Paul Gerber

Say goodbye to manual data collection and hello to real-time insights. Iso-Smart™ provides corrosion professionals with remote, accurate, and actionable asset data at their fingertips. Watch our video to see how Iso-Smart™ transforms pipeline monitoring! Learn more & book a demonstration:

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Funding Announcement: The U.S. Department of Energy and the EPA announced $850 million in federal funding to reduce methane emissions from the oil and gas sectors. Methane Reduction: Methane is a potent greenhouse gas, and this funding aims to cut emissions significantly, supporting clean air and climate goals. Job Creation: The initiative will create good jobs, especially in disadvantaged communities, and support small oil and gas operators in adopting new technologies. Community Benefits: Applicants must show how their projects will benefit local communities, focusing on diversity, equity, and environmental justice

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Tuesday Cannonball FerVID as an organization is organized in three divisions. A Venn Diagram if you will. This organization creates great synergies in the overlaps. The three are: Executive Recruiting and HR Consulting (ERHR) Data Management (DM) Geoscience and Engineering (G&E) Examples: G&E works with ERHR to high grade candidates. ERHR works with G&E to find optimally credentialed consultants. G&E works with DM to provide an operator view to deliver great results. DM works with G&E to find the right stakeholders for new business opportunities. This list is just a few examples. The intersection of the three circles form a shape called a Reuleaux triangle. Within that shape, that I call the nirvana zone, we find that the very experienced entrepreneurial leadership in each division builds better business and delivery to customers in total via our deep trust-based relationships. FerVID - Lean and Mean. No Brick and Mortar - Just Brains and Hard-Won Expertise. FerVID Geoscience and Engineering – Our staff earned their PHDs at the cutting edge with decades of experience at Operators. You can rely on us to provide both the size of the prize and importantly the risks of the prize from those who have learned via projects with CAPEX/NPV measured in the BILLIONS At FerVID, subsurface characterization is in our DNA along with delivery. Contact us for a great outcome! https://lnkd.in/gWqFjNwQ

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Have you ever struggled with forecasting young PDP wells? Geology, completions design, and well spacing are critical predictors for well performance, and by incorporating them into early-time forecasting, you can dramatically improve accuracy. Here, I'm showing results from our PDP forecasting models on younger wells from the Permian, Williston, and Appalachia. These models use machine learning to directly forecast declines, incorporating not just prior production but also geology, completions, spacing, parent-child, etc. This data is especially useful for younger wells, where the production data may be too noisy or non-hyperbolic to get a good fit using a traditional Arps curve. This is especially the case with public data sources! Across these three basins, our machine learning PDP forecasts improve accuracy by 32%, 46%, and 29% on the primary production stream, compared with a traditional DCA methodology. Why does this matter? Newer wells (<1.5 years old) make up about half of production in the L48, though it's even higher for some basins and assets. Poor forecasts on young wells leads to incorrect valuations, inaccurate supply models, and bad type curves. Our operator customers have been using these models for over three years now to improve their forecast accuracy, but we have recently released these forecasts as a live, auto-updating data product for our subscribers. At URTeC in two weeks, we are diving deeper into this technology as applied in the Permian Basin. Thanks to lead author Kiran Sathaye for his insightful work in this study. For more information, head to our URTeC page (link in the image). #oilgas #permian #urtec

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#LNG News: DOE pressed to advance major LNG project after pause reversal Developers of the Lake Charles LNG project — one of the largest proposals for the Gulf Coast — said a court ordered DOE “to act without delay.” The developer of a major liquefied natural gas terminal in Louisiana is pushing the Department of Energy to act speedily on its export application following a federal judge’s reversal of the Biden administration’s pause on pending and new LNG export licenses. In a letter last week to DOE, a lawyer for the Lake Charles LNG project said the department’s Office of Fossil Energy and Carbon Management should “expeditiously act on its pending application in this docket and issue an order without delay.” The company’s dispatch is one of the first examples of pressure on the department to act on an export application since the end of the pause, which froze consideration of permits to countries that don’t have a free trade agreement with the United States. Read More: https://lnkd.in/ecyeJRtu

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#LNG News - Lake Charles LNG Update 👇👇👇 Follow Allstream Insiders - “Insider” News for Industry - our dedicated Industry News Channel #FromIndustryForIndustry

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🚀 We’re back with another video! 🎥 Dive into the world of gas compression monitoring with Palantir Foundry and see how we're transforming data into insights. Don't miss out – watch now and discover the future of smart monitoring! 🔍💡 https://lnkd.in/ghVp_c2X

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#natgas #futures #basics #eia The #naturalgas #futuresmarket is a marketplace where standardized contracts for the future delivery of set natural gas volumes are traded. Most natural gas futures are bought and sold in the New York Mercantile Exchange (NYMEX) and the Intercontinental Exchange (ICE). #Futurescontracts allow participants to manage their exposure to market volatility by locking in a price today for a future purchase or a future sale of a physical commodity. Natural gas futures contracts settle both physically and financially. Although other commodity futures might only have a financial obligation, this marketplace also bears the responsibility of physical delivery. A buyer must agree to receive natural gas at a future date at a specified location for a predetermined price, while a seller agrees to deliver the natural gas under these terms. However, less than 2% of NYMEX contracts are physically delivered. ❔ Why do people trade natural gas futures contracts? Natural gas producers face uncertainty over their future revenue from sales, so they may sell a futures contract now to lock in a natural gas sales price for a future date. ❓ What are some common futures market pricing dynamics? Futures traded for the month immediately following the current month are referred to as front-month contracts, or Contract 1 futures. At the time of publication, August 2024 is the front-month contract. Natural gas futures contracts expire about 3–5 business days before the start of the front month. The futures market forward curve displays the closing prices of linked individual monthly contracts across various months into the future. If futures prices increase over time compared with the current price, the market is referred to as being in a state of contango. Conversely, the market is said to be in a state of backwardation when future prices are lower than the current price. ❓ What influences directionality of the natural gas futures curve? he major supply-side factors affecting natural gas prices are domestic production and imports. The major demand-side factors affecting natural gas prices are: ✍ Variations in temperatures ✍ Macroeconomic activity ✍ Natural gas exports ✍ Availability and prices of other fuels Storage volumes help balance the market. Stored natural gas can be used when demand outpaces supply and built when supply outpaces demand. For that reason, storage behaves as a source of both supply and demand within the natural gas futures market. ❔ How is the natural gas futures curve today? The natural gas futures market is presently in contango. The market currently indicates higher natural gas prices for next winter (Dec 2024–Mar 2025), increasing even further (+82%) through winter 2025–26. Overall, this contango reflects a market expectation for demand to surpass supply over that period. Source: U.S. Energy Information Administration Andrew Iraola 👇 👇 👇 https://lnkd.in/d9yVPEW5 #oilgas #energy

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@Allgheny Petroleum products have a point that there are pros and cons and it depends upon the situation and the requirement of the Individual lubricant brand. @ILMA I am of the opinion Toll blending is better when you are exporting to a far away Country and you need flexibility in quantity and packaging. for eg exporting in bulk form isn't so practical,when you are shipping from one country to another. Exports from Middle East ,Europe and other countries. The typical example is brands being exported from Middle East to Canada,where shipment time is around 45 days plus friegt factor.The Customers need product instantly. secondly most important is that the brand exporter to have their own Consultsnt to check the Quality ,efficiency and services of the Toll blenders. Few thoughts just came into my mind,there are many more,for which I am open for discussions,as I am based in Canada, as a Consultant,open giving guidance to the lubricants exporters to Canada #Lubrication #qualityconyrol #ROI #tollblending #exports #ILMA #Canada

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Latest Insights from the EIA Weekly Petroleum Status Report This week's report showcases the vitality of the U.S. petroleum industry with some standout figures: Refinery Operations 🛢️ U.S. refineries are maintaining high efficiency, operating at 95.4% capacity. This reflects our industry's commitment to productivity and operational excellence. Production Uptick 📈 With crude oil inputs reaching 17.1 million barrels per day, we see a clear indication of sustained demand and robust supply chain activities. What does this mean for you? The consistent high performance of refineries ensures reliable product availability, which is essential for maintaining smooth operational schedules. This stability is crucial for effective logistics management and strategic planning, directly supporting your well completion projects. Stay ahead with Victory Well Servicing, where we translate industry trends into actionable insights for your business.

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I don't know if anyone else has realized this or maybe I was the only who found the EIA-Drilling Productivity report a well laid out and useful data reference, but as of June, it's been discontinued. It's merged as a table with no graphical representations, the monthly Short Term Energy Outlook. In its present format it's virtually useless. Have a look. Am I being too critical? https://lnkd.in/gZZEjVVC

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🆕 Emission factors, calculation methodologies, emission sources, and reporting requirement - complying with the new Subpart W requirements isn't going to be easy or free. The US Environmental Protection Agency (EPA) estimates that the cost to adopt processes and reporting to the new requirement will cost: 💸 $82,701/E&P reporter 💸 $15,245/gathering and boosting reporter 💸 $24,670/natural gas processing reporter, and 💸 $10,370/ natural gas compression and pipeline reporter Find out how Iconic Air is providing a cost-effective, sustainable #carbon accounting platform to #oilandgas operators

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Go give this article a read!

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Great article by Makayla Christensen!

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A great solution for Resource Planning for Oil & Gas companies.

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If your oil analysis program isn’t reducing downtime, it's time to evaluate its maturity. Here's how: https://lnkd.in/gteDeJ2z Bryan Debshaw explains how a mature oil analysis program leads to early failure detection and cost savings. Is your program delivering?

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We know SLB’s R&D spend intensity is dropping. We’re not seeing the same story from Halliburton though. The top chart below shows two data sets. The first is Halliburton’s annual R&D spend in millions of US dollars. Those are the gray bars that map to the left axis. The second is Halliburton’s annual R&D spend intensity, i.e. R&D spend divided by revenue. That’s the red line that maps to the right axis. We see that in 2023, Halliburton spent more on R&D than it had since 2015. Also, we see that Halliburton’s R&D spend intensity is pretty much in line with its historical average since 2008. That’s a different story than we get from SLB. The bottom chart shows us how R&D spend intensity has changed for both SLB and Halliburton since 2008. We see that SLB’s intensity has declined over time, with the notable exception of 2015 and 2016, when revenues were falling but R&D expenses weren’t getting pulled out as aggressively. Each of the past 16 years, SLB has had a higher R&D spend intensity than Halliburton. But that may soon change. And this one is important, given the huge focus on innovation across the oilfield service sector. Unfortunately Halliburton only reports its R&D spend in its annual report, so we can’t get quarterly updates here. But just a few months from now, we’ll have the 2024 figures, and it’s going to be pretty interesting to see if Halliburton moves past SLB on this particular innovation-focused metric. ≡≡≡≡≡≡≡≡≡≡≡≡ 𝘐𝘧 𝘺𝘰𝘶’𝘳𝘦 𝘸𝘰𝘳𝘬𝘪𝘯𝘨 𝘰𝘯 2025 𝘱𝘭𝘢𝘯𝘴 𝘢𝘯𝘥 𝘸𝘢𝘯𝘵 𝘢𝘯 𝘰𝘶𝘵𝘴𝘪𝘥𝘦 𝘱𝘦𝘳𝘴𝘱𝘦𝘤𝘵𝘪𝘷𝘦 𝘣𝘶𝘪𝘭𝘵 𝘢𝘳𝘰𝘶𝘯𝘥 𝘱𝘶𝘣𝘭𝘪𝘤𝘭𝘺 𝘢𝘷𝘢𝘪𝘭𝘢𝘣𝘭𝘦 𝘧𝘪𝘯𝘢𝘯𝘤𝘪𝘢𝘭 𝘢𝘯𝘥 𝘰𝘱𝘦𝘳𝘢𝘵𝘪𝘰𝘯𝘢𝘭 𝘥𝘢𝘵𝘢, 𝘳𝘦𝘢𝘤𝘩 𝘰𝘶𝘵. 𝘔𝘢𝘳𝘬𝘦𝘵 𝘳𝘦𝘴𝘦𝘢𝘳𝘤𝘩 𝘪𝘴 𝘢𝘵 𝘵𝘩𝘦 𝘩𝘦𝘢𝘳𝘵 𝘰𝘧 𝘸𝘩𝘢𝘵 𝘐 𝘥𝘰 𝘢𝘵 𝘒𝘚𝘎. 𝘐’𝘥 𝘭𝘰𝘷𝘦 𝘵𝘰 𝘤𝘩𝘢𝘵 𝘸𝘪𝘵𝘩 𝘺𝘰𝘶 𝘢𝘣𝘰𝘶𝘵 𝘰𝘱𝘱𝘰𝘳𝘵𝘶𝘯𝘪𝘵𝘪𝘦𝘴 𝘧𝘰𝘳 𝘱𝘰𝘵𝘦𝘯𝘵𝘪𝘢𝘭 𝘤𝘰𝘭𝘭𝘢𝘣𝘰𝘳𝘢𝘵𝘪𝘰𝘯. #energy #oilandgas #oilfieldservices #ksg

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An interesting look at the electrification of fracturing.

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