Refineries are among the major consumers of water that has both process and non-process origins. The average refinery requires 2.5 gallons of water for every gallon of crude oil processed. Depending on the type of crude oil, composition of condensate and treatment processes, the characteristics of refinery wastewater varies widely. The design and operation of modern refinery wastewater treatment plants are challenging and are driven by technology. This article will highlight the most common types of waste streams in a refinery and suitable wastewater treatment strategies.
There are a number of point level approaches to measuring the interface between water and oil for water dump control in the oil and gas industry. However, each has disadvantages — manual methods introduce human error, conductivity switches are rendered inaccurate by buildup, and float switches are susceptible to wear and tear. This white paper introduces capacitance level switches as an accurate and reliable alternative for water/oil interface detection.
Flare gas is the name given to the surplus waste gas produced during the extraction of crude oil and the subsequent refining process.
The use of low salinity water in Enhanced Oil Recovery processes has been a recent topic of discussion. The potential to increase recovery rates by altering the reservoir characteristic from an oil-wet to a water-wet state, along with potential cost savings, has garnered attention in recent years.
An Oklahoma refinery required a flow meter for a finished product line leaving the refinery site. When the local Siemens representative visited the site, it was determined there simply wasn’t enough straight run of pipe to install the Siemens clamp-on check meter/interface detector that the company had already standardized on.
The primary fluid used in hydraulic fracturing is water and the completion process can require from 2.75 - 8.25 million gallons per well. This white paper discusses the different water management and instrumentation requirements for controlling and processing drilling mud, hydraulic fracturing fluid, flowback water and produced water.
An optimized pump and slurry system can make or break a business in the Canadian Oil Sands. Costing up to $100,000 per hour due to lost production, it’s no secret that sites plagued by frequent shutdowns, pump malfunctions, or constant parts replacements struggle to control costs.
To ensure quality production of petroleum-based products in oil refineries, including gasoline, diesel, kerosene, heating oil, and byproducts for plastics and a variety of lubricants, operators must establish reliable water monitoring and treatment. There are three refinery process areas that require large amounts of water: cooling water units, desalter units and wastewater treatment plants.
Recently launched by ABB, the VIS (VEGA Isokinetic Sampling) Multi-Phase Flow Meter is the ideal solution for measuring and monitoring flow rates of oil, gas and water close to the wellhead. VIS enables simultaneous measurement of the three different phases with extreme accuracy.
Upstream oil/gas production companies around the globe depend on mud logging service companies to analyze mud samples that help them maintain the correct direction for their drilling field operations. In mud logging, samples of rock cuttings from bore holes are brought to the surface by recirculating drilling media (mud) for analysis by a mobile laboratory to determine the lithology and fluid content of the sample.
The Aqua Caiman™ represents the next generation of multi-rake mechanical bar screens. In designing the screen, Parkson combined over 40 years of experience working on thousands of in-channel screen installations with in-depth market and engineering research. This allowed us to better understand the weaknesses of existing multi-rake and articulating rake screens.
This video provides a simple overview of the screen’s creation, function, features and benefits. From the beginning, Parkson engineers took it a step further by working with a leading design firm to rethink the industry standard step style screen from the ground up. They reviewed current offerings on the market and improved upon the common weak points. The result is the most durable escalating screen out there – the Aqua Rhino.
Runoff from farmlands can carry nutrients, insecticides and sediment that impact source water for downstream communities.
Scientists are developing robots that might someday be able to creep through the pitch-black mines to help prevent spills. A 2015 spill from Colorado’s Gold King Mine unleashed 3 million gallons of water that fouled rivers in three states with toxins.
As the popularity of hydraulic fracturing continues to strain available water supplies, a new technology may be the key to recycling produced water in an affordable way.
In the midst of a global water crisis, industries today too often overlook a river of revenue opportunity: their own wastewater.
There is no doubt that the practice of hydraulic fracturing, also known as fracking, has completely changed the oil and gas landscape in recent history. There is also no doubt that this is a highly technical process.
A $15 million federal, solar desalination funding program seeks to foster a world where utilities and industrial operations have easier access to fresh water.
Hydraulic fracturing is a hot-button issue, but no matter where you land you should agree that more efficient produced water filters will go a long way in improving the practice.
A new study led by researchers with Colorado School of Mines exposes limitations with the current methods used to detect chemicals in oilfield wastewater and offers solutions to help regulators make better decisions for managing this waste stream.
A new report from the Academy of Medicine, Engineering and Science of Texas (TAMEST) is shedding more light on what we know and don’t know about the potential health and environmental impacts caused by oil and gas development in Texas.
Researchers at MIT have developed a system that uses visible light to treat produced water, a potential economic and environmental savior for the oil and gas industry.
A new report from the Oklahoma Water Resources Board’s Produced Water Working Group indicates that oil and gas companies looking for ways to dispose of large volumes of wastewater should focus on recycling those liquids within the oil and gas fields, and not use it for irrigation or other surface applications where human and environmental exposure is a risk.
With the change in administration comes a potential paradox for water and wastewater treatment in the oil and gas industry: Will increased production accompanied by decreased regulations call for more treatment technology or less? Either way, the market is poised for change.
As water scarcity continues to be a major, ongoing challenge in the U.S., public and private sector leaders are seeking new insights on sustainable solutions. In this work, they are grappling with challenges on a scale that oil and gas organizations have been confronting for decades now. It’s understandable that stakeholders can get caught up in the tactical side of dealing with water crises — but there is also guidance to be gained by taking a high-level view.
The drop in price of a barrel of oil has had an understandable impact on major projects in the oil and gas industry. Three years ago, with crude trading above $100 a barrel, schedule was the overriding priority. As time delays were equated to lost revenue opportunity, there was less attention paid to the ultimate cost efficiency of a major project.
About 50 percent of the nation’s residents source their fresh water supply from groundwater wells, which have deteriorated throughout the U.S. over the past decade. For shallow wells, severe drought conditions have gradually depleted groundwater levels.
A new generation of electrocoagulation-based water treatment has successfully treated wastewater and effluent from a remote onshore natural gas exploration and production project with over three years of continuous operation. To compound the challenges of treating this wastewater and effluent, the unit was required to operate in an extremely environmentally sensitive environment — a pristine tropical rainforest.