Status of Heavy-Oil Development in China

Shouliang, Z.; Yitang, Zhang; Wu, Shuhong; Liu, Shangqi; Li, Xiuluan; Li, Songlin

doi:10.2118/97844-ms

Cited by 22 publications

(3 citation statements)

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“…According to the reservoir depth, those with depths exceeding 900 m, classified as deep heavy oil reservoirs, account for more than 80% of China’s proven heavy oil reservoirs. Taking the Shengli Oilfield as an example, with formation depths generally exceeding 1500 m, the total reserve is 7680.2 × 10 4 tons, and it is largely untapped, indicating significant development potential. − …”

Section: Introductionmentioning

confidence: 99%

Synthesis and Application of Viscosity Reduction and Pour Inhibition Systems for Deep Heavy Oil

Meng,

Lu,

Wang

et al. 2024

Energy Fuels

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A targeted viscosity reduction and pour inhibition mixed system was developed to address the issues of high steam injection pressure, low thermal efficiency, and field incompatibility in deep heavy oil reservoirs. A pour inhibitor was synthesized from monomeric acrylic acid octadecyl ester and vinyl acetate, and a low-molecular weight viscosity reducer was synthesized from dopamine hydrochloride and methacryloyl chloride. The viscosity reduction and pour inhibition systems were constructed by compounding the pour inhibitor and viscosity reducer at different mass ratios. The viscosity reduction rate, pour inhibition performance, resistance of stability, mineralization, and temperature of the systems were tested and evaluated. The results showed that the viscosity reduction and pour inhibition systems exhibited high stability and a wide range of temperature and mineralization resistance. The system demonstrated viscosity reduction and pour inhibition effects in the mass concentration range of 2–10%, with the effectiveness increasing with higher concentration. At a concentration of 10%, the viscosity reduction rate reached 95.2% and the pour point decreased by 10.2 °C. Among them, the mixed system by compounding the pour inhibitor, viscosity reducer, and polyglycerol-10 caprylate in a mass ratio of 40:50:10 exhibited the best viscosity reduction and pour inhibition effects. Laboratory core flooding tests showed that the optimized mixed system had a recovery rate of 32.8% for heavy oil samples, significantly higher than that of traditional displacement methods such as water flooding, polymer flooding, and surfactant flooding. A field test was conducted, and the results demonstrated a significant increase in oil fluidity and oil production.

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Section: Introductionmentioning

confidence: 99%

Synthesis and Application of Viscosity Reduction and Pour Inhibition Systems for Deep Heavy Oil

Meng,

Lu,

Wang

et al. 2024

Energy Fuels

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“…Thin heavy oil reservoirs are widely distributed in Venezuela, Canada, and China. For example, the pay zone thickness of 55% of heavy oil resources in Saskatchewan, Canada, is less than 5 m while 50% of the reserves in Liaohe, China, have a pay zone thickness of less than 8 m. , The oil recovery factor of the water-flooding process in these formations are as low as 10–20% original oil in place (OOIP) due to extremely high oil viscosity, the adverse mobility ratio between heavy oil and water, and water channeling. − In addition, thermal recovery methods (e.g., cyclic steam stimulation and steam-assisted gravity drainage), which are the most common commercial in situ recovery methods for heavy oil, − have been considered unsuitable and inefficient due to the severe steam override, steam channeling, and significant heat loss to the over- and under-burden formations . Thus, it is urgent to find an efficient and economic enhanced oil recovery (EOR) method to recover the huge amount of residual oil in these thin reservoirs.…”

Section: Introductionmentioning

confidence: 99%

Polymer-Enhanced Foam Flooding for Improving Heavy Oil Recovery in Thin Reservoirs

et al. 2020

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Oil reserves of the thin heavy oil reservoirs are estimated to be over 400 billion barrels. The recovery factor of waterflooding in these reservoirs is as low as 10−20% due to the high oil viscosity and correspondingly unfavorable mobility ratio. In addition, the commonly used thermal recovery methods are also unsuitable in such formations due to the significant heat loss to the adjacent formations. Thus, it is urgent to find an efficient and economic enhanced oil recovery (EOR) method to maximize the recovery factors in the thin heavy oil reservoirs. In this study, the feasibility of polymer-enhanced foam (PEF) flooding for the thin heavy oil reservoirs is investigated using the micromodel and core-flood experiments. The micromodel experiments show that foam quality has significant effects on the resistance factor and heavy oil recovery of the PEF flooding, where the displacement front of a low-quality foam case is more even than that of a high-quality foam case and surfactant−polymer (SP) flooding case. Core-flood tests further reveal that there is an optimal slug size under the experimental conditions, and the heavy oil recovery of PEF flooding is 23.9% higher than that of SP flooding when using the same slug size. Finally, a field-scale reservoir simulation is conducted, and the results show that after initial water-flooding in thin heavy oil reservoirs, the recovery factor achieved by the PEF flooding is 11.7% higher than that of the SP flooding and 21.4% higher than that of the continuous water-flooding process.

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“…If increasing the temperature of saturated steam, the pressure keeping unchanged or changed a little. Then superheated steam is gotten [6] , which has a higher temperature, carries more heat and has greater heating capacity than saturated steam.…”

Section: Introductionmentioning

confidence: 99%

Superiority of Superheated Steam Flooding in Development of High Water-Cut Heavy Oil Reservoir

et al. 2012

AMR

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The dryness of superheated steam is 100% and it exists in the form of pure steam whose properties are like ideal gas. When the steam has a large degree of superheat, it may take a relatively long time to cool, during which time the steam is releasing very little energy and transmitted long distances. The heating radius of superheated steam in the formation is 5-10m larger than saturated steam. In the heating area of superheated steam, the comprehensive effects by superheated steam (crude oil viscosity reduction, improved flow environment, changes in rock wettability and improved oil displacement efficiency, etc.) is much higher than that of saturated steam. Superheated steam stimulation in Kenkyak high water cut heavy oil reservoir pilot test results showed that the average daily oil production of single well by superheated steam stimulation was 2-4 times than that of saturated steam stimulation. Superheated steam is more effective to heat water-invaded oil reservoir than saturated steam.

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Status of Heavy-Oil Development in China

Abstract: fax 01-972-952-9435. AbstractChina has significant heavy oil deposit of more than 1.9

Cited by 22 publications

References 0 publications

Synthesis and Application of Viscosity Reduction and Pour Inhibition Systems for Deep Heavy Oil

Synthesis and Application of Viscosity Reduction and Pour Inhibition Systems for Deep Heavy Oil

Polymer-Enhanced Foam Flooding for Improving Heavy Oil Recovery in Thin Reservoirs

Superiority of Superheated Steam Flooding in Development of High Water-Cut Heavy Oil Reservoir

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