The following maps show the drilling history and oil and gas production of selected low-permeability, continuous-type shale reservoirs. Selected geologic characteristics pertinent to occurrence of producible oil and gas resources are also shown when available. The Volumetrically Largest U. Top U.
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September, — OnePetro. This study presents a novel method to estimated pore volume compressibility of shale samples based on mercury injection test data. We revisit our previous study SPEPA for more realistic estimation of pore volume compressibility for shale samples.
We present a mathematical model to determine accessible porosity and pore compressibility as a function of pressure using Mercury Injection Capillary Pressure MICP data. During MICP testing in a typical shale sample, the rock sample experiences conformance, compression, and intrusion stages as effective pressure increases. By evaluating compression stage, we calculate bulk compressibility.
Further by introducing a system of equations, bulk compressibility is decomposed to estimate accessible pore and grain compressibility separately. Different from our previous model, in this study grain compressibility is calculated based on weight average of mineralogy determined from Fourier-transform infrared spectroscopy FTIR experiments. Moreover, bulk compressibility obtained from MICP data is compared with the values calculated from ultrasonic velocity measurements.
Samples from both Haynesville shale plays are used to perform our study and validate the hypothesis. Moreover, when compared with ultrasonic velocity measurements, results indicate that bulk compressibility obtained from MICP is overestimated at lower pressures and slightly underestimated at higher pressures.
The outcome of the paper changes the industry's take on prediction of the reservoir performance, especially the rock compaction mechanism. This study suggests that production owing to rock compaction can be much greater than what has often regarded, which can change the performance evaluation on a great number of reservoirs in terms of economic feasibility.
The Haynesville Shale is an informal, popular name for a Jurassic Period rock formation that underlies large parts of southwestern Arkansas , northwest Louisiana , and East Texas. The Haynesville Shale underlies an area of about 9, square miles and averages about to feet thick. It contains vast quantities of recoverable natural gas. This natural gas is known as " shale gas " because the wells produce from low permeability mudstones that are also the source for the natural gas.
Pore Volume Compressibility in Shale - Revisited
It was deposited about million years ago in a shallow offshore environment. Geologists have long known that the Haynesville Formation contained natural gas. However, because of its low permeability the Haynesville was originally considered to be a gas source rock rather than a gas reservoir. Today, natural gas production from the Haynesville occurs from rocks about two miles beneath northwestern Louisiana, southwestern Arkansas and eastern Texas. The Marcellus Shale is a new gas resource of the Appalachian Basin. Haynesville Stratigraphy Gas production is mainly in the Haynesville Formation. Find out what others are being offered and share advice at this forum.