- Published on Monday, 24 February 2014 10:53
- Written by Leon Berckenhoff
With the rapid development of unconventional shale plays throughout the U.S. has come the challenge of transporting product to refiners and markets. The large number of wells and the high volume of natural gas being produced has led to an increase in the size and number of gathering and other midstream pipelines.
What is “Unconventional Gas Play”?
An unconventional gas play involves extracting the natural gas from within shale formations. The gas is embedded in rock rather than a bubble or pocket of gas captured over water or oil.
The drilling path typically follows a horizontal path into the formation. With the aid of fracture stimulation, gas and liquids are released to the surface.
There are about seven major active shale plays across the U.S., and throughout all plays, many sites contain multiple well heads to make it possible to gather the gas in the most-efficient way possible.
This results in large volumes of gas that then must be gathered in pipelines, many of which traverse populated areas and roadways.
Because of the quantities of gas, gathering lines may be of larger size and higher pressure than traditional pipelines, and many are routed through high consequence areas (HCAs). An HCA is an area where pipeline releases could have greater consequences to health and safety or the environment. To deal with the growth in this sector and to insure safety of the public in the vicinity, the U.S. Department of Transportation Pipeline and Hazardous Materials Safety Administration (PHMSA) has indicated it may further study regulation of large size and higher pressure gathering lines. Regulation typically involves a requirement for shutoff valves in high consequence areas to add protection in the event of a natural gas release.
A large midstream pipeline company recently installed a pipeline that will eventually be flowing produced natural gas that contains hydrogen sulfide (H2S). The pipeline is routed under a major South Texas Interstate highway in the Eagle Ford. This highway is busy with a lot of interstate commerce transportation.
The company needed rapid closing valves on each side of the highway for emergency shutdown in the event of a gas leak or line break. In the event of an emergency, the pipeline company also did not want to send personnel to the valves because of the time it could take to react and to eliminate their exposure to the possible lethal gas.
Control and Actuation Requirements
It was important that the actuator would be able to close the valves locally on site using hydraulic power or a manual hand pump, remotely from gas control, and/or automatically by responding to pressure sensors on the pipeline. The control system had to monitor the pipeline pressure, react if linebreak conditions were detected, and signal the actuator to close the line valves.
The actuators and controls would be mounted on previously installed valves that were already in service. These valves are operated very infrequently, usually only during annual testing. Still, they have to be able to close in less than 12 seconds after signal input. There could be no allowance for inadvertent or false closures.
In addition to these requirements, it was essential the overall system be reliable with minimal maintenance.
Normally, a gas/hydraulic actuator would be used and powered with the pipeline gas. However, that was not possible in this instance because of the H2S content. To complicate matters further, this is a desolate site, so there was no utility electric power available. Electric motor actuators were not selected because a sizable reserve power source would be required to assure speed of operation and reliability.
Solution: Power Source
A battery-powered electrohydraulic system was chosen to provide hydraulic power. A charged accumulator provides the power to achieve the speed requirement and for additional stroke capability. Batteries are kept adequately charged by a bank of solar panels aimed at the South Texas sun.
A rotary vane type actuator was selected because the hydraulic actuator can operate the valve smoothly and the hydraulic fluid will protect the internal components from the harsh South Texas environment.
A hand pump was included for manual operation backup if the power fails.
Linebreak detection was provided by the Emerson LG 2300 linebreak detection system, which constantly monitors line pressure. This allows the customer to determine normal pressure variations and compensate settings before arming for automatic closure.
The system will then alarm or close the line valve when the rate of drop, low- and/or high-pressure set points are exceeded. It also alarms if the accumulator head pressure is too low for adequate reserve power.
For added reliability, the linebreak detection system has a power system separate from the electrohydraulic power unit. The pipeline company also added communication that allows valve position visibility at the gas control site in another state.
The pipeline company has the capability to monitor these two valve settings, and remotely close them in the event of an emergency. They are also collecting data on the actual pipeline flow conditions, and it is their intention to configure the detection system setting to automatically close the valve if the set points are exceeded.