Fluid Selection for Fracturing High-Permeability Formations

McGowen, J.M.; Vitthal, Sanjay; Parker, Mark A.; Rahimi, Al; Martch, William Edward

doi:10.2118/26559-ms

Cited by 31 publications

(2 citation statements)

References 54 publications

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“…Selection of fracturing fluids depends on formation & desired permeability. Reservoirs with sufficient permeability need only to bypass damage from drilling operations . Water with KCl, NaCl, bactericides, scale inhibitors along with polyacrylamide, can be used as a solvent for water‐saturated coal seams.…”

Section: Cbm Productionmentioning

confidence: 99%

Coal Bed Methane Enhancement Techniques: A Review

2019

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Paper investigates the potential impact of Coalbed methane (CBM) in near present and future. CBM is a natural gas that mainly consists of methane present in physically adsorbed state on the surface of porous coal seam under geothermal pressure. CBM is a cleaner fuel which can be used in the transportation industry, conventional power generation, and many other ways. 50–60% of CBM recovery can be obtained under primary operations and enhancement techniques can increase recovery as high as 80%. Recovery enhancement can be made through temperature increase, pressure release or by selective adsorption in which an injection gas displace methane from coal surface. Recovery through the use of CO2, N2, CO2 & N2 mixture is discussed in detail. Underground coal gasification can be used to recover energy from methane depleted, unminable coal reservoirs and has many advantages over surface mining. CBM consists of both thermogenic and biogenic origin. Depleted CBM reservoirs are observed to produce methane even after recovery is done. Native naturally occurring microbes decomposes coal into methane which explains biogenic origin, through a series of reaction. Kinetics of these decomposition reaction could be escalated significantly through the injection of nutrients and genetically enhanced methanogens. These processes has a great potential and could provide a fossil fuel which is almost renewable as large amount of methane can be generated from small amount of coal.

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Section: Cbm Productionmentioning

confidence: 99%

Coal Bed Methane Enhancement Techniques: A Review

2019

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“…Refs. [5][6][7][8][9][10][28][29][30] but space restrictions require that most points be made by extensive references to more general work and explained in the context of overall dominant fracturing issues. As well, unfortunately, presentation will be somewhat inhibited by delayed approval for use of field data and somewhat incomplete laboratory experiments.…”

Section: Introductionmentioning

confidence: 99%

Critical Issues in Hydraulic Fracturing of High-Permeability Reservoirs

Cleary¹

1994

Proceedings of European Production Operations Conference and Exhibition

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The paper focuses on the sub-class of issues which can affect/dominate the performance of hydraulic fracturing in (gas or oil) reservoirs with higher-permeability, of order 1 mD (1Om D) or more in gas (oil) reservoirs. These issues are placed in the broader context of five major aspects which have been newly extracted from data-analysis over the past five years and which have greatly polarized/reversed industry thinking on hydraulic fracturing: heretofore, primary implications have been for lower-permeability reservoirs, where convection and tortuosity constraints impose a narrow (or nonexistent) window for successful design of fracture treatments, especially in light of properly-interpreted higher net fracturing pressures (than conventional industry models) induced by nonlinear rock response to (mul~iple) fractures. A much wider design window has made successful stimulation of higherpermeability reservoirs relatively easy and economically more rewarding, a result surprising to some. Perhaps more surprising are conclusions that appropriate proppant concentration may vary somewhat inversely with reservoir permeability and that fractures may preferentially grow (vs. initiate) in lowerpermeability strata/sections, the main theme of this paper. Fluid rheology also plays a much more important role in (leakoff behavior during) fracturing of high-permeability reservoirs vs. a lower-permeability role limited to near-wellbore (tortuosity) response. Some issues are illustrated with simulations performed by a unique computerized system, which allows credible matching of (treatments and production) data over a wide range of reservoir, fluid and job parametersthereby allowing establishment of conclusions with casehistories, supported by some careful laboratory experiments. With the aid of this computerized capability, dramatic results have been achieved in reducing job costs and improving production, especially for low-to medium-permeability reservoirs, but many of the implications can be carried over to high-permeability reservoirs.

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