【出版年】：2006 【卷】：0 【期】：25 【起页】：5 【止页】：6 【总页数】：2 【分类号】：TD 【语种】：英语 【文摘】：
QGC has announced two wells at the Berwyndale South Gasfield development, are effectively now each producing around 2,500,000 cubic feet per day (cfd). During the week ending 18 June, the combined production of wells #60 and #9 was 5 million cfd equivalent to an annualised rate of 1.9 petajoules per year. \production, these two wells will have paid for their drilling and completion costs by August this year\said Richard Cottee, Managing Director.
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1. Reconciling longwall gob gas reservoirs and venthole productionperformances using multiple rate drawdown well test analysis C. ?zgen Karacan
,
National Institute for Occupational Safety and Health (NIOSH), Pittsburgh Research Laboratory, Pittsburgh 15236, PA, USA
Received 2 June 2009. Revised 21 September 2009. Accepted 29 September 2009. Available online 8 October 2009.
http://dx.doi.org/10.1016/j.coal.2009.09.006, How to Cite or Link Using DOI Cited by in Scopus (4) Permissions & Reprints Abstract
Longwall mining is an underground mining method during which a mechanical shearer progressively mines a large block of coal, called a panel, in an extensive area. During this operation the roof of the coal seam is supported only temporarily with hydraulic supports that protect the workers and the equipment on the coal face. As the coal is extracted, the supports
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automatically advance and the roof strata cave behind the supports. Caving results in fracturing and relaxation of the overlying strata, which is called “gob.” Due its highly fractured nature, gob contains many flow paths for gas migration. Thus, if the overlying strata contain gassy sandstones or sandstone channels, gas shales or thinner coal seams which are not suitable for mining, then the mining-induced changes can cause unexpected or uncontrolled gas migration into the underground workplace. Vertical gob gas ventholes (GGV) are drilled into each longwall panel to capture the methane within the overlying fractured strata before it enters the work environment. Thus, it is important, first to understand the properties of the gas reservoir created by mining disturbances and, second, to optimize the well parameters and placement accordingly.
In this paper, the production rate-pressure behaviors of six GGVs drilled over three adjacent panels were analyzed by using conventional multi-rate drawdown analysis techniques. The analyses were performed for infinite acting and pseudo-steady state flow models, which may be applicable during panel mining (DM) and after mining (AM) production periods of GGVs. These phases were analyzed separately since the reservoir properties, due to dynamic subsidence, boundary conditions and gas capacity of the gob reservoir may change between these two stages. The results suggest that conventional well test analysis techniques can be applicable to highly complex gob reservoirs and GGVs to determine parameters such as skin, permeability, radius of investigation, flow efficiency and damage ratio. The insights obtained from well test analyses can be used for a better understanding of the gob and for designing more effective gob gas venthole systems. Keywords
Well testing; Drawdown test; Multi-rate test; Longwall mining; Gob gas ventholes
2. Productionperformance of hydraulic fractures in tight gas sands, a numerical
simulation approach J. Ostojic, Rezaee, H. Bahrami
Department of Petroleum Engineering, Curtin University, Australia
Received 8 June 2011. Accepted 25 November 2011. Available online 13 December 2011.
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http://dx.doi.org/10.1016/j.petrol.2011.11.002, How to Cite or Link Using DOI Permissions & Reprints Abstract Hydraulically fractured tight gas reservoirs are one of the most common unconventional gas sources being produced today, and will be a regular source of gas in the future. The extremely low permeability of tight gas sands leads to inaccuracy of conventional build-up and draw-down well test results. This is primarily due to the increased time required for transient flow in tight gas sands to reach pseudo-steady state condition. To increase accuracy, well tests for tight gas reservoirs must be run for longer periods of time which is in most cases not economically viable. The large amount of downtime required to conduct well tests in tight sands makes them far less economical than conventional reservoirs, which leads to the need for accurate simulation of tight gas reservoir well tests. This paper presents simulation results of a 3-D hydraulically fractured tight gas model created using Eclipse software. The key aims are to analyze the effect of differing fracture orientation, number and length. The focus of the simulation runs will be on the effect of hydraulic fracture orientation and length. The results will be compared to simulation runs without the abovementioned factors to determine their effects on production rates and wellperformance analysis. All results are plotted alongside an un-fractured tight gas scenario in order to put the hydraulic fracture performance in perspective. Key findings from this work include an approximately linear relationship between initial gas rate and the number of hydraulic fractures intersecting the wellbore. In addition, fracture length is found to have less of an impact on initial gas rate compared to number of fractures intersecting the wellbore, for comparable total fracture volumes. Highlights ? Well test and production data simulated for early time fracture productivity. ? Fracture size, number and orientation sensitivities modelled. ? Early production rate and productivity comparison of different fracture scenarios. Keywords 7
Productionperformance; Hydraulic fractures; Tight gas sands; Numerical simulation approach 八．石油工程专业学员检索《美国石油工程师学会（SPE）会议论文数据库》(https://www.onepetro.org/)
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Publisher Content Type Title
Society of Petroleum Engineers Journal Paper
Language DOI
English
10.2118/138843-PA
Document ID 138843-PA
Impacts of the Number of Perforation Clusters and Cluster Spacing on
Production Performance of Horizontal Shale-Gas Wells
Authors Journal Volume Date Copyright Discipline Categories 6.9.2 Shale Gas
6.7.5 Economic Evaluations 3.7.2 Unconventional Resources Keywords
Shale gas, Horizontal well, Perforation cluster, Production performance, Economic evaluation 6.10 Management of Challenging Reservoirs
6.9 Unconventional Hydrocarbon Recovery
Y. Cheng, SPE, West Virginia University SPE Reservoir Evaluation & Engineering Volume 15, Number 1 February 2012
2012. Society of Petroleum Engineers
Pages ISSN
pp. 31-40 1094-6470
Preview Summary
Multistage hydraulic fracturing has become the key technology to complete horizontal wells in shale-gas reservoirs. In each stage, multiple perforation clusters are used to create multiple transverse fractures. How these clusters are placed significantly affects both the short-term and long-term production performance of horizontal shale-gas wells. The author's previous work has demonstrated that when more than two fractures are created, mechanical interaction among fractures creates strong stress concentrations around the inner fractures. As a result, the fractures between two edge fractures (i.e., subcenter and center fractures) experience only limited dilation, and their widths are much smaller than the edge-fractures' width.
In this paper, reservoir-simulation models were constructed by quantitatively incorporating the findings of the author's previous work to investigate the impacts of the number of perforation clusters and cluster spacing on production performance of horizontal shale-gas wells. The paper illustrates that with the same cluster spacing, the
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scenarios with more clusters have lower ultimate gas recovery because of the increased number of less-effective inner fractures. Given the same lateral length of a horizontal well, although reducing cluster spacing increases the total number of fractures, smaller cluster spacing does not necessarily improve well performance. Inadequate small cluster spacing can actually lead to a greater number of less-effective or ineffective fractures, and, therefore, lower gas rate and ultimate recovery. 2. Publisher Content Type Title
Society of Petroleum Engineers Conference Paper
Language DOI
English
10.2118/136532-MS
Document ID 136532-MS
Stress Anisotropy, Long-Term Reservoir Flow Regimes and Production
Performance in Tight Gas Reservoirs
Authors Source ISBN Copyright Discipline Categories
1.3.1 Wellbore Integrity/Geomechanics
6.6.3 Pressure Transient Testing
1.2.4 Trajectory Design, Survey Calculation, Collision Checking 1.5.2 Perforating Preview Abstract
Tight gas reservoirs normally have production problems due to very low matrix permeability and different damage mechanisms during drilling, completion and stimulation. Tight reservoirs need advanced drilling and completion techniques to efficiently connect wellbore to the formation open natural fractures and produce gas at commercial rates.
Stress regimes have significant influence on tight gas reservoirs production performance. The stress regimes cause wellbore instability issues while drilling, which can result in large wellbore breakouts. The stress regimes can also control the well long-term production performance, since they affect permeability anisotropy. The preferred horizontal flow direction is expected to be parallel to the maximum in situ horizontal stress. The production and welltest data in non-fractured as well as hydraulically fractured wells in tight reservoirs have indicated the presence of a long-term linear flow regime due to the well and reservoir geometry and also as a result of the permeability anisotropy.
The stress anisotropy leads to different permeabilities in different directions, and the natural fractures that are aligned with maximum horizontal stress; they might have larger aperture and greater permeability. Due to the more
Hassan Bahrami, M. Reza Rezaee, M. Sadegh Asadi / Curtin University, Australia SPE Eastern Regional Meeting, 12-14 October 2010, Morgantown, West Virginia, USA 978-1-55563-310-3
2010. Society of Petroleum Engineers
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