Potential of Solar Enhanced Oil Recovery in the Major Heavy Oil Areas of China

2016 ◽  
Author(s):  
Miguel Frasquet ◽  
Manuel Silva
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Heavy Oil ◽  
Injection Rate ◽  
Surface Model ◽  
Steam Generation ◽  
Thermal Methods ◽  
Oil Reserves ◽  
Solar Steam Generation ◽  
Solar Resource

Solar steam generation for enhanced oil recovery has a significant potential at regions where, in addition to heavy oil reservoirs, solar resource is abundant. China ranks amongst the countries with greater heavy oil reserves. In addition, Western regions of China have a solar resource equivalent to that of places in which solar energy is being developed in a commercial scale. This paper addresses the technical feasibility of using concentrating solar collectors to produce the steam required in the recovery of heavy oil through thermal methods. Three locations have been selected for this study. In each location, three different reservoir injectivity scenarios have been taken into account: No injectivity limitation (as upper bound), partial limitation and full limitation (meaning that the injection rate cannot be greater than the design value for constant rate). In the first scenario, the surface model uses parabolic through collectors and direct steam generation. When injectivity is restricted, thermal storage becomes necessary in order to be able to inject the same amount of heat into the reservoir within the limits of the reservoir’s injectivity. Therefore, molten salts tower system with sensible storage is proposed as technology for the second scenario. In the third scenario, also parabolic through collectors are used but in this case, the solar system is coupled with conventional Once-Through Steam Generators (OTSGs) in a hybrid scheme (this approach represents the current state of the art).

scholarly journals Enhanced Oil Recovery Using CO2 in Alaska

Geosciences ◽  
2021 ◽  
Vol 11 (2) ◽  
pp. 98
Author(s):  
Banabas Dogah ◽  
Vahid Atashbari ◽  
Mohabbat Ahmadi ◽  
Brent Sheets
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Comprehensive Overview ◽  
Thermal Methods ◽  
Oil Reserves ◽  
Viscous Oil ◽  
Co2 Eor ◽  
Permafrost Thawing ◽  
Petroleum Reserves ◽  
Shallow Reservoirs

Alaska holds more than 68 billion barrels of proved oil reserves and more than 36.7 trillion cubic feet of proved natural gas reserves with some special conditions such as proximity to permafrost, making Alaskan petroleum reserves unique. The low temperature in shallow reservoirs prohibited hydrocarbons’ ideal maturation, thereby generating several heavy and viscous oil accumulations in this state. This also limits the enhanced oil recovery (EOR) options, leaving the thermal methods off the table to avoid permafrost thawing, which can cause wellbore collapse. Several solutions have been attempted for improving oil production from heavy and viscous oil in Alaska; however, they have not yielded the desired recovery, and ultimate recovery factors are still less than the global average. One solution identified as a better alternative is using CO2 as an injecting fluid, alternated by water or mixed with other injectants. This paper provides a comprehensive overview of all studies on using CO2 for enhanced oil recovery purposes in Alaska and highlights common and unique challenges this approach may face. The suitability of CO2-EOR methods in the Alaskan oil pools is examined, and a ranking of the oil pools with publicly available data is provided.

scholarly journals Enhanced Oil Recovery Practices: Global Trend, Nigeria’s Present Status, Prospects and Challenges

2021 ◽  
pp. 79-92
Author(s):  
Adeolu J. Alawode ◽  
Olugbenga A. Falode
Keyword(s):  
Interest Rates ◽  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Heavy Oil ◽  
Present Status ◽  
Oil Reserves ◽  
Global Trend ◽  
Low Interest Rates ◽  
Favorable Tax Policy ◽  
Carbon Dioxide Co2

Enhanced oil recovery (EOR) techniques are considered due to unimpressive oil recovery, limited oil reserves, and non-applicability of primary recovery methods in some (heavy oil) fields. In Nigeria, preparation is in gear towards implementing EOR projects. This paper therefore reviews the global trend of EOR practices and discusses Nigeria’s present status, prospects, and challenges. Most EOR projects are employed in sandstone (high permeability) reservoirs; hence based on lithological considerations, all EOR methods are feasible in Nigeria. However, miscible hydrocarbon gas injection is found to be a very good EOR choice because it would drastically reduce the uneconomical practice of gas flaring; besides, transportation of carbon dioxide (CO2) and flue gas is virtually non-existent in Nigeria. Chemical (especially surfactant) flooding is costly; hence it would be feasible in Nigeria if oil price is high. At present, cost implications of heat treatment facilities may be an impedance to implementing thermal EOR for heavy oil in Nigeria. Though microbial EOR is the cheapest, it is not favorable in high temperature (above 85 oC), high salinity (above 100,000 ppm) and deeper (beyond 3,500m) reservoirs. For EOR practices to thrive in Nigeria, there should be an extensive economic evaluation and forecasting, effective research and development, effective training of technical staff for proper operation, surveillance and maintenance of EOR projects, implementation of health, safety and environmental (HSE) guidelines, low inflation rates, low interest rates on loans, general price stability, favorable tax policy, low import duties on machineries and equipment used for EOR, modified private market decisions and encouraging legal and regulatory framework.

Downhole Steam Generation for Green Heavy Oil Recovery

2021 ◽  
Author(s):  
Abdulsallam Al-Mashrafi ◽  
Mahmood Fani ◽  
Faisal Asfand ◽  
Mahmood Amani ◽  
Mohsen Assadi ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Heavy Oil ◽  
Steam Injection ◽  
Recent Effort ◽  
Heavy Oil Recovery ◽  
Steam Generation ◽  
Steam Quality ◽  
Thermal Methods ◽  
Feasibility Assessment ◽  
Using Data

Abstract The ultimate target of heavy oil recovery is to enhance oil mobility by transferring steam's thermal energy to the oil phase, incrementing its temperature, and reducing heavy oil's viscosity. While the various types of steam floods such as Cyclic Steam Injection (CSI) and Steam-Assisted Gravity Drainage (SAGD) are widely used worldwide, they have certain limitations that need further improvements. Notably, in surface steam generation systems, downhole steam quality is around 70% which means that 30% of latent heat is lost while steam travels from the surface to the pre-determined downhole location. Downhole steam generation (DHSG) can be a viable alternative for the surface steam injection in which steam will be generated downhole instead of on the surface. The asserted method presents significant benefits such as preventing steam quality loss, decreasing the environmental effects, and enhancing the heavy oil recovery by co-injecting the flue gas products such as CO2, and consequently, the economic outcomes will be increased. In this research, a comprehensive techno-economic case study has been conducted on a heavy oil reservoir to evaluate the economic and technical advantages of DHSG compared to surface steam generation. Various technical expenses and revenues such as investment costs, operating costs, royalties, and taxes have been considered in a simulation model in MATLAB. This DHSG feasibility assessment has been performed using data of a heavy oil reserve currently under steam flood. Results showed that DHSG could increase up to 50% economic and technical interest than conventional steam injection projects. One of the outstanding benefits of DHSG is the reduction of heat loss. Since steam is produced in-situ, either downhole or in the reservoir, no waste of heat occurs. Typically, most heat losses happen on surface lines and wellbore during steam injection from the surface, which accounts for approximately 32%. Thus, this issue is excluded using the DHSG method. The results of the recent effort fit well into the current industry's requirements. DHSG can (1) increase the rate of heavy oil production, (2) decrease the extra expenses, and (3) dwindle the environmental side effects of CO2 emission of surface steam generation. Compared with conventional thermal methods, in DHSG, the steam to oil ratio remains constant with depth change while the desired steam quality can be achieved at any location. The asserted benefits can ultimately optimize the steam injection with a significant reduction in UTC, hence, improved profitability.

Prospects for Heavy Oil Recovery and its Role in the Energy Picture

1986 ◽  
Vol 4 (5) ◽  
pp. 321-348
Author(s):  
Rawya Selby ◽  
S. M. Farouq Ali
Keyword(s):  
Oil Recovery ◽  
Heavy Oil ◽  
Oil Sands ◽  
Thermal Recovery ◽  
Heavy Oil Recovery ◽  
Heavy Oils ◽  
Thermal Methods ◽  
Oil Reserves ◽  
Recovery Processes ◽  
Cyclic Steam Stimulation

Heavy oil and oil sands deposits constitute an important resource, with in-place estimates varying between 600 × 109 and 980 × 109 m3. These deposits are mostly concentrated in Canada, the US and Venezuela. The gradual depletion of conventional oil reserves is leading to a greater interest in heavy oil recovery. This paper presents on overview of heavy oil characteristics, worldwide deposits and recovery methods, with special emphasis on the heavy oils and oil sands of Canada. Thermal recovery techniques such as cyclic steam stimulation, steamflooding and in-situ combustion have been generally more successful than non-thermal methods. The principal thermal recovery processes are discussed in detail. Reservoir characteristics influencing the applicability of these processes are mentioned, and possible operational problems are outlined. Most of the Canadian heavy oils and oil sands deposits occur in the provinces of Alberta and Saskatchewan. Selected recovery projects currently in operation are described, outlining modifications to the basic process, problems encountered and range of success.

scholarly journals Recovery rates, enhanced oil recovery and technological limits

2014 ◽  
Vol 372 (2006) ◽  
pp. 20120320 ◽  
Author(s):  
Ann Muggeridge ◽  
Andrew Cockin ◽  
Kevin Webb ◽  
Harry Frampton ◽  
Ian Collins ◽  
...  
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Current Status ◽  
Comprehensive Overview ◽  
Oil Reserves ◽  
The North ◽  
History Of ◽  
The North Sea ◽  
Giant Fields ◽  
Broad Consensus

Enhanced oil recovery (EOR) techniques can significantly extend global oil reserves once oil prices are high enough to make these techniques economic. Given a broad consensus that we have entered a period of supply constraints, operators can at last plan on the assumption that the oil price is likely to remain relatively high. This, coupled with the realization that new giant fields are becoming increasingly difficult to find, is creating the conditions for extensive deployment of EOR. This paper provides a comprehensive overview of the nature, status and prospects for EOR technologies. It explains why the average oil recovery factor worldwide is only between 20% and 40%, describes the factors that contribute to these low recoveries and indicates which of those factors EOR techniques can affect. The paper then summarizes the breadth of EOR processes, the history of their application and their current status. It introduces two new EOR technologies that are beginning to be deployed and which look set to enter mainstream application. Examples of existing EOR projects in the mature oil province of the North Sea are discussed. It concludes by summarizing the future opportunities for the development and deployment of EOR.

scholarly journals Enhanced Oil Recovery by Thermal Methods

1977 ◽  
Vol 42 (1) ◽  
pp. 44-44
Author(s):  
Kanemitsu NAKAYAMA ◽  
Hidenobu HAMANO
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Thermal Methods

Effect of pressure variation on polymer flooding

2021 ◽  
Author(s):  
Ahmad Ali Manzoor
Keyword(s):  
Polymer Solution ◽  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Heavy Oil ◽  
Constant Pressure ◽  
Maximum Pressure ◽  
Core Flooding ◽  
Sweep Efficiency ◽  
Black Oil Model ◽  
Original Oil In Place

Chemical-based enhanced oil recovery (EOR) techniques utilize the injection of chemicals, such as solutions of polymers, alkali, and surfactants, into oil reservoirs for incremental recovery. The injection of a polymer increases the viscosity of the injected fluid and alters the water-to-oil mobility ratio which in turn improves the volumetric sweep efficiency. This research study aims to investigate strategies that would help intensify oil recovery with the polymer solution injection. For that purpose, we utilize a lab-scale, cylindrical heavy oil reservoir model. Furthermore, a dynamic mathematical black oil model is developed based on cylindrical physical model of homogeneous porous medium. The experiments are carried out by injecting classic and novel partially hydrolyzed polyacrylamide solutions (concentration: 0.1-0.5 wt %) with 1 wt % brine into the reservoir at pressures in the range, 1.03-3.44 MPa for enhanced oil recovery. The concentration of the polymer solution remains constant throughout the core flooding experiment and is varied for other subsequent experimental setup. Periodic pressure variations between 2.41 and 3.44 MPa during injection are found to increase the heavy oil recovery by 80% original-oil-in-place (OOIP). This improvement is approximately 100% more than that with constant pressure injection at the maximum pressure of 3.44 MPa. The experimental oil recoveries are in fair agreement with the model calculated oil production with a RMS% error in the range of 5-10% at a maximum constant pressure of 3.44 MPa.

Sign in / Sign up

Export Citation Format

Share Document