This course discusses the fundamental sand control considerations involved in completing a well and introduces the various sand control techniques commonly used across the industry, including standalone screens, gravel packs, high rate water packs and frac-packs. It requires only a basic understanding of oilfield operations and is intended for drilling, completion and production personnel with some sand control experience who are looking to gain a better understanding of each technique’s advantages, limitations and application window for use in their upcoming completions.
Reducing the complexity and controlling the cost of major offshore projects are together one of the biggest challenges facing the oil and gas industry. Disruptive technological advances may produce significant improvements in completion techniques. As it has since 1969, the world came to OTC to make critical decisions, share ideas, and develop business partnerships to meet global energy demands. To survive in the current low-price environment, exploration and production (E&P) companies must better handle the complexities inherent in their projects through practices that promote capital effectiveness and collaboration.
When a rig is stacked, its owner has two choices: spend millions to keep it in good shape, or let it rust out. These two companies describe what it is like to maintain their assets for the day that a contract comes. This paper shows how a new approach to small fields could unlock more than twice the net present value (NPV) of larger conventional fields in Southeast Asia at a similar level of capital expenditure (CAPEX). This paper reviews the efforts to exploit CBM resources in Indonesia, the challenges these efforts have faced, and possible solutions that can make operations more efficient and profitable. This paper presents a literature review to determine the engineering challenges and opportunities presented by CBM production in China.
Maxime, France Geosteering Technologies - 9-14 September Downhole Water Management - 16-21 September Wells - How Smart Can They Get? - 23-28 September Asia Pacific Nusa Dua, Indonesia The Application of Seismic Attribute Analysis and Geostatistics in Reservoir Prediction - 13-18 May Optimising Well Productivity with Modern Completion and Stimulation Practices - 20-25 May South America and Caribbean Margarita Island, Venezuela Underbalanced Operations vs Designer Fluids - 28 October-2 November Middle East Muscat, Oman Produced Water Management - The New Reality - 3-8 November 2002 North America Park City, Utah, USA Enhancing Recovery from Deepwater Reservoirs - 7-12 July The Offshore Facility of the Future - 7-12 July E-Well and Wellbore Robotics - 14-19 July Decision-Driven Asset Development and Management - 14-19 July Europe Ste. Saint Maxime, France Smart Drillling - 5-10 September Sand Control and Management - 12-17 September Tight Gas Development - 19-24 September Middle East Muscat, Oman Smart Wells: How Smart Can They Get? - 10-15 January Mature Reservoirs: The Appropiate Application of Technology - 17-22 January P a g e 13 17 Middle East Hammamet, Tunisia The Heavy Oil Challenge: Completion Design and Production Management - 17-22 May 2010 North America Park City, Utah, USA Meet me at the Wellhead - Enhancing the Value Chain in Offshore Installations - 20-25 June - Cancelled Getting to Zero-An incident Free Workplace: How do we get there? P a g e 14 17 Europe The Algarve, Portugal Unlocking the Potential of Nanotech for Exploration and Production - 25-30 September Shale Gas: Beyond Current Technologies and Going Global - 2-7 October CO2 Geological Storage: Will we be ready in time? Can supply expand to keep up with demand exceeding projections? P a g e 15 17 Europe Adaptive Well Construction - 13-18 October Managed Pressure Drilling - Niche Technology or the Future of Drilling?
Maxime, France Geosteering Technologies - 9-14 September Downhole Water Management - 16-21 September Wells - How Smart Can They Get? - 23-28 September Asia Pacific Nusa Dua, Indonesia The Application of Seismic Attribute Analysis and Geostatistics in Reservoir Prediction - 13-18 May Optimising Well Productivity with Modern Completion and Stimulation Practices - 20-25 May South America and Caribbean Margarita Island, Venezuela Underbalanced Operations vs Designer Fluids - 28 October-2 November Middle East Muscat, Oman Produced Water Management - The New Reality - 3-8 November 2002 North America Park City, Utah, USA Enhancing Recovery from Deepwater Reservoirs - 7-12 July The Offshore Facility of the Future - 7-12 July E-Well and Wellbore Robotics - 14-19 July Decision-Driven Asset Development and Management - 14-19 July Europe Ste. Saint Maxime, France Smart Drillling - 5-10 September Sand Control and Management - 12-17 September Tight Gas Development - 19-24 September Middle East Muscat, Oman Smart Wells: How Smart Can They Get? - 10-15 January Mature Reservoirs: The Appropiate Application of Technology - 17-22 January P a g e 10 17 Asia Pacific Phuket, Thailand Challenges in Completions for 2007 and Beyond - 9-14 May Innovations for Gas Field Development - 16-21 May South America and Caribbean Mar del Plata, Argentina Adaptive Development and Management of Oil and Gas Fields - 7-12 November 2005 North America Te Can supply expand to keep up with demand exceeding projections?
Panomrit, Agkarat (PTT E&P PLC) | Sri-intra, S. (PTT E&P PLC) | Limpanachaipornkul, S. (PTT E&P PLC) | Tanmon, W. (PTT E&P PLC) | chaisalee, d. (PTT E&P PLC) | Buato, A. (PTT E&P PLC) | Sawattanakit, N. (PTT E&P PLC) | Kanokwareerat, N. (PTT E&P PLC) | Panmungmee, C. (PTT E&P PLC) | Udomsri, J. (PTT E&P PLC) | Chiawwattana, N. (PTT E&P PLC) | Taranut, N. (PTT E&P PLC) | Salee, W. (PTT E&P PLC) | Limsakul, C. (PTT E&P PLC) | Wichetthammasak, R. (PTT E&P PLC) | Thamvechvitee, P. (PTT E&P PLC) | Kanlayanopakorn, N. (PTT E&P PLC) | Tangpuk, S. (PTT E&P PLC) | Wipoosanawan, W. (PTT E&P PLC) | Limprachaya, S. (PTT E&P PLC) | Nubsuwan, S. (PTT E&P PLC) | Sitthiwasuwat, T. (PTT E&P PLC) | Bamrungwong, A. (PTT E&P PLC) | Pongtemsuk, J. (PTT E&P PLC) | Chintanapatumporn, S. (PTT E&P PLC)
The low-oil price situation impacts many oil and gas producers and operators across the globe. Some oil and gas giants called for cost-cutting or other quick-win means to sharply reduce their cost first with enhancing working performance later. This seems to be the effective, silver bullet solution for big company which wider cost reduction gap can be easily identified, but not for middle-to-small companies of which "Competitive Performance" is a key driver.
This paper presents how to survive not only during this difficult time, but also strive for sustainability in the long run. The main emphasis in this paper is paid on "Maintenance and Inspection (M&I)" programs and pertinent activities (e.g. inventory management), which pose the significant share in operating cost in exploration and production business entirely.
The reassessment of maintenance and inspection data leads to reconsideration of methods and philosophy to be applied for each installation, system, unit, down to maintainable items. The data structure in enterprise resource planning database is modified to pipe the data systematically to ease this data analysis and support the other continuous improvement when needed.
Various techniques have been applied to make our maintenance and inspection more efficient and effective. These rank from simple (e.g. reliability-based techniques, such as Reliability-Centered Maintenance (RCM), Risk-based Inspection (RBI), Safety Integrity Level (SIL) to sophisticated approaches, such as parametric modeling; classical Artificial Neural Network (ANN), Similarity-based Modeling (SBM), etc., which are selected for best-fit with our applications.
The obsolescence and aging equipment management is unforgettable – It is built-in with the review process to deliberate how to manage the maintenance and inspection programs to suit with the asset life cycle; in term of total cost of ownership against remaining life and obtainable profits.
All stock parameters, associated formula/ calculation in relation with (e.g. reorder points, minimum and maximum quantity limit, etc.) and relevant management codes are reviewed and reinvented to come in close proximity with "Just-In-Time" requirement. Doing so helps reducing the non-movement spare parts in some extent, and in turn, lower the overall inventory cost, for instance, stock holding and carrying cost.
Moreover, that optimization are enhanced across the entire organization – Not limited only to one entity. All outcomes from one is fairly shared with others. Then our maintenance and inspection programs become more and more efficient and effective according the number of collaboration rounds and later enable the standardization throughout our company and affiliates.
All aforementioned lifts our competitive advantages; obviously the reduction in maintenance cost per Barrel of Oil Equivalence (BOE) approximately 10-30% depending on installation base and makes maintenance job value more meaningful.
Following my theme for the year on risk and reward, this month’s column looks at how partnerships affect the risk/reward balance. Our industry is full of partnerships—it’s how we share the risk in a very risky business. But when times are hard, the partnerships can be strained—as they are today. Can we adjust the business models and partnership alliances so that both operators and service providers can survive and thrive going forward? Can partnerships be adjusted to benefit both parties? Is it time for some new business models?
Whenever I speak to students and SPE’s Young Professionals, I remind them this is the oil business. As engineers and SPE members, we love to focus on technology, but ultimately oil companies thrive on dollars and barrels. Generally, international oil companies (IOCs) make money from very long-term investments while national oil companies (NOCs) are more focused on developing long-term, sustainable oil and gas fields within their borders. NOCs also nurture their own citizens’ job skills and support local industries.
The past 2 years for the service side of our business have been a matter of survival. Or, in some cases, not. Everyone agrees that the service sector has taken the strongest hit during this downturn. Operators still have cash flow because of the underlying producing assets. But when the operators stop investing, the service companies’ cash flow stops. The operators’ cash flow may be down by half, but at least they still have cash flow. Many service companies’ cash flow has gone to almost zero. These service companies have few options other than to retire or mothball equipment, cut their staffs, and “hold our breath and hope for better times soon.” See Schlumberger CEO Paal Kibsgaard’s presentation at the Scotia Howard Weil 2016 Energy Conference, 21 March 2016 at http://www.slb. com/news/presentations/2016/2016_0321_pkibsgaard_scotia_ howard_weil.aspx.So, what’s at stake? Operators (both NOCs and IOCs) are completely dependent on the service sector to execute our projects. They drill our wells, build our production and refining facilities, and, most importantly, provide us with innovative new products. IOCs provide integration capability, the full value chain, and usually a very long-term view for asset management. IOCs have the capability and incentive to actually apply the new technologies developed by the service companies—for cost reduction, increased production and recovery, and long-term asset management.
Particle-size analyzers deliver precise measurements of drilling fluids, which allow drillers to quickly determine wellbore conditions and avoid problems. Automated particle-size analyzers are something you will not see on most drilling rigs, but some think this outside-the-oilfield technology will play a big role in the future of the drilling sector. Directly measuring these particles would give rig crews and engineers an unprecedented ability to quickly determine how the well is really holding up and react if things head south. Fully automated analyzers would go one step further by acting on the data to make precise adjustments to the fluid mix, creating a savings opportunity on drilling chemicals. Eric van Oort, a professor of petroleum engineering at the University of Texas (UT) in Austin, believes the adoption of such technology is in the early stages, but he sees immediate benefits for operators and contractors who commit to using it.
To survive in the current low-price environment, exploration and production (E&P) companies must better handle the complexities inherent in their projects through practices that promote capital effectiveness and collaboration. Owners and operators must emphasize the long-term viability of their assets over high returns, an expert said. In a presentation hosted by the SPE Gulf Coast Section Projects, Facilities, and Construction Study Group, Neeraj Nandurdikar discussed the collective actions the industry should take to improve project efficiency. Nandurdikar’s presentation, “Journey Towards Efficiency,” was the fourth installment of the study group’s Spring Event Series, “Delivering Projects at Less Than USD 50/bbl.” He is the director of the E&P practice at Independent Project Analysis.
The force required to drill through a rock is a direct test of its strength and stiffness. For the past 2 decades, the use of DNA sequencing technology has largely been relegated to the domains of criminal forensics and the healthcare industry. One company is betting that the shale industry soon will join that list. A company known for being a pioneer in methods built on imaging ultratight rock at the core level has built a business testing drilling cuttings to help identify productive, fracturable rock to help operators design better completions. A service using pressure data from a few nearby unconventional wells to map fracturing will soon be for sale.