Can oil and water really mix? (part 1)
About to enter its fourth year, the California drought has resulted in stringent controls on water usage, to say the least: Governor Jerry Brown has imposed unprecedented measures to cut water use by 25 percent across the state—and even though farmers in the delta of the Sacramento and San Joaquin rivers have volunteered extra reductions, efforts to stave off further mandatory cuts have failed thus far.
However, as California’s agriculture sector struggles to reduce its consumption of water – estimated to be 80 percent of the state’s total – eyes are turning to California’s other big producer: the oil and gas industry.
California is not only the biggest producer of fruits, nuts and vegetables in the U.S., the state is also the third biggest producer of oil in the country, extracting roughly 200 million barrels per year. The rock formations that bear oil in the region also tend to harbor large volumes of brackish saltwater. The ratio of water to oil produced by operators in the region is, on average, ten to one.
As Chevron recently explained, the Kern River oilfield neatly illustrates the situation.
Kern River is the second-highest producing oilfield in California; moreover, for every barrel of oil, the field also produces around nine barrels of water.
Almost 25 percent of this water is treated to remove solids as well as free, dispersed and dissolved hydrocarbons before being used in enhanced oil recovery (EOR) applications. Because the Kern River field tends to produce heavy oil, steam flooding is used to reduce the crude viscosity and boost production.
Continuing with the case of the Kern River oilfield, 75 percent of the produced water is not required for further oil extraction, which is at the lower-end of the range for oil producers in California (many of whom often have to dispose of, or find ways to re-use, up to 99 percent of their produced water).
This, coupled with recent discussions by state officials regarding the closure of nearly 100 disposal wells, will more than likely push the reuse of this produced water even further.
Naturally, however, that remaining water still needs to be treated, and until now there has been little economic incentive for operators and farmers to get together in an effort to work out a deal for the treated water: Historically, re-injection has been cheaper than re-use given the treatment that is required even for agricultural purposes.
But that financial equation has not taken into account a record-breaking drought, nor does it allow for the precipitous drop in oil prices, which have had a heavy impact on the state’s producers’ bottom-line: On the one hand, farmers need water to maintain healthy production of essential crops; on the other, oil producers are looking for innovative and cost-effective solutions to boost their margins.
For the most part, these solutions look at how best to optimize output from existing wells or minimize production costs.
But technological advances mean that there are now solutions available that make it possible to treat produced water on a much more cost-effective basis.
Not only does this reduce the OPEX associated with finding new freshwater or disposing of produced water safely and compliantly, it could provide oil producers with a new asset to offer to market: water that is fit for agricultural purpose.
The numbers add up. Farmers typically buy fresh water at approximately 25 cents a barrel. Even taking into account a lower cost for recycled water – say 18 cents a barrel – it is now possible to perform the necessary processing for less than this amount for significant quantities of produced water, if not all of it. Even considering initial capital costs, when the difference is factored up by several million barrels a day, the results can be significant both for the operators and the farmers.
So what treatment is required in California?
Look for the answer in the second part of our two-part series, coming soon!
UK Nissan fleet owners receive commercial charging service
UK fleet owners of Nissan Leaf and e-NV200 models can avail of a new commercial charging service using vehicle-to-grid (V2G) technology.
The V2G technology developed by DREEV, which is a joint venture between EDF and Nuvve, which specialises in V2G technology, allows for two-way energy flow; both recharging an EV’s battery when electricity is at its cheapest, and discharging excess energy to sell back into the grid.
Fleet customers will save around £350 savings per charger each year, which equates to approximately 9,000 miles of driving charge per year.
EDF’s V2G business solution includes:
The supply and installation of a two-way connected compact 11kW charger capable of fully charging a Nissan LEAF, depending on the battery model, in 3 hours and 30 minutes - 50 per cent faster than a standard charger - with integrated DREEV technology.
A dedicated DREEV smart phone app, to define the vehicles’ driving energy requirements, track their state of charge in real time, and control charging at any time
Philip Valarino, Interim Head of EV Projects at EDF, said today’s announcement marks an important step on the UK’s journey towards electric mobility. "By combining the expertise and capabilities of EDF, Nissan and Dreev we have produced a solution that could transform the EV market as we look to help the UK in its journey to achieve Net Zero," he said. “Our hope is that forward-thinking businesses across the country will be persuaded to convert their traditional fleets to electric, providing them with both an environmental and economic advantage in an increasingly crowded market.”
Andrew Humberstone, Managing Director, NMGB, said Nissan has been a pioneer in 100% electric mobility since 2010, and the integration of electric vehicles into the company is at the heart of Nissan's vision for intelligent mobility.
He added the Nissan LEAF, with more than half a million units already sold worldwide - is the only model today to allow V2G two-way charging and offers economic opportunities for businesses "that no other electric vehicle does today". Click here for more information.
FirstEnergy Corp, which aims to electrify 30% of its approximately 3,400 light duty and aerial fleet vehicles by 2030, has joined the Electric Highway Coalition. The group of electric companies, which has grown to 14 members, is committed to enabling long-distance EV travel through a network of EV fast-charging stations connecting major highway systems.
The Edison Electric Institute estimates 18 million EVs will be on US roads by 2030. While many drivers recognize the benefits of driving an EV, some are concerned with the availability of charging stations during long road trips. Through their unified efforts, the members of the EHC are addressing this "range anxiety" and demonstrating to customers that EVs are a smart choice for traveling long distances as well as driving around town.
Volta Industries has installed new charging stations at Safeway in Upper Marlboro, Maryland, and Renton, Washington.