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Third EAGE Workshop on Naturally Fractured Reservoirs
- Conference date: February 5-7, 2018
- Location: Muscat, Oman
- Published: 05 February 2018
24 results
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Fracture Corridors in Fold and Thrust Zone, Devonian Sandstones Icla Syncline (Bolivia)
Authors J. Lamarche, B.D.M. Gauthier, G. Ondicolbery, D. Gallinier, J. Fleury, S. Viseur, M. Chavez and S. ChateléeSummaryFracture corridors are zones of high density of persistent fractures within a rock bearing scarcer diffuse fractures. They occur at all scales from cm to km. The underground hydraulic properties of fracture corridors are well characterized but their structural architecture is poorly constrained because of their sub-seismic resolution. Particularly, their distribution laws and geomechanic conditions of growth remain poorly known. The aim of this study is to decipher the tectonic condition and the geometry for fracture corridors affecting the Devonian sandstones of Huamapampa formation (Icla syncline, Bolivia). This formation is the stratigraphic and structural analogue for many gas field located in the area of the Icla Syncline.
We proceeded a structural analysis in the field at metric scale, an analysis of Digital Outcrop Models from photogrammetry at pluri-metric scale, and 3D structural models with Gocad at the Syncline scale. We show that fracture corridors of the Icla Syncline are early and transverse, and they formed at the early onset of the folding. They formed as anastomosing sets as a function of the stratigraphic distribution of the layered sandstones. Fracture corridors are observed at all scales with a vertical persistence depending on the mechanical stratigraphy.
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Pore Network and Hydraulic Behaviour Characterization of Fractured Sandstones
Authors C. Bossennec, Y. Géraud, I. Moretti and L. MattioniSummaryHydraulic behaviour is controlled, in fault zones, by fracture and pore network properties but the interactions between parameters of the pore, fracture and fault networks and fluid-flow are not fully understood, due to the strong dependence to rock characteristics and external conditions (stress and pressure field, physical and chemical conditions of fluid-flow). To determine the control of these factors on fractured sandstone hydraulic behaviour, an outcrop was selected on the Upper Rhine Graben western border, in the footwall of a normal fault affecting Triassic sandstones. On samples belonging to the damage zone of this fault, pore and petrophysical properties were determined using mercury intrusion porosimetry (MIP), NMR relaxometry and petrography (SEM, cathodoluminescence). The matrix pore network dimensions vary depending on the distance between the sample and the closest fracture plan, and the behavior is different for the two facies identified. These variations are linked with differing mechanisms of deformation and diagenesis for each facies, but both result in an enhanced drainage in the “damage” zone around the fracture. At the fault scale, the hydraulic behaviour can be determined by combining the global fracture intensity and the effect of each single fracture damage zone.
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Understanding Controls on Fracture Geometry Using a Geomechanical Model of Fracture Propagation
More LessSummaryFracture prediction and modelling is one area where there is scope for significant technical advance. At present fractures are modelled either by modifying the bulk rock properties to take account of the fracture porosity and permeability, or using stochastically generated Discrete Fracture Network (DFN) models. Both methods tend to give a poor history match because the distribution, orientation, length and connectivity of fractures in the subsurface is not well constrained. We propose to improve the prediction of fluid flow in a fractured reservoir, by developing an algorithm to accurately model the key parameters of a fracture population (fracture density, fracture size distribution, and connectivity) based on the geomechanics of fracture nucleation and propagation, and using this to generate a mechanically-based DFN that more accurately represents the subsurface fracture geometry. We will use a preliminary version of this model to demonstrate some of the key geomechanical controls on fracture geometry, such as fracture propagation rate and strain anisotropy, and illustrate the different types of fracture network that can develop under different conditions.
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DFN Simulation to Quantify Fracture Density Uncertainty in Wells. Impact of Some Typical Geological Constraints
Authors B.D.M. Gauthier and M.H. GarciaSummaryIn naturally fractured reservoirs characterization and modelling, a key fracture parameter is fracture density. Classically, fracture density along well trajectories is estimated from image log data interpretation using various methods and applying corrections to account for 1D sampling bias. Various methods and concepts are then used to extrapolate/interpolate the fracture density beyond the well control. The well density data are often assumed to be hard data (precisely known). It has been showed, however, that this should not be the case. Consequently, estimating fracture density uncertainty is a key issue in fracture modelling.
Methods have been proposed to estimate fracture density and related uncertainty but they are based on assumptions (fractures nearly parallel to the borehole, randomly distributed fractures) that are always met. The fracture density can also be controlled by many different geological constraints: fracture clustering, bed thickness, stress shadow effect...
This paper presents a methodology to simulate DFN that can be controlled by various types of geological constraints in order to assess the uncertainty attached to wells drilled through the simulated DFN. Uncertainty tables are generated, which can then be applied to well fracture data in real NFR reservoirs.
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Maps of Natural Fracture Reactivation Likelihood: a Comparison Between Homogeneous and Heterogeneous Stress Fields
Authors R. Plateaux, J.P. Joonnekindt, F.M. Maerten and L.M. MaertenSummaryPrevious methods (e.g.: Zoback, 2007) for fracture reactivation assumed a uniform stress field to apply on either fault or fracture. However, local stress is often perturbed by different mechanisms such as faulting, folding, mechanical contrast between layers, salt body effect or even subsidence caused by reservoir production. Ignoring local perturbation on the stress field can lead to unrealistic reactivation map and dramatically fail to assess fracture seal integrity. In the present work, we propose to compare fracture reactivation maps based on a uniform stress field (classic method) and a more realistic heterogeneous stress-field using a Mohr-Coulomb failure criterion. To do so, we introduce a geomechanically-based stress inversion method iBem3D that generates stress-field controlled by faulting and regional tectonic stress ( Maerten F., 2010 ; Maerten et al, 2016a , 2016b ; Maerten F. and Maerten L., 2016c ), which are the mechanisms considered in this present work. The resulting maps show that reactivation can be dramatically different in places where seal integrity can be breached in places for uniform stress-field while likely intact for the heterogeneous stress field.
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Aperture Modelling for the Flow-Based Determination of Fracture-Matrix Ensemble Saturation Functions for Naturally Fractured Reservoirs
Authors S.K. Matthai, M. Sedaghat and H. AgheshluiSummaryDFN (fracture-only) and DFM (fracture and rock matrix) modelling is a rapidly growing field. While more and more geometrically realistic models get published, fracture aperture is often treated as single-valued or as set-by-set constant parameter. However, this is incompatible with field observations indicating variable apertures, lognormal or multimodal aperture distributions, and-or partial sealed fractures in naturally fractured hydrocarbon reservoirs.
This presentation explores how realistic aperture variations across multiple sets of intersecting fractures can be modelled taking into account geometry (orientation, length versus frequency distributions, abutting relationships), mechanical rock properties, in situ stress, and pore pressure. New algorithms are used to account for fracture dilatation, asperity gliding, asperity crushing, and dissolution-precipitation. They are used in concert to produce physically realistic aperture models. These techniques are already part of a fracture modeling and upscaling workflow that has been applied in the field, and flow simulation highlights the first-order control that the ensuing variable apertures exert on permeability, anisotropy and flow localisation.
The key remaining challenge, however, is the modeling of mechanical interactions between fractures and rock fragments. As an important aspect of this, here we address whether far-field-stress-based fracture aperture computations are applicable to rock fragmented by multiple fracture sets.
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Fracture Aperture in Flow Models: to Average, or not to Average?
More LessSummaryFracture networks are heterogeneous systems creating anisotropic flow patterns, though field-scale flow models of fractured reservoirs use up-scaling of the fracture network to effective properties to model flow. We study the impact of upscaling aperture from a realistic aperture model, where aperture is defined by a stress-aperture relation that considers aperture variations within single fractures, to an arithmetically averaged distribution. This analysis is done through calculation of the equivalent permeability tensor of a discrete fracture and matrix flow model, taking into account different contrasts between fracture and matrix permeability. Results show that a strong equivalent permeability anisotropy emerges for a low matrix permeability, and that accurate representation of fracture aperture is as important as the fracture topology, particularly when the fracture matrix permeability ratio is large. The orientation of the permeability tensor varies with varying rock matrix permeability, reflecting anisotropy of the permeability that is impossible to extract from the fracture patterns itself. The results also highlight that utilizing a constant aperture for the fracture network may not reproduce the true anisotropy of the permeability. Utilizing an equivalent aperture in flow simulations introduces errors in both the direction and magnitude of principal permeabilities and the equivalent permeability anisotropy.
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Hybrid Modelling of Fractured Reservoirs Using the Effective Medium Theory
Authors D.L.Y. Wong, F. Doster, S. Geiger and A. KampSummaryNaturally Fractured Reservoirs usually exhibit power law length distributions which do not possess any characteristic length scale, rendering the use of continuum methods difficult. This necessitates the adoption of hybrid models that represent a subset of the fractures as continua and the remainder as discrete fractures. However, the appropriate partitioning of fractures into these two subsets is an unresolved issue. In this regard, we propose a workflow which utilizes the Effective Medium Theory (EMT) by Sævik et al. (2013) as both an upscaling tool and a partitioning guide for single porosity hybrid modelling. EMT is used to find the largest non-percolating subset of small fractures which will be upscaled into a single porosity background. The remaining fractures will be represented explicitly. This workflow allows reservoir engineers to systematically design an appropriate partitioning strategy for hybrid modelling. The paper explores this workflow via a two-part study. Part one validates the accuracy of EMT. Part two compares simulation results generated from different partitioning choices. The results show that the output of EMT matches that of numerical upscaling and that the workflow proposed leads to a hybrid model that is fit-for-purpose with a reduction in computational costs.
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Integrated Approach for Fractured Basement Characterization – the Lancaster Field, a Successful Case Study in the UK
Authors D. Bonter and R. CarvajalSummaryHurricane Energy, founded in 2005, is a leading O&G company in fractured basement exploration in the UK. Hurricane currently operates licences in West of Shetland with a 100% working interest and, while having further exploration and appraisal opportunities, the company is focused on bringing the Lancaster Field (37 MMbbl 2P reserves & 486 MMbbl 2C resources) into development with an Early Production System (EPS).
Throughout a successful drilling campaign since 2009 to date, Hurricane Energy has acquired a comprehensive, high-quality static and dynamic dataset using off-the-shelf technology, which is often not optimised for fractured basement reservoirs. However, by using the acquired data in innovative ways, Hurricane has been able to incorporate the recent characterization studies to update and calibrate the subsurface models in use to support a field development plan for the Lancaster Early Production System (EPS).
This paper summarizes the methodologies and workflows used by Hurricane Energy to integrate concurrently all the available interpreted field data to feed a sound high-resolution representative subsurface model of Lancaster which contributed to confirm an increased estimate of recoverable volumes, on a 2C basis, from 200 million barrels to just under 600 million.
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Realizing the Multi-Scale Nature of Fractured Reservoirs in Dual Porosity Dual Permeability Models
Authors L. Wei and K. RawnsleySummaryFracture systems observed in naturally fractured reservoirs (NFRs) tend to be hierarchical ( Figure 1 ): (1) regional faults going through the reservoir or forming the reservoir boundaries and in-field seismically mappable faults; (2) fracture corridors sometimes associated with faults and (3) background fractures. Vertically, background fractures tend to be impacted by mechanical stratigraphy while fracture corridors and faults usually cross-cut through the reservoir units ( Figure 2 ). For fractured carbonate reservoirs, background fractures are usually more abundant but with much lower effective permeability than fracture corridors, and must be treated differently in a reservoir model.
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Fracture Model Permeability and Porosity Calibration Using Core and Pressure Transient Analysis Data
Authors P. Richard, S. Lamine, P. Swaby, C. Pattnaik, V. Kidambi, R. Narhari, X. LeVarlet and Q. DashtiSummaryThe North Kuwait Carbonate (NKJG) reservoirs are currently under development by KOC (Kuwait Oil Company). The appraisal and development of the NKJG offer challenges such as lateral variations in reservoir quality, tight to very tight reservoirs and natural fracturing to a varying degree spatially. The presence of open and connected fractures is one of the key elements to achieve a successful development. Also, the presence of fracture corridors increase the risk associated with drilling. Numerous fracture modelling studies have been supporting both appraisal and development strategies of the fields. A structural evolution model has been developed based on field observations and linked to the regional phases of deformations. Detailed fracture characterization using static BHI (bore hole images) and core data as well as dynamic data has been carried. A wide spectrum of scales of discrete fracture network (DFN) models have been built. The smaller scale models have supported the planning and drilling activities of future appraisal wells has been carried out. The larger scale (i.e. full field) have been used to complete production history matching and forecast. An invaluable set of core and pressure transient analysis data have been acquired with the objective the reduce the uncertainty inherent to the sub-surface natural fracture network.
This paper concentrates on the specific aspect of the calibration of the upscaled porosity and permeability properties from the DFN’s.
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Progressive Multi-zone Pressure Transient Test Design and Interpretation in Ansagan Fractured Carbonate Reservoir
Authors Y. Kaipov, T. Kulagina, M. Aimagambetov, B. Yeskozha, A. Burlibayev and A. ZhandinSummaryNew methodology of pressure transient test design and interpretation demonstrated in this paper allows the quantitative estimation of fractured reservoir parameters and use of the seismic, logging and core data at the stage of well test planning to divide the intervals of interest for well testing depending on difference in fracture intensity and predicted flow regimes and estimate the required build-up time to extract the maximum information about the each formation and confirm the possible heterogeneity or fractured regions at a distance from the well by conducting the global sensitivity analysis of BU signal on matrix and fractures parameters
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New Calibration of Fracture Properties Using Geological Well-Testing
Authors D. Egya, S. Geiger, P. Corbett, J.P. Norgard, S. Hegndal-Andersen and L. SundalSummaryA geological well testing model containing fractures and matrix was built to match an observed complex well test response in a reservoir that was known to be fractured. The resulting match of a well intersecting minor fractures near a major fracture was considered a good match in consideration of alternative geological scenarios. This match leads to a better understanding of the key reservoir features to reliably support development decisions
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Flow Diagnostics for Naturally Fractured Reservoirs
Authors V.E. Spooner, S. Geiger and D. ArnoldSummaryCarbonate reservoirs contain much of the world’s remaining hydrocarbon resources. These reservoirs are challenging to characterise and forecast production due to uncertainty in the fracture distribution and wettability. Ideally a large number of models needs to be simulated to quantify uncertainty but, due to time constraints, typically only a small subset of scenarios is considered. A dual-porosity module with a flow diagnostic toolbox has been implemented into MRST by the Carbonate Reservoir Group at Heriot-Watt University. The new diagnostics provide useful information that approximates the reservoir dynamics and matches full-physics simulation results, but can be obtained in a fraction of the time needed for simulation. Using flow diagnostics hence enables the fast screening and ranking of vast numbers of static models for fractured reservoirs. This enables us to consider the full range of geological uncertainty whilst minimising the number of models required for traditionally heavy simulation tasks such as, production forecasting, optimisation and uncertainty analysis that rely on full-physics simulations. Flow diagnostics hence complement and extend knowledge obtained from conventional fractured reservoir characterisation, calibration, and simulation workflows.
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Deciphering Diffuse Fractures from Damage Fractures in Fault Zones and Their Effect on Reservoir Properties in Urgonian Carbonates
Authors I. Aubert, J. Lamarche, P. Leonide, N. Semmani, R. Bourezak and R. CastillaSummaryIn carbonate reservoirs, fracture networks impact reservoir properties. Unlike background fractures, fault-related fractures are heterogeneously distributed along the fault zone and can form drains or barriers depending on the diagenetic history. The aim of this study is to identify the structural and diagenetic attributes of both types of fractures and to determine their respective impact on the reservoir properties. To this end, our study focused on an outcrop of Urgonian carbonates in SE France which affected by poly-phase tectonics (burial, extension, folding and strike-slip). We made a 290m scan-line along the outcrop to characterize fracture network inside and outside five fault zones and a diffuse shear zone. The diagenetic analysis on 45 thin sections in LPA and cathodoluminescence evidenced diagenetic stages that have affected the host rocks since the Barremian. This study allowed to identify 2 sets of diffuse early fractures. One set was reactivated by the faults while neo-formed fractures appeared. The diagenetic processes in faults zones and diffuse fractures differ too, and specifically affected the petrophysical properties of the host carbonates.
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Controlling Factor Analysis and Modeling of Fractures in Volcanic Rocks on The Basis Of Outcrop Database
More LessSummaryResearch results show the following: first, Structures of rock fragment belt, en echelon fold, fracture corridor and pinnate cleavage are likely present near faulting belt, and there was a conspicuous negative exponential correlation between fracture frequency and distance to main fault set. Second, this paper modified the weathering crust model of fractured volcanic rock, further subdividing it into 4 sections of soil layer, water-resolved, fracture and bedrock downward, which could be used to better explain the vertical distribution pattern of subsurface fractures in volcanic rocks. Third, the volcanic explosion breccia is the most preferable lithology for fracture, followed by overflow lavas, and the least one is tuff. Fracture favors acidic volcanics more than neutral and basic volcanics. Simulation runs revealed that, the producer connected directly by fracture with injector was flooded soon after injection, while the producer connected by fracture and matrix combination with injector presented a displacement feature resembling matrix flow. It is therefore inferred that, although with fracture present, the impact of matrix permeability of fractured volcanic reservoirs on water-flooding development cannot be ignored.
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Calibration of Fracture Models Using Multi-Scale Outcrop Analogues – the Importance of Mechanical Stratigraphy
Authors R.R. Jones, S. Kokkalas, J.J. Long, S.E. Daniels, S.R. Gilment, M.W. Wilkinson and D.M. OxladeSummaryMechanical layering exerts a critical influence in the development of fracture systems within reservoir units, therefore understanding the distribution of mechanical packages, on the scale of individual beds up to entire stratigraphic formations or groups, is essential when modelling natural fracture systems.
Outcrop analogues provide critical insight into the mechanical stratigraphy that cannot readily be derived from sub-surface data alone, although image logs or core are very useful to allow outcrop-derived interpretations of the thicknesses and proportions of different mechanical packages to be suitably calibrated.
Scaling of fracture properties is important for successful prediction of reservoir properties. Fracture size distributions are critical, but require reliable data over many orders of magnitude. Combining traditional field studies with modern geospatial technologies, together with sub-surface data when available, provides reliable, robust inputs for fracture modelling.
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Dimensional Threshold for Fracture Linkage and Hooking
Authors J. Lamarche, A. Chabani and B.D.M. GauthierSummaryFracture connectivity in rocks depends on spatial properties of the pattern including length, abundance and orientation. When fractures form a single-strike set, they hardly cross-cut each other and the connectivity is limited. Linkage probability increases with increasing fracture abundance and length as small fractures connect to each other to form longer ones. A process for parallel fracture linkage is the hooking, where two converging fracture tips mutually deviate and then converge to connect due to the interaction of their crack-tip stresses. Quantifying the processes and conditions for fracture linkage in single-strike fracture sets is crucial to better predicting fluid flow in Naturally Fractured Reservoirs. For 1734 fractures in Permian shales (Lodève Basin, SE France), we measured geometrical parameters, characterizing the underlapping, overlapping and linkage stages, deciphering the threshold values, shape ratios and limiting conditions. The hook affect fractures of similar length (L2≈L1). Its set up depends on the spacing (S) and fracture length (Lh) with S ≈ 0.15 Lh. Once initiated with the fracture deviation length (L) L≈ 0.4 Lh , fractures reach the link only when spacing is reduced to S ≈ 0.02 Lh and the convergence (C) is <0.1 L. These conditions apply to multi-scale fractures.
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Morphological Changes of Carbonate Deformed Clasts in a Neogene Fault Zone
Authors O.A. Igbokwe, M. Mueller, O. Abah, G. Bertotti and A. ImmenhauserSummaryWe studied the morphological changes of a deformed shallow-water carbonate -that has been dolomitized at an early diagenetic stage in a Neogene fault zone. Orthorhombic rock lithons characterise the structural fabric of the fault zone. Lithons are generated from the intersection of fracture sets. Fractures intersect at approximately 90 +/− 20o and dip from steeply inclined to vertical with dominant strike directions W-SW. The thickness and the spacing of the lithons vary between 1 and 35cm and 0.5–5cm respectively. Their geometrical analysis gives an overall mean aspect ratio (mAr) values of 1.5, that is, mean aspect ratio of 1.6 (large-sized), 1.5 (Medium-sized) and 1.5 (small-sized) with standard deviation (sd) between 0.4 - 0.6. We proposed a general deformation and morphological change of clast model in carbonate fault zone assuming elastic deformation. Fluids play a great role and they are linked with the dolomitization of the brecciated rocks.
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Diffraction Imaging Via Depth-Oriented Seismic Decomposition: High-Definition Characterization of Fracture Fields
Authors E. Landa, K. Smirnov and C.M. PaleariSummarySeismic data decomposition into depth Local Angle Domain [LAD] opens a new way in creating high fidelity and high resolution seismic images, especially in complex geological settings, including fractured carbonates. Two LAD-derived complementary sets of angle common-image gathers, dip and scattering/opening, allow the data selection for the optimal illumination and the optimal aperture in seismic imaging. Moreover, dip angle gathers are core for separating the reflective and the diffractive components of the full seismic wavefield, procedure which is fundamental for diffraction imaging.
Seismic diffraction is a key ingredient in establishing resolution, and it is a direct seismic expression of small structural and lithological discontinuities in the subsurface. Diffraction images define such discontinuous small-scale geo-features, with high resolution and high confidence.
The integration of diffraction-imaged data with standard seismic-derived volumes like coherency and AVAZ/VVAZ anisotropy (all obtainable from the same survey), allows the reliable characterization of fracture fields.
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Discrepancies in Fracture Related Anysotropy Direction Obtained from Multi Scale Data
Authors I. Bogatyrev, E. Kharyba, K. Ezhov, T. Olneva, D. Semin and A. InozemtsevSummaryThe naturally fractured reservoirs play very important role in hydrocarbon production within Panonian basin. The well production crucially depends on the possibility to penetrate the fractured zone Fracture network cause significant anisotropy of rock properties which, in turn, could be studied with a combination of seismic and wellbore data.
AVAZ inversion and full-wave acoustic logging coupled with borehole images were implemented to estimate fracture parameters in order to predict zones of high productivity. The independent techniques revealed differences in estimated fracture direction. Discovered descrepancies are explained by different scales of the applied methods and should be taken into consideration during well planning.
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Calibration and Optimisation of Foam EOR in Fractured Carbonate Reservoirs
Authors A. Al-Maqbali, V.E. Spooner, D. Arnold and S. GeigerSummaryFractured carbonate reservoirs are known for its complexity, this has big impact on production especially when EOR methods are used. Foam is known for its potential to improve recovery by diverting the flow to the poorly swept regions. In order to capture the uncertainties associated with foam EOR in fractured carbonates, multiple simulations of different geological scenarios must be tested.
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Tensorial Fracture-Matrix Ensemble Relative Permeabilities in Naturally Fractured Reservoirs: Evidence from Discrete Fracture and Matrix Simulations
Authors M.S. Sedaghat, S.M. Matthai and S.A. AzizmohammadiSummaryThe prediction of water breakthrough and oil recovery for naturally fractured reservoirs (NFRs) cannot be performed accurately without dynamic upscaled relative permeability functions. Relative permeability is commonly assumed to be a scalar quantity, although a justification for NFRs has yet to be presented. In this study, we show how accurate this assumption is for fracture-matrix ensemble relative permeabilities determined by numeric simulations of unsteady-state core flooding.
Numerical determination of relative permeability requires a realistic flow model, a spatially adaptive simulation approach and a sophisticated analysis procedure. To fulfil these requirements, we apply discrete fracture and matrix modelling to well characterised hm-km outcrop analogues. These are parametrized with aperture, permeability, and capillary pressure data. Fracture attributes are allowed to vary from segment to segment, trying to emulate in situ conditions. The finite-element-centered-finite-volume method is used to simulate two-phase flow in the fractured rock, considering different wettability conditions.
Our results indicate that the ensemble relative permeability of 2D digital NFR outcrop analog models is a tensor property. The tensors are not necessarily symmetric, and their eigenvalues are not always equal to the diagonal terms. Also, the off-diagonal terms can determine the type, i.e., counter vs co-current imbibition, and the direction of imbibition.
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Static Reservoir Modelling of Fractured Carbonates: Multi Scenario Approach, Case Study from the Potwar Basin, Pakistan
More LessSummaryThe Dhurnal field is a mature hydrocarbon accumulation discovered in 1984 and located 60 km South West of Islamabad, Pakistan in the Potwar basin, at the foothills of the Himalayas. To date, seven wells have been drilled in the Dhurnal structure and are producing hydrocarbons from several stacked carbonates reservoirs aging from the Permian to the Miocene. Due to the tight nature of the reservoirs, hydrocarbon production is enabled by the existence of an extensive fracture network.
The ongoing Dhurnal Reservoir Modelling project represents the last opportunity to identify late life opportunities and to ensure that no stones are left unturned (bypassed Oil).
A state of the art fractured carbonates reservoir static model exercise has been conducted to:
- Serve as platform for history matching the historical performance of the field
- Subsequently Locate the Remaining Oil
- Forecast with adequate uncertainty ranges potential further development opportunities
- Establish a standardized workflow to routinely model fractured carbonates reservoirs in the Potwar Basin.
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