Total Computer Simulation of a Gas Producing Complex
- Robert A. Cooksey (Northern Natural Gas Co.) | James H. Henderson (Northern Natural Gas Co.) | John R. Dempsey (Northern Natural Gas Co.)
- Document ID
- Society of Petroleum Engineers
- Journal of Petroleum Technology
- Publication Date
- August 1969
- Document Type
- Journal Paper
- 942 - 948
- 1969. Society of Petroleum Engineers
- 4.1.6 Compressors, Engines and Turbines, 5.5 Reservoir Simulation, 5.2.1 Phase Behavior and PVT Measurements, 4.2 Pipelines, Flowlines and Risers, 4.6 Natural Gas
- 1 in the last 30 days
- 162 since 2007
- Show more detail
- View rights & permissions
An ADI computer model is used to match the pressure-production history of a gas reservoir. Tied to this model is a steady-state model that, by locating energy sources and sinks, can help to determine the optimum investment scheme for a given gas gathering system.
An accurate prediction of reservoir performance is of prime importance for all gas reservoirs. Equally prime importance for all gas reservoirs. Equally important is the ability to optimize investments and still obtain good reservoir performance. Failure to give proper consideration to investment factors will diminish the economic attractiveness of the reservoir. In addition, reservoir performance can be altered drastically by the flow facilities wells, flowlines, compressors that are available to produce and process gas. Adequate flow facilities must be present to permit good reservoir performance.
Application of reservoir simulators to the study of reservoir behavior and investment planning is gaining a widespread appeal. An earlier paper by Henderson, Dempsey and Tyler discusses how well placement and reservoir operational strategy can be optimized by analysis with a reservoir simulator. In the present study the problem of investment planning is approached at a different level. This paper shows that required flow facilities can be optimized if the reservoir behavior can be predicted under various conditions.
Rather than an idealized condition deigned to fit a reservoir model, this study is an actual field case history using observed and predicted data for a particular reservoir. particular reservoir. The location and amount of compression along a gathering line is determined for a certain reservoir production rate. Compressor stations are located at production rate. Compressor stations are located at various points on the gathering line. Also, consideration is given to various production rate schemes of certain poor gas wells in an effort to reduce the amount of poor gas wells in an effort to reduce the amount of compression necessary to operate the field. The reservoir performance was predicted using a two-dimensional single-phase simulator based on Eq. 1.
The gas gathering system predictions were solved using the well known Weymouth equation for flow of gas in a pipeline. The reservoir model is described in dear in Ref. 4.
Statement of Problem
This study was conducted on a dry gas sandstone reservoir containing 25 wells. The planned total reservoir withdrawal rate is shown in Fig. 1. The gathering system consists of a variety of pipelines linked together in a normal fashion and connected to a single downstream outlet (Fig, 4). Compression currently is installed at the downstream end of the gathering system, located at Site A. Earlier expectations indicated that additional compression would be located at the same station. This plan necessitates that gas from all wells in the gathering system be compressed.
|File Size||617 KB||Number of Pages||7|