The Effects of Stress on Coalbed Reservoir Performance, Black Warrior Basin, U.S.A.

Sparks, D.P.; McLendon, T.H.; Saulsberry, J.L.; Lambert, S.W.

doi:10.2118/30734-ms

Cited by 24 publications

(5 citation statements)

References 10 publications

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“…The coal permeability is sensitive to stress, and the relationship concluded by a lot of experiments is as follows [16].…”

Section: (1)mentioning

confidence: 99%

Research of Network Fracturing Method for Coalbed Methane Reservoirs

Li¹,

Wan²

2016

TOPEJ

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The application of conventional hydraulic fracture treatment is not ideal in coalbed methane reservoirs, which influences the industry development in China, thus, the present technique should be improved. From two aspects of net pressure and stress sensibility of permeability, it is analyzed and considered that permeability around hydraulic fractures is damaged severely, so this is the main flaw of conventional hydraulic fracturing in CBM. It is proposed to shear natural fractures by fracturing treatment, which are plentiful in coalbed methane reservoirs, and the mechanical condition to generate sheared fractures is presented, in the meanwhile, it is verified that the permeability of sheared fractures is much larger than coal matrix permeability. When the angle between natural and hydraulic fractures is small in coalbed methane reservoirs, the natural fractures will shear easily at low net pressure, so network fractures can be formed. In comparison with conventional hydraulic fracturing, this new methodology can make natural fractures shear at low net pressure to form transverse network fractures, hence, the stimulated reservoir volume is larger, and damage to coal permeability is avoided. This new technique is advantageous in both stimulated reservoir volume and permeability improvement, and it is more adaptable for coalbed methane reservoirs, thus, it has a wide application prospect and significant value.

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“…The coal permeability is sensitive to stress, and the relationship concluded by a lot of experiments is as follows [16].…”

Section: (1)mentioning

confidence: 99%

Research of Network Fracturing Method for Coalbed Methane Reservoirs

Li¹,

Wan²

2016

TOPEJ

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“…Generally speaking, ISIP in second time was higher than the value of first time with the reason was pore pressure around the wellbore happens to change variously as the fracturing fluid leak-off enters the pay zone [7]. The change of pore pressure affects the stress-state and induces increasing stress around the wellbore.…”

Section: Fig1 Hydraulic Fractures and Leak-off Regionsmentioning

confidence: 95%

Leak-Off Coefficient Analysis in Stimulation Treatment Design

Chen

Ding

Lü

et al. 2014

AMR

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Hydraulic fracturing was first used in the late 1940s and has become a common technique to enhance the production of low-permeability formations.Hydraulic fracturing treatments were pumped into permeable formations with permeable fluids. This means that as the fracturing fluid was being pumped into the formation, a certain proportion of this fluid will being lost into formation as fluid leak-off. Therefore, leak-off coefficient is the most leading parameters of fracturing fluids. The accurate understanding of leak-off coefficient of fracturing fluid is an important guidance to hydraulic fracturing industry design. In this paper, a new field method of leak-off coefficient real time analysis model was presented based on instantaneous shut-in pressure (ISIP). More than 100 wells were fractured using this method in oil field. The results show that average liquid rates of post-fracturing was 22m3/d which double improvement compared with the past treatment wells. It had an important role for hydraulic fracturing stimulation treatment design in low permeability reservoirs and was proven that the new model for hydraulic fracturing treatment is greatly improved.

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“…They also suggest that field estimates of relative permeability can be obtained analogously to procedures derived for solution gasdrive reservoirs (Al-Khalifa et al 1987). Sparks et al 1995 IFOT/SLUG In this study, coal permeability was quantified as a function of stress -late-time falloff data was analyzed from IFOT tests in the Cedar Cove area, and slug tests were analyzed in the Oak Grove area of the Black Warrior basin. Minimum stress values in both areas were obtained from acid-breakdown tests.…”

Section: Authormentioning

confidence: 99%

Coalbed Methane: Current Evaluation Methods, Future Technical Challenges

Clarkson

Bustin

2010

Proceedings of SPE Unconventional Gas Conference

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Coalbed methane (CBM) produced from subsurface coal deposits, has been produced commercially now for over 30 years in North America, and relatively recently in Australia, China and India. Historical challenges to predicting CBM well performance and long-term production have included: accurate estimation of gas-in-place (including quantification of in-situ adsorbed gas storage); estimation of initial fluid saturations (in saturated reservoirs) and mobile-water-in-place, estimation of the degree of under-saturation (undersaturated coals produce mainly water above desorption pressure); estimation of initial absolute permeability (system); selection of appropriate relative permeability curves; estimation of absolute permeability changes as a function of depletion; prediction of produced gas composition changes as a function of depletion; accounting for multi-layer behavior, and accurate prediction of cavity or hydraulic fracture properties. These challenges have primarily been a result of the unique reservoir properties of CBM. Much progress has been made in the past decade to evaluate fundamental properties of coal reservoirs, but there is still work to be done to obtain accurate estimates of some basic reservoir properties.In recent years, horizontal wells and more complex well architectures and stimulation methodologies have been implemented to improve recovery of CBM. These more complex development options bring with them a new set of challenges for operators producing CBM. The exploitation of more geologically-complex coal with poorer reservoir quality will necessitate new and inventive ways to develop the existing natural gas resources and possibly combine this with new methods to extract energy from the coal in-situ. Development planning in these scenarios will become increasingly complex as will evaluation methods.The purpose of the current work is to review the state-of-the-art in CBM reservoir property and stimulation efficiency evaluation and speculate on possible CBM development scenarios for the future and the technical challenges they will bring. Current and future work required to meet these challenges will be discussed in the hope that industry, academia, and government bodies alike will be proactive in the development of solutions that will make future CBM recovery efficient, economic, and environmentally friendly.

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The Effects of Stress on Coalbed Reservoir Performance, Black Warrior Basin, U.S.A.

Cited by 24 publications

References 10 publications

Research of Network Fracturing Method for Coalbed Methane Reservoirs

Research of Network Fracturing Method for Coalbed Methane Reservoirs

Leak-Off Coefficient Analysis in Stimulation Treatment Design

Coalbed Methane: Current Evaluation Methods, Future Technical Challenges

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