Investigation of a New Fracturing Fluid and Conductivity Enhancement Technology on Coalbed Methane Production

McCabe, Michael A.; Robert, Lavelle M.; Blauch, Matt; Terracina, J.M.; Lehman, Lyle; Bowles, Brad

doi:10.2118/52193-ms

Cited by 16 publications

(7 citation statements)

References 5 publications

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“…Pleasant coals could be more effectively stimulated by placing 10,000 lb/ft of proppant successfully. McCabe et al (1999) describe the mechanism of coal fines creation in CBM fracturing treatments and the way that SMA additives effectively control coal fines migration. The Data Set A design team also felt it was important to maintain the SMA additive due to the excellent results seen in coal fields in other areas.…”

Section: Statement Of Theory and Definitionsmentioning

confidence: 99%

Improved Fracturing Technology for Coalbed Methane Gas Wells in Western Pennsylvania Increases Gas Production Over Offset and Historic Wells in Mount Pleasant CBM Field

Snyder

Jockel

Lopez³

2007

All Days

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fax 01-972-952-9435. AbstractCoalbed methane (CBM) drilling has been occurring in the Mount Pleasant, Westmoreland County, Pennsylvania area for about a decade, with various fracturing techniques applied in these CBM wells using conventional gas well fracture methods. However, production has been response-limited either due to incomplete placement of fracturing designs and/or because these older conventional gas well fracturing designs were not effective for these CBM wells.Due to the poor nature of the production in these coal seams, it was determined to look more closely at the fracturing techniques and apply newer technologies designed specifically for CBM well fracturing. The objective of this review was to make future drilling of the CBM wells in this area economically feasible. This paper will discuss specifics of the coalbed field, fracture designs applied in the past and in the present, fracturing job design considerations, and chemical attributes for the fracturing job.Most of the historic fracs placed on these wells used a linear gel guar system, low sand concentrations, low sand volumes, larger proppant size, and relied on high pump rates to put the sand away. More recent frac designs were developed to utilize a hybrid crosslinked fluid system, higher sand concentrations, higher sand volumes, and a lower pump rate. Also, chemicals designed more specifically for CBM wells are included in the redesigned test wells.Finally, we will discuss gas production with the historic fractures that were placed on these wells in the past along with several current wells in the field that used a different design. We will then compare the gas production from these data sets to the gas production for the wells in the field that were fractured by applying the new fracturing technologies. By comparison of the data sets, this paper will demonstrate that the new fracturing technologies applied to this CBM field have resulted in significantly improved gas production for the operator.

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Section: Statement Of Theory and Definitionsmentioning

confidence: 99%

Improved Fracturing Technology for Coalbed Methane Gas Wells in Western Pennsylvania Increases Gas Production Over Offset and Historic Wells in Mount Pleasant CBM Field

Snyder

Jockel

Lopez³

2007

All Days

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“…A well-documented solution, for example, is to apply proppant-tackifying agents that can mitigate coal-fines invasion into the proppant packs. 7,8 Fracture Design Modeling. The lack of a viable physics model to describe the properties of coal seams sometimes presents an obstacle to the simulation of fracture treatment response, especially predictive modeling.…”

Section: Categorize By Job Design Process Including Fracmodeling Simmentioning

confidence: 99%

“…• Hydraulic refracturing of previously fractured wells • Hydraulic fracturing of previously cavity-completed wells • Chemical-enhancement additives designed to mitigate specific impairment mechanisms included as part of the hydraulic fracturing system 7,8 A significant enabling technology developed recently involves the use of relatively small volumes of remedial cleanup fluid injected into previously hydraulically fractured wells. This mainly occurs in Phase 4 wells that are experiencing premature production declines.…”

Section: Secondary Production Enhancementmentioning

confidence: 99%

Matching Technical Solutions to the Lifecycle Phase is the Key to Developing a CBM Prospect

Blauch

Weida

Mullen

et al. 2002

Proceedings of SPE Gas Technology Symposium

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The early stages of a coalbed methane (CBM) project development often require more extensive use of currently available technologies than can be economically justified when approached from a conventional oil and gas drilling focus. As a result, key evaluation tools and technologies are either omitted or not considered before significant decisions are made regarding viability of a CBM play. Understanding that the various lifecycle phases will each affect different objectives and decision points is important. Following site acquisition and estimating basic drilling costs, at least five lifecycle phases can be identified: (1) Regional Resource Reconnaissance, (2) Local Asset Evaluation, (3) Early Development, (4) Mature Development; and (5) Declining Production.A systematic review of current and recently developed enabling technologies is presented in the context of their potential use and applicability. Environmental risk and other constraints that can impact development vary globally, as do economics and production forecasting. New and emerging chemical technologies, as well as hydraulic fracturing refinements, play key roles in various lifecycle phases and decision making to identify successful CBM development projects as early as possible. The paper presents strategies that can reduce development phase failure risk and help predict or rank production potential. Economic constraints usually become more restrictive as the lifecycle moves to Phase 4 and beyond, but key information needed to enter Phase 4 is often overlooked. Examples of this scenario are presented from a global perspective.Globally, new and existing technologies combined with dynamic gas and electricity markets are changing the nature of CBM development opportunities. More accurate and timely go/no-go information needs to be used in the decision making process. Converting development opportunities to development successes involves integrating planning and evaluation methods, using targeted development technologies in the proper phase, and managing risk. TX 75083-3836, U.S.A., fax 01-972-952-9435.

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“…When the fluid pressure in nature fracture system decreases to some degree, the adsorbed methane will begin to desorb from the surface of micro-pore, diffuse to nature split, and seepage to near well bore area (Schein & Mack, 2007). Hydraulic fracturing with gel should be applied to CBM reservoir as routine, which helps to stimulate the flow channel in the near wellbore zone, to make the gas production commercially viable (McCabe et al, 1999;Cramer, 2008).…”

Section: Introductionmentioning

confidence: 99%

The pilot appraisal of acid fracturing of coalbed methane reservoir in southeast Qinshui Basin, China

Yang¹,

Zhang²,

Tian³

et al. 2016

Earth sci. res. j.

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The reserves of Coalbed Methane (CBM) in Qinshui Basin are quite promising, but the outputs from CBM wells are quite small even after massive hydraulic fracturing. Herein the fracture system with #3 and #15 coal seams in Qinshui basin was analyzed, and it was found that both of the macro-scale fractures and micro-scale fractures are filled with clay and carbonate minerals, which explains the low productivity of CBM wells after conventional hydraulic fracturing. Acid fracturing has long been an effective method for carbonate gas reservoir to improve the gas well production. However, there were few reports about the application of acid fracturing in coal bed methane field. Based on the mineral identification and acid sensitivity test, the feasibility of acid fracturing demonstrated that the acid does more help than damage to increase the permeability of coal seams in Qinshui basin. Onsite operations have shown that acid fracturing is applicable for the CBM wells in Jincheng Mining Area. It was also observed from the microseismic survey that when applying the acid fracturing treatment, the stimulated reservoir area depends on the acid volume pumped in the first stage, which is crucial to the success of the stimulation. Las reservas de gas metano de carbón (CBM, del inglés Coalbed Methane) en la cuenca Qinshui son más que prometedoras, pero la producción en los pozos es muy pequeña, incluso después de fracturas hidráulicas masivas. En este trabajo se analizaron los sistemas de fractura de las vetas de carbón #3 y #15 de la cuenca Qinshui y se encontró que tanto las fracturas a macroescala como aquellas a microescala están cubiertas con arcillas y minerales carbonatos, lo que explica la baja productividad de los pozos de gas metano de carbón después de la fractura hidráulica convencional. La fractura ácida ha sido un método efectivo en los depósitos de gas carbonato para mejorar la producción en el pozo de gas. Sin embargo, existen pocos informes sobre la aplicación de la fractura ácida en el campo del gas metano de carbón. De acuerdo con la identificación mineral y las pruebas de sensibilidad ácida, la factibilidad de la fractura ácida demostró que el ácido es reparador en el incremento de la permeabilidad en las vetas de carbón de la cuenca Qinshui. Las operaciones in situ han demostrado que la fractura ácida es aplicable para los pozos de gas metano de carbón en el área minera de Jincheng. También se observó en el sondeo microsísmico que cuando se aplica un tratamiento de fractura ácida, el área del depósito estimulada depende del volumen de ácido bombeado en primera instancia, lo que es determinante en el éxito de la estimulación. ABSTRACT RESUMENPalabras clave: Gas metano de carbón, fractura ácida, pruebas de sensibilidad ácida, área del reservorio estimulada.Record Manuscript

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Investigation of a New Fracturing Fluid and Conductivity Enhancement Technology on Coalbed Methane Production

Cited by 16 publications

References 5 publications

Improved Fracturing Technology for Coalbed Methane Gas Wells in Western Pennsylvania Increases Gas Production Over Offset and Historic Wells in Mount Pleasant CBM Field

Improved Fracturing Technology for Coalbed Methane Gas Wells in Western Pennsylvania Increases Gas Production Over Offset and Historic Wells in Mount Pleasant CBM Field

Matching Technical Solutions to the Lifecycle Phase is the Key to Developing a CBM Prospect

The pilot appraisal of acid fracturing of coalbed methane reservoir in southeast Qinshui Basin, China

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