The Promise (and Problems) of Low-carbon Offshore Production
Reaching decarbonization goals involves internal discussions over the best technologies to implement for projects that, offshore, may not see first oil for five years, says Petrobras’ João Henrique Rittershaussen during an OTC panel discussion.
Darren Barbee, Hart Energy
HOUSTON—Offshore producers have aggressive ambitions for lowering their carbon and methane emissions, but they also recognize some significant hurdles in their aims, including technology that doesn’t yet exist and the more uncertain economics of carbon capture and sequestration.
Companies such as BPX Energy, Schlumberger, Petrobras and Equinor, speaking at an Offshore Technology Conference (OTC) panel on May 3, all discussed reducing emissions as quickly as possible with the ultimate plan to achieve net-zero emissions by 2050.
But the world is also at a point at which, because of the war in Ukraine in particular, the need for a rapid increase in oil and natural gas production is required to offset potential losses in energy exports from Russia.
The resulting tension is finding ways to meet energy transition targets in the future while serving the world’s energy demands now.
João Henrique Rittershaussen, chief production development officer at Petrobras, said the Brazilian company’s strategy rests on three pillars. First, it aims to be transparent with how it accomplishes and quantifies its progress. The company is also looking to make its fossil fuel position resilient as it transitions into a low-carbon environment. And it’s working to strengthen its skills while finding value in carbon.
The company has about $248 million in its decarbonization fund and projected investments of $2.8 billion in low-carbon technologies from 2022 through 2026.
Petrobras has already targeted 2030 as the year it will reduce its absolute emissions by a quarter while also eliminating routine flaring. Rittershaussen also noted that it has reduced its kilograms (kg) of CO₂ per boe by 48% in 2021 compared with 2009.
But Rittershaussen said making that work involves internal discussions over the best technologies to implement for projects that, offshore, may not see first oil for five years.
Some of those discussions include the “level of new equipment installed in the unit, that we can guarantee in the future the capex—it’s affordable for the project and will have the high efficiency, low carbon for the future. It’s not an easy decision.”
Petrobras also has no way of putting value on the carbon it captures and how that can be realized in a pricing reality that often fluctuates greatly.
“We are also [discussing] a lot about how we can generate value with the decarbonization,” Rittershaussen said. “We cannot have just the mindset that you spend the money that you have to, to decarbonize [without a] win-win solution” financially.
Wallace Pescarini, Schlumberger’s Offshore Atlantic Basin president, said that offshore is part of the low-carbon solution, with upstream carbon intensity is 14 kg/boe.
Pescarini noted that capex has already been earmarked for offshore development, with $500 million anticipated in greenfield financial investment decisions in the next five years globally.
Schlumberger is seeing that the future will be “an energy ecosystem around offshore, not just limited to oil and gas but carbon storage, wind power and hydrogen will be part,” he said.
At BPX Energy, BP’s U.S. onshore oil and gas division, Faye Gerard, vice president of low carbon and sustainability, said the company’s strategy is to pivot “from an international oil company to an integrated energy company.”
That’s not without challenges.
“That transition is going to take some work,” Gerard said.
Like its peers, BP plans to be a net-zero company by 2050 or sooner. As a result, BPX Energy is focusing on actionable science-based technologies. The company intends to use low-emission energy sources, such as solar and wind, to electrify its assets.
BP and BPX also are working to upgrade and improve their infrastructure. The company is in the midst of energy transition modeling for its 2018 acquisition of BHP’s U.S. shale assets. That effort includes moving toward more centralized tanks and routing natural gas through infrastructure rather than flaring.
BPX is also examining equipment process optimization, route optimization, electric vehicle transitions and even using air compressors rather than pneumatic.
While those steps are ongoing, the company is also working with technologies to monitor, repair and, in the future, use its massive trove of leaks and emissions data to predict and deploy preventative maintenance.
“Methane is one of the largest contributors to climate [change],” she said. “So how do we drive that down?”
But BP and BPX want to go further than monitoring emissions as it works toward a net-zero goal by 2050.
One key question for BP and the world is how it looks at emissions measurements that use actual data.
“We’re aiming to install methane measurement at all of our major operating oil and gas sites by 2023 or sooner,” she said. “We want to publish that data.”
But beyond monitoring emissions, BP wants to go even further.
“The problem is technology advancement is moving a little slower than” needed, Gerard said. “So, how do we progress with the technologies that are out there for methane, including detection and quantification?”
Deepwater Resources Critical for Future Energy Mix, Exxon Mobil Exec Says
A senior executive of Exxon Mobil discussed how the company is trying to bring its deepwater discoveries onstream as quickly as possible.
Jennifer Pallanich, Hart Energy
HOUSTON— With overall energy demand expected to continue climbing, deepwater oil and gas will play an ongoing role in the energy mix going forward, according to an industry expert.
Jeff Weidner, vice president of the deepwater portfolio at ExxonMobil Research Co., said new metrics must feature in field development decisions. And when an operator finds “advantaged resources” such as ExxonMobil’s string of deepwater discoveries in Guyana, the key is to bring those reserves onstream as quickly as possible.
That does, however, place a strain on various teams involved in the project as well as the ability to deploy certain technologies. And when it comes to using new technology, its value must meet or exceed the costs, he said during “The Critical Role of Deep Water in the Present and Future Energy Mix” executive dialogue at the Offshore Technology Conference (OTC) on May 4.
Because energy is linked to human development, economic progress and the overall quality of life, “it’s hard to imagine energy demand doing anything but increasing,” Weidner said.
And the expectation is that there will be a “strong need” for oil and gas in the future energy mix. But what the industry currently has on tap won’t be enough to meet projected demand, he said.
“Trillions of dollars are needed over the next 20 years just to meet even those conservative estimates of oil and gas demand,” he said.
When operators make investment decisions, they can no longer consider only factors like potential profitability, materiality and rate of return, he said. They must also consider the carbon intensity of the project over its entire life cycle, he said.
And large deepwater discoveries can check off all those boxes.
“A lot of the industry is focus on the deepwater because it’s recognized that that is where you can make a significant impact and meet those metrics,” Weidner said. “You can get that sweet spot with deepwater. It can provide significant production, and you can usually get it online faster than if you’re trying to build an LNG plant.”
With these things in mind, he said, ExxonMobil is focusing its exploration efforts on deepwater. And that focus has paid off in Guyana, where the supermajor has reported 18 deepwater discoveries since 2015, including three in late April. They achieved first oil on one in 2019 and the second earlier this year.
“This is an advantaged resource,” he said. “We can only cross our fingers and hope for another Guyana.”
One of the things ExxonMobil has also discovered is that it’s vital to bring deepwater discoveries onstream as quickly as possible. For comparison, he cited discoveries made in the 1990s offshore Angola that weren’t brought online until the mid-2000s.
“That’s a bar that the industry is looking at, how do we shorten that timeline?” he asked. “They’re all looking at how can we shorten that timeline from seven years to five years to four years to the unthinkable three years.”
Fast-tracking the Guyana projects has “stressed out our subsurface organization,” he added.
The team only had a certain amount of information on which to design the field development, he said.
“We like to work to a certain level of detail, but what is the level of detail we do need?” Weidner asked.
Enter the need for flexibility in infrastructure that reflects a 20-year or longer investment, he said.
He estimated that countless projects have led to people thinking, “I wish I had a little more capacity or several more well slots, or if I’d only put it here instead of there.”
Building in flexibility can help meet unexpected needs and help that infrastructure remain productive over the entire design life, he said.
Sometimes there is a tradeoff when considering whether to use certain technologies, he said.
For instance, there is a huge desire for data.
“From a reservoir standpoint, the more data I have, the better. Even if I don’t need it, I want it because it’s going to be helpful,” Weidner said.
But in some cases, data can be a hindrance, he said.
He cited smart completions that give control over the well as one example.
“Why wouldn’t I want that on every single well?” he asked.
The answer is that the control comes at a cost, he said.
“There’s a little bit of a bottleneck here and there, and if I put them on all the wells, I won’t have the same high flow rate,” he said. “So you have to step back and look at things and point out the limitations of certain designs.”
That means asking if there’s a better way to achieve the desired outcome and then working with the vendors to make it happen, he said.
Recognizing Offshore Industry's Emerging Leaders
OTC's annual award program recognizes young professionals who are making key contributions to the offshore energy sector.
Faiza Rizvi, Hart Energy
The Offshore Technology Conference (OTC) honored on May 3 the previously announced 2022 class of Emerging Leaders Program, recognizing young professionals with fewer than 10 years of experience in the offshore energy sector. According to an official announcement by the OTC, this year’s program participants are passionate about their field work, dedicated to industry service and highly focused on safety in the workplace.
The honorees, who were recognized during a special ceremony, were nominated by one of OTC’s 15 sponsoring, endorsing, or supporting organizations and selected by last year’s inaugural class of Emerging Leaders.
“The 2022 Emerging Leaders class is filled with incredibly smart and passionate young professionals positioned to help shape the future of offshore energy development,” Leigh Ann Runyan, executive Director of OTC, said in a statement.
“The ability to develop new solutions that help overcome the energy industry’s most pressing challenges has always been dependent on hard-work, determination and innovation; this year’s Emerging Leaders class is filled with young professionals that understand what’s at stake and have the ability to lead our industry into the future," Runyan added.
Below is a list of the fifteen honorees of the 2022 Emerging Leader Class:
- Qian Wu, PhD, Wells Research Engineer, Exxon Mobil Upstream Research Co.
- Lauren Ray, Geoscience Supervisor, Exxon Mobil
- Wojciech Jakubowski, PhD, Senior Scientist, Baker Hughes
- Ajay Shastri, PhD, Project Engineer, Geosyntec Consultants Inc.
- Carlos Lopez, Senior Associate, Stress Engineering Services Inc.
- Sara Young, Director of Growth and Development, Wood
- Gabriel Serrão Seabra, Digital Transformation Manager for E&P-Reservoir Team, Petrobas
- Harish Sarma Krishnamoorthy, PhD, Assistant Professor, University of Houston
- Dongchun Mary Qiao, PhD, Senior Engineer, ABS
- Dairon Campos Dominguez, Engineering and Development Manager, OneStep Power Solutions Inc.
- Dario Mariani Sung, QHSE Data Specialist, TechnipFMC
- Abhinandan Kohli, Senior QI Petrophysicist, Shell
- Manoj Jegannathan, Senior Facilities Marine Engineer, Occidental US Offshore
- Izzat Thiyahuddin, PhD, Executive (Materials), PETRONAS Research Sdn Bhd
- Thomas Shattuck, third year law student at University of Houston and Incoming Associate, Akin Gump Strauss Hauer & Feld LLP
Schlumberger Launches Data-driven Service for Subsea Assets
The system provides equipment health, operational and production insights.
Jennifer Pallanich, Hart Energy
HOUSTON—Schlumberger launched a data-driven performance service for subsea assets during the Offshore Technology Conference (OTC) on May 3.
Subsea Live is intended to make it easier to extract insights from mountains of data and improve decision making, said Cedric Chidiac, product champion for digital solutions at OneSubsea, a Schlumberger company.
“It gives you speed and certainty to help you transition from reactive to proactive,” Chidiac said.
Subsea Live helps identify issues and risks early so mitigation plans can be made to maximize the uptime and availability of the system, he said.
The artificial intelligence- (AI-) powered approach follows on OneSubsea’s years of experience with remote monitoring and data analysis. Subsea Live is meant to provide equipment health, operational and production insights, Chidiac said.
“These are used to monitor conditions of the equipment and identify risks for proactive resolution,” he said. “It will notify you if the chokes are starting to show signs of wear.”
One customer who needed sand slug detection because the problem well could not be identified by acoustic sensors as they were not providing reliable readings, he said. Using a combination of existing VX Omni meters, a sand detection algorithm was created based on historical data to enable Subsea Live to identify the sand-producing well and help the customer rectify the problem, he said.
Another operator needed help with hydrate management in a long fast-tracked subsea tieback that was not protected against hydrates. AquaWatcher sensors detected the free water, and an ultrasonic chemical injection metering valve was used to control the monoethylene glycol (MEG) supply.
WEDNESDAY, 3 MAY
OTC 2022: Talos Energy CEO Charts Path from Shallow Water to Carbon Capture
The Gulf of Mexico oil producer’s Bayou Bend carbon capture and sequestration project lands Chevron as partner.
Brian Walzel, Hart Energy
HOUSTON—Talos Energy CEO Tim Duncan discussed his company’s transition into both an offshore E&P and carbon capture operator at this year’s Offshore Technology Conference (OTC).
Just hours after Chevron announced it was joining Talos Energy’s Bayou Bend carbon capture and sequestration (CCS) project, Duncan explained how Talos wanted to be an early player in the CCS space because of its vast seismic database in the Gulf Coast region plus the relationships with local policymakers and landowners the company has fostered operating nearly two decades as a Gulf of Mexico oil producer.
“We know who we are,” Duncan told OTC attendees during a keynote address on May 3. “We’re oil and gas guys, there is no doubt about that. We want to build as big of a company as possible that can produce reliable energy every day. When we looked into our skill set, we realized we can do more than that.
“When we started looking at the skills we have at our company, we started asking ourselves, can we participate in a low-carbon economy? We know it’s coming, and we’re not running away from that. There is no doubt the majors are doing it, and they should do it—they’ve got the R&D, they’ve got the tech, they’ve got some of the smartest people in the world and they should participate in it. But it doesn’t mean a company like ours can’t participate in it too. But where is our niche?”
Duncan said the company considered a variety of options for its latest capital outlay projects, including offshore wind on the East Coast, which ultimately proved to be too costly.
“We thought about CCS, and we looked at our skills as geologists, project managers, drillers, and we realized we can be involved in that, and we can be involved in that right now,” he said.
Talos, along with partner Carbonvert, jumped into CCS when it earned the winning bid in a 2021 request for proposal offered by the Texas General Land Office for a carbon storage site along the Gulf Coast. That winning bid ultimately became the Bayou Bend CCS project.
Bayou Bend CCS is one of four CCS projects Talos Energy is currently involved with and encompasses over 40,000 gross acres and, based on Talos and Carbonvert’s preliminary estimates. The project could potentially sequester 225 million to 275 million metric tons of CO₂ from industrial sources in the area, according to Talos Energy. First injection is estimated for 2025.
Under the terms of the venture with Chevron, Talos and Carbonvert would contribute the Bayou Bend CCS lease to an expanded joint venture (JV) including Chevron in exchange for consideration of cash at closing and capital cost carry through project financial investment decision. Upon closing, equity interests in the JV would be 25% Talos, 25% Carbonvert and 50% Chevron, and Talos would remain the operator.
Other Talos CCS projects include the Freeport LNG point source project with Storegga, with a capacity of 24 million metric tons and first injection estimated for late 2024; the River Bend hub, with a capacity of more than 550 million metric tons, with project partners Storegga and EnLink, and the Coast Bend point source project with Howard Energy, with storage estimated up to 100 million metric tons.
Overall, Talos Energy has a CCS portfolio of 800 million metric tons of possible CO₂ storage capacity.
As Duncan explained, Talos’ journey into a CCS operator ultimately began with their expertise in shallow-water production, and their vast database of seismic.
“We believe we can participate in areas where we know the biggest and most sophisticated companies in the world are going to be there, but we can be there too, and the thing goes for CCS,” he said. “We’re big seismic guys. We have over 90 million acres of seismic in the Gulf of Mexico, there isn’t much we don’t have covered up.”
Duncan said that going forward, the focus of the company’s capital outlay will be on debt reduction and CCS.
“We want to generate free cash flow and our view is, does it make more sense to allocate capital into what’s next rather than what’s now?” he said. “And what’s next is CCS.”
What’s Needed for the Energy Transition?
Leaders from Chevron, Equinor, SBM Offshore, Siemens and TotalEnergies share insight on the energy transition during the Offshore Technology Conference.
Velda Addison, Hart Energy
HOUSTON—Collaboration, policy support and technology are required for the energy transition, according to a group of panelists representing some of the world’s biggest energy and service companies.
Industry players—service companies, majors, small operators and international companies—have collaborated amongst themselves but the new energy mix will bring new partners together, Manish Misra, vice president of strategy and integration for Chevron New Energies, said May 2 at the Offshore Technology Conference.
“They have a different perspective; they have a different way of working and that’s where we will have to open our approach and be ready to collaborate with folks who are not our natural partners in our businesses,” Misra said.
Traditional energy and service companies have been transforming their operations, seeking to reduce emissions, better manage carbon and/or move deeper into renewables and low-carbon energy sources, on the road to net-zero by 2050.
Chevron has allocated $10 billion through 2028 for low-carbon initiatives. Its approach focuses on lowering carbon intensity, having already identified nearly 100 greenhouse-gas (GHG) abatement projects to pursue. Its strategy also includes growing its lower carbon business by focusing on renewable fuels, hydrogen, carbon capture, utilization and sequestration (CCUS) and offsets.A ‘Clear Path’
The energy transition also requires policy support, panelists agreed.
“I think it’s very important for governments to supply not only policies that encourage renewables but reliability,” free of worry about who is in office and what type of lease sales will be available, said Lauren Spence, senior business development manager of offshore wind for TotalEnergies.
Like its peers, TotalEnergies has also integrated climate change into its strategy as it pursues CCUS activities, generates electricity from renewables and gas and further expands its renewable energy portfolio, including in the U.S. where it recently acquired Austin-based Core Solar.
“We also need a clear path from the permitting and regulatory standpoint where we don’t feel like our opportunity will be able to stop or stalled,” she said.
However, policy support alone won’t get the industry there, said Anish Simon, vice president of emerging technologies and innovation for Equinor. Support such as subsidization and favorable taxation policy bring benefits for businesses. However, “what does that lead to? Probably inflation, probably social unrest.”Invest in Tech
The key to the energy transition is technology, Simon said.
“You’ll have to invest in technology and you have to believe in the ingenuity of scientists and researchers,” he said. “When I look at it, there’s technology in one arm and there’s policy in another arm.”
Both will create social behaviors that shape the energy transition, possibly further reshaping the energy businesses.
Equinor’s net-zero ambitions include reducing its net carbon intensity by 20% by 2030 and 40% by 2035 as it increases capex allocation for renewables and low-carbon solutions to more than 50% by 2030. In addition to bringing down GHG emissions and reducing the carbon intensity of its business, it intends to establish up to five hydrogen clusters by 2035.
Getting to net zero by 2050 is important and companies must have plans to get there, added Stein Rasmussen, group strategy director for SBM Offshore.
“To really get to net zero by 2050, you have to have a plan to get to that 45% by 2030 and that’s starting to become more urgent,” he said. “This forces us to take action and to work with our clients as a service company. If we all have the same ambition, we can get there.”
SBM’s strategy is built on three pillars: optimize, including reducing cost and emissions during a project’s life cycle; transform, lowering carbon footprints, breakevens and cycle times; and innovate, launching products such as an FPSO with near-zero carbon emissions.A price on carbon?
Is a price on carbon required for the energy transition?
How else would a change in behavior be incentivized, Simon said, pointing out it could bring cost parity to, for example, sustainable aviation fuel. “It also gives some predictability on what your investment would look like,” he said.
As the carbon tax debate continues, companies are pushing forward with new technologies and improving existing ones. Still, there are hurdles to overcome, panelists said.
For existing technologies, this includes modification and improvement to the technology qualification process, Poul Skjærbæk, head of service innovation for Siemens Gamesa Renewable Energy, said before turning to floating wind new product development.
“We have to, of course, go through the technology readiness levels and then we have to pilot test,” he said.
“If you have one issue with a unit, you have 50 issues in the field,” Skjærbæk said, signaling scale could pose risks. He stressed the importance of pilot tests in developing the next generation of technology before scaling up. The end product, as mentioned by other panelists, is not yet known, he said, noting the industry is going through a learning phase during this energy transition.More than hydrogen, wind
For Simon, the energy transition is not just about hydrogen, wind or the next generation of low- or carbon-free energy. He said his team explores any and everything when it comes to emerging technology innovation; however, thoughts don’t stop at energy. Change comes with potential societal impacts that the energy industry should heed.
Take rising ethanol production’s impact on food supplies. Or, “You cut off your gas value chain. What’s your impact on fertilizers?” he asked. The story is the same with water.
Massive amounts of water are needed for green hydrogen, something that could become problematic in water-scarce areas—perhaps, calling for more investment and research in desalination, as noted by an OTC attendee who brought up the topic during Q&A.
“If you look at these clean technologies, all this comes into play,” Simon said. “That’s why an energy transition that I look at or when my company looks at it, it’s not just wind, hydrogen. [It’s] the whole society. The way we interact is going to change, and that’s why we started asking the question, ‘What would energy business look like?’”
That’s a question other energy companies may be asking, too, as the energy transition drive reshapes business models and operations.
‘Innovation’ is More Than Just a Buzzword
To keep up with energy demand, OTC panelists agreed that innovators will need to find solutions at a faster pace to catch up to a mounting human population. “Innovation is the way that we adapt to survive,” added Intelie’s Augusto Borella Hougaz.
Madison Ratcliff, Hart Energy
HOUSTON—Innovation, the driving factor in human growth, has brought an abundance of new technologies to the energy sector since the Industrial Revolution.
The evolution of these technologies has led energy professionals to face their newest challenge of supplying an ever-growing human population with energy that isn’t only affordable and plentiful, but also sustainable and clean, according to a panel at the Offshore Technology Conference (OTC) on May 3 titled “The Intersection of Innovation, Energy Transition and Digital Transformation”.
“Mankind[’s] journey is about innovation; innovation is human,” Augusto Borella Hougaz, director of oil and gas products at Intelie, said during the OTC panel.
Joined by panelists Juliana Garaizar, vice president of innovation at Greentown Labs; Amy Henry, CEO and co-founder of Eunike Venture; Jon Nordby, managing director at MassChallenge; and Allyson Book, vice president of energy transition at Baker Hughes, the group discussed the corporate pivot, workforce, entrepreneurship, risk-taking and innovation philosophy driving innovation, the digital transformation and the energy transition.
“This is the intersection of innovation and how it works with what we're doing in our world,” said Barbara Thompson, North American engineering manager for subsea production systems at Baker Hughes who served as the panel’s moderator. “We’re talking about the role of innovation, but [also] why are we doing this? We need change.”
In his presentation, Hougaz drew attention to the fact that with 8 billion people on the planet, there is about 100,000 tons of CO₂ emissions per day to mitigate, a staggering number that has grown as the human population has increased more drastically than any other animal species on the planet. He then walked through the evolutionary stages of mankind, ending with humanity’s biggest challenge to solve in this era: creating sustainable and affordable energy.
Hougaz emphasized the need for solutions to “prioritize innovations that deliver for individuals more power, more decision and more autonomy.”
“When we look back in different moments and different eras of our species, we see that when we have the evolution of the creation of humanity, we allow creation of processes and new growth of the population,” he said.
“Innovation is the way that we adapt to survive,” he added. “We take this technology and we incorporate new actions [and] usually new tools that drives individual empowerment.”
While energy innovation and transformation is critical to supplying a rapidly expanding world with reliable energy, with 8 billion people on the planet, supply needs to be increased with more urgency. However, to keep up with energy demand, Hougaz and Thompson agreed that innovators will need to find solutions at a faster pace to catch up to a mounting human population.
“But innovation is a different mindset,” Thompson said. “And if you work at large companies, you find innovation doesn’t happen very fast; it moves like an ocean liner, or maybe like inflation. But if you’re doing innovation, it’s a very [slow] thing.”
“At the end of the day, the transformation that we are going through is a human process; it’s about the human journey,” Hougaz added.
Baker Hughes Launches New Subsea Wellhead Technology
The new MS-2 Annulus Seal adds more reliability to cover more temperatures and pressures, said Daniel Barton, offshore business leader at Baker Hughes.
Jennifer Pallanich, Hart Energy
HOUSTON—Baker Hughes launched the next generation of an annulus seal during the Offshore Technology Conference (OTC).
The new MS-2 Annulus Seal has already been ordered for North and South American wells and first installations are expected to occur by the end of 3Q 2022, said Daniel Barton, offshore business leader at Baker Hughes.
It is the next generation of the existing wellhead seal, the MS-SN, and it integrates with the company’s existing MS-800 wellhead system.
“It’s the same seal we’ve had” with thousands of installations, he said. “This adds more reliability to cover more temperatures and pressures. It’s an extension of what you already run.”
At the same time, the seal is a more standardized product that can cover many of the market’s needs, he said. The upshot of this is that it gives customers more flexibility and requires less lead time, Barton said.
The MS-2 can be installed in a single trip. It has an integrated lock ring that improves rig efficiency by providing immediate lockdown of up to 2 million pounds force without the need for a second trip, the company said. The MS-2 also provides easier access to wells because there is no need for supplemental lockdown devices, according to the company.
Barton said the seal has been tested to 20,000 psi, and to 200 load cycles, which demonstrates sealing integrity and ensures life-of-field reliability.
TUESDAY, 3 MAY
How BP is Optimizing Gulf of Mexico for Net-zero World
BP’s Starlee Sykes provided an inside look during an OTC keynote presentation on how the operator is optimizing all four of its producing hubs in the Gulf of Mexico as part of its net-zero goals.
Jennifer Pallanich, Hart Energy
HOUSTON—To reach net-zero emissions by 2050, BP Plc is measuring the actual emissions, rather than basing plans on calculations, according to Starlee Sykes, senior vice president for Gulf of Mexico (GoM) and Canada at BP.
The first step is to have “accurate methane measurement on all operations so we’re clear on where our emissions come from,” Sykes said May 2. “Once we understand better where it’s coming from, the better we can apply technology to reduce it.”
During a keynote presentation at the Offshore Technology Conference (OTC), Sykes said the operator had carried out comprehensive energy studies at all four of its producing hubs in the GoM. And through those studies, BP determined that most of the emissions came from rotating equipment that powers the facilities, flaring and the logistics fleet.
“How we optimize all those areas is critical to making improvements,” Sykes said.
For example, she said, BP is considering things like biofuels for the logistics fleet. Also under consideration are electrification and carbon capture and sequestration (CCS).
Oil and gas are expected to remain critical components of the energy system for years to come, so BP wants to further lower its carbon footprint while still increasing production rates, Sykes said.
BP is using seismic to identify new volumes. Another way is through development infill projects to tie new wells into existing infrastructure, she said. As part of that effort, the operator has several tiebacks to production hubs in the GoM, including last year’s startup of the Manuel tieback to Na Kika.
BP also is focused on optimizing systems to improve the reliability of assets, she said.
In terms of system optimization, she said, a better understanding of how the fluids flow can yield better results. And digital technologies are helping with that. Automation and more quickly processing data such as seismic imaging are important, she said.
Digital technologies help make better and faster decisions, she said.
“It goes throughout all of our work processes and workflows,” she said.
Preventing a Cyberwar Offshore
It may not have been declared, but the entire oil and gas industry—including offshore—is facing a cyberwar, says Nicholas Andersen, cybersecurity expert and COO at Invictus International Consulting.
Jennifer Pallanich, Hart Energy
HOUSTON—It’s unrealistic to expect to protect all assets from the threat of a cyberattack, but it is possible to minimize risk, according to a cybersecurity expert.
“You’re not going to protect everything all the time,” Nicholas Andersen, COO at Invictus International Consulting, said May 2 during “The Cyber War Among Us” executive dialogue at Offshore Technology Conference (OTC) in Houston.
Instead, he said, companies can prioritize protection for areas that could have the “highest consequences” if a cyberattack succeeded and then build layers of defense around that.
And the entire industry is facing a cyberwar.
“Each of you is on the front lines of this war that was never declared,” Andersen said.
It may not have been declared, but attacks are constantly evolving, and it would behoove the industry to have a community of people with whom they share information, he added.
“With cybersecurity, what affects you today is going to affect me tomorrow,” he said. “New vulnerabilities and attack methods are being discovered every day.”
One method is to breach a system and linger hidden for some time as they work to gain influence, he said.
“It doesn’t matter that you don’t see them today. They don’t want you to see them today. They want to lay in wait until a time of their choosing,” he said.
Andersen said information technology (IT) and operational technology (OT) teams should work much more closely together. The conversation needs to start with prioritizing potential consequences and should have risk owners “who can drive change on the OT and IT sides.”
And groups like Linking the Oil and Gas Industry to Improve Cybersecurity (LOGIIC) can help with things like teasing out root cause analysis, he said.
While the industry has a strong focus on safety, Andersen said cybersecurity should be just as integral.
“Cybersecurity needs to be baked into that safety conversation,” he said.
And there are many potential points of entry into a company’s system.
“One of the greatest vulnerabilities we have is visibility into the supply chain,” including things that are integrated into the systems, he said.
Things to consider when working with original equipment manufacturers include how an item is being built and secured and how it would be maintained over the course of its life cycle, Andersen said.
And maintaining cybersecurity is becoming even more difficult as more connected devices enter the world and the Internet of Things increases in scope.
The market is exploding with the technology in such a way that it’s difficult to understand the whole supply chain and how they’re managing security, he said. That means there is a lot of risk associated with those items, he said.
“We’re still losing sleep over traditional IT systems and the vulnerabilities there, and that’s been around for years,” he said. He does, however, anticipate changes in requirements for IoT devices.
But as a cybersecurity expert, there are certain things he doesn’t do.
“I don’t have a smart anything in my house. Alexa’s not getting through my front door,” Andersen said.
Turning US Offshore Wind Challenges into Opportunities
OTC panelists highlight opportunities and challenges for reaching U.S. offshore wind goals.
Velda Addison, Hart Energy
HOUSTON—Affordability, scalability, vessel needs and grid connections are among the challenges ahead for offshore U.S. wind developers as the nation aims to deploy at least 30 gigawatts (GW) of capacity by 2030, panelists said May 2 at the Offshore Technology Conference (OTC).
However, the industry is capable of turning those challenges into opportunities by building on transferrable skills from the offshore oil and gas industry along with learning lessons from regions—such as Europe—where offshore wind developments are further along to avoid making the same mistakes, they agreed.
The conversation between the group of experts—some of which got their start in oil and gas—took place as the energy transition moves forward with focus on carbon management, lowering emissions and increasing reliance on renewable energy in a shift away from carbon-intense fossil fuels.
“Energy transition is a global priority right now. Offshore wind is not the only answer to that but it’s going to be a critical part of the energy mix of the future,” said Rain Byars, technical director of Atlantic Shores, the 50:50 joint venture between Shell New Energies US LLC and EDF Renewables developing a wind project offshore New Jersey with a potential to produce of 3 GW of wind energy—enough to power about 1.5 million homes.
“It’s going to be really challenging to deliver the quantity of offshore wind farms that we need, but it’s not technically infeasible. … It’s very possible as long as we bring the necessary amount of focus, planning and careful management.”
Keeping offshore wind affordable is another challenge, according to Karolina Pietrzak, deputy chief development officer for SimplyBlue Group. She cautioned that developers should be aware of the cost of energy when making substantial investments in wind projects.
Key to affordability is sustainable industry growth and optimizing project development to help avoid cost overruns, she said.
Deploying 30 GW by 2030 requires 2,100 wind turbines and foundations, 6,800 miles of cable and an annual workforce of at least 12,300, Pietrzak said, adding both state and federal local content will be needed to enable local supply chain growth. Add to this the need for 58 crew transfer vessels, 11 service operation vessels, 10 transport vessels, five to six wind turbine installation vessels, four cable lay vessels and two scour protection vessels.
Between 2023 and 2030, about 15 subsea rock installation vessels will be needed, according to Eleni Beyko, senior vice president for offshore wind for Great Lakes Dredge & Dock Co.
The company, which has been dredging in the U.S. since 1890, is working to meet vessel demand by constructing the First Jones Act-compliant subsea rock installation vessel in the U.S., Beyko said. Expected delivery is 2024.
The vessel, which marks the company’s entry into the U.S. offshore wind market, will be equipped with battery power, shore-power connection system and be capable of burning biofuel, the company has said.
“The market is real and it is real in the U.S. as well,” she said. “It is a great opportunity to use and transfer talent from oil and gas development supply chains that will be required,” including for developing infrastructure and vessels needed to deliver offshore wind in the U.S.
For Antoine Peiffer, vice president of engineering for floating offshore wind tech provider Principle Power, deploying large utility-scale projects—about 50-100 units of 15-20 megawatt (MW) capacity—will be a major challenge that brings design, logistical and procurement constraints. More steel and mooring lines will be needed, and turbines will have to be larger. That’s something Peiffer said the company’s WindFloat technology can handle.
WindFloat is a permanently moored semisubmersible, three column platform for offshore wind turbines. It’s operational at two wind farms, including the 50-MW Kincardine offshore Aberdeen. Peiffer said the technology can accommodate larger offshore wind turbines, highlighting its nonlinear scaling relationship between hull weight and turbine capacity among other features.
In addition to getting needed infrastructure to deploy projects, he added a capacity on the grid for large-scale projects is another challenge, singling out opportunities offshore California.
Off the East Coast, however, offshore wind developments are progressing.
Vineyard Wind is the first commercial-scale wind project offshore the U.S. Located offshore Massachusetts, Vineyard Wind 1 will include an array of 62 wind turbines spaced about 1 nautical mile apart, generating 800 MW of electricity annually—enough to power over 400,000 homes, the company has said. It includes about 124 miles of 66 kV array cables.
Duncan Sokolowski, interarray cable package manager for Vineyard Wind, suggested U.S. offshore wind players learn lessons from European offshore wind companies.
Some companies went bankrupt and there were cost overruns, he said. “There are a lot of key lessons to be learned. … If ignored, you’re reinventing the wheel and there’s no need to do that.”
Full-Field Development—Revitalizing Oil and Gas Fields
How Schlumberger creates value for its customers’ offshore projects.
Contributed by Schlumberger
For offshore oil and gas producers, capital stewardship is translating to an operating environment defined by lower total expenditures. There is a keen focus on reducing capex and opex, while also accelerating time to first oil and gas, and enhancing production or total recovery. Underlying all of this is the imperative of reducing the environmental impact of each barrel produced.
To deliver more predictable, lower-cost and lower-carbon energy, while unlocking asset value faster, the industry must rethink how to develop its fields.Living the production journey
Today, Schlumberger takes a full-field development approach when working with its customers. In this model, close and early engagement and collaboration is inherently built into the production journey—enabling key drivers to be identified at the onset of a project and strategic, performance-based decisions to be made throughout the asset’s lifetime.
Schlumberger is engaging with operators through open digitally connected collaboration, with their asset always at the center of everything, aligning to their needs for performance. Value is created by living the production journey responsively, sustainably, predictably and dynamically for the life of the asset.Changing linear workflows
To remain competitive in today’s dynamic operating environment, the industry can no longer have a segmented, linear workflow. Through open, digitally connected collaboration, operators share their end goal, and service providers help them make the right decisions early and throughout the full life of the asset. Through this workflow, operators can:
* Select the optimum production systems for the lowest total cost and emissions. Schlumberger leverages its Subsea Planner* collaborative field development solution to work directly with its customers on their field development plans. This software, included in Schlumberger’s field development service, combines full-field economic calculations with reservoir engineering, production assurance, and subsea technologies and systems spanning the entire planning process. In essence, the service actively manages risks associated with system selection, design, delivery and production and helps create leaner, cleaner solutions.
* Configure, to optimize capex and reduce opex during the production phase. Through this, Schlumberger creates solutions that are fit for purpose from the widest selection of innovative and standard technology.
* Deliver solutions that accelerate project execution to achieve first oil faster. This cuts delivery times through a total life cycle approach to technology innovation and increases project certainty.
* Produce maximum production and recovery at the lowest cost and lowest carbon per barrel. This enhances reservoir access and control to increase production and recovery, reduce waste, reduce emissions, and improve safety—for the life of the asset. Schlumberger leverages its Process Live* data-enriched performance service and Subsea Live* data-driven performance service. Process Live service integrates digitally enabled equipment, collaboration with OEM experts, and maintenance to enhance asset life cycle management, while Subsea Live enables collaboratively enhancing subsea operations by providing prescriptive health, operational and production insights.
This working philosophy is facilitating greater trust and the adoption of novel concepts that are delivering step-changes in performance and reductions in overall environmental impact. With electric energy systems, the industry can de-risk the interfaces across the lower to upper completion, through the subsea production and processing systems all the way to topside.The role of electrification
All-electric production systems assist operators in reducing total expenditure while simultaneously accelerating digital transformation efforts and reducing the carbon intensity per barrel produced. As a lighter, more agile solution, all-electric production systems are a lower-carbon intensity alternative to the hydraulically powered production systems supporting a large portion of offshore production today.
All-electric production systems include many benefits—from enabling longer step-outs and enhancing completions to optimizing field architecture through simplification of the infrastructure and significantly reducing space constraints at the topside due to a more compact actuator size when compared to hydraulic actuators.Revitalizing fields
By living the production journey responsively, sustainably, predictably, and dynamically for the life of the asset, significant value from offshore operations can be realized today and into the future.
*Mark of Schlumberger
For more information, visit Booth 1916
MONDAY, 2 MAY
OTC 2022: ‘Career Achievers’, Deepwater Megaproject Receive Conference’s Highest Honors
OTC recognized Drew Michel, Shell’s Appomattox Project and Roland Moreau with the 2022 Distinguished Achievements Awards
Jennifer Pallanich, Hart Energy
Two “career achievers” and one exemplary project were recognized with the Offshore Technology Conference’s highest honors.
The 2022 Distinguished Achievement Awards honored Drew Michel for individual achievement, Roland Moreau for the Heritage Award and Shell’s Appomattox Project for institutional achievement on May 1 at the NRG Center in Houston.
Michel pioneered offshore technologies like diving and ROVs. Early in his career, he worked for Taylor Diving and Salvage, a Halliburton Company. He was also the owner of ROV Technologies Inc. for nearly three decades.
OTC chairperson Paul Jones called him a true pioneer.
“He was instrumental in migrating diving from the basic shallow water into deeper waters in the Gulf of Mexico. He always was a very keen safety-focused individual,” Jones said.
In fact, Jones said, some of Michel’s earliest efforts set the industry’s pattern for safe diving, even as the industry approached the limits of personal diving.
Michel “developed the ROV technology to where it is today,” Jones said. Those ROVs are “our eyes and ears at some of the amazing water depths where we produce oil and gas from.”
Roland Moreau was honored with the OTC Heritage Award for his efforts to improve industry safety through the sharing and analyzing of data and learnings.
Moreau “has spent his entire career focused on industry safety activities,” Jones said.
During his nearly four-decade career, he contributed to enhancing communications and bridging the knowledge gap between the offshore oil industry and government bodies.
“He enabled the industry, government and regulators to work collaboratively and together,” Jones said.
Now retired, Moreau worked at Exxon Mobil, Macrosys, United Nuclear and Ragen Precision Industries and served as a president of the American Institute of Mining Engineers (AIME) as well as vice president of finance and technical director of HSE for the Society of Petroleum Engineers.
“These guys are career achievers,” Jones said, adding they both made the industry “a better place to work in.”
Shell received the OTC Distinguished Achievement Award in recognition of its Appomattox Project in the Gulf of Mexico. Located in 7,400 ft water depth, Appomattox is the operator’s largest and most complex deepwater megaproject to date. The field went onstream in May 2019 four months ahead of schedule and 40% less than initial cost estimates, Jones said.
“That wasn’t Shell on their own. There were lots of companies involved,” he said. “It was an exemplary project.”
OTC 2022 Q&A: Excitement Abounds as Offshore Rebounds
Paul Jones, chairperson of OTC 2022, gives a preview of what to expect May 2-5 in the technical sessions and exhibit hall at this year’s conference.
Len Vermillion, Hart Energy
Paul Jones, chairperson of the Offshore Technology Conferences (OTC) 2022, says offshore activity is key to meeting the world’s energy demands in the near and long term. That requires a focus on what’s important to the future, including new technologies for sustainable operations, an understanding of emerging opportunities such as carbon capture storage (CCS) and hydrogen, and more.
Jones, principal at Lockbridge Energy, took a moment during a busy ramp-up week to the big event in Houston to talk to Hart Energy about the future of offshore and this year’s conference.
Hart Energy: What are you expecting from OTC this year now that it's back in-person without the specter of COVID-19 hanging over it?
Paul Jones: I have high expectations this year for OTC. It is going to be a fantastic event. Everyone I have spoken to in the planning of this event—exhibitors, sponsors and attendees—are delighted to be back in person.
There is a palpable excitement. For more than 50 years, OTC has been the central hub for industry professionals to get together, showcase new technologies, share ideas and innovations, and discuss the pressing topics of the day.
“Virtual” is ok, but “in-person” is much more impactful and rewarding.
Hart Energy: What are you most excited about concerning this year's conference, and what do think will be most interesting?
Paul Jones: I believe this year’s conference and exhibition has something for everyone. We have a diverse technical conference with global expert participation and world-class exhibition space showcasing new technologies and extraordinary offshore expertise.
Highlights for me include:
- The Around the World Series—presentations, panel discussions and special sessions focused on international opportunities, challenges and new technologies impacting France, Guyana, Norway, West Africa, Brazil and Argentina.
- We have the Keynote Speaker Series where industry executives and leaders will cover a wide range of diverse topics including cyber security, diversity, CCUS and hydrogen.
- We have four full days of technical papers on the entire spectrum of offshore energy topics covering traditional oil and gas, renewables and the energy transition.
- Our exhibitors have every facet of offshore technology on display and our 14 “Spotlight on New Technology Awards” winners will be announced and celebrated on the exhibition floor.
- We also have our Emerging Leaders Program where we recognize early career professionals who are passionate about their field of work and dedication to industry service. They will be announced and celebrated on Tuesday afternoon and will be followed by a YP networking event.
Finally, we have a saying that you can get “a year’s worth of training in a week” at OTC. This year is no exception!
Hart Energy: There is an energy transition pavilion this year. How prevalent is energy transition in the offshore sector and how does the show represent that?
Paul Jones: As we race to meet global climate goals, countries around the world are embracing new and sustainable technologies to develop and deliver energy resources and transition to a lower-carbon economy. As home to traditional and renewable resources, the offshore industry has a significant role to play.
At this year’s OTC, we will have more than 20 technical sessions and panel discussions under the energy transition umbrella. Our new Energy Transition Pavilion will feature companies, organizations and institutions making significant strides by advancing low-carbon technologies, driving sustainability and improving energy efficiency. The pavilion will also serve as a meeting space for attendees and exhibitors alike to take part in the energy transition dialogue.
Hart Energy: We hear a lot about the return of offshore activity. What do you see as far the near- and long-term futures of offshore activity?
Paul Jones: I see offshore activity being key to meet the world’s energy demands in the near and long term.
A significant portion of the world’s remaining oil and gas reserves are located offshore with several notable discoveries over the past years. Deepwater continues to attract significant interest from international oil and gas companies, which regard it as an important part of future global energy mix.
Of course, countries around the world are opening up frontiers to offshore wind and embracing the potential for floating solar, offshore hydrogen production, as well as tidal and wave energy production. Additionally, offshore carbon capture and storage
[CCS] is emerging as a key component of the energy transition with several well-known regions, including the U.S. Gulf of Mexico, being prime prospects for CO₂ storage.
Hart Energy: How much can we expect to see in terms of renewables, such as offshore wind and floating solar, at this year's conference?
Paul Jones: There is a significant renewables theme running through all four days of OTC 2022. Each day has an Offshore Wind Technical Session, covering all the key aspects of this energy sector. There are also sessions on the challenges and value of offshore hydrogen production, and as I mentioned earlier, our Energy Transition Pavilion will be on the exhibition floor showcasing how renewables can and will contribute to a future low carbon economy.
OTC 2022: Insight into Oil and Gas’ Decarbonization Challenges, Achievements
The 2022 OTC’s new Energy Transition Pavilion will explore the complicated roles decarbonization and renewable energy sources play in the energy industry.
Madison Ratcliff, Hart Energy
For the first time since before the pandemic, the Offshore Technology Conference (OTC) is back fully in-person. At this year’s conference, held from May 2-5 at NRG Park in Houston, attendees can participate in a new event: the Energy Transition Pavilion focusing on the low-carbon industry outlook.
The pavilion will consolidate the technical sessions and floor exhibitions, allowing conference-goers to gain expertise from industry specialists and serving as the center for discussion surrounding all aspects of the energy transition.
“This is a great opportunity for us to put a focal point to that discussion, to get all the experts in one location and have some meaningful dialogue to debate, discuss opportunities and challenges to some of the problems that we see in the energy transition space,” Paul Jones, chairperson of the OTC board of directors, told Hart Energy.
“We've given [attendees] a place on the exhibit floor where we're going to have experts there; some of the exhibitors themselves will be providing key experts there at specific times during the week,” he continued. “So it's an engagement opportunity for everybody to learn more, challenge, debate and generally move our capabilities forward in this area.”
Headlining the pavilion is the moderated panel discussion “Decarbonizing Oil and Gas Operations: A Key Component of the Energy Transition” on Tuesday, May 3 from 9:45-11 a.m., which will explore how the continued need for hydrocarbons intertwines with the need for decarbonization in the energy transition.
“I think what you're going to see are industry experts talking about this whole area of decarbonization,” Jones said. “It's multifaceted and is important to all sectors of the oil and gas industry, as we move to lower carbon production and a more sustainable future. What I think the panel is going to do is give a broad overview and some specific insights into the challenges and successes that have been had so far.”
Deloitte vice chairman and U.S. oil, gas and chemicals lead Amy Chronis, who will speak on the decarbonization panel, recently emphasized the growth of the net-zero focus as the energy transition has become increasing important in a recent video roundtable with Hart Energy.
“The net-zero focus is real, and it’s going to continue to grow stronger,” she said in the roundtable. “The global energy system is set to undergo transformational change, with a reduced role for fossil fuels, a higher share for renewables in the energy mix, greater consumer choice and increasing levels of integration and competition for cleaner technologies.”
Chronis will be joined by Guillermo Sierra, vice president of strategic initiatives, energy transition, Nabors Industries; Paul Sims, vice president of marketing, Schlumberger; and Nicolas Tcherniguin, head of offshore technologies, Technip Energies, with Jane Stricker, vice president of energy transition and executive director of HETI, Greater Houston Partnership, moderating the panel.
Panelists will discuss the difficulties the industry is facing with the energy transition, including navigating financial challenges and finding a balance between traditional forms of energy and renewables, as well as the often unsung successes the industry has achieved.
“We’re finding that the energy transition is a journey with many pathways and, as with any new product or solution, still has a long way to go toward becoming scalable, economical and reliable,” Chronis said. “Investors and businesses need to create a managed and orderly transition that strives the balanced economics and the environment, and strike a balance between hydrocarbons and renewable energy.
OTC 2022: Decarbonizing Oil and Gas Operations
Meeting the world’s energy needs while reducing the industry’s impact on climate change.
Contributed by Schlumberger Ltd.
Today, the oil and gas industry finds itself at the beginning stages of an exceptional growth cycle. It’s at this pivotal moment that the industry stands to improve the lives of billions of people by providing them with access to a reliable energy source. But this cannot be done in a vacuum—the industry must consider the impact of its operations on climate change and take action to decarbonize them. In doing so, the industry can reconcile its role as a provider of a vital energy resource to the current and future energy mix with emissions reduction goals to reduce its impact on climate change.
Committed to net-zero emissions
In 2021, Schlumberger announced its Decarbonization Plan, laying out its commitment to achieve net-zero greenhouse gas (GHG) emissions by 2050.
Reducing its customers’ operational emissions is a key focus area for its plan. Today, Schlumberger is helping its customers do just that by leveraging its Transition Technologies* portfolio, which includes products and services with a quantifiable emissions reduction impact; consultative business solutions; and digital technologies.
Addressing methane emissions
Methane is an extremely potent GHG. Over a 20-year period, one ton of emitted methane causes as much global warming as 84 tons of emitted carbon dioxide. Historical methane emissions are responsible for 0.5 C of the 1.1 C that our planet has already warmed, and the oil and gas industry is one of the largest sources of methane emissions today.
To help the industry with its methane emission reduction goals, Schlumberger recently launched its Schlumberger End-to-end Emissions Solutions (SEES) business. Based on three pillars—plan, measure, and act—this consultative service is intended to accelerate an operator’s emissions reduction journey.
One of the biggest challenges is finding methane leaks. Today, there are many detection technologies, so selecting the correct one can be a challenge. SEES experts provide a deep understanding of emerging technologies, oil and gas facilities, and local operating conditions and can design optimal measurement programs, often including combinations of different technologies from Schlumberger or its extensive partner network.
Fixing methane leaks
When it comes to fixing methane leaks there are a wide range of solutions. One key challenge is leaky valves. To resolve this, Schlumberger offers a large selection of Low-Emissions (Low-E) valves. These Transition Technologies cover a wide range of conventional and new valve applications and are certified to industry fugitive emissions design standards API 624 and 621 and ISO 15848-1.
Another challenge is inherent methane leaks from pneumatic equipment on production technologies, including separators. Transition Technologies like Schlumberger’s Vx Spectra* surface multiphase flowmeter can eliminate the need for a separator, thus eliminating methane emissions from their pneumatic components.
Reducing or eliminating flare emissions
Flaring is one of the most visible emissions sources in our industry, and their elimination is a key focus area for Schlumberger’s decarbonization services. If they cannot be eliminated, impact minimization is the focus. Flares are supposed to combust methane into carbon dioxide, and any inefficiency in combustion results in methane emissions to the atmosphere, greatly increasing the GHG footprint due to methane’s potency. Flare monitoring, including laser technologies that measure uncombusted methane and successfully combusted carbon dioxide, can ensure flares operate at peak efficiency.
Digital solutions—including open cloud-based platforms and applications, digitally connected technologies, edge computing and intelligent systems—present some of the industry’s best opportunities to reduce emissions. Schlumberger is focused on digitally enabled technologies for everything from carbon capture, utilization and sequestration to advisory platforms that use AI to identify opportunities to reduce or eliminate emissions.
Ultimately, a combination of technological innovation, digital enablers and expertise across multiple domains—both inside and outside of the industry—will be required to tackle the decarbonization challenge. And Schlumberger is leading the way.
For more information, visit Booth 1916
*Mark of Schlumberger