Drilling fluid is critical for successful oil extraction. Typically made up of water, clay and a complex mix of chemicals, it supports the drilling process in a variety of ways — from lubricating and cooling the drill bit under high-temperature and high-pressure conditions, to lifting drill cuttings to the surface, to maintaining oil well stability and safety. But drilling fluid is not a “one size fits all” solution. To work properly, the fluid must be optimized for the unique geographic conditions of individual well sites.
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.
The flare gas discussion is heating up again. According to the Bureau of Land Management (BLM), U.S. oil production is at an all-time high, and so are the harmful methane emissions from leaks, flaring and venting.
For the unfamiliar, the term “disruptive technology” initially sounds quite bad, as though it describes something that gets in the way. Far from impeding progress, however, disruptive technologies actually accelerate progress exponentially by disrupting the status quo. Think personal computers vs. mainframes, or cell phones vs. land lines.
In the oil and gas industry, regulations and requirements to measure, monitor and report flared gases continue to expand and extend. The U.S. EPA continues to focus on enhancing regulations aimed at reducing emissions of methane and volatile organic compounds (VOCs) into the environment.
Degassing applications in the oil industry are numerous; steam is used in nearly all processes for refining oil. Therefore, water must be treated to prevent scale and pipe pitting through the removal of dissolved ions and dissolved gasses such as oxygen and CO2. Boiler feed water for producing steam must also be free of dissolved CO2 and oxygen; SEPAREL® degassing membranes can remove both gasses in a single compact system.
Petrogas LLP, one of the world’s largest oil rehabilitation companies, required demineralized water for a new boiler component to its Turkmenistan refinery.
Petron Bataan Refinery wanted to expand production to process 180 thousand barrels of crude oil per day while changing its feedstock from Arab Light to less costly heavy and sour crudes.
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.
Last year the EPA implemented new regulations entitled “Mandatory Reporting of Greenhouse Gases.” The new regulations called for certain facilities emitting 25,000 metric tons or more per year of specified GHG’s to provide an annual report of their actual GHG emissions.
Since the first Coriolis flow sensors were introduced to the marketplace in the 1970s, the technology has evolved considerably. As the installed base for Coriolis grew, the sensors were being called upon to deliver data in environments with increasing levels of complexity. This meant that Coriolis sensors had to adapt and conform to a dizzying array of ever-changing installation requirements, process conditions, communication formats, and configuration parameters. The following article highlights four key advances in Coriolis flow measurement’s journey from the 1970s to today.
See how Xylem partnered with WateReuse Colorado and Invintions Winery to create wine using purified recycled water.
At Fluence, we have more than 30 years of experience in the design, construction, and operation of waste-to-energy plants for a wide range of industrial and municipal clients. Our proprietary anaerobic treatment technologies process wastewater and sludge to produce biogas, which can be used to produce electricity and thermal energy, or which can be purified to produce biomethane for injection into the grid.
L'eau Claire upflow filters offer an alternative to conventional water clarifiers for removing suspended solids and colloidal material such as silica. Despite the influent loading, this cost-effective filtration process removes 98% of particulates ≥2 microns without the use of clarifiers, flocculation, sedimentation, dry chemical addition or mixers. Watch the video to see how it works.
A hospital had been pumping their wastewater with a submersible pump for years. But after seeing the benefits of the S&L Above Grade Wet Well Mounted Pump Station, they quickly saw the benefits - easier and safer maintenance, higher efficiency, long pump life, and more. Hear from the operator himself to learn why the hospital now prefers S&L's EVERLAST™ Wet Well Mounted Pump Station.
Collaborative research is a critical element for identifying unforeseen risks associated with using the oil industry’s wastewater outside the oilfield. That’s the recommendation of a new peer-reviewed paper accepted this week in the Journal of Integrated Environmental Assessment and Management (IEAM).
We’re past the midpoint of the Texas legislative session and the bill filing deadline is behind us. Because the legislature only meets for five months every other year, there’s a lot to accomplish in a short span.
Keeping an eye on what happens with domestic oil and gas regulation is a bit like herding cats. We’ve seen encouraging progress on air quality issues related to oil and gas, but an equally critical front that’s seen major action is protection of our land and water resources.
When it comes to answering questions about whether the oil and gas industry’s wastewater can be safely reused for other purposes, like food crops, livestock, or even drinking water, there are a number of other serious factors to be considered.
Onshore crude oil production has increased in the United States over the past few years. Oil producers, specifically the North Dakota Pipeline Authority and the Bakken Shale field producers are transporting crude oil by rail and train to both the East and West Coast oil refineries. While rail tends to be one of the safer and more efficient ways of transporting crude oil, there is still a risk of a spill. Oil spills are threats to both ground and surface waters, which can ultimately impact drinking water.
Regulators from across the country met in Vermont this week at the Environmental Council of the State’s (ECOS) fall meeting to discuss some of the nation’s most pressing environmental challenges. I joined members of ECOS’ Shale Gas Caucus to discuss an emerging threat imminently impacting oil and gas-producing states: the question of what to do with the massive amount of wastewater produced by the oil and gas industry each year.
Most industries are required to remove contaminants from wastewater systems before discharge to a receiving stream or municipal facility. Depending on the industry, contaminants may be numerous or difficult to treat. Finding the most effective, cost-efficient treatment method is critical for both business and the environment.
Last year was full of twists and turns for the drinking water and wastewater treatment industries. What can 2017’s biggest stories tell us about what’s to come this year?
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.