The Incredible Fiber-Optic Flowmeter

Online, Real-Time Multiphase Measurements Improve Safety of Oil and Gas Production

By Béla Lipták

Share Print Related RSS
Page 1 of 2 « Prev 1 | 2 View on one page

Last year, when I was asked about the publication date of the 5th edition of my handbook, I answered, 2014. Today, my answer is late 2015, and if you ask me next year, my answer might also shift. Why? Because of the explosion of inventions and international competition during the past decade to meet the needs of the new processes from deep-sea drilling to solar hydrogen, from high-density batteries to bitumen and fracking processes, or in automating new nuclear power plants that will operate underwater (a design that as-yet exists only on paper).

Here I will give only one example of this advance in only one area of measurement, an area about which, a decade ago I would have said that everything that can be discovered, already has. Well, I was wrong! The area I am talking about is flow measurement. I will describe only one new flow detector, but in future columns I might continue.

Also read related The Latest in Instrument Technology.

We Have Entered a New Age

The stone age ended, not because we ran out of stone, but because we discovered that bronze tools were better than stone ones. Similarly, the hydrocarbon/nuclear age will end, not because we run out of these materials, but because we will slowly discover that inexhaustible, safe and clean energy is better. Yet, it will take another generation or two to make this transformation. (The transition from the stone to the bronze age took even longer, because mobile phones didn’t exist.)

I call this transition time the “scraping the bottom of the barrel” period. During this period, the less intelligent “tribes” (today we call them nations) will be waging wars over what oil and gas is left, while the smart ones will redirect some of their military budgets to develop green energy technology, which is already advancing (solar collector prices dropped five-fold in a decade, the needs of 2 million Texas homes are met by wind energy, etc.).

So what is the challenge for our profession? It is to help both tribes. We can help the smart ones make their green processes cost-effective, and we can help the less intelligent ones make their outdated processes safer and less damaging. Here I will concentrate on the processes of this second group and will focus only on the oil and gas flow measurement advances that are occurring in fracking and undersea production processes.

Offshore Drilling and Fiber-Optic Flowmeters

Oil or natural gas production is a multiphase stream consisting of oil, water, gas and sand. When drilling a couple of miles deep under the ocean or fracking a couple miles below the groundwater layer in North Dakota, it’s good to know if the total flow rate or the composition of the product changes. This is very important for safety reasons. The BP accident was caused by methane blow-out that was discovered too late. You might have also have heard of groundwater contamination because fracking fluid escaped and was not discovered in time.

Measurement of the multiphase fluid rate and fluid composition is also important for production efficiency reasons and for zonal allocation of gas production in multi-zone completions. It also supports identification and localization of injection or production anomalies in real time, determination of well productivity index, reduction of the need for surface well tests and surface facilities, etc.

The Old Way

In the past, the flow rate and composition of the product was determined by above-ground separators and after separation, the oil, water and gas flows were separately measured (Figure 1). These separators were not only slow (often intermittent), but they usually separated only a small bypass stream, which was not necessarily representative. In addition to being slow, this technique was also expensive and took up a lot of space. 

Therefore, replacing the separators with in-line subsea multiphase flowmeters (Figure 2) was a major advance both in terms of safety and efficiency. 

Early Undersea Flowmeters

Most of today’s multiphase flow rate measurements used Venturi tubes and nuclear densitometers (Figure 2). They have no moving parts, do not require much maintenance and use sophisticated flow models to interpret the multiple measurements (flow, density, pressure and temperature) into dynamic multiphase flow and composition determinations.

Page 1 of 2 « Prev 1 | 2 View on one page
Share Print Reprints Permissions

What are your comments?

Join the discussion today. Login Here.

Comments

No one has commented on this page yet.

RSS feed for comments on this page | RSS feed for all comments