Layer | Fill | Outline |
---|
Map layers
Theme | Visible | Selectable | Appearance | Zoom Range (now: 0) |
---|
Fill | Stroke |
---|---|
Collaborating Authors
Abstract Heavy oil production presents tremendous challenges in subsurface development, production wells, and surface transport. Therefore, highly efficient transportation calls for innovative engineering processes to facilitate the transport from subsurface to downstream. In Block 192- Peru, previous production experience indicated that mixing light oil at the well production manifold to heavy oil stream was a feasible option. However, this option strongly depends on the availability of light oil. The aim of this study is to present alternatives to improve heavy oil transportation performance in the block 192. Results of a fundamental study conducted on the heavy oil transportation performance in Jibaro, Jibarito and San Jacinto fields are presented herein where multiple possibilities are evaluated to reduce the ratio of light oil per barrel of heavy oil production (i.e. to increase the efficiency of the diluent). This study provides guidelines to select one of the three following methods: diluent injection, emulsion injection or reservoir-based technology. Previous operators performed extensive reservoir characterization and simulation modeling which led to recovering over 200 million barrels of heavy oil (up to July 2015) through Vivian sands. Therefore, this confirmed the suitability of introducing new methods to feasible transport and sell heavy oil. Jibaro, Jibarito and San Jacinto fields are used in this study due to their significant heavy oil reserves. The complexity of these fields includes high water cut production, Heli transportable logistics and high cost of produced oil. The first method proposed in this study consists of injecting a diluent in the extraction stream of heavy oil up. The second method uses emulsion water to transport high viscous oil. The third method involves applying a technology in the extraction process to reduce the viscosity of heavy oil, and in-situ upgrade the heavy oil up to sales specifications with a consideration of long distance between fields. This study concludes that a conceptual engineering and a selection of a compatible diluent and solvent are critical. Finally, environmental permitting increases the complexity of any project in the area and the possibility to introduce new technology.
- South America > Peru > Loreto Department (0.54)
- North America > United States > Texas (0.47)
- North America > Mexico > Tabasco > Bellota-Jujo (0.45)
- Research Report > New Finding (1.00)
- Research Report > Experimental Study (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.36)
- Asia > India > Gujarat > Cambay Basin > North Cambay Basin (0.99)
- South America > Peru > Marañón Basin > Chonta Formation (0.98)
- South America > Peru > Loreto Department > Marañón Basin > Block 192 > San Jacinto Field > Vivian Formation (0.94)
- (10 more...)
- Information Technology > Knowledge Management (0.40)
- Information Technology > Communications > Collaboration (0.40)
Abstract Heavy oil waterfloods have been operating in the petroleum industry for more than fifty years. Over this time, many researchers have tried to identify flood management practices that would optimize recovery from these waterfloods. This multidisciplinary work ties simulation with the evaluation of field statistical results to determine the best operating practices for heavy oil reservoirs that have high permeability thief zones. The particular type of thief zone of concern in Alaskan heavy oil waterfloods is called a Matrix Bypass Event, or MBE. An MBE is a dramatic water breakthrough event in the form of a direct connection between the injector and producer whereby the waterflood process ceases and the injection water cycles directly to the producer without sweeping the matrix. This study evaluates operating strategies for reservoirs where MBEs have developed, taking into account the effects and interdependencies of pre-production, Voidage Replacement Ratio (VRR), and oil viscosity. Evaluation of production from 30 Canadian heavy oil waterfloods indicated that oscillation of the VRR resulted in more oil recovery than a reservoir operated at a constant VRR ~ 1.0. This finding laid the foundation showing that an operational practice called Cyclic Injection/Production would be beneficial, especially for heavy oil waterfloods. Cyclic Injection/Production alternates active injection while production is shut in, followed by active production while injection is shut in. Simulation was performed with a 3-D compositional finite difference reservoir model based on a heavy oil reservoir in Alaska's North Slope. The simulation confirmed that optimal waterflooding practices for heavy oils are significantly different from optimal practices for light oil waterfloods. The best practices also varied according to whether the waterflood had developed an MBE. As long as no MBEs are present and the producers are not bottomhole pressure limited, VRR of less than 1.0 and continuous injection are recommended. For heavy waterfloods that have high perm thief zones, however, Cyclic Injection/Production and a VRR of less than 1.0 improve recovery.
- North America > United States > Texas (0.49)
- North America > United States > Alaska (0.35)
- North America > United States > Texas > Permian Basin > Midland Basin > Spraberry Field > Spraberry Formation (0.99)
- North America > United States > Alaska > North Slope Basin > Kuparuk River Field > West Sak Field (0.99)
- North America > United States > Alaska > Schrader Bluff Formation (0.98)
A Comprehensive Review Heavy Oil Reservoirs, Latest Techniques, Discoveries, Technologies and Applications in the Oil and Gas Industry
Temizel, Cenk (Aera Energy) | Canbaz, Celal Hakan (Schlumberger) | Tran, Minh (USC) | Abdelfatah, Elsayed (University of Calgary) | Jia, Bao (University of Kansas) | Putra, Dike (Rafflesia Energy) | Irani, Mazda (Ashaw Energy) | Alkouh, Ahmad (College of Technological Studies)
Petroleum in general is found in sub-surface reservoir formation amongst pores existent in the formation. For several years due to lack of information regarding production and technology, free-flowing, low viscosity oil has been produced known as conventional crude oil. Fortunately, in recent times, due to advancement of technology, high viscosity with higher Sulphur content-based crude has been produced known as heavy oil. There are also exists significant difference in volatile materials as well as processing techniques used for the two types of crude. (IEA, 2005; Ancheyta et al., 2007). The oil viscosity is a huge problem in regard to heavy oil as both recovery and processing charges increase proportional to Sulphur content and viscosity of the crude. Heavy Oil can be used by definition internationally to describe oil with high viscosity (Although the Oxford dictionary might have several variations of the same, within the contents of this paper, we refer to heavy oil as high viscosity crude). Heavy oil generally contains a lower proportion of volatile constituents and larger proportion of high molecular weight constituents as compared to conventional crude oil (often referred to as light oil, we shall describe the characteristics of the types of oil further in the introduction). The heavy oil just doesn't contain a composition of paraffins and asphaltenes but also contains higher traces of wax and resins in its composition. These components have larger molecular structures leading to high melting and pour points. This makes the oil a bad candidate for flow profiles and adversely affects the mobility of the crude. (Speight, 2016). It is crucial to know the heavy oil constitution as it affects: Recovery: Low viscosity and high melting points Processing: Higher Resin, Sulphur and aromatic content Transportation: Low Viscosity These all together impact the economics related to E&P (Exploration and Production) of heavy oil resources. These resources generally have a higher of production associated with them and are one of the first candidates to be affected by reduction of crude prices as seen in 2014 and early 2015. Crude oil can generally be classified into its types by using its API values that are generally obtained through lab testing. Table B1 provides a few popular crude types and their associated API Values.
- Asia > Middle East (1.00)
- North America > Canada (0.94)
- Europe (0.93)
- (2 more...)
- Overview (0.81)
- Research Report > New Finding (0.46)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Asia > China > Xinjiang Uyghur Autonomous Region > Tarim Basin (0.99)
- North America > United States > California > San Joaquin Basin > Lost Hills Field (0.98)
- Africa > Middle East > Libya > Murzuq District > Murzuq Basin > Block NC 115 > Field A Field > Silurian Tanezzuft Formation > A11 Well (0.93)
- Africa > Middle East > Libya > Murzuq District > Murzuq Basin > Block NC 115 > Field A Field > Silurian Tanezzuft Formation > A10 Well (0.93)
Abstract The 2009 global recession, which reduced oil demand and created tight credit conditions, has largely receded. Oil demand, which had declined, has since begun to grow again. Some of the large projects related to heavy crude production, upgrading and refining that had been suspended have been revived. Oil prices have rebounded and investments in higher cost non-conventional oil resources are again being made in many parts of the world. The lower costs that were seen during the recession have also rebounded, though the costs for labor and services are still lower than before the recession.recession. This presentation will take these changes into consideration. This presentation will highlight conventional heavy oil as well as extra-heavy oil and bitumen production projections. This presentation will provide:* Detailed analysis of North American PADD regions * Disposition by region - internal market vs. export * Country-by-country analysisResources and state of development Costs and economics Political, environmental and regulatory considerations Production forecasts * New heavy oil projects and expansions * Technology, constraints and environmental impacts * Pricing analysis, cost of processing different quality crudes Refer to Global Heavy Crude Oil Outlook to 2035 Mrs Kristine Klavers Mrs Laura Atkins The 2009 global recession, which reduced oil demand and created tight credit conditions, has largely receded. Oil demand, which had declined, has since begun to grow again. Some of the large projects related to heavy crude production, upgrading and refining that had been suspended have been revived. Oil prices have rebounded and investments in higher cost non-conventional oil resources are again being made in many parts of the world. The lower costs that were seen during the recession have also rebounded, though the costs for labor and services are still lower than before the recession.recession. This presentation will take these changes into consideration. This presentation will highlight conventional heavy oil as well as extra-heavy oil and bitumen production projections. This presentation will provide:* Detailed analysis of North American PADD regions * Disposition by region - internal market vs. export
- South America (1.00)
- North America > United States (1.00)
- Europe (0.74)
- (2 more...)
- South America > Venezuela > Orinoco Oil Belt > Eastern Venezuela Basin > Junin Block (0.99)
- North America > Canada (0.99)
- Asia > Middle East > Iraq > Maysan Governorate > Arabian Basin > Widyan Basin > Mesopotamian Basin > West Karoun Block > Azadegan Field > Sarvak Formation (0.98)
- (10 more...)