As gas demand rises and operators turn to tight gas reservoirs for new supplies, the need to optimize the capacity and recovery potential from this type of reservoir has risen.
In this environment, a multidomain integrated process enables the data and activities of multiple domains to be integrated for single-well completion optimization and field geocellular and simulation modeling. Through this process, various development scenarios for completions and drilling locations can be systematically and rigorously analyzed.
Case studies from North America and the Middle East show applications of this process in two different environments, one mature and one emerging. The case from North America illustrates a use of the proposed process in a high-volume field development and the value of applying new technology to optimize the process until it reaches a "SMART"-factory-like workflow. With our new process, new technology can be integrated with adaptive modification to the factory mode. This approach will identify the development process that will result in the highest recoveries while maximizing the net present value from the asset. Alternatively, the case from the Middle East shows the application in a gas-condensate, tight gas reservoir in an emerging area. The challenge in this case is in collecting adequate necessary data early enough to plan for optimal development. Our case shows the value of collecting the key data early in a complex, tight gas environment and how early collection can impact the development later and avert costly decisions. Also, the special nature and cost of mobilization and limited equipment introduce a need for more stringent early collection of data (e.g., formation evaluation, core, fluid, geomechanics, etc.) that impacts our development before we start the project. This project illustrates the challenges of the developments in a new environment where the services and technology have not matured to the North America levels. A key conclusion of the paper is that applying the field management process in both environments (North America and the Middle East) has resulted in significant improvements in production optimization, as well as in single-well and field development planning.
Introduction
The 2008 BP statistical review of world energy (Fig. 1) highlights the volumes of proved natural gas reserves at the end of 2007 and shows where they are located.
Of particular interest are the volumes of proved reserves in the Middle East. By far the largest volumes reside in areas where in the past our focus has been on oil, but we need to change our focus now to how to develop the available gas reserves. Globalization of gas supply and demand has launched tight gas as an increasing source of energy. A recent gas presentation sourced Wood Mackenzie as stating that in 2003 17% of gas was tight gas and 73% was conventional. In 2003 shale accounted for 2% and the remaining 8% was coalbed methane (CBM). They projected that in 2010 the portion of gas that was tight gas would increase to 26%, whereas conventional gas would decrease to 58%. Shale would only increase to 3% of the volume and CBM would increase to 13%. With the increased percentage of gas being tight gas, it has become more challenging to produce, especially as production moves to more remote areas and deeper or more difficult well paths.
