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Journal of Petroleum Science & Engineering
Elsevier Science B.V.
Journal of Petroleum Science & Engineering

Elsevier Science B.V.

0920-4105

Journal of Petroleum Science & Engineering/Journal Journal of Petroleum Science & Engineering
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    A comparative study to accelerate field development plan optimization

    Ashish Kumar LoombaVinicius Eduardo BotechiaDenis Jose Schiozer
    14页
    查看更多>>摘要: Rigorous and continual advancement in the computational domain have drastically reduced the time consumed for simulations. Despite this, the heterogeneity and requirement to use compositional models, among constraints such as field size, can still thwart the optimization of the field development plan (FDP) in terms of time spent. To address this, we proposed and compared different techniques to underscore how to optimize FDP efficiently under uncertainty using an example of a giant benchmark field. We compared four workflows to improve the efficiency of the optimization process. Method 1 uses a full-field model (FFM) approach with an intelligent selection process to eliminate the poorest FDPs. As it is usual to divide a field into sectors for risk-aversion and strategic purposes, Method 2 uses an isolated-sector approach to reduce average simulation time. Method 3 employs the FFM approach to perform the optimization using only the monetary value of the partial life of the field. Method 4 uses a cluster-based search space reduction technique for a predictive analysis from the technical results obtained with partial simulations, which are similar to Method 3. To ensure good decisions, the optimized FDP was always implemented in the FFM with complete field-life at the end of all methods. All proposed workflows are promising in terms of efficiency, acknowledge the entire envelope of uncertainty, and consider multiple scenarios to improve the chances of success of the optimized FDP in the real field. Aside from obtaining good results when compared to traditional methods, we also saved 80-93% of the computational time with these methods. Thus, one can reduce exorbitant costs and delays in performing the FDP optimization. As anticipated, we observed a generic trade-off between decreasing computational time and increasing field objective function. Despite this, using a new algorithm with predictive analytics in Method 4 produced the best improvement within the shortest timespan, which demonstrates that one can use shorter-term data to understand a field's non-linear response. Numerous authors have already presented various algorithms to optimize an FDP. Despite the existing computational capabilities, these algorithms are still inept at developing a field with time-consuming simulation models. Unlike previous studies, this work presents practical solutions to assist field development, considering probabilistic scenarios to capture associated uncertainty. We also discuss the advantages and disadvantages of the methods to establish their application in different situations.

    Multiple hydraulic fractures growth from a highly deviated well: A XFEM study

    Yun ZhouDiansen YangMeirong Tang
    18页
    查看更多>>摘要: A fully coupled extended finite element (XFEM) model is presented to investigate the effect of different well types (highly deviated and horizontal wells) on simultaneous growth of multiple fractures. The importance of the use of deviated wells is briefly described and the governing equations for multi-cluster hydraulic fracturing in a saturated porous media are stated. The weak forms of both stress equilibrium and fluid mass continuity equations are turned into a system of linear equations through XFEM-type enrichments in space and Newmark scheme in time, which are solved by Newton-Raphson iteration method. In addition, the secant method is employed to impose the pressure continuity and mass conservation conditions at the fracture-well intersections. A numerical example with considering the simultaneous propagation of four hydraulic fractures is first adopted to validate the proposed numerical model. Several examples are then employed to investigate the influence of operational parameter, deviation angle, fracture spacing, placement and number on final fracture patterns. Numerical results show that coefficient of variation in multiple fracture heights for high-angle well is lower than that for horizontal well for all fracture placements. The opposite growth directions for two neighboring fractures, partially arising from the height difference at fracture-well intersection points, can reduce the stress shadow effect, thus promoting uniform growth of multiple fractures. Those results potentially unveil the causes for higher oil and gas production rates measured after multi-cluster hydraulic fracturing along highly deviated wells.

    Changes to interfacial characteristics by low salinity water/nanoparticle flooding in carbonate reservoir

    Jeong Woo KimSunlee HanJinju Han
    10页
    查看更多>>摘要: Nano-enhanced oil recovery (nano-EOR) and low salinity water flooding (LSWF) has been considered a promising EOR method. We investigated the interfacial properties between the nanofluid, oil, and rock when both methods were applied simultaneously to the carbonate reservoir. SiO2 and Al2O3 nanoparticles (NPs) were used, and interfacial tension (IFT) and contact angle were measured using a drop shape analyzer to investigate the effect of each NP and low salinity water (LSW). In addition, to analyze the complex oil recovery mechanism caused by each interfacial property change, we generated a capillary pressure curve using IFT and contact angle. As a result, LSW significantly reduced contact angle due to the charge screening effect, which increases the NP adsorption on the rock surface. Si02 NPs with a negative zeta potential considerably decreased contact angle by electrostatic attraction with carbonate rock which has a positive zeta potential, but its effects on IFT were minimal. Meanwhile, Al2O3 NPs, which have relatively weak hydrophilicity than SiO2, migrated to oil after vortexing and significantly reduced the IFT. Although each NP improved the recovery by a different mechanism, they considerably decreased the capillary pressure that oil can be displaced more efficiently. In this study, Al2O3 NPs are more appropriate for carbonate rock due to their high IFT reduction effect, but additional experiments are essential for the various NPs and salinity conditions in the perspective of the interfacial property alteration.

    Wellbore storage removal in pressure transient analysis for gas wells

    Mina S. KhalafNoha SolimanAhmed H. El-Banbi
    13页
    查看更多>>摘要: Wellbore storage (WBS) occurs due to fluid loading/unloading in the wellbore, when a well starts production or is shut-in. This phenomenon creates variable sandface rate and time lag between the surface production rate and the stable sandface rate. Wellbore storage effects can sometimes conceal important information and complicate well test analysis and interpretation. In well tests that suffer from long WBS, removal of WBS effects can usually recover important features in the reservoir signal and lead to significant improvement in identifying the reservoir model and calculating reservoir parameters. Until recently, WBS removal relied on direct deconvolution techniques that require accurate well test data. Presence of noise in the pressure and rate data usually makes direct deconvolution methods unstable. Well test pressure and rate data usually suffer from some noise, and therefore, application of direct deconvolution methods may not work. This work develops a stable technique to eliminate WBS effects present in gas wells. The technique uses two deconvolution steps and applies the recently developed deconvolution algorithms (e.g. von Schroeter algorithm) for stable computations. Unlike the direct deconvolution methods (which become largely unstable when minor noise is present in data) in WBS removal, the proposed approach also extends the reservoir signal over both the drawdown and buildup periods. The new technique is applied to simulated gas well test data in a variety of conditions for validation. The applications considered different well/reservoir models and included different levels of data noise. The technique is also applied to a field case to show the value of the proposed approach. The findings of this study can be used to eliminate WBS effects and recover reservoir signal. It has applications in variety of gas reservoirs where WBS can hide information such as low permeability reservoirs, natural fractured reservoirs, small reservoirs, and wells with large wellbore volume. The reservoir properties calculated from reservoirs after removal of WBS can be used in further calculations such as estimates of gas in place and well productivity to help engineers optimize their wells/reservoirs performance.

    The diagnostic criteria of borehole electrical imaging log for volcanic reservoir interpretation: An example from the Yingcheng Formation in the Xujiaweizi Depression, Songliao Basin, China

    Tao NianGuiwen WangDan Cang
    17页
    查看更多>>摘要: Electrical image log can be used to establish volcanic fades sequences, and thus used for reservoir interpretation, while the key is to set up available diagnostic criteria to guide lithology, structure and fades interpretation. A total of 50 datasets of borehole image logs, combined with wireline logs and cores, have been collected in the Yingcheng volcanic reservoir in the Xujiaweizi Depression, Songliao Basin, providing an opportunity for repeated image interpretation in the volcanic strata. The interpreted lithology includes rhyolite, dacite, andesite, basalt, welded ignimbrite, tuff, volcanic breccia and agglomerate, sedimentary tuff, sedimentary volcanic breccia and agglomerate. The volcanic structures are calibrated in terms of fluidal and deformed fluidal structure, vesicular and amygdaloidal structure, and massive structure. Based on the lithology and structures, volcanic fades including volcanic sedimentary fades, effusive facies, explosive fades and volcanic conduit fades, have been further determined. Layered structures of the weathered volcanic crusts are shown in borehole images and mainly developed at the top of the Yingcheng Formation. Borehole images indicate that Samax direction in the area is consistent with the regional SHmax direction, with a preferable trending of 88°. Four sets of filled/open tectonic fractures are developed with approximately north, south, NNE and NW dipping. It infers that different volcanic facies can be well correlated between wells, and tectonic movements have a slight influence on the Yingcheng volcanic strata. The proposed diagnostic criteria and the workflow can be referred for a direct image interpretation in volcanic reservoirs or ocean drilling programs when cores are unavailable.

    A review of the mechanics of heavy-oil recovery by steam injection with chemical additives

    Randy Agra PratamaTayfun Babadagli
    18页
    查看更多>>摘要: The efficiency improvement of steam injection (more oil, less steam) is a critical challenge in heavy oil recovery. Using chemical additives is one option to achieve this efficiency improvement, but many different mechanisms are involved in this process, and different considerations need to be taken depending on the existing conditions and chemical type. For example, many tested thermally stable chemicals-surfactants, nanofluids, and water-soluble solvents-were able to favorably alter the wettability. The underlying physics behind this favorable alteration and other mechanisms are not well comprehended yet, especially for new generation chemicals under thermodynamic conditions. The comprehensive review and discussion presented in this paper mainly focus on the improvements on heavy-oil and bitumen thermal recovery, particularly on the late-stage steam injection as well as the fundamentals of the residual oil development mechanism post-steam injection. More importantly, this paper presents the experimental result-based, and comparative analyses of potential chemical additives (alkali, ionic liquid, surfactants, hydrocarbon solvents, water-soluble solvents, and new generation chemicals) applied to improve heavy oil recovery. This analysis is necessary not only to further evaluate the chemical's performance on the recovery improvement-specifically at the late-stage steam injection-but also to investigate the underlying recovery mechanisms, such as viscosity reduction, wettability alteration, interfacial tension (IFT) reduction, foaming effect, and emulsification presented by the chemical additives. Based on the outputs obtained from different experimental methodologies, the underlying recovery mechanisms induced by the potential chemical additives were identified. The results revealed that synergy among the recovery mechanisms presented by chemical additives could potentially improve the heavy oil recovery by more than 80% during steam injection. A comprehensive analysis of the mechanics of the heavy oil recovery provides valuable substantiation and understanding, honoring the potential implications of utilizing chemical additives as potential steam additives to the heavy oil recovery process. The results present beneficial information and recommendations for oil fields operating under steam injection applications.

    Multi-scale and multi-technique characterization of hybrid coquinas: A study case from the Morro do Chaves Formation (Barremian-Aptian of Sergipe-Alagoas Basin, Northeast Brazil)

    Marcos NunesBruno ValleLeonardo Borghi
    17页
    查看更多>>摘要: The coquinas are carbonate rocks with variable content of siliciclastics and have a complex porous framework that implies an issue for their characterization as reservoirs. Furthermore, these rocks are considered important reservoirs due to the giant accumulations in the Campos and Santos basins (Coqueiros and Itapema formations, respectively), increasing the interest in understanding and characterizing these complex and heterogeneous lithologies. In this context, this study aims to introduce a novel method of petrophysical characterization of coquinas through a multi-technique and multi-scale approach in a continuous well core of approximately 135 m, drilled in the 'Atol Quarry', Sao Miguel dos Campos County, Alagoas State. Based in mineralogical content, x-ray attenuation and pore type, seven tomofacies were defined using computerized tomography and allowed a representative sampling (plugs and thin sections). Five rock types were defined based textural aspects (tomofacies and petrography) and petrophysical data (routine core analysis and micro-computerized tomography). The rock types were compared to well logs, establishing boundary values and distributed along the whole well, in an upscaling process from thin-section and plugs (microscopic scale) to the well core (macroscale). The Morro do Chaves Formation core was divided into two portions: upper portion, with better reservoir quality and greater influence of mineral dissolution; and lower portion, a poor reservoir quality portion influenced by cementation processes. The upscaling method using the concepts of tomofacies and rock types proved to be a successful way to improve the understanding of reservoir characterization in heterogeneous of complex limestone successions, which can improve the recovery factor and aid in the field development.

    Experimental study on liquid production law, oil recovery mechanism, and influencing factors of water huff-n-puff in the tight sedimentary tuff oil reservoir

    Shuai LiShenglai YangXinyuan Gao
    17页
    查看更多>>摘要: Water huff-n-puff (WHP) is an effective means of improving the recovery factor (RF) of the tight sedimentary tuff oil reservoir. In this study, through the tight oil WHP experimental platform monitored by online nuclear magnetic resonance, the liquid production law, oil recovery mechanism, and influencing factors of tight sedimentary tuff WHP were investigated. The results show that the optimal cut-off pressure and depletion rate of core natural energy depletion are 5 MPa and 0.3 ml/min, respectively. WHP can effectively improve the RF of the tight sedimentary tuff, and the core RF increased by 23.04% after five cycles of the WHP. In multiple cycles of the WHP, the volume of the injected water and produced liquid of each cycle is relatively stable, but the oil production gradually decreases. The first three cycles of the WHP are high-efficiency stage, the fourth and fifth cycles are low-efficiency stage, and there is no WHP value after the fifth cycle. The range of the WHP oil production gradually extends from the injection end to the far end with increasing huff-n-puff cycles, and the oil comes mainly from the medium pores of the core. Both elastic and imbibition displacements are important mechanisms for WHP oil recovery. In five cycles of the WHP, the proportion of elastic displacement oil production to the total oil production of each cycle was 89%, 88.22%, 85.92%, 22.78%, and 0%. When the water injection pressure of each cycle is fixed, the elastic displacement oil production of the WHP is mainly affected by the water shielding, multiphase flows resistance, carrying and scouring, and capillary resistance. Meanwhile, imbibition displacement oil production is mainly affected by the contact area of oil and water. The RF of the WHP has a parabolic relationship with the water injection and reinjection pressures, and a positive correction relationship with the well soaking time.

    Two parameter optimization methods of multi-point geostatistics

    Xixin WangSiyu YuShaohua Li
    12页
    查看更多>>摘要: Multi-point geostatistics has been widely used, but it involves many parameters when applying the method. These modeling parameters are usually sensitive to the quality of the model, such as the template size of the simpat algorithm, the number of nodes in the neighborhood searched of the Snesim algorithm, and the multigrid. in common use. What kind of evaluation criteria for selecting the value and ranges of the parameters has become an urgent problem to be solved. Some methods to optimize these modeling parameters have been proposed. These methods either statistics the pattern feature distribution of training image, or use some certain spatial structure as the index to quantitatively evaluate the quality of training image reconstruction of stochastic realizations, or use cross-validation to compare the sample matching degree between the realization and the training image. However, these methods have their limitations in optimizing modeling parameters. In this paper, two methods to optimize the modeling parameters of multi-point geostatistics were proposed based on gray level co-occurrence matrix and convolutional neural network. Both methods can optimize the appropriate parameters by analyzing the influence of the parameters on modeling quality. Taking the frequently used parameters of Snesim and simpat as an example, the parameter optimization results of the GLCM-based method and the Deep Learning-based method are very close, which indicates that both methods can effectively extract and distinguish the spatial features of the model. In addition, the relationship between modeling parameters and evaluation indexes accords with the visual features of stochastic models. Therefore, the method proposed in this paper will be helpful to solve the difficulty of parameter setting in multi-point geostatistical modeling.

    Huff-n-puff gas injection or gas flooding in tight oil reservoirs?

    Weiyu TangJames J. Sheng
    12页
    查看更多>>摘要: Because of the ultra-low permeability of tight formations, gas injection is believed to be an effective method to enhance oil recovery (EOR). However, it has two modes: huff-n-puff injection (HNP) and continuous flooding. Which mode is more efficient? This study aims to answer this question through an experimental and simulation study. In the experimental study, tight core samples of permeabilities of 0.16 mD, 0.045 mD, 0.001 mD, and 0.00029 mD were used to compare the oil recovery from huff-n-puff gas injection with flooding. The gas used was nitrogen. Both flooding and huff-n-puff experiments were conducted on the same core in each core sample. Experimental results show that gas flooding had higher recovery in the cores than HNP with the permeability above 0.001 mD, but lower when the permeability was lower 0.00029 mD. To further analyze the gas injection performance, a numerical simulation was performed. The conducted experiments were used to validate the numerical models by historically matching the experimental data. Based on the validated simulation models, HNP is optimized. Simulation results show that optimized HNP is superior to gas flooding when the permeability is lower than 0.001 mD core. Finally, based on published data, a filed-scale model consisting of two well-propped fractures was established to compare the performance of the two gas injection modes. Filed-scale simulation results show that gas flooding can achieve a higher recovery when the matrix permeability is above 0.01 mD, while HNP injection can yield more oil when the matrix permeability is lower than 0.001 mD. However, from an economic point of view, the HNP performance is more justified than the corresponding flooding when the permeability is higher than 0.01 mD, and it is difficult to be economic for both HNP and flooding when the permeability is lower than 0.001 mD.