should be (2 * n+m) x8x 16, for example, the number of 18 Chinese characters, 1 Spanish, 2 training sample "China has independently developed numbers. After the transposition of each character, it J55 heavy oil thermal recovery casing to composes 39 (2 x18+3) x 8=312 rows and 16 successfully substitute the import", with total column of the two value image.

2015 ◽  
pp. 299-299
Keyword(s):  
Heavy Oil ◽  
Training Sample ◽  
Thermal Recovery ◽  
Chinese Characters ◽  
Total Column

Application and Exploration of Early In-Situ Combustion Huff-and-Puff Technology in a Deep Undisturbed Reservoir with Extra Heavy Oil

2021 ◽  
pp. 1-13
Author(s):  
Wang Xiaoyan ◽  
Zhao Jian ◽  
Yin Qingguo ◽  
Cao Bao ◽  
Zhang Yang ◽  
...  
Keyword(s):  
High Pressure ◽  
High Temperature ◽  
Heavy Oil ◽  
Gas Injection ◽  
Thermal Recovery ◽  
Oil Field ◽  
Pilot Test ◽  
In Situ Combustion ◽  
Coiled Tubing

Summary Achieving effective results using conventional thermal recovery technology is challenging in the deep undisturbed reservoir with extra-heavy oil in the LKQ oil field. Therefore, in this study, a novel approach based on in-situ combustion huff-and-puff technology is proposed. Through physical and numerical simulations of the reservoir, the oil recovery mechanism and key injection and production parameters of early-stage ultraheavy oil were investigated, and a series of key engineering supporting technologies were developed that were confirmed to be feasible via a pilot test. The results revealed that the ultraheavy oil in the LKQ oil field could achieve oxidation combustion under a high ignition temperature of greater than 450°C, where in-situ cracking and upgrading could occur, leading to greatly decreased viscosity of ultraheavy oil and significantly improved mobility. Moreover, it could achieve higher extra-heavy-oil production combined with the energy supplement of flue gas injection. The reasonable cycles of in-situ combustion huff and puff were five cycles, with the first cycle of gas injection of 300 000 m3 and the gas injection volume per cycle increasing in turn. It was predicted that the incremental oil production of a single well would be 500 t in one cycle. In addition, the supporting technologies were developed, such as a coiled-tubing electric ignition system, an integrated temperature and pressure monitoring system in coiled tubing, anticorrosion cementing and completion technology with high-temperature and high-pressure thermal recovery, and anticorrosion injection-production integrated lifting technology. The proposed method was applied to a pilot test in the YS3 well in the LKQ oil field. The high-pressure ignition was achieved in the 2200-m-deep well using the coiled-tubing electric igniter. The maximum temperature tolerance of the integrated monitoring system in coiled tubing reached up to 1200°C, which provided the functions of distributed temperature and multipoint pressure measurement in the entire wellbore. The combination of 13Cr-P110 casing and titanium alloy tubing effectively reduced the high-temperature and high-pressure oxygen corrosion of the wellbore. The successful field test of the comprehensive supporting engineering technologies presents a new approach for effective production in deep extra-heavy-oil reservoirs.

Phase Behaviour and Physical Properties of Dimethyl Ether DME/CO2/Water/Heavy Oil Systems under Reservoir Conditions

2021 ◽  
Author(s):  
Desheng Huang ◽  
Yunlong Li ◽  
Daoyong Yang
Keyword(s):  
Physical Properties ◽  
Heavy Oil ◽  
Vapour Phase ◽  
Thermal Recovery ◽  
Phase Behaviour ◽  
Binary Interaction ◽  
Molar Ratio ◽  
Polar Components ◽  
Translation Strategy ◽  
Oil Mixtures

Abstract In this paper, techniques have been developed to quantify phase behaviour and physical properties including phase boundaries, swelling factors, and phase volumes for reservoir fluids containing polar components from both experimental and theoretical aspects. Experimentally, a total of five pressure-volume-temperature (PVT) experiments including three sets of DME/CO2/heavy oil systems and two sets of DME/CO2/water/heavy oil systems have been carried out to measure saturation pressures, phase volumes, and swelling factors by using a versatile PVT setup. Theoretically, the modified Peng-Robinson equation of state (PR EOS) incorporated with the Huron-Vidal mixing rule and the Péneloux volume-translation strategy is employed as the thermodynamic model to perform phase equilibrium calculations. It is observed that the experimentally measured saturation pressures of DME/CO2/water/heavy oil mixtures are higher than those of DME/CO2/heavy oil mixtures at the same temperature and same molar ratio of solvents and heavy oil, owing to the fact that more water molecules can be evaporated into vapour phase. The binary interaction parameters (BIPs) between DME/heavy oil and CO2/DME pair, which are obtained by matching the measured saturation pressures of DME/CO2/heavy oil mixtures, work well for DME/CO2/heavy oil mixtures in the presence and absence of water. In addition, a swelling effect of heavy oil can be enhanced by adding the DME and CO2 mixtures compared to only DME or CO2. The new model developed in this work is capable of accurately reproducing the experimentally measured multiphase boundaries, swelling factors, phase volumes with a root-mean-squared relative error (RMSRE) of 4.68%, 0.71%, and 9.35%, respectively, indicating that it can provide fundamental data for simulating, designing, and optimizing the hybrid solvent-thermal recovery processes for heavy oil reservoirs.

Research Status and Prospect of Heavy Oil Recovery Technology

2021 ◽  
Vol 888 ◽  
pp. 111-117
Author(s):  
Yi Zhao ◽  
De Yin Zhao ◽  
Rong Qiang Zhong ◽  
Li Rong Yao ◽  
Ke Ke Li
Keyword(s):  
Oil Recovery ◽  
Heavy Oil ◽  
Development Trend ◽  
Thermal Recovery ◽  
Hot Water ◽  
Water Flooding ◽  
Oil Reservoir ◽  
Heavy Oil Recovery ◽  
Steam Flooding ◽  
Heavy Oil Reservoir

With the continuous exploitation of most reservoirs in China, the proportion of heavy oil reservoirs increases, and the development difficulty is greater than that of conventional reservoirs. In view of the important subject of how to improve the recovery factor of heavy oil reservoir, the thermal recovery technology (hot water flooding, steam flooding, steam assisted gravity drainage SAGD and steam huff and puff) and cold recovery technology (chemical flooding, electromagnetic wave physical flooding and microbial flooding) used in the development of heavy oil reservoir are summarized. The principle of action is analyzed, and the main problems restricting heavy oil recovery are analyzed The main technologies of heavy oil recovery are introduced from the aspects of cold recovery and hot recovery. Based on the study of a large number of literatures, and according to the development trend of heavy oil development, suggestions and prospects for the future development direction are put forward.

The Application of the Multi-Component Thermal Fluid Huff and Puff Technology to Daqing Heavy Oil Block

2021 ◽  
Author(s):  
Xianjun Wang ◽  
Xiangbin Liu ◽  
Borui Li ◽  
Qiang Yin ◽  
Zhonglian Han ◽  
...  
Keyword(s):  
High Temperature ◽  
Corrosion Inhibitor ◽  
Oil Recovery ◽  
Heavy Oil ◽  
Thermal Recovery ◽  
Gas Absorption ◽  
Composition Ratio ◽  
Steam Flooding ◽  
Gas Channeling ◽  
Lock In

Abstract The reservoir of Daqing Heidimiao Oilfield (permeability 1736×10−3μm2) contains heavy oil, with the average viscosity of 3306 mPa•s. It is developed by steam flooding and steam huff and puff, however, the recovery rate is only 14.6%. Therefore, the multi-component thermal fluid huff-and-puff technology is applied to, dealing with pertinent problems such as gas channeling, corrosion and oil pump lock in the process so as to improve oil recovery and production. Mechanism: Cooling by water, the ultra-high temperature gas generated via combustion of diesel or natural gas with air produces a multi-component thermal fluid containing CO2,N2 and vapor, combining the advantages of gas absorption and thermal recovery. Simulation: A multi-component and multi-phase percolation model is built to optimize the huff-and-puff parameters including composition ratio, temperature and injection volume. Supporting techniques: a high temperature oil-and-acid resistant foam system to form a precedent-blocking slug and automatically adjust the huff-and-puff profile. a dedicated low-cost and high-efficiency corrosion inhibitor system to realize corrosion-resistance. a four-node down-hole gas-liquid separation device to increase efficiency. The comprehensive reduced-viscosity rate is more than 30%; high-pressure air chambers, ranging from 0.2 to 2.0MPa, are formed for elastic energy replenishment. Field tests show the average annual oil increase per well is about 3800 barrels, with the highest being about 7200 barrels. The numerical simulation results show that the optimal composition ratio (N2: CO2: vapor) is 5:1:1.5, that the best injection amount is 30∼50×104Nm3 and that the injection temperature is preferably 280 ∼ 300 °C. The oil-and-acid resistant foaming agent has improved recovery efficiency, as a significantly improved profile of gas absorption, and the oil extraction degree increases by about 31.5%. High temperature corrosion is prevented, through intermittent injection of high-temperature-resistant corrosion inhibitor (corrosion inhibition rate 70.5% at 350 °C), and the frequency of pipeline corrosion is reduced averagely by 98.5%. Air-lock in pump vanishes via gas-liquid separation devise, with the average indoor pump efficiency increases by more than 50% (gas-liquid ratio ≤3000m3/m3)and the one in field test increases from less than 20% to over 45%. More importantly, the maintenance period has reached 662d. This technology has been applied to 98 wells in Daqing to date, 95 of which are stimulated successfully. The multi-component thermal fluid huff-and-puff technology solves the problems such as gas channeling, corrosion and air-lock in pumps through supporting techniques and the synergism of steam flooding and thermal recovery to enhance oil recovery and can be used as a superseded technology after steam huff-and-puff treatment to increase the EUR, especially for heavy oil reservoirs with medium and high permeability.

The Slag Influence on High Temperature Resistance of Aluminophosphate Cementfor Heavy Oil Thermal Recovery

2014 ◽  
Vol 33 (4) ◽  
pp. 325-328 ◽  
Author(s):  
Zaoyuan Li ◽  
Yan Wang ◽  
Xiaowei Cheng ◽  
Xiaoyang Guo
Keyword(s):  
Compressive Strength ◽  
High Temperature ◽  
Low Temperature ◽  
Heavy Oil ◽  
Thermal Recovery ◽  
Temperature Resistance ◽  
High Temperature Resistance ◽  
Zonal Isolation ◽  
Cement Strength ◽  
Isolation Performance

AbstractThe sharp strength recession of silicate cement in high temperature is the crucial reason of casings damage and zonal isolation failure in heavy oil thermal recovery. Although aluminophosphate cement has a better high temperature resistance in comparison with silicate cement, its compressive strength recession in high temperature slightly recessed. The results show that adding slag into aluminophosphate cement can not only develop compressive strength of cement at low temperature, but it can also improve the high temperature resistance of the cement. After adding slag, the formation of C2ASH8 conduces to develop cement strength at low temperature, and C3AS2H2 conduces to high temperature resistance. To increase temperature resistance of aluminophosphate cement, C3ASH4 generation and Al(OH)3 decomposition should be avoided. Crystal structure of cement after high temperature is well developed with compactly and neatly arranged, allowing cement to maintain good mechanical properties to help protect the casing and improve zonal isolation performance.

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