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Natural Gas well overview Natural gas is a fossil fuel energy source. Natural gas contains many different compounds. The largest component of natural gas is methane, a compound with one carbon atom and four hydrogen atoms (CH4). Natural gas also contains smaller amounts of natural gas liquids (NGLs, which are also hydrocarbon gas liquids), and nonhydrocarbon gases, such as carbon dioxide and water vapor. We use natural gas as a fuel and to make materials and chemicals. Here's a concise breakdown of the natural gas drilling process: Site Preparation: Selection of the drilling site based on geological surveys and exploration. Clearing the area and setting up the drilling rig and related equipment. Drilling Rig Setup: Rig assembly involves setting up the drill, casing, and other necessary components. Drilling begins with a rotary drill bit attached to a drill pipe, gradually penetrating the Earth's surface. Drilling Process: Drilling mud (a mixture of water, clay, and additives) is circulated down the drill pipe to cool the drill bit, carry rock cuttings to the surface, and stabilize the wellbore. As the drill progresses, steel casing is inserted and cemented into place to prevent collapses and protect surrounding layers. Well Depth and Target Formation: The drilling continues until the desired depth is reached, often thousands of feet below the surface. The target formation, where natural gas is expected, is accessed through vertical, directional, or horizontal drilling. Completion and Extraction: Once the target depth is reached, perforations are made in the casing to allow gas to flow into the well. Hydraulic fracturing (fracking) might occur, involving the injection of high-pressure fluid to create fractures in the rock and release gas. Gas flows up the wellbore due to pressure differentials between the underground reservoir and the surface. Surface Equipment Installation: Wellhead and collection infrastructure are installed to gather the gas. Separators and filters remove impurities like water and solids from the gas stream. Testing and Production: Initial tests assess the flow rate and quality of the extracted gas. Once confirmed is viable, the well enters production, continuously extracting natural gas. Monitoring and Safety Measures: Regular monitoring of pressure, equipment, and environmental impact ensures safe and efficient operations. Safety protocols and regulations are strictly followed to prevent accidents and protect workers and the environment. Continued Maintenance and Decommissioning: Ongoing maintenance and periodic inspections are conducted to ensure the well's integrity and efficiency. Upon depletion or when the well becomes uneconomical, it's properly plugged and abandoned, with the site restored to its natural state. Understanding these steps provides insight into the intricate and controlled process involved in drilling natural gas wells.

🛢️ Artificial Lift Technology ✍️ Today, we're diving deep into the fascinating world of artificial lift technology and how it revolutionizes petroleum engineering. 🌍🔬 🔌 What is Artificial Lift? In the realm of oil and gas production, artificial lift refers to the method used to increase the flow of hydrocarbons from a well when natural reservoir energy is depleted. Essentially, it's like giving a helping hand to Mother Nature, ensuring that oil and gas keep flowing to meet the ever-growing energy demands. 💡💪🏼 ✨ Importance of Artificial Lift in Petroleum Engineering ✨ Artificial lift plays a pivotal role in petroleum engineering by: 1️⃣ Boosting Efficiency: As reservoirs age, natural pressure declines. Artificial lift technologies can compensate for this reduction by maintaining a steady flow rate, maximizing production and ensuring optimal resource recovery. 2️⃣ Ensuring Continuous Production: From submersible pumps to gas lift systems, artificial lift techniques keep the hydrocarbons flowing, ensuring a steady stream of oil and gas to meet market demands. 3️⃣ Extending Well Life: Artificial lift technologies can help extend the lifespan of wells, allowing us to extract more hydrocarbons from reserves that would otherwise be abandoned. 4️⃣ Enhancing Safety: By reducing the pressure differential within a well, artificial lift systems help in preventing formation damage, minimizing operational risks, and ensuring safer operations for petroleum engineers. 💡 Types of Artificial Lift Techniques 💡 1️⃣ Electric Submersible Pumps (ESPs): These efficient pumps are submerged in the well, providing the power to lift fluids to the surface. ESPs are widely used and effective for reservoirs with high fluid viscosity or at deep depths. 2️⃣ Gas Lift Systems: This technique employs compressed gas injected into the well to lower the density of the fluid, enabling it to rise to the surface. Gas lift systems are versatile, cost-effective, and suitable for a range of reservoir conditions. 3️⃣ Rod Lift Systems: Consisting of a sucker rod string assembled with a surface-mounted pumping unit, rod lift systems use a reciprocating motion to lift fluids to the surface. This method is commonly used for shallow wells with low bottom-hole pressures. 🌟 Future Trends in Artificial Lift 🌟 As technology continues to advance, petroleum engineers are exploring innovative methods for artificial lift. This includes: 🔮 Intelligent Automation: Leveraging artificial intelligence and data analytics to optimize artificial lift operations, improve equipment performance, and reduce downtime. 🔮 Electrification: Harnessing renewable energy sources, like solar power and batteries, to drive artificial lift systems, reducing carbon footprints. 🔮 Advanced Sensors: Implementing advanced sensor technology to monitor and optimize lift systems in real-time, providing valuable insights #PetroleumEngineering #ArtificialLift #Innovation #EnergyProductio

The location of the oilfield drilling project has poor grid resources, long construction cycles for grid power, seasonal power restrictions, and a shortage of high-power gas power generation equipment. Additionally, the drilling grid has low capacity, low end-voltage, and cannot support continuous use for electric fracturing. These factors have limited the large-scale development of electric-driven fracturing. Traditional diesel generator sets can provide power output, but they have high fuel consumption, cause significant environmental pollution, and produce a lot of noise. In response to the customer's demand for fuel-saving during the day and silent power supply for living areas at night, our company has customized 8 smart power stations for the project. Each includes a 360kW diesel generator and a 250kW energy storage system. Based on the microgrid power supply system of the diesel generator, the energy storage system is configured to quickly release and absorb active power, with a response time of less than 100ms. Before the diesel generator responds to impact loads, the energy storage system rapidly detects the frequency drop, automatically adjusts the power output, and injects energy into the system to maintain frequency stability. When the diesel generator overshoots, the energy storage system quickly absorbs energy to suppress frequency fluctuations, stabilizing the power supply system. The intelligent control system provides smooth power output for the project, effectively ensuring the normal and safe operation of electric-driven fracturing equipment and the power supply for the production and living needs of the platform.

Offshore oil production is a state-of-the-art engineering technology. It is important to highlight that continued investment in oil and gas is required all energy scenarios, including those with an accelerated decarbonization process.

* Europe’s first full-scale onshore CO2 storage project: https://lnkd.in/d_CJf5Pn A unique project is being realised in Denmark, where CO2 is planned to be stored down flank of a gas storage site. Read here about how this is being achieved. Mikael Lüthje, Martin Patrong Haspang; Gas Storage Denmark and Carsten Møller Nielsen; GEUSOctober 6, 2023. Gas Storage Denmark (GSD) is currently in the detailed engineering phase of Europe’s first large-scale, commercially operational onshore CO2 storage facility (CO2RYLUS). This initiative aims to accelerate the development of a full carbon capture and storage (CCS) value chain, thereby accruing invaluable insights, expertise, and know-how for others to learn from. Operating within a stringent timeline, GSD’s objective is to have a subsurface storage facility operational before 2026. The chosen site, the Stenlille structure, is situated in Central Zealand, Denmark and provides a good starting point with more than three decades of experience in storing natural gas and an accepting local community. The Stenlille structure is a salt-induced anticlinal 4-way closure that provides excellent conditions for injecting and storing media such as natural gas or CO2. The data from Stenlille is considered the most comprehensive onshore dataset in Denmark and includes 2D and 3D seismic data as well as twenty wells with wireline log data. Fourteen of the wells are presently used for natural gas injection production, and the rest are used for monitoring. These data, coupled with the knowledge and understanding of the subsurface from operating the gas storage facility, are an ideal starting point to quickly establish a CO2 storage facility.

Oil and Gas - transformational technologies - microbial enhanced oil recovery MEOR I believe oil and gas will have a key role in any just net zero transition. I also believe we have to have a plan to rapidly minimise their use as unabated fuels. Oil and gas will also be needed in a net zero future for their non-fuel uses. Much is being made of no new oil. We are leaving vast quantities of old, unrecoverable oil behind in the UK mega fields that are being decommissioned. I’ve been technology driven throughout my career. A number of years ago I wrote a piece for The Chemical Engineer on oil and gas transformational technologies I had witnessed - extended reach drilling, subsea and the FPSO. I also suggested that MEOR could be a transformational technology and speculated on using methanogens to convert unrecoverable oil into much more mobile methane. Prior to field decommissioning, inoculate the reservoir with methanogens and nutrients and let the bugs produce a methane gas cap. Use the existing facilities to process and transport the methane to shore. The landed methane could be used as a chemical building block for non-fuel chemicals. Just a thought? https://lnkd.in/ewbyRQw

The oil and gas industry is facing many challenges, such as rising demand, price volatility, environmental regulations, and the transition to renewable energy sources. Some of the challenges that managers in this industry have to deal with are: Operational and cost risks. Managers have to optimize the efficiency and safety of their operations, while reducing costs and complying with regulations. They have to deal with uncertainties in the extraction processes, such as drilling in unfamiliar or difficult terrains, and manage the risks of accidents, spills, or disruptions Budgeting and costs. Managers have to plan and execute projects within budget and time constraints, and cope with the fluctuations in oil and gas prices. They have to balance the short-term and long-term goals of their organization, and allocate resources wisely Regulation. Managers have to adhere to the laws and standards of the countries and regions where they operate, and respond to the changing regulatory environment. They have to ensure that their activities are environmentally and socially responsible, and meet the expectations of their stakeholders Technology. Managers have to keep up with the technological advancements and innovations in the industry, and leverage them to improve their performance and competitiveness. They have to invest in research and development, and adopt new tools and methods, such as digitalization, automation, or drones Construction. Managers have to oversee the design, construction, and maintenance of their facilities and infrastructure, such as pipelines, refineries, or rigs. They have to ensure the quality and reliability of their assets, and prevent or mitigate any damages or failures These are some of the challenges that managers in the oil and gas industry face. They require a combination of skills, knowledge, and experience to overcome them and achieve their objectives.

Thank you Jason for posting this, and also pointing out the unknowns for vintage pipelines to transport hydrogen or hydrogen/natural gas blends. Accelerated fatigue and decreased fracture toughness are known factors that may require decreasing re-inspection intervals. Susceptibility can be more pronounced at weld (seams, girth welds), areas of high stress (bends, soil movement), and in areas of damage (dents, gouges, or wall thinning). Other mechanisms may also be affected. For example, are external SCC rates increased by internal hydrogen exposure resulting in atomic hydrogen in the steel? Risk models developed for natural gas will have to be reviewed and adjusted to account for hydrogen transport. Mitigation of material degradation may need to be different when dealing with hydrogen pipelines too.

"The course was very insightful especially with having zero background knowledge of CCS. Many topics f rom CCS are similar to those in the petroleum industry therefore one can apply similar management schemes." - Geologist, Kumul Petroleum Holdings Limited In this 5 half-day Virtual Instructor Led Training (VILT) course, the methods for managing risk in CCS projects are addressed with a focus on CO2 injection and storage. The VILT course will also demonstrate how to assess storage capacity of a potential CO2 storage reservoir, model framing techniques, and well injectivity issues related to CO2 injection. The potential leak paths will be discussed such as reservoir seals, leakage along faults and aspects of well integrity. In the VILT course, the design of a monitoring programme will also be discussed. The VILT course will be supported by various case studies. This VILT course will cover the following modules: • CCS projects in an international context • Site selection and site characterization • Storage capacity assessment • Injectivity assessment • Containment assessment • Measurement, monitoring & verification What you will learn: • Uncover the functions and associated components required to capture, transport and store CO2 in subsurface aquifers and (depleted) hydrocarbon reservoirs • Find a systematic and integrated approach to risk identification and assessment for CO2 storage projects (maturation) • Appreciate the requirements (physics modelling) and uncertainties to assess the CO2 storage capacity of a selected site, more... To know more about this training course: https://lnkd.in/gTdYTMt #petroleum #petroleumindustry #petroedge #petroleumengineering #petrochemicalindustry #oilgas #oilandgas #oilfield #oilandgasindustry #oilindustry #oilandgascompanies #oilpatch #oilfieldservices #oilandgasservices #oilpatch #energy #energytransition #oilandgasindustry #oil #CCS #CCSProjectRisks #VILT #CarbonCapture #CarbonStorage

German Existing "Gas Pipelines" Can Transport "Hydrogen" Safely DVGW Project SyWeSt H2 ✅ “Investigation of Steel Materials for Gas Pipelines and Plants for Assessment of their Suitability with Hydrogen”. 🟦 "DVGW Project SyWeSt H2" research project tested steel materials for hydrogen compatibility in gas pipelines. 🟦 Test Conducted: (a) Cyclical Tests: Testing and Evaluation as per ASME E647 (b) Static Fracture-Mechanical Testing: Testing and Evaluation as per ASTM E1820 🟦 Investigated Materials: (1) L290 NE, Grade A, St35 (2) 15k (St.35), X42, RR St 43.7 (3) P355 NH, L360 NE, StE 360.7 (4) L360 NB, 14 HGS, TStE 355 N (5) WSTE 420, St53.7, X56.7 (6) St60.7, P 460 NH, X70 (7) L485, GRS550/X80, L485 (HV high/low) (8) L415 (curve), P355 NL1 (Valve), GJS 400 (Valve) (9) C22.3 (Valve), GS C25 N (Valve), P460 QL1 (Valve) (10) StE 320.7, StE 480.7 TM, L360 🟦DVGW Project SyWeSt H2 Results: (i) Fracture-mechanical crack growth investigations were conducted on a selection of pipeline steel grades of very different ages and material strengths and the results were compared with the crack growth relationships in ASME B 31.12. (ii) This comparison showed considerable quantitative agreement between the crack growth relationships in ASME B31.12 and those established in DVGW Project SyWeSt H2. (iii) All pipeline steel grades investigated in DVGW Project SyWeSt H2 are fundamentally suitable for hydrogen transmission. 🟩 ASME B31.12 Fracture Control and Arrest 1. A fracture toughness measure defined by ASME B31.12 to control fracture propagation when a hydrogen pipeline is designed to operate at hoop stress over 40% of the SMYS (SH > 40% SMYS). 2. When you use a fracture toughness measure, you should ensure that the pipe has adequate ductility. 3. ASME B31.12 provides two options on fracture control, option A and option B. 4. In Option A (Prescriptive Design Method): (-a) Brittle Fracture Control: You have to do fracture toughness testing as per Annex G of API 5L to ensure that the pipe has adequate ductility. (-b) Ductile Fracture Arrest: To ensure that the pipeline has adequate toughness to arrest a ductile fracture, you have to test the pipe as per Annex G of API 5L. 5. Option B (Performance-Based Design Method): The pipe and weld material have to be qualified for satisfactory resistance to fracture in hydrogen gas at or above the design pressure and at ambient temperature using the applicable rules provided in Article KD-10 of ASME BPVC, Section VIII, Division 3. 🟩 References: 1- DVGW Project SyWeSt H2: “Investigation of Steel Materials for Gas Pipelines and Plants for Assessment of their Suitability with Hydrogen”, January 2023. 2- ASME B31.12, Hydrogen Piping and Pipelines ✅ I post about hydrogen technology on LinkedIn daily. My posts reflect my personal perspective, knowledge, experience, and advice. 👇What do you think should be the next step in ensuring that current gas pipelines are suitable for hydrogen use?