ABSTRCTThe explosive growth of shale gas production in the US has sparked a global race to determine which other regions from around the world have the potential to replicate this success. One of the main areas of focus is the Asia Pacific region, specifically Pakistan.In this paper, real results from seven different US shale basins-Marcellus, Eagle Ford, Haynesville, Barnett, Woodford (West-Central Oklahoma), Fayetteville and Bakken-have been used to develop a comprehensive sequence of shale exploitation strategy for emerging shale plays.The study involves integration of shale gas exploitation knowledge reinforced by a decade of experience across most of the North American shale gas basins, with published data. Different reservoir properties have been compared to develop a comprehensive logic of the effective techniques to produce from shale-gas reservoirs. We have validated the sequence with real results from US shale production ventures, published case histories, and by global experts who have been directly involved in shale reserves evaluation and production. Subsequently, several different reservoir attributes of Pakistan shale plays have been compared with US basins, in an attempt to identify analogues.It is the intent of this paper to diminish the difficult and often expensive learning cycle time associated with a commercially successful shale project, as well as to attempt to illustrate the most influential factors that determine optimum production. A very few papers in the petroleum literature that provide an extensive and systematic approach towards shale exploitation strategy for given shale-reservoir conditions

Maximizing productivity from every well has always been the ultimate objective of industry experts. Connecting the wellbore with the reservoir is a key element towards meeting this challenge. In the case of perforated completions, techniques like static and dynamic underbalance are used to try and remove the crushed zone caused by the perforation process. In marginal reservoirs, poor connectivity can be the difference between a commercial discovery and a dry well. Reactive liner perforation technology is a new technique which removes the crushed zone using a highly exothermic reaction, providing a step-change improvement in perforation geometry and performance. The reaction breaks up and expels debris to leave a clean, undamaged tunnel, even in variable or low quality rock. This process is independent of lithology and wellbore conditions. This next generation perforating technique has recently been launched in Pakistan with exceptional results. This paper describes these successes in greater detail. When compared with offset wells with identical parameters, perforated using relatively new techniques, the superiority of the reactive technique was proven. Significant rate improvements and very low (negative in some cases) values of total skin were measured. When applied prior to hydraulic fracturing, significantly reduced initiation pressures and lower horsepower requirement added significant value through optimized fracturing treatment, reduced risk of screen-out, and reduced expenditure. Results in-hand prove the superiority of this technology in improving well connectivity, particularly in tight gas reservoirs. The independency from rock properties and wellbore conditions are truly added advantages of the reactive liner technology. This is a technically viable and cost efficient option for ensuring operators achieves their production objectives. Introduction Achieving optimum well productivity depends on effective connectivity to the reservoir. Poor connectivity will not only have a detrimental effect on the well production but will increase the completion and operating cost of the well due to additional remedial treatments and interventions required to improve the well production. Poor connectivity can lead to incorrect diagnosis of the reservoir's true potential which can affect the operator decision if the well is commercially viable for production or if it is to be plugged and abandoned. In cased and perforated completions, perforating techniques are used to provide a conduit for the inflow of hydrocarbons or injection points for injectants. Since its introduction in 1950s, shaped charge perforators have been the dominant perforating method. The shaped charges employ an explosive cavity effect coupled with a metal liner to maximize penetration. Once the main explosive is detonated, the liner collapses to form a high-velocity jet that is propelled outward at approximately 30,000ft/sec. The shaped charge deployment simplicity is its main advantage and over the years, new developments in shaped charge perforations have allowed operators to create deeper perforation tunnels. Achieving maximum penetration depth is important as it contributes to the effective wellbore radius, however the main factor which leads to optimum well flow performance is the quality of the perforation tunnel. Shooting so deep requires a violent and damaging event, where the rock surrounding the tunnel is deformed far beyond its plastic limit and smashed rock fragments are driven into the adjacent pore throats (Bell 2009). This so called "crushed zone" is almost impermeable to flow. In addition, the compacted fill at the tip of the tunnel and debris remaining in the tunnel further contributes to inefficiency of the perforation.

POGC Rehman-1 discovered gas from the Pab sandstone in mid-2009. The well had low productivity primarily due to low reservoir permeability. In December 2009, the well’s Upper and Lower Pab zones were fractured, resulting in a four-fold increase in production. Post-frac testing of the zones discovered very little proppant flowback. This paper outlines the history of this successful hydraulic fracturing treatment in the Kirthar region. The document also discusses the detailed job design, fracture modeling, pre-frac production model calibration, and sensitivities to treatment size. A series of fracture designs was developed to evaluate the uncertainty in fracture geometry predictions. The successful stimulation of a low-permeability gas reservoir dictated placing a long conductive fracture. An important aspect of fracture design is fluid selection. The fluid must maintain excellent proppant transport characteristics throughout the pumping sequence, yet break rapidly and cleanly once the treatment is completed. Another important aspect of fracture design: proppant selection. The proppant is basically the life of the fracture and should maintain adequate conductivity throughout the designed exploitation life of the fracture and completion. The fracturing program and the main treatment’s actual execution are presented in the paper. Operational issues are also discussed. One-hundred mesh sand was used to minimize the risks associated with pressure dependent leakoff (PDL) into natural hairline fractures seen on the FMI log. Post-fracture well-testing data was recorded and analyzed. The results were used to quantify the fracture effectiveness.