dry granitoid; therefore, it is necessary to create permeable flow channels in the formation for the injection water to penetrate and extract heat for power generation. We have previously used the same pressure falloff analysis procedure in numerous unconventional reservoirs. We measured the permeability of the matrix rock and the permeability of an embedded fracture, as well as the porosity for several 1-1/2-inch by 2-inch cores. Then, we used the measured permeabilities and porosities in the analysis of multi-rate pressure falloff field data to determine the effective macro-fracture spacings adjacent to the hydraulic fractures. The cores used for the experimental study were outcrop granite, geothermal granitoid, and several unconventional (Niobrara, Codell, Wolfcamp) reservoirs. To determine a representative macro-fracture spacing associated with the hydraulic fractures, the pressure falloff field data analyses were fine-tuned via numerical modeling iteratively. Finally, the experimentally measured core porosities and permeabilities were used as input data for the interpretation of the analytical model used in the pressure falloff test analyses. Such analysis indicates that fracturing fluid entering the rock surrounding the hydraulic fracture is dominated by the micro-fractures. Nonetheless, it is important to note that FORGE rock is highly water wet; thus, water imbibition plays a significant role in water entering the rock pores despite their low permeabilities. Finally, one can appreciate the importance of the stimulated fractured zone both in providing surface area for heat extraction in geothermal wells and for mass transport in improving primary production and EOR in unconventional shale reservoirs.
- North America > United States > Texas (0.47)
- North America > United States > Colorado (0.47)
- North America > United States > Utah (0.46)
- North America > United States > California > Santa Clara County (0.28)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Igneous Rock > Granite (0.90)
- Energy > Oil & Gas > Upstream (1.00)
- Energy > Renewable > Geothermal > Geothermal Resource (0.67)
- Government > Regional Government > North America Government > United States Government (0.47)
- North America > United States > Wyoming > Laramie Basin > Niobrara Formation (0.94)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.94)
- North America > United States > New Mexico > Permian Basin > Wolfcamp Formation (0.94)
- (3 more...)
Abstract Organic-rich shales have been contributing significantly to gas production in the US, led by new developments in horizontal drilling and hydraulic fracturing techniques. Shales have been known to be the source of wellbore instability problems in drilling processes. In the past practice, shales were treated as isotropic for mud window calculation and trajectory design. However, organic-rich shales are anisotropic due to their laminated structure and chemical properties. Thus, it is vital to theoretically and experimentally investigate the anisotropic strength of shale. This study aims to evaluate the anisotropic mechanical properties of shale by tri-axial tests and predict anisotropic shale properties by well-logging data interpretation. Shale mechanical properties (Young's Modulus, Shear Modulus, and Poisson's Ratio) of different bedding plane orientations (0/ 45 / 90 degrees) were studied. Both compressive strength and tensile strength were investigated in different directions. A simple Plane of Weakness and Modified Cam Clay failure criteria were applied to describe the shear failure mechanism. Well logging data were used to connect experimental data and actual field data. Compressional wave velocity was predicted with different inclination angles by stiffness parameters. The predicted compressional wave velocity for a 45-degree inclination angle perfectly fits the field logging data. Experimental data indicated the mud window for a particular shale formation. This study provides an understanding of shale anisotropic strength of different bedding orientations and instructions on safety mud window calculation for directional drilling through shale formations.
- North America > United States > Wyoming > Laramie Basin > Niobrara Formation (0.99)
- North America > United States > Texas > West Gulf Coast Tertiary Basin > Eagle Ford Shale Formation (0.99)
- North America > United States > Texas > Sabinas - Rio Grande Basin > Eagle Ford Shale Formation (0.99)
- (7 more...)