Natural Soda uses wireless technology to monitor mining operations

Mining nahcolite requires careful monitoring of temperature, pressure, and flow to optimize production performance

By Raymond Pfister

Cover Story art Mar-Apr  

Located in Northwest Colorado in the Piceance Creek Basin, Natural Soda operates seven production well pairs to produce saturated nahcolite brine for manufacturing sodium bicarbonate (baking soda). The plant is approximately 50 miles northwest of Rifle, Colo., on property managed by the Bureau of Land Management (BLM), which is part of the U.S. Department of the Interior.

Mining nahcolite requires very careful monitoring of temperature, pressure, and flow to not only optimize production performance—but also to mine the product sustainably and protect the freshwater aquifer. Wireless transmitters make it possible to monitor remote injection wells to protect the environment, increase efficiency, and improve productivity. Our operating permits require us to continuously monitor and record fluid temperature, pressure, and flow rate in both the recovery and injection wells. We must also keep these parameters within specified ranges as detailed in our BLM-approved mine plan.

The facility is located in mountainous, rugged terrain (figure 1), making it difficult and very expensive to employ wired devices. To improve overall efficiencies, we installed wireless temperature, pressure, and flow sensors to monitor all the parameters specified in the plan.


Cover Story art Mar-Apr fig 1 

Figure 1. Natural Soda mines nahcolite at this facility in Northwest Colorado. Nahcolite brine from seven wells is pumped to the sodium bicarbonate production plant.



Protecting the aquifer

Natural Soda recovers sodium bicarbonate using a process known as solution mining. This involves pumping heated water approximately 1,900 feet underground (figure 2) to dissolve the underlying nahcolite beds. The water, now saturated with sodium bicarbonate, is then returned to the surface by a submersible pump.

A key element of the BLM mine plan is controlling the pressure of the saline aquifer (referred to as the dissolution surface aquifer) immediately above the mining zone. The mine plan specifies that the pressure in this aquifer must stay below the pressure of the upper freshwater aquifers to eliminate the potential of cross contamination between the aquifers.

Continuous monitoring and adjustment of injection and recovery flow, temperature, and pressure allow us to maintain full compliance with this requirement, and to collect the necessary historical data for proper record keeping and required regulatory submissions.


Cover Story art Mar-Apr fig 2
 Figure 2. Solution mining involves the injection of steam into a 2,000-foot long seam of nahcolite
to form a brine solution that is pumped up and sent to the production plant. A freshwater
aquifer lies between the surface and the nahcolite seam, making control of pressure critical.
Some of these wells are more than a mile away from the processing facility.


Upgrading the system

The original Natural Soda facility was built in 1990 with the capacity to produce 60,000 tons per annum (tpa) of feed-grade product to be sold domestically. Expansion in 1996 increased capacity to 125,000 tpa. In March 2013, Natural Soda completed construction of an additional production train, increasing annual production from 125,000 tpa to 250,000 tpa, making Natural Soda the second-largest producer of sodium bicarbonate in the U.S.

In addition to the new train, the expansion included additional packaging and distribution infrastructure, supporting Natural Soda’s move to provide sodium bicarbonate to multiple markets, such as the highly competitive food and personal care markets around the globe, rather than just focusing on the domestic animal feed market.

The number of well pads where solution mining takes place increases in proportion with production, as do reporting and technology requirements, including the need to acquire data from the additional well pads.

At Natural Soda, the existing wells have WirelessHART capability, communicating to an Emerson Wireless 1420 Gateway that is hardwired via an RS-232 serial link to the DeltaV distributed control system (DCS) in the production plant. The DCS monitors inputs from the wireless transmitters at each well pad and sends valve control instructions to each well pad’s programmable logic controller (PLC) (figure 3) via a radio link, separate and different from the WirelessHART network.

Serial data is sent to the PLCs using a GE MDS 900 radio master and MDS 900 radios as slaves at each well pad. The radios transfer data back and forth between PLCs in the field and the control room via a hardwired RS-232 data link between the radio master and the DCS.

The bottleneck was our use of a two-port RS-232 serial I/O card installed at the DCS. Data from the wireless gateway used port #2, and the radio master used port #1. Serial data is limited to 16 data sets per port. At the time of the expansion, port #1 was at 15 data sets, and port #2 was being used by the wireless gateway. To accommodate more wells, we needed to free port #2 so we could send commands to the additional PLCs.

That meant measurement data from new wells might have to be hardwired from the field to the DCS. The distances involved made this an expensive proposition, since some of the wells were more than a mile from the production plant. Installing wire and conduit the entire distance from the well fields to the DCS would have cost $80,000–$90,000, and we were hesitant to proceed with this installation due to the environmental impact it would have on the flora and fauna.

Instead, we installed a wireless I/O card (WIOC). The WIOC (figure 4) was installed in one of the DCS racks. It receives WirelessHART data and transfers it to the DCS. The cost of installing the WIOC was a fraction of the price of hard wiring, and it could be installed within our required timeline, saving time and approximately $70,000.

Before the expansion, we had 30 wireless devices on five wells connected to the wireless gateway. The WIOC was simple and quick to install and commission. It took fewer than 36 hours to transfer all 30 devices from the existing gateway to the WIOC, with no downtime or interruption to the process. From 2013 to 2016, new wells were brought on line, bringing the total to 48 wireless devices. We plan to have 60 wireless devices on 10 wells operating by the fall of 2017, thus doubling the size of the original system at a minimal cost.

The expansion also included a new controller in the DCS interfacing directly with the WIOC (figure 5). It sends valve control and other data to the PLCs via the serial radio link.

Each well pad includes a steam injection well and a recovery well for pumping out the nahcolite brine. Instrumentation at each injection wellhead includes a wireless temperature transmitter, a wireless pressure transmitter, and a magmeter with a wireless adapter (figure 6). A wireless output is used to control the injection valve. Instrumentation at the recovery wellhead includes the same type of wireless flow, temperature, and pressure transmitters.

Each PLC also has hardwired connections from analog outputs to control valves, analog inputs from flowmeters, and discrete I/O for control of remote water wells.


Cover Story art Mar-Apr fig 3

Figure 3. Each well pad has a PLC controlling the well’s steam injection valve.

Cover Story art Mar-Apr fig 4

Figure 4. Emerson’s wireless I/O cards were installed to provide fully redundant communications for up to 100 wireless devices.

Cover Story art Mar-Apr fig 5

Figure 5. An Emerson S-Series controller in the DeltaV DCS takes WirelessHART data from the WIOC, makes the necessary calculations, and sends valve control information to the PLCs at each well pad.

Cover Story art Mar-Apr fig 6

Figure 6. The injection and recovery wells at each well pad have wireless temperature, pressure, and flow transmitters.




Results

The most important result of using WirelessHART flow, pressure, and temperature transmitters at the well pads is that Natural Soda can confidently operate and deliver expected results within the parameters of the BLM mine plan with no leakage into the freshwater aquifer. The system works flawlessly to protect the environment.

In addition, maintenance costs have been reduced by half because the system has no fuses or power supplies, and no wires. WirelessHART status and diagnostic information indicates if any transmitter has a problem, and the system alerts the operators accordingly. If a problem does occur with any transmitter, technicians can go right to the device and troubleshoot with a HART communicator. A laptop is not required in the field for maintenance.

There were some initial concerns regarding wireless instrument battery life, but we have only had to change three batteries in more than five years of operation. This long battery life is achieved with an update rate of four to eight seconds from each wireless instrument.

Future plans call for installation of asset management software to enhance troubleshooting, including the installation of pump and motor health management hardware and software. The WIOC will accommodate additional well pads and wireless transmitters, which is very important, because we plan to expand production to 500,000 tpa and add wireless monitoring of tank levels in the near future.


               

 

 

Fast Forward

  • The existing wireless system had limited I/O capacity and could not handle data from new wells, some of which were more than a mile from the production plant.
  • To avoid hardwiring data from new wells, Natural Soda installed a wireless I/O card at its existing control system.
  • The new wireless network will accommodate more well pads and wireless transmitters, allowing further expansion and the addition of wireless monitoring of tank levels soon.
 

About the Author

 Cover Story art Mar-Apr fig 7Raymond Pfister is maintenance I/E lead at Natural Soda. He joined Natural Soda LLC in March 2010. He has 20 years of electrical experience, 13 years of instrumentation and maintenance experience, and 10 years of automation experience in industrial and commercial industries, including pharmaceuticals, oil and gas, food-grade products, and construction. Pfister has been a licensed electrician for 16 years and is a certified instrumentation technician. He received certification as a PLC technician from George Brown College, and has completed multiple training courses with Emerson.

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