Influence of Matrix Shrinkage and Compressibility on Gas Production From Coalbed Methane Reservoirs'

1990 ◽  
Author(s):  
S. Harpalani ◽  
R.A. Schraufnagel
Keyword(s):  
Coalbed Methane ◽  
Gas Production ◽  
Matrix Shrinkage

scholarly journals A Comprehensive Coal Reservoir Classification Method Base on Permeability Dynamic Change and Its Application

Energies ◽  
2020 ◽  
Vol 13 (3) ◽  
pp. 644 ◽  
Author(s):  
Xinlu Yan ◽  
Songhang Zhang ◽  
Shuheng Tang ◽  
Zhongcheng Li ◽  
Yongxiang Yi ◽  
...  
Keyword(s):  
Coalbed Methane ◽  
Dynamic Change ◽  
Initial Permeability ◽  
Gas Production ◽  
Gas Desorption ◽  
Reservoir Permeability ◽  
Geological Conditions ◽  
Production Stages ◽  
Productivity Potential ◽  
Coal Reservoir

Due to the unique adsorption and desorption characteristics of coal, coal reservoir permeability changes dynamically during coalbed methane (CBM) development. Coal reservoirs can be classified using a permeability dynamic characterization in different production stages. In the single-phase water flow stage, four demarcating pressures are defined based on the damage from the effective stress on reservoir permeability. Coal reservoirs are classified into vulnerable, alleviative, and invulnerable reservoirs. In the gas desorption stage, two demarcating pressures are used to quantitatively characterize the recovery properties of permeability based on the recovery effect of the matrix shrinkage on permeability, namely the rebound pressure (the pressure corresponding to the lowest permeability) and recovery pressure (the pressure when permeability returns to initial permeability). Coal reservoirs are further classified into recoverable and unrecoverable reservoirs. The physical properties and influencing factors of these demarcating pressures are analyzed. Twenty-six wells from the Shizhuangnan Block in the southern Qinshui Basin of China were examined as a case study, showing that there is a significant correspondence between coal reservoir types and CBM well gas production. This study is helpful for identifying geological conditions of coal reservoirs as well as the productivity potential of CBM wells.

scholarly journals Quantify Coal Macrolithotypes of a Whole Coal Seam: A Method Combing Multiple Geophysical Logging and Principal Component Analysis

Energies ◽  
2021 ◽  
Vol 14 (1) ◽  
pp. 213
Author(s):  
Chao Cui ◽  
Suoliang Chang ◽  
Yanbin Yao ◽  
Lutong Cao
Keyword(s):  
Principal Component Analysis ◽  
Coal Seam ◽  
Coalbed Methane ◽  
Principal Component ◽  
Component Analysis ◽  
Gas Production ◽  
Index Model ◽  
Geophysical Logging ◽  
The Relationship ◽  
Observation Results

Coal macrolithotypes control the reservoir heterogeneity, which plays a significant role in the exploration and development of coalbed methane. Traditional methods for coal macrolithotype evaluation often rely on core observation, but these techniques are non-economical and insufficient. The geophysical logging data are easily available for coalbed methane exploration; thus, it is necessary to find a relationship between core observation results and wireline logging data, and then to provide a new method to quantify coal macrolithotypes of a whole coal seam. In this study, we propose a L-Index model by combing the multiple geophysical logging data with principal component analysis, and we use the L-Index model to quantitatively evaluate the vertical and regional distributions of the macrolithotypes of No. 3 coal seam in Zhengzhuang field, southern Qinshui basin. Moreover, we also proposed a S-Index model to quantitatively evaluate the general brightness of a whole coal seam: the increase of the S-Index from 1 to 3.7, indicates decreasing brightness, i.e., from bright coal to dull coal. Finally, we discussed the relationship between S-Index and the hydro-fracturing effect. It was found that the coal seam with low S-Index values can easily form long extending fractures during hydraulic fracturing. Therefore, the lower S-Index values indicate much more favorable gas production potential in the Zhengzhuang field. This study provides a new methodology to evaluate coal macrolithotypes by using geophysical logging data.

scholarly journals Modeling and prediction for gas production during coalbed methane drainage based on two indirect reservoir parameters

2018 ◽  
Vol 36 (6) ◽  
pp. 1424-1437 ◽  
Author(s):  
Mingjun Zou ◽  
Xiaochun Lv ◽  
Zhiquan Huang ◽  
Simin Wei ◽  
Miao Zhang ◽  
...  
Keyword(s):  
Coalbed Methane ◽  
Good Accuracy ◽  
Simulated Data ◽  
Gas Production ◽  
Methane Drainage ◽  
Modeling And Prediction ◽  
Cubic Polynomial ◽  
Southern Qinshui Basin ◽  
Two Parameters ◽  
Gas Production Prediction

Two indirect parameters influencing coalbed methane (CBM) drainage performances are proposed in this paper, which are effective desorption radius and difference between reservoir pressure and critical desorption pressure (DRPCDP). Variations of the two parameters during CBM drainage are investigated, which shows that they have a linear relationship. By using formula derivations, a theoretical model for gas production prediction is built. It suggests that the cumulative gas production is a product of square of effective desorption radius with DRPCDP, and there is also a cubic polynomial relationship between cumulative gas production and linear average DRPCDP. Furthermore, well PM01 located at southern Qinshui basin of China is selected as a case, and a commercial software is adopted to predict the gas production. Compared with the simulated and modeled cumulative gas productions, the simulated data match well with the modeled data, which indicates that the model has a good accuracy.

scholarly journals Influence and Sensitivity Study of Matrix Shrinkage and Swelling on Enhanced Coalbed Methane Production and CO2 Sequestration with Mixed Gas Injection

2011 ◽  
Vol 29 (6) ◽  
pp. 759-775 ◽  
Author(s):  
Fengde Zhou ◽  
Guangqing Yao ◽  
Zhonghua Tang ◽  
Oyinkepreye D. Orodu
Keyword(s):  
Methane Production ◽  
Coalbed Methane ◽  
Net Present Value ◽  
Sensitivity Study ◽  
Mixed Gas ◽  
Methane Recovery ◽  
Matrix Shrinkage ◽  
Enhanced Coalbed Methane Recovery ◽  
Shrinkage And Swelling ◽  
Enhanced Coalbed Methane

Matrix compressibility, shrinkage and swelling can cause profound changes in porosity and permeability of coalbed during gas sorption and desorption. These factors affect the distribution of pressure, methane production and CO2 sequestration. This paper compares the effects of cleat compression and matrix shrinkage and swelling models with the injection of different compositional gas mixtures (CO2 and N2). It shows that well performance, pressure distribution and properties of the seam are strongly affected by matrix shrinkage and swelling. Matrix shrinkage and swelling also affects net present value of the enhanced coalbed methane recovery scheme. In order to select the best enhanced coalbed methane recovery schemes, economic evaluation and sensitivity studies are necessary.

Effect of Pressure-Propagation Behavior on Production Performance: Implication for Advancing Low-Permeability Coalbed-Methane Recovery

SPE Journal ◽  
2018 ◽  
Vol 24 (02) ◽  
pp. 681-697 ◽  
Author(s):  
Zheng Sun ◽  
Juntai Shi ◽  
Keliu Wu ◽  
Tao Zhang ◽  
Dong Feng ◽  
...  
Keyword(s):  
Prediction Model ◽  
Coalbed Methane ◽  
Control Method ◽  
Gas Production ◽  
Production Performance ◽  
Phase Flow ◽  
Two Phase ◽  
Propagation Behavior ◽  
Flow Stage ◽  
Pressure Propagation

Summary Low-permeability coalbed-methane (CBM) reservoirs possess unique pressure-propagation behavior, which can be classified further as the expansion characteristics of the drainage area and the desorption area [i.e., a formation in which the pressure is lower than the initial formation pressure and critical-desorption pressure (CDP), respectively]. Inevitably, several fluid-flow mechanisms will coexist in realistic coal seams at a certain production time, which is closely related to dynamic pressure and saturation distribution. To the best of our knowledge, a production-prediction model for CBM wells considering pressure-propagation behavior is still lacking. The objective of this work is to perform extensive investigations into the effect of pressure-propagation behavior on the gas-production performance of CBM wells. First, the pressure-squared approach is used to describe the pressure profile in the desorption area, which has been clarified as an effective-approximation method. Also, the pressure/saturation relationship that was developed in our previous research is used; therefore, saturation distribution can be obtained. Second, an efficient iteration algorithm is established to predict gas-production performance by combining a new gas-phase-productivity equation and a material-balance equation. Finally, using the proposed prediction model, we shed light on the optimization method for production strategy regarding the entire production life of CBM wells. Results show that the decrease rate of bottomhole pressure (BHP) should be slow at the water single-phase-flow stage, fast at the early gas/water two-phase-flow stage, and slow at the late gas/water two-phase-flow stage, which is referred to as the slow/fast/slow (SFS) control method. Remarkably, in the SFS control method, the decrease rate of the BHP at each period can be quantified on the basis of the proposed prediction model. To examine the applicability of the proposed SFS method, it is applied to an actual CBM well in Hancheng Field, China, and it enhances the cumulative gas production by a factor of approximately 1.65.

Caprica Energy and Its Choices

2017 ◽  
pp. 1-24
Author(s):  
Jared D. Harris ◽  
Samuel E. Bodily ◽  
Jenny Mead ◽  
Donald Adolphson ◽  
Brad Carmack ◽  
...  
Keyword(s):  
United States ◽  
Natural Gas ◽  
Coalbed Methane ◽  
The United States ◽  
Gas Production ◽  
Potential Harm ◽  
Natural Gas Development ◽  
Unconventional Natural Gas ◽  
Potential Risks ◽  
Different Parts

Jane Barrow, CEO of Caprica Energy, must recommend to the board which of three potential “unconventional ” natural-gas development sites in different parts of the United States the company should pursue. The case takes place in January 2011, when the “low-hanging fruit ” of natural-gas production in the United States had essentially been picked. All three of the potential sites (shale, coalbed methane, and tight sands) would require hydraulic fracturing, a process of removing gas that was formerly considered inaccessible by injecting water and chemicals into the ground. Because of emerging concerns about the potential harm “fracking ” can do to drinking water, Barrow must not only analyze which site might be most profitable but also what the potential risks to the environment and area residents might be.

Production and development across Australia 2016

2017 ◽  
Vol 57 (2) ◽  
pp. 363
Author(s):  
Frankie Cullen
Keyword(s):  
Coalbed Methane ◽  
East Coast ◽  
Price Volatility ◽  
Volatile Oil ◽  
Gas Production ◽  
North West ◽  
The North ◽  
Start Up ◽  
Reduction Strategies ◽  
Gas Supply

In 2016, sustained depressed and volatile oil prices led companies to continue cost reduction strategies. Proposed developments have seen delays and reductions in scope as a result. Australian oil production declined by around 10%. However, new and continued liquefied natural gas (LNG) production bolstered both Australian and global gas supply. Australia was the strongest contributor to global LNG growth in 2016, showing the biggest year-on-year increase. In the first half of 2016, 20% of global LNG came from Australia, second only to Qatar with 29% of the market share. Australia remains on track to become the world’s largest LNG producer in the next 3–5 years. 2016 saw the start-up of Gorgon LNG in March, the first of Chevron’s two North West Shelf LNG projects and the third of several producing, developing and proposed LNG projects within the North Carnarvon Basin – already Australia’s most prolific producing basin. On the east coast, development of the coalbed methane (CBM) to LNG projects continued with an additional train brought onstream at each of the Origin/ConocoPhillips-operated APLNG Project and Santos’ GLNG Project. This further increased production in the Bowen–Surat Basins and drove discussions around the ability of east coast gas to meet both the demands of the LNG projects and ensure continued domestic gas reliability. Additional gas may be required for both, opening opportunities for production from other basins. Gas production continues to drive the Australian industry, with substantial inputs from LNG and unconventional operations. The next phase, in all sectors, will be key to Australia’s future in the global energy market. Will it be able to overcome the expected challenges of global oversupply, continued price volatility and domestic reliability concerns to fulfil its potential?

scholarly journals Biogeochemistry and the associated redox signature of co-produced water from coalbed methane wells in the Shizhuangnan block in the southern Qinshui Basin, China

2020 ◽  
Vol 38 (4) ◽  
pp. 1034-1053
Author(s):  
Yang Li ◽  
Shuheng Tang ◽  
Songhang Zhang ◽  
Zhaodong Xi ◽  
Pengfei Wang
Keyword(s):  
Coalbed Methane ◽  
Produced Water ◽  
Dissolved Inorganic Carbon ◽  
Gas Production ◽  
Redox Conditions ◽  
Effective Parameters ◽  
Production Rates ◽  
Qinshui Basin ◽  
Southern Qinshui Basin ◽  
Biogeochemical Parameters

To meet the global energy demands, the exploitation of coalbed methane has received increasing attention. Biogeochemical parameters of co-produced water from coalbed methane wells were performed in the No. 3 coal seam in the Shizhuangnan block of the southern Qinshui Basin (China). These biogeochemical parameters were firstly utilized to assess coal reservoir environments and corresponding coalbed methane production. A high level of Na+ and HCO3– and deuterium drift were found to be accompanied by high gas production rates, but these parameters are unreliable to some extent. Dissolved inorganic carbon (DIC) isotopes δ13CDIC from water can be used to distinguish the environmental redox conditions. Positive δ13CDIC values within a reasonable range suggest reductive conditions suitable for methanogen metabolism and were accompanied by high gas production rates. SO42–, NO3– and related isotopes affected by various bacteria corresponding to various redox conditions are considered effective parameters to identify redox states and gas production rates. Importantly, the combination of δ13CDIC and SO42– can be used to evaluate gas production rates and predict potentially beneficial areas. The wells with moderate δ13CDIC and negligible SO42– represent appropriate reductive conditions, as observed in most high and intermediate production wells. Furthermore, the wells with highest δ13CDIC and negligible SO42– exhibit low production rates, as the most reductive environments were too strict to extend pressure drop funnels.

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