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Search Petrowiki: Core analyses in tight gas reservoirs
...Core analyses in ...tight gas reservoirs Obtaining and analyzing cores is crucial to the proper understanding of any layered, complex rese...the cores. To provide all the data needed to characterize the reservoir and depositional system, a core should be cut in the pay interval and in the layers of rock above and below the pay interval. ...
Obtaining and analyzing cores is crucial to the proper understanding of any layered, complex reservoir system. To obtain the data needed to understand the fluid flow properties, the mechanical properties and the depositional environment of a specific reservoir requires that cores be cut, handled correctly, and tested in the laboratory using modern and sophisticated laboratory methods. Of primary importance is measuring the rock properties under restored reservoir conditions. The effect of net overburden pressure (NOB) must be reproduced in the laboratory to obtain the most accurate quantitative information from the cores. To provide all the data needed to characterize the reservoir and depositional system, a core should be cut in the pay interval and in the layers of rock above and below the pay interval. Core from the shales and mudstones above and below the pay interval help the geologist determine the environment of deposition.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
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- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock (0.56)
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...Log analyses in ...tight gas reservoirs Logs provide the most economical and complete source of data for evaluating layered, complex, low... porosity, tight gas reservoirs. The recommended logging suite for a ...
Logs provide the most economical and complete source of data for evaluating layered, complex, low porosity, tight gas reservoirs. All openhole logging data should be preprocessed before the data are used in any detailed computations. The steps required to preprocess the logs are: * Digitize all log data * Depth shift the data as required * Perform all environmental corrections * Normalize data so that all logs from different wells are reading the same in zones, such as thick marine shales in which one expects the log readings to be consistent from well to well.[1][2] Once the data have been preprocessed and stored in a digital database, a series of statistical analyses must be conducted to quantify certain evaluation parameters. The series of articles by Hunt et al.[3] clearly describes the steps required to: * Preprocess the logs * Develop the correlation parameters * Analyze logs in shaly, low porosity formations To correctly compute porosity in tight, shaly (clay-rich) reservoirs, one of the first values to compute is the volume of clay in the rock. The clay volume is normally computed using either the self-potential (SP) or the GR log readings.
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...Modeling tight gas reservoirs To evaluate a layered, ...tight gas reservoir and design the well completion, the operator must use both a reservoir model and a hydrau...portant to the design engineer: * The gross thickness of the reservoir * The net thickness of the gas producing interval * The permeable thickness that accepts fluid loss during the hydraulic fracture...
To evaluate a layered, tight gas reservoir and design the well completion, the operator must use both a reservoir model and a hydraulic fracture propagation model. The data required to run both models are similar[1] and can be divided into two groups. One group consists of data that can be "controlled." The second group reflects data that must be measured or estimated but cannot be controlled. The data required to run a reservoir model depends on the type of model one chooses to use.
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...Reserves estimation in tight gas reservoirs The resource triangle, Fig. 1, describes the distribution of original ...gas in place (OGIP) in a typical basin.[1] At the top of the triangle are the high permeability ...reservoirs. These ...
The resource triangle, Figure 1, describes the distribution of original gas in place (OGIP) in a typical basin.[1] At the top of the triangle are the high permeability reservoirs. These reservoirs are small, and, once discovered, as much as 80 to 90% of the OGIP can be produced using conventional drilling and completion methods. As we go deeper into the resource triangle, the permeability decreases, but the size of the resource increases. Higher gas prices and better technology are required to produce significant volumes of gas from these tight gas reservoirs. The recovery efficiency is computed by dividing the cumulative gas produced by the OGIP volume.
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...Permeability estimation in tight gas reservoirs In addition to knowing the values of in-situ stress, it is also extremely important to know the v...s of formation permeability in every rock layer. The values of permeability control everything from gas flow rate to fracture fluid leakoff. It is impossible to optimize the location of the perforations,...permeability in every rock layer. In addition, one must know the formation permeability to forecast gas reserves and to analyze post-fracture pressure buildup tests. To determine the values of formation ...
In addition to knowing the values of in-situ stress, it is also extremely important to know the values of formation permeability in every rock layer. It is impossible to optimize the location of the perforations, the length of the hydraulic fracture, the conductivity of the hydraulic fracture, and the well spacing, if one does not know the values of formation permeability in every rock layer. In addition, one must know the formation permeability to forecast gas reserves and to analyze post-fracture pressure buildup tests. To determine the values of formation permeability, one can use data from logs, cores, production tests, and prefracture pressure buildup tests or injection falloff tests. The most data that are available vs. depth comes from openhole logs.
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...Statistical data correlations in tight gas reservoirs Tight gas reservoirs generate many difficult problems for geologists, engineers, and managers. Cumulative ...gas recovery (thus income) per well is limited because of low ...gas flow rates and low recovery efficiencies when compared to most high permeability wells. To make a m...
Tight gas reservoirs generate many difficult problems for geologists, engineers, and managers. Cumulative gas recovery (thus income) per well is limited because of low gas flow rates and low recovery efficiencies when compared to most high permeability wells. To make a marginal well into a commercial well, the engineer must increase the recovery efficiency by using optimal completion techniques and decrease the costs required to drill, complete, stimulate, and operate a tight gas well. To minimize the costs of drilling and completion, many managers want to reduce the amount of money spent to log wells and totally eliminate money spent on extras such aswell testing. However, in these low-permeability layered systems, the engineers and geologists often need more data than is required to analyze high permeability reservoirs.
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...Tight gas reservoirs Tight gas is the term commonly used to refer to low permeability ...reservoirs that produce mainly dry natural ...gas. Many of the low permeability ...
Tight gas is the term commonly used to refer to low permeability reservoirs that produce mainly dry natural gas. Many of the low permeability reservoirs that have been developed in the past are sandstone, but significant quantities of gas are also produced from low permeability carbonates, shales, and coal seams. Production of gas from coal seams is covered in a separate chapter in this handbook. In this chapter, production of gas from tight sandstones is the predominant theme. However, much of the same technology applies to tight carbonate and to gas shale reservoirs. Tight gas reservoirs have one thing in common--a vertical well drilled and completed in the tight gas reservoir must be successfully stimulated to produce at commercial gas flow rates and produce commercial gas volumes. Normally, a large hydraulic fracture treatment is required to produce gas economically.
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...Category:5.8.1 Tight gas . Pages in category "5.8.1 ...Tight gas" The following 6 pages are in this category, out of 6 total. C * ...Core analyses in ...
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...Tight gas drilling and completion The definition of a ...tight gas reservoir is that the reservoir does not produce at commercial ...gas flow rates, or recover commercial volumes of natural ...
The definition of a tight gas reservoir is that the reservoir does not produce at commercial gas flow rates, or recover commercial volumes of natural gas, unless a hydraulic-fracture treatment is properly designed and pumped. As such, the entire drilling and completion procedures should focus on making sure the optimum fracture treatment can be designed and pumped in the field. When drilling a tight gas well, the most important aspect of the drilling operation is to drill a gauge hole. Many times this means the well should be drilled at a balanced mud weight or slightly overbalanced. In other cases, air drilling or underbalanced drilling works best, as long as the hole remains in gauge.
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...Hydraulic fracturing in tight gas reservoirs The definition of a ...tight gas reservoir is one that must be successfully fracture treated to produce economic volumes of ...gas at economic flow rates. In this page, we will discuss a few basic considerations for fracture treat...
The definition of a tight gas reservoir is one that must be successfully fracture treated to produce economic volumes of gas at economic flow rates. In this page, we will discuss a few basic considerations for fracture treatment design and application. Propping agent selection * 1.4 Fracture treatment execution in the field * 2 Post-fracture reservoir evaluation methods * 3 Transient flow considerations * 4 Types of models * 4.1 Semisteady-State models * 4.2 Semianalytical models * 4.3 Finite difference models * 5 Analyzing post-fracture production data * 6 Post-fracture pressure transient analysis * 7 Nomenclature * 8 References * 9 Noteworthy papers in OnePetro * 10 External links * 11 See also * 12 Category Many tight gas reservoirs are thick, layered systems that must be hydraulically fracture treated to produce at commercial gas flow rates. To optimize the completion, it is necessary to understand the mechanical properties of all the layers above, within, and below the gas pay intervals. Basic rock properties such as in-situ stress, Young's modulus and Poisson's ratio are needed to design a fracture treatment. The in-situ stress of each rock layer affects how much pressure is required to create and propagate a fracture within the layer. The values of Young's modulus relate to the stiffness of the rock and help determine the width of the hydraulic fracture.
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