Fracture Height Growth and Production From Multiple Reservoirs

Saulsberry, J.L.; Schraufnagel, R.A.; Jones, Andrew Meirion

doi:10.2118/20659-ms

Cited by 6 publications

(1 citation statement)

References 3 publications

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“…Numerous technological advances that have been noted previously, such as horizontal drilling capabilities 266,267 and hydraulic fracturing methods, 13,15,[268][269][270][271][272][273][274][275][276][277] (263) Seidle, J. P. J. Pet Well spacing and well patterns have an important role in production optimization.…”

Section: How Cbm Recovery and Co 2 -Ecbm Recovery Are Performedmentioning

confidence: 99%

Sequestration of Carbon Dioxide in Coal with Enhanced Coalbed Methane RecoveryA Review

et al. 2005

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This article reviews the storage of captured CO2 in coal seams. Other geologic formations, such as depleted petroleum reservoirs, deep saline aquifers and others have received considerable attention as sites for sequestering CO2. This review focuses on geologic sequestration of CO2 in unmineable coalbeds as the geologic host. Key issues for geologic sequestration include potential storage capacity, the storage integrity of the geologic host, and the chemical and physical processes initiated by the deep underground injection of CO2. The review topics include (i) the estimated CO2 storage capacity of coal, along with the estimated amount and composition of coalbed gas; (ii) an evaluation of the coal seam properties relevant to CO2 sequestration, such as density, surface area, porosity, diffusion, permeability, transport, rank, adsorption/desorption, shrinkage/swelling, and thermochemical reactions; and (iii) a treatment of how coalbed methane (CBM) recovery and CO2-enhanced coalbed methane (ECBM) recovery are performed (in addition, the use of adsorption/desorption isotherms, injection well characterization, and gas injection are described, as well as reservoir screening criteria and field tests operating in the United States and abroad); (iv) leak detection using direct measurements, chemical tracers, and seismic monitoring; (v) economic considerations using CO2 injection, flue gas injection, and predictive tools for CO2 capture/sequestration decisions; (vi) environmental safety and health (ES&H) aspects of CO2-enhanced coalbed methane/sequestration, hydrodynamic flow through the coal seam, accurate gas inventory, ES&H aspects of produced water and practices relative to ECBM recovery/sequestration; (vii) an initial set of working hypotheses concerning the chemical, physical, and thermodynamic events initiated when CO2 is injected into a coalbed; and (viii) a discussion of gaps in our knowledge base that will require further research and development. Further development is clearly required to improve the technology and economics while decreasing the risks and hazards of sequestration technology. These concerns include leakage to the surface, induced seismic activity, and long-term monitoring to verify the storage integrity. However, these concerns should not overshadow the major advances of an emerging greenhouse gas control technology that are reviewed in this paper.

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Section: How Cbm Recovery and Co 2 -Ecbm Recovery Are Performedmentioning

confidence: 99%

Sequestration of Carbon Dioxide in Coal with Enhanced Coalbed Methane RecoveryA Review

et al. 2005

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Lessons Learned From Modeling Hydraulic Fracture Treatments in Coals Using a Fully Functional Three-Dimensional Fracture Model in a San Juan Basin Project

Ramurthy

Lyons

2007

Rocky Mountain Oil &Amp; Gas Technology Symposium

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The two main objectives of using a hydraulic fracture model in coals are:optimization of job design and placement, andpost-fracture diagnostics. Though certain limitations still exist, hydraulic fracture modeling in coals has undergone major advancements in the past decade. Pseudo or lumped three-dimensional (3-D) models have usually been employed to try and meet the objectives mentioned above. The effectiveness of using such models in coals has been very limited. Fully functional 3-D models are currently available in the industry and can be used to obtain better estimates of the fracture dimensions. This paper shows that a grid-oriented fully functional 3-D fracture simulator with shear decoupling can be especially useful in coals for post-fracture diagnostics if sufficient input data can be fixed from logs and Diagnostic Fracture Injection Tests (DFIT). When problems occurred with placement of fracture treatments, especially in the upper Fruitland coals of a San Juan basin project, instead of experimenting with various ideas arbitrarily, technical evaluation using DFIT data and fracture modeling with a grid-oriented, fully functional 3-D fracture simulator, was used to pin-point the issues and address them accordingly. This paper will discuss the deficiencies of using 2-D and pseudo-3-D fracture models in coals and also will discuss the lessons learned from using a grid-oriented, fully functional 3-D fracture simulator in this project along with the successful implementation of the results developed from the modeling work. Literature Review Over the last 25 years, numerous papers have been published regarding hydraulic fracturing and modeling in coals.1–19 Trevits, et al.1 investigated how well the fractures are contained in coal during a stimulation treatment. In this study, 12 vertical wells were drilled, completed, and subsequently evaluated via mining excavation. The treatment designs were adjusted using the information gathered from excavation. Layne, et al.2 through their U.S. Department of Energy (DOE) work wanted to advance the hydraulic fracturing techniques in coals by improving the understanding of fracturing treatments using mineback observations. They used five fracture models that were developed under contract to the DOE to analyze the mineback observations. Jones, et al.3 evaluated 130 fracturing treatments in their study. They observed high treating pressures during fracture treatments in Black Warrior basin and attributed the following as possible causes:high pore pressure buildup due to fluid leakoff,multiple fracture propagation, andfracture-tip plugging by coal fines. They modified a pseudo-3-D model to replicate a fracture tip-screenout caused by coalfines plugging within the pad. Jones, et al.4 presented another paper addressing the unusual treating pressures observed during hydraulic fracture treatments in coal. As part of that work, they presented methodologies to design fracture treatments in coal. Logan, et al.5 performed extensive fracture treatment diagnostics in two wells at the GRI Deep Coal Seam Project test site. Data collected from such diagnostics was presented in their work. Holditch, et al.6 described four basic scenarios to explain fracture growth in coal reservoirs but did not discuss the need for a fully functional 3-D fracture model to address these four scenarios. The fracture model used by Jones, et al.3,4 was used in a study by Saulsberry, et al.7 to determine the fracture geometry and its effectiveness from two separate hydraulic fracturing treatments in the Oak Grove field of Alabama. In the same field, Palmer and Sparks 8 used a downhole camera to study the propped fractures in coalbeds. The information gathered was then used to calibrate a pseudo-3-D fracture model for optimizing stimulation treatment designs. The authors clearly state that more detailed modeling required the use of a fully functional 3-D fracture simulator.

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Laboratory Tests To Determine Parameters for Hydraulic Fracturing of Coalbed Methane

Penny¹,

Conway²,

Klem³

1991

Low Permeability Reservoirs Symposium

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A series of laboratory experiments have been conducted with specially designed equipment to aid in quantifying the pressure drop of proppant-Iaden slurries while flowing between coal. and measuring the conductivity of various proppants once placed in a coal fracture.The rheology and proppant transport of boratecrosslinked fluids with and without proppant has been evaluated in a slot with walls cast from the surfaces of fractured coal. in an effort to quantify the impact of tortuous coal fractures on the pressure drop down the fracture. A second device has been constructed to view the flow of slurries through cleats of various sizes. Data is presented on the measurement of pressure increases due to bridging vs cleat size, proppant size, concentration and rate.The long-term conductivity and permeability of various sands have been measured between fractured Fruitland Coal. Predictive equations have been developed to predict permeability between coal vs sand sieve size, and predict loss of permeability due to embedment. Non-Darcy flow factors and constants are presented for calculating non-Darcy flow vs sand type and size between coal.References and illustrations at end of paper.

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Fracture Height Growth and Production From Multiple Reservoirs

Abstract: The objective of two separate fracture treatment experiments performed in the Oak Grove Field, Alabama, was to estimate fracture geometry and effectiveness.

Cited by 6 publications

References 3 publications

Sequestration of Carbon Dioxide in Coal with Enhanced Coalbed Methane RecoveryA Review

Sequestration of Carbon Dioxide in Coal with Enhanced Coalbed Methane RecoveryA Review

Lessons Learned From Modeling Hydraulic Fracture Treatments in Coals Using a Fully Functional Three-Dimensional Fracture Model in a San Juan Basin Project

Laboratory Tests To Determine Parameters for Hydraulic Fracturing of Coalbed Methane

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