Layer | Fill | Outline |
---|
Map layers
Theme | Visible | Selectable | Appearance | Zoom Range (now: 0) |
---|
Fill | Stroke |
---|---|
Collaborating Authors
Results
This article, written by Dennis Denney, contains highlights of paper SPE 164716, ’Applications of Nanotechnology in the Oil and Gas Industry: Latest Trends Worldwide and Future Challenges in Egypt,’ by Abdelrahman Ibrahim El-Diasty, SPE, and Adel M. Salem Ragab, American University in Cairo and Suez University, prepared for the 2013 North Africa Technical Conference & Exhibition, Cairo, 15-17 April. The paper has not been peer reviewed. Precise manipulation and control of matter at dimensions of 1–100 nm have transformed many industries including the oil and gas industry. Nanosensors enhance the resolution of subsurface imaging, leading to advanced field-characterization techniques. Nanotechnology could greatly enhance oil recovery by use of molecular modification and by manipulating interfacial characteristics. Egypt’s oil consumption has grown by more than 30% in the past 10 years. Hydrocarbon reserves in Egypt have increased 5%/year over the past 7 years, while the average recovery factor remains at 35%. Nanotechnology is key to solving this production/ consumption imbalance. Introduction Nanotechnology is the use of very small pieces of material, with dimensions between approximately 1 and 100 nm, by themselves or by manipulation to create new larger-scale materials with unique phenomena enabling novel applications. A nanometer is one-billionth of a meter— a distance equal to two to twenty atoms laid down next to each other (depending on the type of atom). Nanotechnology refers to manipulating the structure of matter on a length scale of nanometers, interpreted at different times as meaning anything from 0.1 nm (controlling the arrangement of individual atoms) to 100 nm or more. Fig. 1 compares the scale of various items referenced to a nanometer. Engineered Nanomaterials Nanoparticles are the simplest form of structures with sizes in the nanometer range. In principle, any collection of atoms bonded together with a structural radius <100 nm can be considered a nanoparticle. The tiny nature of nanoparticles yields useful characteristics, such as increased surface area to which other materials can bond in ways that make stronger or lighter materials. At the nanoscale, size is a factor regarding how molecules react to and bond with each other. Suspensions of nanoparticles are possible because the interaction of the particle surface with the solvent is strong enough to overcome differences in density, which usually would result in a material either sinking or floating in a liquid-forming nanofluid. Nanofluids for oil and gas applications are defined as any fluid used in the exploration and exploitation of oil and gas that contains at least one additive with a particle size in the range of 1–100 nm. A few oilfield uses are described in the following. See the complete paper for additional uses and details.
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.34)
This article, written by Senior Technology Editor Dennis Denney, contains highlights of paper SPE 115058, "Case Study: Restoring Sand-Prone Subsea Wells to Production," by M. Vazir, SPE, and L.G. Acosta, SPE, BP, prepared for the 2008 SPE Annual Technical Conference and Exhibition, Denver, 21-24 September. The paper has not been peer reviewed. This case study describes intervention efforts that returned one dry-tree and two subsea wells to production after an extended shut-in in a mature BP-operated Gulf of Mexico deepwater field. The three wells had been shut in because of sand production. The production facility was not designed with any sand-management capability. Several operational challenges were faced during the planning and execution of this operation. They were carefully assessed, and the risks were managed effectively to return all three wells to production. Introduction Pompano is the oldest BP-operated facility in the Gulf of Mexico; first production was in 1994. The facility was developed with 33 dry-tree wells and a 10-well subsea-template tieback to the fixed-jacket platform. The template is tied to the platform through two subsea flow loops, one 8-in. insulated loop for normal production and one 3-in. uninsulated loop for well testing and well servicing (Fig. 1). Pompano-field production peaked at 65,000 BOPD in 1999. By July 2007, total field production was approximately 11,500 BOPD. Low-cost high-return well-intervention work was key to maximize field value. The challenge for the Pompano team was to identify and implement unique and creative production-enhancement activities. At the forefront of this search was a rigorous effort to revisit and recover production from shut-in wells. Well Histories This project focused on three shut-in wells, one dry-tree well (A-03) and two subsea wells (TB-03 and TB-07). Well A-03 was producing 290 BOPD, 52 BWPD, and 1.04 MMscf/D of gas before shut-in. The well was shut in August 2000 because of solids observed in the shake-outs during the monthly testing of the well. Well TB-03 was shut in initially because of Hurricane Katrina in September 2005. The well remained shut-in for almost 5 months as a result of this event. Before this shut-in, the well was producing 930 BOPD, 480 BWPD, and 1.09 MMscf/D of gas. A startup was attempted in January 2006, and the well produced approximately one-half cup of solids in 8 hours. Shake-outs during this period showed between a trace amount and 10% solids in the flow stream. The well was shut in pending analysis of the produced solids. Laboratory analysis of the produced solids showed them to be fine grained and that they could have been produced through the type of frac-pack completion in Well TB-03. This information indicated that the integrity of the completion might still remain and that the well could be restored to production.
This article, written by Technology Editor Dennis Denney, contains highlights of paper SPE 114163, "Toward Production From Gas Hydrates: Current Status, Assessment of Resources, and Model- Based Evaluation of Technology and Potential," by George J. Moridis, SPE, Lawrence Berkeley National Laboratory; Timothy S. Collett, SPE, US Geological Survey; Ray Boswell, US Department of Energy; M. Kurihara, SPE, Japan Oil Engineering Company; Matthew T. Reagan, SPE, Lawrence Berkeley National Laboratory; and Carolyn Koh and E. Dendy Sloan, SPE, Colorado School of Mines, prepared for the 2008 SPE Unconventional Reservoirs Conference, Keystone, Colorado, 10–12 February. The paper has not been peer reviewed. Gas hydrates are a vast energy resource with global distribution in the permafrost and in the oceans. Even if conservative estimates are considered and only a small fraction is recoverable, the size of the resource is so large that it requires evaluation as a potential energy source. This review paper discusses the distribution of natural-gas-hydrate accumulations, the status of the primary international R&D programs, and the remaining science and technology challenges facing commercialization of production. Introduction Gas hydrates are solid crystalline compounds in which gas molecules (referred to as guests) occupy the lattices of ice-like crystal structures called hosts. Hydrate deposits occur in two geographic settings where the necessary conditions of low temperature and high pressure exist for their formation and stability: in the permafrost and in deep ocean sediments. Most naturally occurring hydrocarbon-gas hydrates contain CH4 in overwhelming abundance. Simple CH4 hydrates concentrate methane volumetrically by a factor of 164 when compared to standard-temperature/-pressure conditions. Some modeling suggests that the energy needed for dissociation could be less than 15% of the recovered energy. Natural-gas hydrates also can contain other hydrocarbons (alkanes), but may also comprise lesser amounts of other gases (mainly CO2, H2S, or N2). The full-length paper contains the complete review. Occurrence, Research Activities and Priorities, and Prospective Production Targets Knowledge of the occurrence of in-situ gas hydrates is incomplete and is obtained from both indirect and direct evidence. There are 23 locations with irrefutable evidence of hydrates (direct recovery of hydrate samples): three in permafrost regions and 20 in ocean environments. In permafrost regions, evidence of gas hydrates is provided from two ongoing R&D programs and from analysis of industry 3D-seismic data and data obtained during the drilling and logging of conventional oil and gas wells. The ability to prospect for gas-hydrate deposits by use of these data was demonstrated in the Prudhoe Bay region of the Alaska North Slope. In the marine environment, most data supporting the interpretation of gas hydrates are indirect indicators (such as bottom-simulating reflections) on relatively low-quality 2D-seismic data. However, direct gas-hydrate detection and characterization from marine 3D data have been shown, and the use of four-component ocean-bottom seismic also shows great promise.
- Research Report (0.54)
- Overview (0.34)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.88)
The annual event posted a 20-year high in attendance at 51,320 and attracted more than 2,000 exhibiting companies (Figure 1). Peter J. Robertson, Vice Chairman of Chevron Corp., laid out those "To me the interesting part is that none of these items are particularly new, but the volume on all of them has been turned up and the combined effects of all of them operating in unison is putting a strain on our collective capabilities," he said. Those challenges will require huge financial investments. Robertson said that Chevron's "big 5" upstream projects include three technically challenging deepwater developments in the Gulf of Mexico (GOM), Nigeria, and Angola; the expansion of the Tengiz field in Kazakhstan; and the Greater Gorgon project in Australia that includes two 5-million-ton liquefied natural gas (LNG) trains and a carbon sequestration project. But the real test for the industry may not be in locating and developing hydrocarbons, but in finding and developing highly skilled technical people "to carry out all of this work," he said.
- North America > United States (1.00)
- Africa (1.00)
- Asia > Kazakhstan > Mangystau Region (0.24)
- Geophysics > Seismic Surveying (1.00)
- Geophysics > Borehole Geophysics (1.00)
- Europe > United Kingdom > North Sea > Central North Sea > Moray Firth > Moray Firth Basin > Block 20/1 > Atlantic Field > Captain Sandstone Formation (0.99)
- Europe > United Kingdom > North Sea > Central North Sea > Moray Firth > Moray Firth Basin > Block 14/26a > Atlantic Field > Captain Sandstone Formation (0.99)
- Europe > United Kingdom > North Sea > Central North Sea > Moray Firth > Moray Firth Basin > Block 13/30 > Atlantic Field > Captain Sandstone Formation (0.99)
- (22 more...)
Introduction Gas hydrates form when water molecules Formation of gas hydrates can be eliminated amounts of alcohols, glycols, or salts are crystallize around "guest" molecules. The or slowed by several methods. These additives thermodynamically water/guest crystallization process occurs Thermodynamic prevention methods destabilize hydrates and effectively lower at many combinations of temperature and control or eliminate elements necessary the hydrate-formation temperature. Light hydrocarbons (methane to for hydrate formation: the presence of function by bonding to water molecules heptanes), nitrogen, carbon dioxide, and hydrate-forming guest molecules, the through hydrogen bonds or solvation. Eliminating any one of these method in a system at hydrate-formation Depending on pressure and gas composition, four factors from a system precludes the conditions is especially difficult in gasproducing gas hydrates may build up at any formation of hydrates.
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.30)
The Malampaya development is in be achieved through the vent tubing remote deepwater offshore the in the umbilicals. The paper has not been peer reviewed. The Malampaya subsea development oilfield activity and devoid of any customary requires high overall system availability infrastructure. The nearest oilfield to ensure continuity of gas supply. Key elements of key spare parts and backup equipment surface imperfections on the connector included simplicity, redundancy, be procured and held offshore to hub sealing faces.
- Asia > Philippines > Palawan > South China Sea > West Philippine Sea > Northwest Palawan Basin > Block SC 38 > Malampaya Field (0.99)
- Asia > Philippines > Palawan > South China Sea > Quezon > Northwest Palawan Basin > Block SC 38 > Malampaya Field (0.99)
- Asia > Philippines > Palawan > Palawan > West Philippine Sea > Northwest Palawan Basin > Block SC 38 > Malampaya Field (0.99)
- (5 more...)
When polyvinyl which is wireline-conveyed through are expected to be major energy caprolactam mud is used and the the drillpipe. This insulated inner barrel resources for Japan. The evaluation hydrate zone is cased off, if the mud retains downhole pressure by use of project drilled an exploration well offshore temperature is high enough to dissolve a ball-valve mechanism and retains Japan in the Nankai trough area the hydrate, the zone will become downhole temperature with a batterypowered in 1999. The well evaluated the unstable, and the decomposed gas thermoelectric cooler. When hydrate, as well as deeper conventional may cause an unsafe situation. To prevent the barrel arrives at the surface, it is oil and gas objectives. The drill site such problems, a mud-cooling packed in a portable service unit, in was 50 km south of Shizuoka prefecture system was designed.