Tight Gas Sands Development is Critical to Future World Energy Resources

Abstract

With the increased global demands on oil and gas, operators strive to maximize production by conducting more advanced drilling operations, such as extended reach, horizontal and high-pressure/high-temperature (HP-HT) drilling and are expanding globally into drilling unconventional resources. Unconventional gas resources offer significant gas production growth potential in the coming years, currently accounting for 43% of the US gas production. Tight Gas Sands (TGS) represents approximately 70% of the unconventional production and significant reserves are yet to be developed. Although "tight gas sands" are an important type of basin-centered gas reservoir characterized by low permeability, abnormal pressure, gas saturated reservoirs and no down dip water leg., not all of the TGS are Basin-centered gas (BCGAs). An intensive technology effort to both better understand tight gas resource characteristics and develop solid engineering approaches is necessary for significant production increases from this low-permeability, widely dispersed resource. Gas production from a tight-gas well will be low on a per-well basis compared with gas production from conventional reservoirs. A lot of wells have to be drilled to get most of the oil or gas out of the ground in unconventional reservoirs However, economical production of TGS is very challenging as it exists in reservoirs with micro-Darcy range permeability and low porosity but has a huge potential for production in the future. Poor permeability results in lower gas production rates from TGS reservoirs. In order to economically develop TGS resources an advanced technology has to be developed and implemented. Most of the TGS reservoirs are characterized by being thick (hundreds to thousands of feet thick) and multilayered where their gas production rates can be enhanced by hydraulic fracturing. Although service companies have large capabilities for conventional/unconventional reservoirs but the used technology to drill, complete and stimulate tight gas reservoir is quite complex and the results are often unexpected and unforeseen. The appropriate completion methods and stimulation techniques in these reservoirs are dependent on many parameters and variables, such as depth, pressure, temperature, capillary and overburden pressures and the number of sand layers. This paper provides a technical overview of the state of the art technology used to develop those reservoirs. This work takes a multidisciplinary approach to better understand how gas can be produced from tight gas sand reservoirs. Two real case histories will be presented and discussed; Travis Peak formation in eastern Texas, USA; and Risha gas field in eastern Jordan.

Cause analysis and solutions of water blocking damage in cracked/non-cracked tight sandstone gas reservoirs

“…Unconventional natural gas resources play an increasingly important role in the current energy supply, meanwhile in unconventional reservoirs, new techniques are especially important to improve oil/gas recovery. At present, unconventional natural gas production in US accounts for more than 43% of the total gas production, of which the natural gas from tight sandstones accounts for approximately 70% and most reservoirs have not yet been developed (Khlaifat et al 2011). Due to the low natural productivity of a single well, horizontal drilling and fracturing are used to promote reservoir stimulation, achieving economic exploitation.…”

Unconventional Gas Production from Hydraulically Fractured Well-An Application of Direct Search Based Optimization Algorithm

“…As a significant amount of time, money, material and manpower is involved, it is crucial to optimize the design while achieving the target. Further studies indicate that for an effective, efficient and economical hydraulic fracture treatment design the impact of various in-situ parameters along with the design parameters must be analyzed in depth to better understand the fracture propagation behavior [6][7][8][9].…”

A Two-Phase Flowback Model for Multiscale Diffusion and Flow in Fractured Shale Gas Reservoirs

“…Shale gas reservoirs have gradually become a major source of hydrocarbon fuel in the global energy market [1][2][3]. However, the extraction of shale gas confronts difficulty because shale gas reservoirs have extremely low permeability and high formation pressure [4,5].…”