ormed in 2019, STRYDE is a seismic technology startup spun out of bp. STRYDE’s node receiver technology is the smallest on the market and delivers high-quality subsurface images at a low cost, according to the company. The technology is designed to reduce environmental footprint and HSE risk as well as provide faster surveys and significant operational efficiencies. The first field trial was completed in 2013, and in 2019 the nimble node receiver project was commercialized.

“STRYDE was set up in August 2019 with a primary goal in mind—enabling clients in any industry to access high-definition seismic images, whether those clients are in oil and gas, geothermal, CCUS [carbon capture, utilization and storage], mining or even archaeology,” STRYDE CEO Mike Popham said. “Until STRYDE was available, very few industries and companies could afford to acquire the quality of seismic they needed.”

espite turbulent pricing for oil and gas and a strong social pivot toward the energy transition and decarbonization, determination and cautious optimism prevails to make a success of the remaining life in the U.K. Continental Shelf (UKCS).

In its 2019 economic report, Oil & Gas UK (OGUK) asserted that North Sea firms were on track to produce roughly the same amount of oil and gas in 2020 as they did the previous year, regardless of the unforeseen challenges thrown up by the COVID-19 pandemic. However, with more than GBP35 billion of investment opportunities over the next 10 years included in companies’ plans at the outset of 2020, the annual study concedes there is “real uncertainty” about the viability of many of these initiatives going forward.

mid the fallout from the COVID-19 pandemic, oil and gas companies have been forced to confront a crash in energy prices, as some industries reduced production and transportation activity collapsed. Nearly three-fourths of energy executives in the EY Realizing Strategy Survey indicated that COVID-19 will impact or even cause them to pivot their organizations’ medium- to long-term strategy.

il and gas companies continue to search for and develop hydrocarbon resources, and seismic data remain an effective tool for identifying and delineating these resources. As a result, the inventory of seismic data that a company has continues to grow.

A seismic data library in most cases has been acquired over many decades, which makes keeping track of data contracts, ownership and entitlements a complex and challenging task for oil and gas companies. The consequences of not knowing ownership status and entitlements can be severe.

hile production from unconventional reservoirs has vaulted the U.S. into the world’s leading producer, a proliferation of pay zones both around the world and in North America remain inaccessible because of the poor economics needed to produce them.

In places like the Middle East, China and South America, vast reservoirs of oil and gas are virtually locked because they are too expensive to drill, complete and produce. One of the barriers to accessing these reservoirs is the ability to quickly drill through hard rock. The time it takes to drill through hard rock strata makes hydrocarbon production not economically feasible. However, one company believes it has discovered the solution.

electing appropriate proppants is an important part of hydraulic fracture completion design. Proppant selection choices have dramatically increased in recent years as regional sands have become the proppant of choice in many liquid-rich plays. But are these new proppants the best long-term choices to maximize production? Do they provide the best well economics?

n mature basins, sand issues can account for up to 10% of all shut-in wells either due to failure of the existing downhole sand control or onset of sand production due to pressure depletion and/or water production.

There are many reasons for sand or fine material entering and accumulating in the wellbore. Depending on the level of severity, the consequences need not be detrimental. However, the accumulation of sand production downhole or in surface equipment can lead to production being killed, wells shut in or collapse of the formation.

roduct quality directly drives hydrocarbon prices and determines where barrels can be delivered. It’s a critical factor in optimizing how oil and gas is produced, transported and refined. Despite the importance of quality, it remains difficult to measure accurately and in real time. With products moving quickly and mixing constantly throughout the supply chain, maintaining an accurate record of quality is complicated.

ithout a reliable maintenance program underpinning everyday functions, offshore operations can prove to be untenable. Only by having a solid program in place behind the scenes can operators gain the peace of mind that enables them to get on with their key priority of maximizing hydrocarbon production.

In the first quarter of 2020, a 10-year contract was signed between Logan Industries and Diamond Offshore Drilling Inc. for Logan to provide a risk reduction and continuous based monitoring program aboard four of Diamond’s vessels. Each vessel is equipped with 16 risers, with the scope of the program encompassing 64 wireline riser tensioners (WRTs) plus a small number of spares.

Mobile power system achieves emission compliance, improves frac performance

Thriving in today’s hydraulic fracturing market requires reliable power and performance while reducing emissions. NRG Technologies, an AFG Holdings Co., recently field-tested their novel technology alongside its DuraStim electric powered fracturing pump. The DuraPax mobile power unit performed successfully and surpassed strict emission standards despite severe heat and varying power loads. The technology delivers 3.6 MW of continuous duty power per trailer, while fully complying with EPA Clean Air Act standards. No additional exhaust stacks or catalysts are required. The power unit’s NO_x emissions are 40 to 50 times cleaner than blended fuel systems. At full load, it is 75% lower than EPA CO₂ emission requirements. This remote power system achieves emission compliance and high operational performance across a broad range of operating parameters. Reliable, economic operation is ensured by continuous run times as high as 750 hours before preventive maintenance is due. Versatility is further enhanced by a low, 60-psi to 100-psi gas supply requirement, versus 535-psi turbine demands. Generator output of 480 v is easily transformed up or down to meet specific voltage requirements. Powerful enough for hydraulic fracturing, the versatile mobile unit also provides emissions-compliant economic electricity generation to run rigs and other wellsite operations, along with the option to sell back to the grid.

PEOPLE

Schlumberger New Energy, the CEA and partners have appointed Florence Lambert CEO of the Genvia clean hydrogen production technology venture.

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Gilmore, a provider of flow control solutions, has appointed David Nemetz CEO.

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n the Fourth Industrial Revolution, digital is becoming the foundation of every industry. Energy sector winners will be defined by their ability to leverage digital technologies to design sustainable and profitable business models. This does not mean merely applying the latest tech to existing business processes—a “digital varnish” approach that is fraught with pitfalls. Digital technologies must be embedded across the value chain, from exploration to production to distribution to consumption, and extended to customers and ecosystem partners.