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Silviu Livescu - One of the best experts on this subject based on the ideXlab platform.

  • Technology Focus: Reservoir Performance (September 2020)
    Journal of Petroleum Technology, 2020
    Co-Authors: Silviu Livescu
    Abstract:

    2020 is going to be remembered in oil and gas history for its unexpected free fall in oil prices in less than 2 months. This year’s severe supply-and-demand imbalance is going to have tremendous implications for adopting new business models, developing new technologies, and attracting new talent into the industry. Collaboration and automation are going to continue being drivers for both operators and services providers in all their business segments. While the ongoing trends in data science and engineering analytics are going to show more benefits in lowering production costs and increasing efficiencies, the well-established Reservoir and production engineering disciplines will continue to be critical for Reservoir Performance improvements. In the past 12 months, 93 technical papers were presented at various conferences with a Reservoir Performance focus and were reviewed for this feature, showcasing further advances in Reservoir Performance monitoring and optimization. For comparison, 133, 157, and 160 technical papers were reviewed for the 2019, 2018 and 2017 features, respectively. Interestingly, this year, 34 papers had first authors from academia (37%), 49 had first authors from operating companies (53%), and 10 had first authors from oilfield services companies and consulting firms (11%). For comparison, the review for the 2019 feature included 39 papers with first authors from academia (29%), 63 with first authors from operating companies (47%), and 31 with first authors from oilfield services companies and consulting firms (23%). It will be interesting to see this data for the 2021 feature. The three primary papers selected and three alternative papers recommended as additional reading are a representative sample of the 93 papers reviewed for this feature. They have been selected on the basis of their technical contributions and geographic diversity.

  • Technology Focus: Reservoir Performance (September 2019)
    Journal of Petroleum Technology, 2019
    Co-Authors: Silviu Livescu
    Abstract:

    Technology Focus Since the last Reservoir Performance feature in September 2018, complex supply- and-demand challenges have continued to shape our technology and business-innovation models. Under significant pressure from several angles, operators around the world are focusing on lowering their production costs for both conventional and unconventional assets, while oilfield service companies are responding to customers’ cost-saving requests with incremental improvements in technology, supply chains, automation, and collaboration. While the current trends in machine learning and artificial intelligence certainly can help lower the production costs, future Reservoir-Performance improvements still will have to rely on Reservoir characterization, surveillance, and optimization. The current quest for production-cost savings cannot continue without improvements in both operational efficiency and recovery factors. In the past 12 months, 133 technical papers were presented at various conferences and meetings with a Reservoir-Performance focus and were reviewed for this feature, showcasing further advances in Reservoir-Performance monitoring, analysis, and optimization. For comparison, 157 and 160 technical papers were reviewed for the 2018 and 2017 features, respectively. Interestingly, this year, 39 papers had first authors from academia, 63 had first authors from operating companies, and 31 had first authors from oilfield service companies and consulting firms. For comparison, the review for the 2018 feature included 62 papers with first authors from academia, 70 with first authors from operating companies, and 25 with first authors from oilfield service companies and consulting firms. The three primary papers selected and three alternative papers recommended as additional reading constitute a representative sample of the 133 papers reviewed for this feature. They are a geographically diverse mix of fundamental research, industrial research and development, and field-application studies, reporting the latest Reservoir-Performance advances. Recommended additional reading at OnePetro: www.onepetro.org. SPE 192881 Reservoir Health Indicators Driving Performance Through Data Analytics by Mohamed Al Marzouqi, ADNOC, et al. SPE 193701 Satellite INSAR Technology for Caprock-Integrity Monitoring of Cyclic Steam Stimulation and Steamflooding Heavy-Oil Production in Kuwait by Zu Biao Ren, Kuwait Oil Company, et al. SPE 195366 Permeability and Porosity Evolution of Organic-Rich Shales as a Result of Heating by Tae Wook Kim, Stanford University, et al.

  • Technology Focus: Reservoir Performance and Monitoring (September 2018)
    Journal of Petroleum Technology, 2018
    Co-Authors: Silviu Livescu
    Abstract:

    Technology Focus Since the last Reservoir Performance and Monitoring feature in 2017, the industry has continued to advance with innovation in technology and business models to drive sustainable change. Operators around the world have continued lowering production costs aggressively, and oilfield service companies have continued to survive by making a low-margin profit in a greatly competitive market. If the industry until recently was lamenting an oversupply of oil and that a global upstream investment slump caused a focus on incremental technology improvements with fewer capital resources and personnel, now a looming oil-supply shortage has reignited discussions about how innovation, digital technologies, and collaborations can accelerate future major project development. In the last 12 months, 157 technical papers were presented at various conferences and meetings with Reservoir Performance and monitoring programs and were reviewed for this feature. For comparison, 160 were reviewed for the 2017 feature. Interestingly, 62 papers had first authors from academia, 70 from operating companies, and 25 from oilfield services companies and consulting firms. Sixty-three papers had authors with different affiliations. The six papers selected and recommended as additional reading are a representative sample of the papers reviewed for this feature. They are a geographically diverse mix of fundamental research, industrial research and development, and field-application studies, reporting the latest published advances in Reservoir-Performance monitoring, analysis, and optimization. In considering the 157 technical papers reviewed for this feature, I am looking forward to seeing how our industry is going to react through innovation and digital technologies to the supply and demand changes of coming years. A new era of operational efficiency improvements, improved recovery factors, and lower production costs from continuous Reservoir Performance monitoring, analysis, and optimization is ready to begin. Recommended additional reading at OnePetro: www.onepetro.org. SPE 188890 Effect of Irreversible Retention on Tracer Deployments: Constraining Novel Material Deployments by Hsieh Chen, Aramco, et al. SPE 189846 Applying Subsurface DNA Diagnostics and Data Science in the Delaware Basin by J. Silva, Anadarko, et al. SPE 190480 Effect of Dilution on Acoustic and Transport Properties of Reservoir Fluid Systems by Ram R. Ratnakar, Shell, et al.  

  • Technology Focus: Reservoir Performance and Monitoring (September 2017)
    Journal of Petroleum Technology, 2017
    Co-Authors: Silviu Livescu
    Abstract:

    Technology Focus Since the last Reservoir Performance and Monitoring feature in September 2016, the industry trends of significantly improving efficiency and reducing operational costs have continued to be implemented. For instance, at the time of writing, in North America, the US oil rig count has risen impressively for 23 straight weeks and the big players have greatly reduced their exposure to Canada’s oil sands. However, while many efforts are focusing on the optimization of current technologies and the study of past Reservoir Performance to improve future developments, with fewer capital resources and personnel available, these efforts may yield only incremental improvements. Technology and innovation are seen industrywide as critical to long-term radical efficiency and productivity. Once the industry becomes less concerned about cost savings and more about investing in future technologies and long-term Performance, the nonrisk-averse innovation culture from other industries could help us develop new disruptive technologies and implement them in the field. For instance, with the proper resources in place, automated Reservoir-Performance modeling and monitoring may no longer be a science-fiction scenario. Once this downturn appears in the rear-view mirror, our industry will need to change its model disruptively to thrive sustainably in the next growth cycle. During the past 12 months, 160 technical papers were presented at various conferences and meetings with Reservoir-Performance-and-monitoring programs and were reviewed for this feature, displaying further advances in Reservoir-Performance monitoring, analysis, and optimization. The papers selected and recommended as additional reading are representative samples of the reviewed papers. They are a geographically diverse mix of academic work, industrial research and development, and field applications, describing numerical simulation and laboratory research, field-data-acquisition and -interpretation studies, new-technology development and field trials, and multi-year reviews of current technologies and work flows. Recommended additional reading at OnePetro: www.onepetro.org. SPE 181550 Current State and Future Trends in the Use of Downhole Fluid Analysis for Improved Reservoir Evaluation by H. Elshahawi, Shell, et al. SPE 184131 Production Optimization Through Voidage Replacement Using Triggers for Production Rate by Cenk Temizel, Aera Energy, et al. SPE 183195 Development of Crosswell Electromagnetic Monitoring System Using the HTS-SQUID Magnetometer by Makoto Harada, Japan Oil, Gas, and Metals National Corporation, et al.

  • Technology Focus: Reservoir Performance and Monitoring (September 2016)
    Journal of Petroleum Technology, 2016
    Co-Authors: Silviu Livescu
    Abstract:

    Technology Focus Since the last Reservoir Performance and Monitoring feature, in September 2015, unfavorable market conditions have significantly constrained the operating cash flow of energy companies worldwide. This has prompted a response to delay or cancel capital-intensive projects, improve efficiency, and reduce operating costs. The response to innovation of the industry to survive through this downturn and thrive afterward could be perceived as slow. However, despite the current downturn, the industry has seen further advancements in innovation, including in Reservoir-Performance monitoring, analysis, and optimization. As an indicator of these advancements, almost 240 technical papers presented in the past 12 months at various conferences and meetings with Reservoir-Performance- and-monitoring programs were reviewed for this feature, as compared with approximately 100 in the preceding year. The current Reservoir-Performance-monitoring technologies are being improved continuously for better Reservoir understanding, more-accurate short- and long-term production forecasting, and lower overall operational costs. The industry is becoming more efficient at using existing technologies to improve mature-field Performance and surveillance. For instance, new approaches and models have been presented recently for operational optimization and future-production-behavior predictions, especially in unconventional Reservoirs. Interwell tracers have been evaluated in the laboratory for their applicability in different mineralogies, and their full-field implementation in carbonate Reservoirs has been reported. Temperature and acoustic measurements with fiber-optic technologies have been reported to add value to heavy-oil- Reservoir monitoring. New theoretical and experimental models at micro-and nanoscales have been proposed to improve the industry understanding of fluid/formation interaction. Integrated multidisciplinary work flows have been developed to increase the value of Reservoir-data monitoring. The current advancements in efficiency and innovation should lead to future successes as market conditions improve. The papers selected and recommended as additional reading are representative samples of the reviewed papers for this feature and are intended to show diverse examples of implementing multiple concepts and methodologies for production evaluation and achieving better Reservoir Performance. They are a mixture of field and academic applications, from all regions of the world, reporting case histories, field-data acquisition and interpretation, work flows, theoretical models, and laboratory results. JPT Recommended additional reading at OnePetro: www.onepetro.org. SPE 180369 Detecting Opal-CT Formation Resulting From Thermal Recovery Methods in Diatomites by C.M. Ross, Stanford University, et al. SPE 180061 Dynamic Reservoir Characterization and Production Optimization by Integrating Intelligent Inflow Tracers and Pressure-Transient Analysis in a Long Horizontal Well for the Ekofisk Field, Norwegian Continental Shelf by M. Prosvirnov, ConocoPhillips, et al. SPE 178984 Comprehensive Field-Scale Injection-Performance Analysis Associated With Injected-Water-Quality Parameters by Bangkog A. Sabut, Saudi Aramco, et al. OTC 26232 From Nanoscale Wetting Toward Enhanced Oil Recovery by R. Giro, IBM Research, et al.

Dilhan Ilk - One of the best experts on this subject based on the ideXlab platform.

  • Deconvolution of Variable-Rate Reservoir Performance Data Using B-Splines
    Spe Reservoir Evaluation & Engineering, 2006
    Co-Authors: Dilhan Ilk
    Abstract:

    This work presents the development, validation and application of a novel deconvolution method based on B-splines for analyzing variable-rate Reservoir Performance data. Variable-rate deconvolution is a mathematically unstable problem which has been under investigation by many researchers over the last 35 years. While many deconvolution methods have been developed, few of these methods perform well in practice - and the importance of variable-rate deconvolution is increasing due to applications of permanent downhole gauges and large-scale processing/analysis of production data. Under these circumstances, our objective is to create a robust and practical tool which can tolerate reasonable variability and relatively large errors in rate and pressure data without generating instability in the deconvolution process. We propose representing the derivative of unknown unit rate drawdown pressure as a weighted sum of Bsplines (with logarithmically distributed knots). We then apply the convolution theorem in the Laplace domain with the input rate and obtain the sensitivities of the pressure response with respect to individual B-splines after numerical inversion of the Laplace transform. The sensitivity matrix is then used in a regularized least-squares procedure to obtain the unknown coefficients of the B-spline representation of the unit rate response or the well testing pressure derivative function. We have also implemented a physically sound regularization scheme into our deconvolution procedure for handling higher levels of noise and systematic errors. We validate our method with synthetic examples generated with and without errors. The new method can recover the unit rate drawdown pressure response and its derivative to a considerable extent, even when high levels of noise are present in both the rate and pressure observations. We also demonstrate the use of regularization and provide examples of under and over-regularization, and we discuss procedures for ensuring proper regularization. Upon validation, we then demonstrate our deconvolution method using a variety of field cases. Ultimately, the results of our new variable-rate deconvolution technique suggest that this technique has a broad applicability in pressure transient/production data analysis. The goal of this thesis is to demonstrate that the combined approach of B-splines, Laplace domain convolution, least-squares error reduction, and regularization are innovative and robust; therefore, the proposed technique has potential utility in the analysis and interpretation of Reservoir Performance data.

  • Deconvolution of variable-rate Reservoir-Performance data using B-splines
    Journal of Petroleum Technology, 2006
    Co-Authors: Dilhan Ilk, P. P. Volko, Thomas Alwin Blasingame
    Abstract:

    This work presents the development, validation, and application of a deconvolution method that uses B-splines to analyze variable-rate Reservoir-Performance data. Variable-rate deconvolution is a mathematically unstable problem. B-splines represent the derivative of unknown unit-rate drawdown pressure, and numerical inversion of the Laplace transform is used in this formulation. When significant errors and inconsistencies exist in the data functions, direct and indirect regularization methods are used (i.e., mathematical "uniformity" processes). The new deconvolution method has broad applicability in variable-rate/pressure problems and can be implemented in typical well-test and production data analysis.

Mohammed S. Ameen - One of the best experts on this subject based on the ideXlab platform.

  • A Paradigm Shift in Understanding Fracture Origin and Fracture Influence on Deep Carbonate Reservoir Performance: A Study of Onshore Permo-Triassic Deep Reservoirs in Saudi Arabia
    2011
    Co-Authors: Mohammed S. Ameen
    Abstract:

    Characterizing fractures and their geomechanical impact on Reservoir Performance is the ultimate objective of fracture and in-situ stress characterization. This presentation provides evidence contrary to the common perception of the major role played by fractures in the production Performance of deep carbonate Reservoirs. It is based on a recent study by Saudi Aramco in Saudi Arabia. The highly variable Performance of the Permo‐Triassic Reservoirs in onshore giant fields in Saudi Arabia has been attributed to the presence of natural fractures. Similar preproduction pressure profiles and hydrocarbons in the different Reservoir units have been attributed to vertical communication through large faults. To validate these assumptions, we studied the static and dynamic data from the Reservoirs. We identified two distinctive fracture domains based on fracture orientation and density. Fracture evolution is mainly controlled by extensional and consequent compressional plate tectonics instead of local structures. In-situ stresses in the study area are dominated by Zagros Plate tectonics and affect fracture aperture differently in the two fracture domains. The impact of fractures on Reservoir Performance is mostly subtle because of the nature and distribution of the fractures. Fracture-enhanced productivity occurs locally in some of the producing wells and results from high-density fracture clusters (including mesoscopic faults) with channel-type apertures. Reservoir Performance is mainly controlled by the matrix porosity and permeability that were preserved by early hydrocarbon placement.

  • the function of fractures and in situ stresses in the khuff Reservoir Performance onshore fields saudi arabia
    AAPG Bulletin, 2010
    Co-Authors: Mohammed S. Ameen, Ismail M Buhidma, Zillur Rahim
    Abstract:

    The highly variable Performance of the Permian–Triassic Khuff Reservoir in onshore Saudi Arabia has been attributed to the presence of natural fractures. Similar preproduction pressure profile and hydrocarbons in the different Reservoir units in some fields have been attributed to vertical communication through large faults. To validate these assumptions, we studied the static and dynamic data from the Khuff Reservoir in 19 major structural traps. We identified two distinctive fracture domains based on fracture orientation and density. Fracture evolution is mainly controlled by the extensional and consequent compressional plate tectonics instead of local structures. In-situ stresses are dominated by the Zagros plate tectonics and affect fracture aperture differently in the two fracture domains. The fracture impact on the Khuff Reservoir Performance is mostly subtle because of the nature and distribution of the fractures. High fracture-enhanced productivity occurs locally in some of the producing wells, and it results from high-density fracture clusters (including mesoscopic faults) with channel-type apertures. The following findings challenge the perceived major functions of fractures in the Khuff Reservoir Performance in onshore fields: (1) Individual fractures are dominantly tensile and small (mesoscopic and microscopic); (2) individual faults are small and not readily resolvable at seismic scale; (3) the depth and carbonate nature of the Khuff Reservoir make the fractures highly susceptible to fast healing unless preserved within the hydrocarbon column; (4) initial vertical pressure gradient changes with production indicate a lack of present-day communication across the anhydrite sealing layers, between the different Khuff Reservoir units; (5) horizontal well direction does not generally have an impact on productivity; and (6) sustained and heavy losses of circulation are rarely encountered in the Khuff Reservoir wells. Mohammed S. Ameen received his Ph.D. and Diploma of Imperial College in structural geology and geomechanics from Imperial College, London, 1988. He has more than 20 years of academic and industrial experience and has patented a new method for the characterization of microfractured Reservoirs. He has published 25 articles on fractures and folds, and has edited three special publications for the Geological Society (London). He conducted the first classic work on the fractures and folds across the Taurus-Zagros Range, Iraq, covering 30 major fold traps. The work is published in the AAPG Bulletin, the Geological Magazine, and the Journal of Petroleum Geology. He joined the Reservoir Characterization Department at Saudi Aramco in 1998. Since 2004, he has been leading the Structural Geology and Rock Mechanics Group in the Geological Technical Services Division, Saudi Aramco. He is an active member of the AAPG, Society of Petroleum Engineers, European Association of Geoscientists and Engineers, and the Geological Society (London). Ismail M. Buhidma is a petroleum engineering consultant in the Gas Reservoir Management Division of Saudi Aramco with 32 years of diverse industrial experience. For the last 12 years, he has been actively involved in Aramco's nonassociated gas development program. His areas of interest include Reservoir management, well Performance analysis, well test analysis, phase behavior, geomechanics, Reservoir simulation, Reservoir characterization, and well stimulation. Prior to joining Aramco, Ismail worked for Exxon in Libya, Schlumberger and Atlantic Richfield in the USA, and Qatar Petroleum in Qatar. Ismail holds B.S. and M.S. degrees in petroleum engineering from the University of Tulsa. He is a member of Society of Petroleum Engineers (SPE) and has published numerous SPE appears. Zillur Rahim is a petroleum engineering consultant with Saudi Aramco working in gas field development. He received his B.S. degree from Algerian Petroleum Institute and M.S. degree and Ph.D. from Texas A&M University, College Station, all in petroleum engineering. He has 25 years of industry experience, has published more than 50 technical papers, and has taught numerous industry courses. Previously, he worked with Holditch and Associates Petroleum Consultants and with Schlumberger Reservoir Technology group. His area of expertise includes Reservoir engineering, hydraulic and acid fracturing, and Reservoir management.

Erik Vikane - One of the best experts on this subject based on the ideXlab platform.

  • Technology Focus: Reservoir Performance and Monitoring (September 2014)
    Journal of Petroleum Technology, 2014
    Co-Authors: Erik Vikane
    Abstract:

    Technology Focus “If you have one watch, you know the time. If you have two, you will never be sure.” This was a quote that my professor in Reservoir engineering, T.D. van Golf-Racht, once stated when he tried to make us students reflect upon the availability and the quality of the data given for a specific exercise. This was in the late 1980s, and the amount of data was rather limited compared with today’s vast amount of data available. The cost of new data is increasing; most operators are cutting cost, and the cost/ benefit exercise is getting more and more challenging. Actionable information is even more important, and payback time is the crucial number to know. When you have obtained the necessary funding for acquiring data, make sure that you spend it wisely by collecting the data the right way and understanding the data you have gathered. Paper SPE 169539, related to diagnostic fracture injection tests, highlights the pitfalls when acquiring data to prepare for a hydraulic-fracture treatment. Understanding well and Reservoir Performance is the ultimate goal of data gathering, and this gives the necessary foundation for making decisions. Regardless of the amount of data available and supercomputers at hand, analytical methods still play an important role in today’s analysis of Reservoir Performance. Another featured paper describes the use of modern analytical tools in an excellent way. Data are of particular importance when you try to establish fundamental knowledge, whether it is drainage strategy for a new discovery or (even more fundamental) recovery processes for new types of hydrocarbons such as hydrates, described in paper OTC 25328. We, the engineers, need to prepare for tougher times ahead. We need to make sure that key data are collected and be prepared to skip the rest. We need to make sure that more time is spent understanding the data than gathering them. We need to make sure that we perform cost/benefit analysis both before and after data acquisition. JPT

  • Technology Focus: Reservoir Performance and Modeling (September 2010)
    Journal of Petroleum Technology, 2010
    Co-Authors: Erik Vikane
    Abstract:

    Technology Focus Understanding and management of subsurface uncertainties are crucial for successful development of early-phase projects. The development solution, drive mechanism, processing capacities, and number of slots needed all affect the net present value and the capital and operating expenses. Planning and execution of early-phase data acquisition and the effect these data have on late-life economics are a theme that deserves more attention. Concept selection is the most important part of an early-phase development from a subsurface point of view. Because of the high well cost, deepwater projects are sanctioned with few appraisal wells and limited dynamic information. The importance of an overall strategy to manage subsurface uncertainties is described in the paper regarding the development of the greater Plutonio area. Dynamic information, both horizontal and vertical permeability, is always on top of every Reservoir engineer’s wish list. Wireline formation testing is a cost-effective way of addressing dynamic information, keeping in mind that an extended well test or a drillstem test is not always feasible for economic or practical purposes. Determination of remaining oil is key to increased oil recovery. A proactive approach to surveillance gives insight into the Reservoir and has potential to mitigate unpleasant surprises. The paper describing the proactive well and Reservoir management and the paper assessing fluid migration and quantifying remaining-oil saturation are both excellent examples of creating value through systematic Reservoir surveillance. Reservoir Performance and Monitoring additional reading available at OnePetro: www.onepetro.org IPTC 13640 • “Successful Reservoir Monitoring With 4D Microgravity at Ras Laffan, State of Qatar” by A.F. AhmadZamri, SPE, RasGas Company, et al. IPTC 13185 • “Reservoir Modeling and Production Evaluation in Shale-Gas Reservoirs” by C.L. Cipolla, SPE, Carbo Ceramics, et al. SPE 127858 • “Perdido: The First Smart Field in the Western Hemisphere” by Robert K. Perrons, SPE, Shell. SPE 128137 • “Integrated-Production-Model Calibration Applied to a Gulf of Mexico Subsea Field” by L. Saputelli, SPE, Hess Corporation, et al.

  • Technology Focus: Reservoir Performance and Modeling (September 2009)
    Journal of Petroleum Technology, 2009
    Co-Authors: Erik Vikane
    Abstract:

    Technology Focus "Reservoir engineering is a complex subject for two reasons. In the first place, we never see enough of the Reservoirs we are trying to describe. Therefore, it is difficult to define the physics of the system and, therefore, select the correct mathematics to describe the physics with any degree of certainty. The second problem is that even having selected a sensible mathematical model, there are never enough equations to solve for the number of unknowns involved" (Dake 2001). Prudent Reservoir management requires active Reservoir surveillance to optimize Reservoir Performance. The challenge for Reservoir engineers is to justify the additional cost involved in gathering data and also to transform those data into valuable information. The paper describing an integrated Reservoir-surveillance process for the greater Burgan field in Kuwait is an excellent example of how to justify implementing a systematic surveillance process. Lack of data and lack of confidence in data are major challenges in developing brownfields. The paper "Revitalization of Old-Asset Oil Fields Into I-fields" describes how old fields can benefit from the application of modern surveillance technology. The trend toward intelligent fields has increased the use (and demand) for real-time Reservoir management. To take advantage of the continuously and rapidly increasing amount of data, the industry will need a workflow shift from the deterministic approach to one based on statistical approaches. The paper "Where is the Gap? Is It in More Reservoir Engineers or in Leveraging New Skills and Workflows That Enhance Individual Productivity?" examines how Reservoir engineers can improve productivity by use of statistical concepts and workflows. The additional reading addresses some of the challenges the industry is facing in developing unconventional hydrocarbon resources—in this case, shale gas. Reference Dake, L.P. 2001. The Practice of Reservoir Engineering, ix. Amsterdam: Elsevier. Reservoir Performance and Monitoring additional reading available at OnePetro: www.onepetro.org SPE 119892 • "Impact of Shale Properties on Pore Structure and Storage Characteristics" by R.M. Bustin, University of British Columbia, et al. SPE 119897 • "Production Analysis and Forecasting of Shale-Gas Reservoirs: Case-History-Based Approach" by L. Mattar, SPE, Fekete Associates, et al.

Federico Maggi - One of the best experts on this subject based on the ideXlab platform.

  • Impacts of relative permeability hysteresis on the Reservoir Performance in CO2 storage in the Ordos Basin
    Greenhouse Gases: Science and Technology, 2016
    Co-Authors: Keni Zhang, Chaobin Guo, Jian Xie, Jing Zhao, Federico Maggi
    Abstract:

    The CO 2 storage Reservoir for the Shenhua Carbon Capture and Storage (SHCCS) Demonstration Project in the Ordos Basin in China is known for its low‐permeability and low‐porosity characteristics. However, injectivity was shown by the in situ monitoring data to be substantially increasing over the years. Previous numerical analyses suggest that such Reservoir behavior might be mainly attributed to the permeability heterogeneity of the injection layers. As an intermittent injection procedure was actually practiced in this project, the hysteretic behaviors in relative permeability and capillary pressure in the Reservoir could be significant. In this study, the hysteretic processes are investigated for a better understanding of the Reservoir Performance. History‐match is achieved with one order of magnitude lower in the overall permeability of the principal injection layer than the previous simulation. Current calibrated permeability is much closer to seismic measurement and well‐log results. Therefore, we believe that the hysteresis effects accompanying the alternation between injection and injection pause might be another important factor accounting for the observed Reservoir Performance. It is indicated in this study that, by considering the hysteresis effects in the injection‐pause sequence, an optimally‐designed intermittent injection procedure could greatly improve the injection Performance in a saline aquifer with low permeability and low porosity that may seem unfavorable to CO 2 storage. © 2016 Society of Chemical Industry and John Wiley & Sons, Ltd.

  • experimental and numerical analysis of Reservoir Performance for geological co2 storage in the ordos basin in china
    International Journal of Greenhouse Gas Control, 2016
    Co-Authors: Cai Li, Keni Zhang, Yongsheng Wang, Federico Maggi
    Abstract:

    Abstract Unique Reservoir Performance was observed in the Shenhua 100,000 t/year Carbon Capture and Storage (SHCCS) Demonstration Project. Suggested by the geological pre-assessments, hydraulic fracturing and a multi-layer injection procedure were employed to improve the injectivity and reduce the risk of an overpressure. However, in-situ data showed the total injection rate increased after the injection started, while the injection initiation pressure decreased with only a minor pressure build-up development. Additionally, the injectivity of the uppermost injection layer, which was not fractured, grew considerably over the years, making this layer potentially able to meet the target rate by itself. To clarify this unforeseen observation, the Reservoir Performance was investigated through numerical simulations and comparison against the 2.5-year historical data. The simulation results indicated that permeability heterogeneity of the injection layers might explain the observed Reservoir Performance. High CO 2 injectivity in the uppermost injection layer could be attributed to its overall permeability being higher than that of other layers, and the considerable injectivity increase over the years could have been caused by the substantial permeability increase along the principal direction of CO 2 migration in this layer. The injectivity improvement caused by hydraulic fracturing was significant in the early time of injection, but it dramatically reduced afterwards. The intermittent injection procedure could effectively reduce the pressure build-up in the Reservoir and helped to maintain the injection at the target rate. Based on these assessments, the cumulative injected CO 2 mass could reach 300,000 t in December 2015, but the yearly average injection rate would drop slightly. The predicted cumulative mass could be underestimated because the higher injectivity in 2014 was not accounted for in the calibration, and because the model size could have affected the Reservoir Performance, as shown by the sensitivity analysis. This research indicated that permeability heterogeneity and the injection procedure could significantly affect the Reservoir Performance, and should be given consideration in the Performance assessment.