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MIT World Peace University

School of Petroleum Engineering

The Barnett Shale success in the 90's has led to a significant amount of focused work on fracturing and its related aspects. The work included understanding its nuances, to be able to design the treatments better, and pump them with enhanced efficiency. Production from these completed wells is highly dependent on both the characteristics of proppants being placed, as well as those of the reservoir being treated. Fracturing leads to an interaction between the minerals of the proppants, formation and the fluids. Incompatible chemical interactions between minerals of the proppants, formation and fracturing fluids lead to precipitations which reduce porosity. Under in-situ conditions, these interactions further facilitate the phenomenon of geo-chemical diagenesis as a result of which rapid loss of fracture conductivity is observed. The diagenesis process includes mechanisms such as diffusion, temperature induced dissolution, precipitation in the pore space, along with chemical reactions at the fracture surface. These mechanisms lead to a reduction in the width and hence, the permeability of the created fracture. Proppant pack permeability reduction is presented in this paper through a mathematical model, which simulates fluid-mineral reactions in the created hydraulic fracture. The model involves solving the diffusion and precipitation equations for each component to simulate the changing porosity and permeability over time. These coded partial differential equations are combined with the reactions occurring at the surface. Further, this work studies the impact of this reduction on the productivity of a well completed in shale reservoir, followed by a sensitivity study of critical parameters. This work will help in a better understanding of reactions occurring within the fractures and their effect on the loss of fracture conductivity. With India looking at developing its shale plays, this work also includes possible issues that could affect this development. © Copyright 2015, Society of Petroleum Engineers.

Engineering and Technology

SPE Annual Technical Conference and Exhibition

Shale Gas Productivity: A Geo-chemical Diagenesis Perspective

Gas from shale reservoirs is difficult to produce, unless they are effectively stimulated. Production from wells completed in these quad-porosity reservoirs is dependent on the placement of hydraulic fractures and their degree of connectivity to the existing natural fractures. These propped fractures and their effectiveness is a direct function of the in situ stress in the formation. Furthermore, geochemical diagenesis in the created fractures significantly impacts fracture conductivity. This paper utilizes a fracture-completed horizontal well in different configurations of quad-porosity shale gas reservoir models to assess the effect of gas flow and storage in these systems on production parameters. Furthermore, sensitivity analysis is carried out on critical parameters to observe its impact on well performance. This work will help to provide a better understanding of hydraulic fracturing treatments and its effect on the forecast of a stimulated well with reasonable certainty.

World University root node

Industrial and Engineering Chemistry Research

Simulation and Mathematical Modeling of Stimulated Shale Gas Reservoirs

National Conference on Energy: Needs and Current Trends 2014

Simulation and Optimization of Biomass fed Gasifier

Update

Simulation and Optimization of Chemical Processes :

National Conference on Energy and Environment

Modelling and Optimization of Fludized Bed Coal Gasifier

International Interdisciplinary Conference

Optimization of Efficiency of Power Plant using HRSG and Combined Cycle Operation

National Conference on Emerging Trends in Engineering, Technology and {\ldots}

Modeling and Simulation of Combined Feed Gasifier for Power Production

With the advent and common usage of high resolution tree gauges, downhole permanent pressure/temperature gauges, and continuous flow measurement, many of the common petroleum engineering calculations and analysis tools for production systems can and have been automated. These include: a) Well Test Analysis, b) Well Productivity, c) Static and Flowing Material Balances and Energy Balances. In addition, the use of rigorous wellbore thermal and phase behavior models allows the two gauges (wellhead and downhole) to be used as a giant differential pressure meter - making it possible to calculate gas rates and water cuts independently of the flow measurements, as well as mid-completion bottomhole pressure (BHP). The purpose of this paper is to present the basic physics involved in these calculations/analyses, as well as to discuss the implications that these processes will have on instrumentation selection and on engineering work flows. The crux of the argument for these types of automated systems is that it is much easier for an engineer to check the results than to spend his/her entire day just looking for useful information in the database, then analyzing it (or getting someone else to analyze it). Furthermore, being able to see the "big picture" - seeing what skin, perm, productivity and apparent hydrocarbon reservoir volumes are now and how they have changed with time, allows engineers to make quicker, more accurate decisions. The use of automated analysis also reduces bias - the computer doesn't care what the answer is. This paper will also include several case studies for both oil and gas wells. Copyright 2014, Society of Petroleum Engineers.

Society of Petroleum Engineers - SPE Asia Pacific Oil and Gas Conference and Exhibition, APOGCE 2014 - Changing the Game: Opportunities, Challenges and Solutions

Using the results from automated petroleum engineering calculations to accelerate decision workflows

Shale gas is one of the most widely discussed unconventional gas resource with vast potential. With the United States having benefitted immensely from it, other countries are also venturing into it. Drilling horizontal wells and hydraulically fracturing them are two major components of developing a shale gas reservoir economically. With many countries in Europe looking at the possibility of producing gas from shale reservoirs, the practice of hydraulic fracturing (HF) is going to gain even more prominence. However, operationally the procedure to hydraulically fracture a well is very complex, and has many possible situations which can lead to an accident. Some of these accidents may lead to catastrophic consequences, leading to loss of lives. In the industry, there are multiple methods used to classify and quantify risk, based on certain parameters. This paper performs a comprehensive risk assessment for the entire hydraulic fracturing job, from an operational perspective. This is done using industry available techniques. The result of this work is to assess the risk factor achieved from each technique, and check whether each of the methods converges onto a single sub-operation, classifying it as the most risky, with the highest risk ranking. Based on the results, this paper recommends steps to counter the minor but risky situations that may arise due to negligence. The results are compared with an actual fracturing operation on the field. Hydraulic Fracturing Most of the reservoirs being explored today have good porosity but poor permeability. Poor permeability reservoirs do not allow oil and gas to reach the wellbore in sufficient volumes. To increase the flow of oil and gas from the reservoir rock to wellbore in poor permeable reservoirs, fracturing of the wells is deemed necessary. Fracturing may also be used in case of depleted reservoirs, where additional energy and surface area is required for fluids to flow to the wellbore. Fracturing is a complex operation, involving multiple equipments, as shown in Figure 1. Fracturing involves the pumping of fracturing fluid and proppant into a formation at a calculated, pre-defined rate and pressure. These defined conditions result in initiation and development of fractures in the rock formation. In shale gas reservoirs, the low permeability of the reservoir impedes the capacity of gas to flow freely within the formation. Poorer the reservoir, the more advanced the technology and. Copyright © 2014, Society of Petroleum Engineers.

SPE Middle East Health Safety Environment &amp; Sustainable Development Conference and Exhibition

A Comparative Assessment of Quantitative Risk as Applied to Hydraulic Fracturing Operations

Introduction: Delay in diagnosis of paucibacillary extra pulmonary tuberculosis (TB) and of smear negative TB has hampered the efforts taken by Control Programs to curb its spread. Better efforts to control spread of TB require more accurate and rapid diagnostic test. Aims: To facilitate early diagnosis of TB directly from clinical specimens, we have standardized and validated the use of a single tube in-house nested PCR in comparison against culture and composite reference standard (CRS). Methods: Single tube nested PCR was performed using primers targeting Insertion Sequence (IS) 6110 of Mycobacterium tuberculosis complex. Microbiological techniques includes AFB smear microscopy and cultivation on solid egg-based medium (Lowenstein-Jensen [LJ]) and on liquid culture medium using BACTEC MGIT 960 system, BD Microbiology Systems. Results: The sensitivity and specificity of PCR against culture was observed to be 89.7% [95% CI: 84.1-93.5] and 73.1% [95% CI: 67.4-78.1] respectively and that against CRS criteria was 80.2% [95% CI: 75.1-84.5] and 97.1% [95% CI: 92.9-98.9] respectively. PCR showed 100% [111/111, 95% CI: 97-100] sensitivity for smear positive specimens. For smear negative specimens sensitivity and specificity of PCR against culture was observed to be 78.4% [69/88, 95% CI: 68.4-86.5] and 77.3% [204/264, 95% CI: 71.7-82.2] respectively and that against CRS was 68.1% [124/182, 95% CI: 60.8-74.8] and 97.1% [165/170, 95% CI: 93.3-99] respectively. Conclusion: CRS criteria were observed to be better than culture for assessing the diagnostic accuracy of PCR test. (copyright) 2013.

Egyptian Journal of Chest Diseases and Tuberculosis

Is a composite reference standard (CRS) an alternative to culture in assessment and validation of a single tube nested in-house PCR for TB diagnosis?