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EAGE/AAPG Middle East Tight Gas Reservoirs Workshop 2011
- Conference date: 30 Oct 2011 - 02 Nov 2011
- Location: Dubai, United Arab Emirates
- ISBN: 978-94-6282-046-3
- Published: 30 October 2011
25 results
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Role of Geomechanics in Accessing Deep Tight Gas Volumes in Northern Oman
By L. QobiAppraisal of deep tight gas reservoirs offers many challenges, including production rate predictions when wells are drilled overbalanced. Overbalance leads to near wellbore porosity / permeability damage to the rock matrix and fractures. Furthermore, poro-elastic effects due to invasion contribute to difficulties initiating and propagating hydraulic fractures. Damage to natural fractures intersecting the well can prevent their detection leading to missed productive intervals. Under-balanced drilling (UBD) can avoid these effects and thereby better indicate the gas potential of these reservoirs. However, not all reservoirs are suitable for UBD as there can be a greater risk of mechanical wellbore instability. Hence, geomechanical analysis prior to drilling can help evaluate the feasibility of UBD operations. Formation evaluation in UBD conditions also poses many challenges due to technical (temperature and pressure) limitations of tools and higher uncertainties with petrophysical calculations. Conventional core to log and porosity/permeability relationships are often inappropriate where matrix permeability is extremely low and fractures contribute to flow, therefore alternative ways of understanding and evaluating the reservoir are essential. In this paper, we demonstrate how geomechanics was used in formulating a strategy for appraisal of a well placed in a tight gas reservoir and also as a decision support tool while drilling. We present here an analysis of data from the Amin reservoir in the Fahud Salt Basin, Sultanate of Oman, where mechanical borehole failure due to in-situ stresses, pore pressure and rock properties was successfully simulated to understand the mechanical behaviour of the rock matrix and natural fractures which played an important role in controlling the gas flow profile. Planning of this Amin reservoir well involved geomechanical analysis prior to well spud to evaluate UBD feasibility based on offset well data, followed by updating the models as the well progressed. Evaluation of natural fractures from image logs and identifying sets of critically-stressed fractures (hydraulicallyconductive fractures) was an important component of the geomechanical analysis that played a key role in supporting the appraisal strategy.
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3-D Drilling Geomechanics for Drilling Optimization and Long Term Openhole Stability
By C. Phuat Tan3-D geomechanical model and coupled geomechanics modeling between geomechanical and reservoir simulators are required for investigating and quantifying the full 3-D nature of in-situ stresses, pore pressure and rock properties, and their spatial and temporal variations. Applications of such 3-D geomechanical model and coupled geomechanics modelling include challenging development and infill well drillings, reservoir compaction, overburden movement and fault re-activation which could impact long term openhole stability. The presentation will introduce novel mud weight cubes for analysis of multiple well trajectories and selection between alternative trajectories for a planned well. The mud weight cubes can also be used for field scale drilling optimization including identification of regions in the field which pose high drilling risks, planning of well locations, optimization of well trajectories etc. in field scale, taking wellbore stability into consideration. In addition, geomechanics of depletion, reservoir compaction, subsidence, fault re-activation and overburden movement as well as their effects/consequences on long term openhole stability will be described. Case studies utilizing 3-D drilling geomechanics and coupled reservoir geomechanics modeling, and applications of the technologies to drilling and long term openhole stability will also be presented and discussed.
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3-D Coupled Reservoir Geomechanics for Optimal Hydraulic Fracture Design and Completion Integrity
By C. Phuat TanCoupled geomechanical modeling capability has been developed specifically for investigating and quantifying the full 3-D nature of the in-situ stresses, pore pressure and rock properties, and their spatial and temporal variations throughout life of the field. This enables complex subsurface conditions and properties through the overburden and reservoir to be modeled and evaluated, and used in subsequent geomechanical analyses, hydraulic fracture design and completion integrity. The presentation will introduce geomechanics of hydraulic fracture and a new workflow to simulate stress distributions in both well-centric and field scales. The stress distributions will help to understand hydraulic fracture behavior, design optimum hydraulic fracture job, both openhole and cased and perforated hole, and forecast the performance of the stimulated well. In addition, depletion, reservoir compaction, subsidence, fault re-actvation and overburden movement as well as their effects/consequences on completion integrity will be described. Case studies on applications of the technologies to optimise hydraulic fracture design and completion integrity will be presented and discussed.
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Coupled Reservoir Geomechanics Modeling for Optimal Field Development Planning and Life of Field
By C. Phuat TanCoupled geomechanics modeling is required for investigating and quantifying the full 3-D nature of the in-situ stresses, pore pressure and rock properties, and their spatial variation. This enables the complex subsurface conditions and properties through the overburden and reservoir to be modeled and evaluated, and then used in subsequent geomechanics analyses, well planning and reservoir management. Pore pressure and stress changes (which may occur in both the overburden and reservoir) due to injection, production and depletion can be quantified and forward modeled, and the coupling of the petrophysics to the geomechanics means that dynamic reservoir behaviour can also be modeled and investigated. Applications of such 3-D modeling and fully coupled analyses include pre-production and infill well planning, wellbore stability, completion design, stimulation, injection, waste and CO2 disposal, reservoir engineering, 4-D seismic, reservoir compaction, subsidence, fault activation and induced seismicity. The presentation will introduce geomechanics and consequences of depletion and injection, reservoir compaction, overburden movement, subsidence, caprock integrity and fault re-activation. Case studies utilizing coupled reservoir geomechanics implementation and applications of this technology to optimal field development planning for life of field will be presented and discussed.
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Well Log Editing and Pseudo Well Log Generation Workflow
By M. A. EissaWell log data are essential input for petrophysical analysis, fluid substitution, AVO modeling, synthetic seismogram to surface seismic tie, seismic inversion, seismic data processing, rock physics, reservoir characterization, 4D modeling, pore pressure prediction, rock mechanic,….etc. The first step in any project that has well log data is well log audit and edit. After editing well log data well by well, field-wide data consistency for all studied wells should be applied. Missing well logs or poor quality measured logs is always a big challenge in oil and gas industry. We are dealing most of the time with either poor quality measured logs or missing logs. Errors due to poor quality measured logs or not quality controlled pseudo logs will lead to wrong results and bad costly decisions. There are many published global relationships for pseudo log generation, for example Faust (1951) to calculate compressional velocity using resistivity and depth, Gardner et al (1974) to calculate density from compressional velocity, Castagna (1985), and Greenberg-Castagna 1993), to calculate shear velocity from compressional velocity and many other relations. The important question one should ask is should I apply any of these relations blindly to my area of study? You may agree with me that the answer is definitely no. The reason is because those relations were built using certain data set in specific location. It may be applicable to your area of study or may not be applicable. This paper is showing pseudo log generation workflow.
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Pressure Transient Analysis in Tight Fluvial Environment, Case Studies
Authors F.M. Al-Thawad and T. Abu ElsoudThis study is an attempt to shed some light on the well testing interpretation challenges of complex fluvial environments, and suggest interpretation and provide numerical well testing models to the pressure data. Four field cases are presented, a well drilled on the flank of a meandering channel, sand lenses effect on pressure data, characterization of a compartmentalized sand reservoir and a well intersecting a fracture network. In the latter case, two examples of a fracture behavior at early times and a conductive fault behavior at late times were identified. Because of the complex nature of these flow problems, the power of numerical simulation along with integrating all available data, including seismic, approach was used to match the pressure responses.
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Sweet Spots Identification over a Basin-Center Gas Play Utilizing Deterministic Seismic Inversion
Authors M.G. Al-Otaibi, M. Al-Duhailan and M. Al-MahmoudBoth pre- and post-stack deterministic inversion of 3D seismic data were applied to map sweet spots within a Permo-Carboniferous clastic unit that has been identified as a potential basin-centered gas play in Saudi Arabia. The resulting acoustic and shear impedances were utilized to locate potential drilling locations. More than 30 wells within the area of interest covered by the 3D seismic data were used for this inversion. A rock physics feasibility study including fluid substitution modeling and cross-plot analysis was carried out using eight wells; prior to conducting the seismic inversion. A mud invasion correction was performed to correct the log readings for the mud invasion zones to calibrate to in-situ reservoir conditions. Shear logs were predicted using different model transforms and fluid substitution was performed with model fluids ranging from brine to gas. This modeling was carried out using Gassmann's equation over all eight wells. Modeling results showed more than 90% correlation between acoustic impedance and total porosity. Modeling also illustrated that λρ was the most sensitive elastic moduli when substituting gas for brine. Results revealed that μρ was highly sensitive to porosity variation, but not to the pore fluid type. Sweet spots of porous hydrocarbon-bearing clastic reservoirs can therefore be identified as having low acoustic impedance, λρ, and μρ. Based on the modeling from the eight wells, a transform was generated to relate porosity to μρ, and another was generated to compute water saturation from λr. Inverted acoustic impedance was used to map the porosity sweet spots. In addition to mapping of the impedance, seismic sections of λρ and μρ were generated and showed an excellent correlation with porosity and water saturation logs from the wells. The transforms generated from the rock physics analysis were also used to create porosity and water saturation volumes from the μρ and λρ estimates, respectively.
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Formation Damage in Tight Gas Reservoirs – Prevention, Control and Remediation
Authors A. Khlaifat and H. QutobTight gas reservoirs have many unique challenges associated with the drilling, completion practices required to obtain economic production rates. Formation damage is an undesirable operational and economic dilemma that may occur during any phase of gas recovery from tight gas reservoirs. Prevention, control and remediation of formation damage are among the most important issues to be resolved for efficient exploitation of tight gas reservoirs. Designing certain chemicals and/or treatment procedures for damage control and remediation is not an easy scientific and engineering task. Recipes that work for certain cases may not necessarily work for others. Formation damage mechanisms affecting tight gas reservoirs, e.g. relative permeability and capillary pressure effects, will be discussed in this paper. A review of commonly practiced methods and tools available for prevention, control and remediation of formation damage will be presented.
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Formation Damage in Tight Gas Reservoirs from Well Test Data
More LessAs the oil and gas industry matures and the known reserves continueto be depleted, the focus moves towards more challengingenvironments. The industry is expanding its exploration and developmentefforts to include the horizons with very low permeabilities as K <0.1 md. The natural productivity of tight formations is extremely poor, and usually permeability enhancement through acid stimulation or fracturing is required to improve their productivity and make them economical. Unlike high permeability reservoirs where they can tolerate formation damage to some degrees, tight reservoirs are very sensitive to formation damage which can adversely impact the formation productivity or even impair it completely. Therefore, extra caution should be exercised during drilling, completion and production phases to avoid causing any damages to the tight reservoirs. During my presentation I will discuss several types of formation damage and show well test data from tight gas fieldsin the Middle East to highlight the above theme.
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Validation of Shallow Microseismic Monitoring Array for Deep Reservoir Monitoring
By A.C RoscaMonitoring reservoir stimulation operations provides data for predicting production performance and for reservoir characterization but also, potentially, for compliance with local regulations. With improved drilling and completion technology the depth of the unconventional reservoirs produced increases and the options for deploying cost–effective microseismic monitoring equipment become limited. The monitoring technology has to adapt by optimizing acquisition geometry and data processing as well as the procedures that demonstrate the validity of the results. A practical solution for microseismic monitoring of stimulation operations in an unconventional reservoir under development is a surface or shallow distributed array. We are analyzing two such datasets together with complementary deep borehole sensor datasets in order to understand how to predict and validate the expected performance of distributed surface and shallow arrays. The surface recorded data is processed by stacking and event detection and location are accepted based on statistical criteria. This catalog of events is compared to the one obtained from borehole array where waveforms can be analyzed individually in order to validate the quality of event analysis.
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Micro-quartz Grain Coatings: Do they help in Tight Gas Sandstones?
By S. ShammariExploration for so-called “tight-gas sandstones” has increased significantly in recent years due to technological advances in drilling and fracturing treatments. Tight gas sands are those with very low porosity and permeability that cannot be economically produced without stimulation or horizontal drilling. It is well known that zones of higher porosity/permeability, “sweet spots”, within otherwise tight sandstones can greatly enhance their economic viability.
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Reservoir Sweet Spots in the Arabian Petroleum Basin; Types and Controls
By M.H. KhalilReservoir sweet spots are areas with better permeability relative to the surrounding country rocks. Theyrepresent a major opportunity in exploration and development of tight gas reservoirs. This paper describes the types of reservoir sweet spots in the Arabian basin and the most common factors controlling their development. Three types of reservoir sweet spots are identified in the Arabian basin; tectonic, sedimentologic and diagenetic sweet spots. The tectonic sweet spots are areas with open fractures being the main control of reservoir productivity. The sedimentologic sweet spots are areas with coarser-grained and possibly thicker sandstone than the surrounding clastics, or areas where porous carbonate build-ups exist. The diagenetic sweet spots are areas with improved permeability due to re-crystallization, dissolution, dolomitization, or early grain coating caused by the flowingfluids. The reservoir sweet spots result from the interplay of one or more of three factors; a) local redistribution of tectonic stresses at the heterogeneous basement fabrics, b) combined effect of sea level changes and sediment influx, and c) diagenetic processes acting on reducing rock volume and increasing its brittleness. Integrated geologic analysis of these factors is a key element to predictpotential locations for sweet spots.
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Fluid Technologies for Tight Gas Reservoir Stimulation
By T. Huanggas reservoir stimulation.Surfactant micellar fluids structured very low-molecular-weight surfactants into elongated micelles have been used as stimulation fluids trying to remove the drawback of polymer fluids. The viscoelastic behavior of these surfactant micellar fluids is believed to be rooted in the overlap and entanglement of elongated micelles which yields both the viscous and elastic characteristics to the fluid.High fluid leak-off and difficult cleanup associated with traditional surfactant micellar fluidshave, however, limited their utilityintight gas stimulation applications. Our recent work has shown that the addition of carefully selected inorganic nano-crystals - less than 100 nanometers in size – to the new surfactant micellar fluid formulation can overcome the above limitation without negatively effecting the internal breaking mechanisms.Our recent results highlight the mechanism of fluid loss control and easy cleanup of this nanoparticle reinforced surfactant micellar fluid system for tight gas stimulation applications.
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Unconventional Gas and HP-HT Reservoirs : Overview of Main Challenges and Use of 4D Seismic and Geomechanics as a Monitoring and Risk Mitigation Tool
By A. Onaisietion. The presentation will focus on two main topics : • An integrated workflow that combines results from 4D seismic inversion, geomechanics modelling and reservoir simulations in a shared earth model • Application to the Elgin and Franklin HP/HT fields located in the UK Central Graben of the North Sea : o Interval time-shifts using an in-house warping method o A coupled faulted reservoir and geomechanical models to determine both the stress redistribution within and around the reservoir including associated reactivated fault slips, and to derive synthetic 4D time-shifts with the help of a rock physics model o Closing the loop by achieving reasonable match between the observed and the synthetic 4D time-shifts. This integrated study proved to be a useful tool for progressing understanding of the reservoir and production behaviour of the Elgin and Franklin Fields, with the ultimate goal being identification of new drilling targets, mitigation of casing integrity risks, safe infill drilling.
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Shift Down Resource Triangle Brings Shift in Cost Structure
By C. FreddThe industry shift down the resource triangle to unconventional resources such as tight gas has led to new challenges. Tight gas reservoirs cannot be produced economically without hydraulic fracturing. As a result, the strategies for drilling, completion, and stimulation workflows are changing to enable hydraulic fracturing. This includes the application of horizontal wells and completion designs to enable the ultimate objective of multi-stage fracturing. With these changes comes a shift in the cost structure that can put as much as 60% of the overall well cost on the fracturing operation. This presentation will provide a snapshot of how the overall well cost shifts as we move down the resource triangle from conventional to unconventional reservoirs. Well cost distribution examples from the Middle East and around the world will highlight differences for the development of various reservoir types such as carbonate, sandstone, tight gas, and shale gas.
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Planning, Optimizing, and Evaluating Geologic Risk and Completion Performance in Tight Gas Reservoirs
By T. JuddThe exploration and exploitation of unconventional gas resources is an expanding trend and is an interesting topic especially within the context of the international marketplace. Unlike the North American tight gas business, where thousands of wells are drilled yearly and the operational infrastructure is proven and in place, the international gas market challenges are significantly different. Rather than enjoying tens of wells to confirm reservoir properties and efficient completion techniques, most international tight gas projects have five or less wells to prove concept sustainability. Subsequently, the key risk is not the hydrocarbon resource itself, but instead the early recognition of areas where critical geological and reservoir factors exist to enable economic and sustainable field development plans. Additionally, the rapid identification and application of the most efficient completion solution is paramount to progress of an economically sanctionable project. Hydraulic fracturing is a critical component of the completion process when appraising, developing, and producing tight gas reservoirs. However, for most regions outside of the large and well established stimulation markets, business and operational success for both operators and service providers is dependent on the ability to maximize the number of synergies while managing an integrated service offering. Therefore, the development of a tailored and carefully planned workflow; that enables speedy evaluation of both the geological and completion performance is essential. Tight gas reservoir understanding is not only limited to presence of hydrocarbons, reservoir distribution, fluid saturation, reservoir contacts, and other geological aspects but is also equally dependent on gas inflow performance (via hydraulic fracturing), ensuring economically attractive well test flow rates and confirmation of sustainable long term production. This generally includes a requirement for an extended well-test in order to confirm the long term reservoir/well behaviour. As a result, an appropriate technical and operational evaluation program for tight gas reservoirs was developed for this project that allowed for several wells to potentially demonstrate the extent, sustainability and nature of reservoir variability and productivity. This presentation will illustrate, the workflow process also incorporates evaluation of these treatments in order to quantify hydraulic fracturing performance and reservoir deliverability. The application of a sound technical strategy, innovative well placement program, and a tailored workflow, provides the greatest chance of success in meeting crucial milestones. It is important that the project stays within technical and budgetary constraints while maintaining flexibility and options for modifications, while not jeopardizing future resource development.
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Applying a New Systematic and Dynamic UBD Procedures Prevented Formation Damage, Wellbore collapse and Improved Oil Production
Authors K. Kartobi, A. Mazouzi, A. Berkat, O. Dhina, H. Qutob, N. Barakat, F. Grayson and A. MareiThe Hassi Massoud oil field is the largest of its kind in Algeria. The reservoir was discovered in 1956 and produces from a Cambrian-age at approximately 3400 meters depth. It produces 45°API oil from a thick Cambro-Ordovician sandstone formation. This sandstone is extremely hard, abrasive and slow to drill. The reservoir is naturally fractured in some parts. Fractures are either open or plugged with materials such as shale, silica, anhydrite, pyrite and bitumen. Porosity is ranging from 6 to 12%. Generally, the permeability is low with a range of less than 1 to more than 100 md in open-fractures layers.
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High Stress Anisotropy : A Common Feature of Tight Gas Reservoirs ?
By A. OnaisiExperience s from three fields involving appraisal and development of Tight Gas Reservoirs (TGR) located in completely different regions share common geomechanical features, especially high in situ stress anisotropy that has a strong impact on drilling and stimulation operations. The presentation will start by introducing stress anisotropy impact in the context of TGR. Geomechanical models of stresses and other mechanical properties for the three fields and the methodology used to determine them will then be shown. Finally, an analysis of the impact of geomechanical conditions on drilling and stimulation operations will be investigated. Among the major issues identified is the optimization of the well trajectory, i.e. azimuth and inclination, according to several criteria that are wellbore stability, especially feasibility of under balanced drilling, interception of natural conductive fracture , success of hydraulic fracturing.
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Exploring and Developing Tight Gas Reservoirs in the Middle East: challenges and opportunities
By R. AgutUnconventional gas resources have major strategic implications for the future of the world’s natural gas supply. The Middle East could play a significant role in this domain, considering its prolific reservoir and source rocks potential. The presentation will focus on the potential role of unconventional gas resources in the gas market of the Middle East. The importance of multi discipline integration and innovation will be underlined as well as the economic challenges both in terms of cost reduction needs and gas price problematic. The presentation will also address the challenges of acceptability both in terms of environment and social responsibility. Tight Gas Reservoir exploration and development requires first the tried and tested know-how already possessed by Total through its activities in mature tight gas countries such as the US. Based on this knowhow, Total is reinforcing its positions in this promising segment through ambitious Research and Development programs.
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The Role of Geomechanical Engineering in Enhancing Production in Integrated Tight Gas Developments
Authors T. Addis, T. Finkbeiner, S. Perumalla, A. Santagatti and D. MoosThe challenges associated with tight gas developments include, the low initial production rates and the rapid production fall-off within the first years of production for any well. Tight gas developments require a multidisciplinary approach in which each element of a field development is addressed in order to develop the gas resources optimally. Each project will need to optimize the technologies and approaches used in order to successfully develop the tight gas resources. Experience from around the world may be relevant to some of these developments, but direct technology transfer from one field to another may not be relevant when the tight gas resources are on different continents with different geology and geological histories. This paper and presentation will address some of the experience gained in the Middle East and relevant North America experience during the appraisal phases of tight gas developments, focusing on how aspects of Geomechanical Engineering applied to stimulation design can be used to optimize initial production rates. In addition, it will address, as projects move from appraisal to the development stages, how Geomechanical engineering considerations may help in maintaining the production (reducing the production decline curve), through phased and structured development drilling campaigns.
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The Quest of the Key Hidden Signal
By L. PaugetSeveral approaches were integrated in order to improve reservoir characterization in field A and optimize the planning of additional delineation and field development. A dense 3D seismic data was acquired on this field. The elastic (IP/IS) impedance inversion of the PrSTM 3D seismic dataset was performed with the objective of providing suitable datasets for reservoir characterization. An evaluation of the main results had the objective of establishing a workflow for delineating potential sweet spots in the main reservoir. In addition, the IP/PR cross plots demonstrate a good discrimination of sandy and shaly facies.
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Stimulation of Low-Permeability Gas Reservoirs in Latin America
By Julio GomezGas figures show that Latin America holds only 4.3% of the world’s conventional gas reserves. However, consumption has become important in some countries such as Argentina and Brazil. On the other hand, some estimates for unconventional reserves set Latin America with 29% of the world’s reserves, which would be comparable with combined US and Canadian reserves. Despite these interesting data, Latin America has undertaken only a few projects involving tight and unconventional gas development. This is relevant in an area where most of the countries satisfy their energy demand from means including gas imports.
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Economic Development of Tight Gas Resources in the Middle East
More LessThe presentation will consider the keys issues and requirements for the successful development tight gas resources; where tight gas fits in the mix of conventional and unconventional gas resources; and how this resource base could be utilized in meeting the growing energy needs of the region. The economics of tight gas development will be reviewed to identify the key value levers and break even gas prices required to generate a 10% project rate of return (IRR).
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Comparisons and Contrasts of Tight Gas Sand and Shale Gas Developments - Drawing upon North American Experience and Trends
Authors D. Georgi, B. Kennedy, B. Knecht and U. Ahmed“All Shale Gas reservoirs are not the same” and “there are no typical Tight Gas reservoirs,” are two statements found numerous times in the literature on shale gas and tight gas reservoirs. The one common aspect of developing these unconventional resources is that wells in both must be ‘hydraulically fractured’ in order to produce commercial amounts of gas. Operator challenges during each phase of the asset life cycle (Exploration, Appraisal, Development, Production, and Rejuvenation) of both shale gas and tight gas are similar. Drilling, well design, completion methods and hydraulic fracturing are similar; but reservoir analysis and formation evaluation techniques are quite different. Much of the experience in shale and tight gas has been developed in the U.S.; and most of the technologies that have been developed by operators and service companies are transferable to Middle East, North Africa and other parts of the world. However, the infrastructure, including equipment and service company availability, governmental regulations, logistics, processing, environmental considerations, and pricing are not the same as in the U.S.; which may impact the rate of the technology transfer as well as the selection of the technology. It is likely that environmental concerns and the drive to reduce development costs of tight and shale gas reservoirs will drive a new “factory” approach to the development of these two types of developments. Whilst shale gas and tight gas reservoirs are no longer considered to be ‘unusual’ projects by investors in the U.S., elsewhere they are regularly referred to as “unconventional resources”. As a subsequence of the technical, logistical and cost challenges mentioned above, shale and tight gas reservoirs require special attention in terms of economic analysis. The economics of producing shale gas and tight gas reservoirs will be discussed in this workshop, with case studies that can demonstrate the challenges of evaluating the commercial viability of projects.
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Reserve Booking of Shale Gas Reservoirs
More LessUnconventional gas development in North America has grown exponentially in the last twenty years due mainly to advances in completion technology and favorable economics. Progress in booking of unconventional gas reserves has been slower. This presentation discusses the applicability of conventional reserve booking techniques to unconventional gas reservoirs and provides insight into North American shale gas and coalbed methane reserve booking practices, as they pertain to a frontier environment such as the Middle East.
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