State Key Laboratory of EOR

Beijing, China

State Key Laboratory of EOR

Beijing, China
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Zhu Y.,State Key Laboratory of EOR | Zhu Y.,Petrochina | Hou Q.,State Key Laboratory of EOR | Hou Q.,Petrochina | And 6 more authors.
Shiyou Kantan Yu Kaifa/Petroleum Exploration and Development | Year: 2013

Great success has been achieved in the fundamental study and field test of chemical combination flooding in recent years. In China, a low concentration ASP formula is employed to achieve ultra-low interfacial tension by the synergistic effect of alkali and surfactant. The viscosity of polymer solution made from produced water can meet the technological requirement when salt tolerance polymer is applied. ASP or SP flooding can increase oil displacement efficiency and enlarge the sweep volume simultaneously. ASP pilot test and industrial field test in Daqing Oilfield have resulted in an oil recovery increase of 18.5%-26.5%. The chemical combination flooding has entered into the industrial promotion and application stage, with a series of supporting techniques formed in the field tests. The main challenges in this technique include short pump-checking period and difficulty in produced liquid handling and high cost. Micelle-polymer flooding as the major chemical flooding technique was applied abroad in the early stage of chemical flooding test. However, the micelle-polymer flooding has not been applied widely due to its high cost. With the rise of oil price in recent years, low concentration chemical combination flooding has drawn more attention. Because of high temperature and high salinity in most reservoirs abroad where chemical combination flooding is used, high performance temperature and salt tolerance oil displacement agents are the bottleneck for future chemical flooding.


Zhu Y.,State Key Laboratory of EOR | Zhu Y.,Petrochina | Zhang Y.,State Key Laboratory of EOR | Zhang Y.,Petrochina | And 6 more authors.
Petroleum Exploration and Development | Year: 2012

Alkali-free surfactant-polymer SP flooding can avoid scaling, strong emulsification and corrosion caused by alkali, thus reduce the investment and operating cost. It is a new chemical flooding technology for Enhanced Oil Recovery (EOR) with a promising application prospect. The main problems of SP flooding are as follows: shortage of industrialized surfactant product with high performance, weak theoretical research on oil displacing mechanisms and main influencing factors, unsound evaluation methods, lack of pilot tests, and high technical risk. The main factors that affect the oil displacement efficiency of SP flooding are displacing fluid viscosity, interfacial tension, and emulsification strength of SP system. The high viscosity of SP flooding formula system is an important guarantee of EOR process. The lower the interfacial tension, the higher the oil recovery degree is. The emulsify ability of SP system can significantly affect efficiency of oil displacing. SP flooding process has obtained certain effects in pilot tests but there are still some problems. The formula adaptability and quality stability of surfactant product should be improved, the injection program should be optimized, and the field monitoring and process tracking and regulation should be strengthened. © 2012 Research Institute of Petroleum Exploration & Development, PetroChina.


Zhu Y.,State Key Laboratory of EOR | Zhu Y.,Petrochina | Zhang Y.,State Key Laboratory of EOR | Zhang Y.,Petrochina | And 6 more authors.
Shiyou Kantan Yu Kaifa/Petroleum Exploration and Development | Year: 2012

Alkali-free surfactant-polymer SP flooding can avoid scaling, strong emulsification and corrosion caused by alkali, thus reducing the investment and operating cost. It is a new chemical flooding technology for Enhanced Oil Recovery (EOR) with a promising application prospect. The main problems of SP flooding are as follows: shortage of industrialized surfactant product of high performance, weak theoretical research on oil displacing mechanisms and main influencing factors, unsound evaluation methods, lack of pilot tests, and high technical risk. The main factors that affect the oil displacement efficiency of SP flooding are displacing fluid viscosity, interfacial tension, and emulsification strength of SP system. The high viscosity of SP flooding formula system is an important guarantee of EOR process. The lower the interfacial tension, the higher the oil recovery degree. The emulsifiability of SP system can significantly affect efficiency of oil displacing. SP flooding process has obtained certain effects in pilot tests but there are still some problems. The formula adaptability and quality stability of surfactant product should be improved, the injection program should be optimized, and the field monitoring and process tracking and regulation should be strengthened.


Zhou T.-Y.,National energy 2 capture and storage research and development center | Zhou T.-Y.,State Key Laboratory of EOR | Zhou T.-Y.,Petrochina
Advanced Materials Research | Year: 2013

According to laboratory physical simulation methods, Achieve the infiltration experiment of overheated steam in the porous medium. The experiment researched overheated steam's improvement to damage and undamaged porous mediums. Permeability was increased 1 to 4 times in the damaged porous mediums, 3 to 6 times in those undamaged. The microstructure of porous medium is characterized by scanning electron microscope photos. A lots of mineral microcrystal adhered on the initial rock particle surface. After the infiltration experiment of overheated steam, mineral microcrystal decreased obviously, and the rock particle surface changes into even and smoothly, which made the filtration resistance precipitous declined. Based on theory assumptions, production calculation formulas were derived in some given conditions. And the regular pattern plate map out, which affected by overheated steam heating radius and water-damaged radius. The results turns out that, inject overheated steam can achieve obviously production increasing. © (2013) Trans Tech Publications, Switzerland.


Wang G.,State Key Laboratory of EOR | Wang G.,Petrochina | Wang G.,National Energy Co 2< Inf> Flooding And Storage Experiment nter | Zheng X.,Petrochina | And 8 more authors.
Shiyou Kantan Yu Kaifa/Petroleum Exploration and Development | Year: 2015

Since the existing gas flooding reservoir screening criteria lack economic indexes reflecting future dynamic production performances, indexes reflecting economic profits are added into the exiting criteria (related single well production indexes) to form a new method of selecting low permeability reservoirs suitable for CO2 flooding. Reservoir engineering methods of single well peak oil production rate (OPR) prediction for gas drive tight reservoirs is given by employing the concept of "OPR multiplier due to gas flooding". Based on the technical economics principles, the method calculating the economical limit OPR of CO2 flooding is also presented. On this basis, a new screening criterion of reservoirs suitable for CO2 flooding is proposed: if the peak OPR predicted by reservoir engineering method is higher than the economic limit OPR, the target reservoir is suitable for CO2 flooding. Furthermore, a four-step reservoirs screening method is advanced: technical screening, economic screening, feasibility evaluation, recommendation of optimal gas flooding blocks. The new screening criteria were applied to evaluate the CO2 flooding potential of seventeen blocks in an oilfield, which ended up with only 32.4% of the geologic reserves from conventional method suitable for CO2 flooding. It is recommended blocks suitable for CO2 flooding be selected according to the new criterion to ensure economic success. ©, 2015, Science Press. All right reserved.


Pingping S.,State Key Laboratory of EOR | Pingping S.,Petrochina | Xinglong C.,State Key Laboratory of EOR | Xinglong C.,Petrochina | And 2 more authors.
Petroleum Exploration and Development | Year: 2010

In the initial period of CO2 flooding, formation pressures of reservoirs do not increase noticeably. Physical simulation experiments were designed to study this phenomenon. In the 1-D infill-sand model, it was found that, under the same pressure conditions, the densities of distilled water, salt water and crude oil increased with CO2 dissolution, and then reached stability. By the volume decrease calculation of the liquid and the distilled water dissolution experiment, it was confirmed that the effects of CO2 dissolved in oil and water are the main reasons for any pressure decrease. In the 2-D sand plate model, injection pressure also decreased. By analyzing production PV (pore volume) and injection PV curves, it was found that the main reason for the pressure decrease is that the injected CO2 can flow into the minute pores that are unavailable to oil and water, and comparatively speaking, dissolution of CO2 can be neglected. The result is also proven by porosity calculations and CO2 flooding experiments using different production control methods and by using carbonate cores. © 2010 Research Institute of Petroleum Exploration & Development, PetroChina.


Caineng Z.,State Key Laboratory of EOR | Caineng Z.,Petrochina | Guangya Z.,State Key Laboratory of EOR | Guangya Z.,Petrochina | And 29 more authors.
Petroleum Exploration and Development | Year: 2010

Large and extra-large oil/gas fields are mainly distributed in Tethys areas, passive margins, foreland thrust belts, and craton basins in the world. Unconventional oil/gas fields are mainly distributed in foreland slopes, basin (depression) centers, craton synclines, and tundra. Since the 21st century, the major exploration discoveries across the globe have been mainly concentrated in the deep water area of passive margins, carbonate rock, lithologic-stratigraphic zone, foreland thrust belt, mature exploration area, new basin and unconventional oil/gas reservoir (field). These major discoveries involve conventional and unconventional oil/gas resources. The conventional oil geology stresses the oil/gas migration and reservoir-forming rules in individual traps; the unconventional oil geology focuses on unconventional resources, reservoir, reservoir-formation and technologies. The geological features, classification program, research content, evaluation method and exploration phase of unconventional oil/gas reservoirs (fields) are different from those of conventional ones. Research should be strengthened on unconventional oil geology to develop unconventional oil geological theories. © 2010 Research Institute of Petroleum Exploration & Development, PetroChina.


Zou C.,Petrochina | Zou C.,State Key Laboratory of EOR | Dong D.,Petrochina | Dong D.,State Key Laboratory of EOR | And 12 more authors.
Petroleum Exploration and Development | Year: 2010

With Sichuan Basin as focus, this paper introduces the depositional environment, geochemical and reservoir characteristics, gas concentration and prospective resource potential of three different types of shale in China: marine shale, marine-terrigenous shale and terrigenous shale. Marine shale features high organic abundance (TOC: 1.0%-5.5%), high-over maturity (Ro: 2%-5%), rich accumulation of shale gas (gas concentration: 1.17-6.02 m3/t) and mainly continental shelf deposition, mainly distributed in the Paleozoic in the Yangtze area, Southern China, the Paleozoic in Northern China Platform and the Cambrian-Ordovician in Tarim Basin; Marine-terrigenous coalbed carbonaceous shale has high organic abundance (TOC: 2.6%-5.4%) and medium maturity (Ro: 1.1%-2.5%); terrigenous shale in the Mesozoic and Cenozoic has high organic abundance (TOC: 0.5%-22.0%) and mid-low maturity (Ro: 0.6-1.5%). The study on shale reservoirs in the Lower Paleozoic in Sichuan Basin discoveried nanometer-sized pores for the first time, and Cambrian and Silurian marine shale developed lots of micro- and nanometer-sized pores (100-200 nm), which is quite similar to the conditions in North America. Through comprehensive evaluation, it is thought that several shale gas intervals in Sichuan Basin are the practical targets for shale gas exploration and development, and that the Weiyuan-Changning area in the Mid-South of Sichuan Basin, which is characterized by high thermal evolution degree (Ro: 2.0%-4.0%), high porosity (3.0%-4.8%), high gas concentration (2.82-3.28 m3/t), high brittle mineral content (40%-80%) and proper burial depth (1500-4500 m), is the core area for shale gas exploration and development, the daily gas production for Well Wei 201 is 1×104-2×104 m3.thomampe © 2010 Research Institute of Petroleum Exploration & Development, PetroChina.


Xulong W.,Petrochina | Mengjun Z.,Petrochina | Mengjun Z.,State Key Laboratory of EOR | Mengjun Z.,China National Petroleum Corporation | And 6 more authors.
Petroleum Exploration and Development | Year: 2010

Natural gas in the Ludong-Wucaiwan area is characterized by typical source-controlled reservoirs. Combining outcrop data, well data and seismic data, this article makes a systematic research and evaluation on the abundance, type, and maturity characteristics of the Carboniferous source rocks in the Ludong-Wucaiwan area. The Carboniferous source rocks are dominantly dark grey and grey mudstones, secondarily tuffs, carbonaceous mudstones, silty mudstones and coals. The source rock abundance of the Upper Carboniferous Batamayineishan Formation (C 2b) is higher than that of the Lower Carboniferous Dishuiquan Formation (C 1d), while the kerogen type of the Lower Carboniferous source rock is better than that of the Upper Carboniferous. The maturity center of the Carboniferous source rocks is located in the west part of Dinan uplift to the Wucaiwan depression area, with maturity decreased towards south and north. The distributions of the Carboniferous source rocks and volcanic rocks are complementary. The source rocks are distributed in zonal shape in east-west direction, and are most developed in the west part of the Dinan uplift and its southern area. © 2010 Research Institute of Petroleum Exploration & Development, PetroChina.


Wang G.,State Key Laboratory of EOR | Wang G.,Petrochina | Wang G.,National Energy 2 Flooding and Storage Experiment R and nter | Zheng X.,Petrochina | And 8 more authors.
Petroleum Exploration and Development | Year: 2015

Since the existing gas flooding reservoir screening criteria lack economic indexes reflecting future dynamic production performances, indexes reflecting economic profits are added into the exiting criteria (related to well oil production rate) to form a new method of selecting low permeability reservoirs suitable for CO2 flooding. Reservoir engineering methods of average well peak oil production rate prediction for gas drive is given by employing the concept of "Oil production rate multiplier due to gas flooding". Based on the principles of technical economics, the method calculating the economical limit well oil production rate of CO2 flooding is also presented. On this basis, a new screening criterion of reservoirs suitable for CO2 flooding is proposed: if the peak well oil production rate predicted by reservoir engineering method is higher than the economic limit well oil production rate, the target reservoir is suitable for CO2 flooding. Furthermore, a four-step reservoirs screening method is advanced: technical screening, economic screening, fine feasibility evaluation, recommendation of optimal gas flooding blocks. The new screening criteria were applied to evaluate the CO2 flooding potential of seventeen blocks in an oilfield, which ended up with only 32.4% of the original oil in place from conventional method suitable for CO2 flooding. It is recommended blocks suitable for CO2 flooding be selected according to the new procedure to ensure economic success. © 2015 Research Institute of Petroleum Exploration & Development, PetroChina.

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