Materia-Rio de Janeiro
·
2025
·
IF 1.2
Yu Meng,Xu Guorui,Li Liang,Zhou Jingjing,Tie Leilei,Zhang Bo,Ma Xiaofei,Feng Xuan,Yang Jinzhou,Wang Lei,Li Weizhi,Zheng Yufei,Wu Bao
VISUAL
研究领域:
石油工程
·
油田化学
·
提高采收率
·
油藏工程
✓ 已验证
产品关联
DOI
高影响因子
Petroleum Science
·
2024
·
IF 6
Wei-Peng Wu,Min Yang,Dong-Chen Ma,Ji-Rui Hou,Tuo Liang,Ming Qu,Tao Tan,Biao Yang,Guo-Rui Ma
In-depth profile control is a crucial technique employed to enhance oil recovery in fractured-vuggy carbonate reservoirs. However, it is a challenge to achieve in-depth profile control. In this paper, two types of organic gel systems, namely s-MPG and MSRG, tailored for fractured-vuggy reservoirs with 140 °C and 22 × 10 4 mg/L have been developed. FTIR was used to analyze the functional groups of s-MPG and MSRG. Additionally, the quality retention rates of s-MPG and MSRG were assessed using TG-DSC, yielding results of 92.85% and 92.65%, respectively. The dilution rates of s-MPG and MSRG are found to be 18.69% and 26.69%, respectively, demonstrating excellent compatibility and adaptability. The enhancement performance depends on the synergistic effect that the anti-dilution s-MPG effectively separates bottom water, while high-strength MSRG separates the oil layer. Moreover, the EOR performances of s-MPG synergy with MSRG in various types of fractured-vuggy carbonate models were also evaluated. The highest oil recovery of 12% is achieved in fracture network model. Laboratory results indicate that the synergistic combination of s-MPG and MSRG for water plugging in fractured-vuggy carbonate reservoirs results in a more effective enhancement of oil recovery compared to using a single gel system for plugging. Finally, the s-MPG synergy with MSRG has been applied in actual fractured-vuggy carbonate reservoirs. As expected, the water cut of typical well is reduced from 100% to 30% and the increased oil production is 1142 t totally. Therefore, this study presents a novel approach to achieving in-depth profile control by leveraging the synergistic effect of s-MPG with MSRG in fractured-vuggy carbonate reservoirs.
研究领域:
石油工程
·
化学工程
✓ 已验证
DOI
高影响因子
Energies
·
2019
·Vol. 12
·期 5
·781
·
IF 2.707
Songyan Li,Chenyu Qiao,Guowei Ji,Qun Wang,Lei Tao
Foam is a kind of ideal fluid for profile control in petroleum engineering, which has attracted intense interests of scholars globally in recent years. In this study, a foam system stabilized with anionic surfactants and clay particles was proposed for profile control in reservoirs, and the formulation was optimized experimentally. Moreover, flooding experiments in visible porous media models and in sandpacks were conducted to test the plugging effect of the foam system on reservoirs, and the effects of different factors such as gas–liquid ratio, temperature and permeability on profile control were also evaluated. According to the experimental results, the clay-HY-2 system was elected for its satisfactory foamability, stability, and salinity resistance, and the optimum concentrations of HY-2 and clay particle are 0.6 wt% and 5.0 wt%, respectively. Compared with traditional foam fluids, the clay-HY-2 system can form denser and smaller bubbles in high- and middle-permeable layers, enhancing the plugging effect there, while there are less bubbles in low-permeable layers, i.e., the restriction on the flow in narrow structures is slight. The clay-HY-2 foam can perform the efficient and uniform profile control effect on sandpacks when the foam quality is around 50%. The resistance factor of the foam decrease gradually with the increasing temperature, however, the resistance factor remains higher than 350.0 when the temperature reaches 80.0 °C. When the permeability exceeds 1502.0 mD, the clay-HY-2 foam can perform deep profile control in reservoirs, and the resistance factor are not sensitive to the change of permeability when it exceeds 3038.0 mD. Besides, the site application case shows that the clay-HY-2 foam do have good profile control effect on reservoirs, i.e., improving oil production and declining water cut.Keywords:clay enhanced foam;profile control;enhance oil recovery (EOR);site application
研究领域:
石油工程
·
化学工程
✓ 已验证
产品关联
DOI
高影响因子
Processes
·
2020
·Vol. 8
·期 9
·1021
·
IF 2.753
Daiyin Yin,Shuang Song,Qi Xu,Kai Liu
The matrix/fracture conductivity of a fractured low-permeability reservoir is variable, and its heterogeneity is serious. When carrying out deep profile control measures, it is difficult to inject under the premise of ensuring the plugging effect. According to the characteristics of the fractured low-permeability reservoir in Chaoyanggou Oilfield, the polymer/chromium ion deep profile control system was optimized via a viscosity evaluation experiment, liquidity experiment and oil displacement experiment. The experimental results show that the high molecular weight main agent/low concentration system and low molecular weight main agent/high concentration system can meet the gel strength requirement. The evaluation results of the injection ability and plugging performance of the fractured low-permeability core show that a high molecular weight profile control system is difficult to inject, while a low molecular weight profile control system has a poor plugging performance and high cost after simulated shear. Therefore, the formulation of the profile control system was determined to be a polymer with a molecular weight of 16 million g·mol−1as the main agent with a concentration of 1000–1500 mg·L−1. As assisting agents, the concentrations of thiourea, NaCl and NaHCO3were 900 mg·L−1, 800 mg·L−1and 700 mg·L−1, respectively. The plugging rate of the system was 87.6%, and the resistance coefficient was 19.2. Finally, a fractured low-permeability core model with parallel long cores was designed, and the optimal profile control system was used for the core oil-displacement experiment. Compared with the water-flooding experiment, the plugging rate can be increased by 6.9–8.0%.Keywords:fractured low-permeability reservoirs;polymer/chromium-ion;deep profile control system
研究领域:
石油工程
·
化学工程
✓ 已验证
产品关联
DOI
高影响因子
MOLECULES
·
2023
·Vol. 28
·期 7
·3125
·
IF 4.6
Jiqiang Zhi,Yikun Liu,Jinfeng Chen,Lifeng Bo,Guohui Qu,Nan Jiang,Weizhong He
We targeted high-temperature and highly saline old oil fields, whose environmental conditions could be attributed to the significantly high heterogeneity cause by long-term water flooding. The Huabei Oilfield was chosen as the research object. We developed a hydrophobic functional monomer–polymer with temperature and salt resistance by introducing the temperature-resistant and salt-resistant monomer NVP and a hydrophobic functional monomer into the main chain for copolymerization. We used a crosslinking agent with phenolic resin to prepare a weak gel system that showed temperature and salt resistance and investigated its temperature and salt resistance, infective property, plugging performance, liquid flow ability, micropore throat migration, and plugging characteristics. The results obtained using the infrared spectroscopy technique revealed the successful preparation of the phenolic resin crosslinker. The weak gel exhibited good temperature and salt resistance when the polymer concentration was 2000 mg/L, the cohesion ratio was 1:1.5, the additive concentration was 2000 mg/L, the reservoir temperature was 120 °C, and the injected water salinity was 40,300.86 mg/L. The average viscosity retention rate of the 90-day weak gel reached more than 80% and its microstructure was examined. The coreflow experiment results revealed that the weak gel system was characterized by good infectivity. After plugging the weak gel, the effect on the direction of the liquid flow was evident and the flow rate of the low permeability layer increased to a maximum of 48.63% under conditions of varying permeability levels. A significant improvement in the water absorption profile was achieved. The plugging was carried out through a sand-filling pipe under varying permeability conditions and the pressure measuring points in the sand-filling pipe were sucessfully pressurized. The migration ability of the weak gel was good and the blocking rate was >85%.Keywords:temperature and salt tolerance;weak gel preparation;profile control;fluid flow direction;plugging performance
研究领域:
石油工程
·
材料科学
✓ 已验证
产品关联
DOI
PubMed
高影响因子
Petroleum Science
·
2024
·
IF 6
Bo-Zhao Xu,Dong-Fang Lv,Dai-Yu Zhou,Ning Sun,Si-Yu Lu,Cai-Li Dai,Guang Zhao,Ming-Ming Shi
Novel wet-phase modified expandable graphite (WMEG) particles were developed for in-depth profile control in carbonate reservoirs. The harsh environment of carbonate reservoirs (≥ 130 °C, ≥ 22 × 10 4 mg/L) brings significant challenges for existing profile control agents. WMEG particles were developed to address this problem. WMEG particles were synthesized via intercalation with ultrasound irradiation and chemical oxidation. The critical expansion temperature of WMEG particles is 130 °C, and these particles can effectively expand 3–8 times under high temperature and high salinity water. The core flow experiments show that WMEG particles exhibit a good plugging capacity, profile control capacity, and a better-enhanced oil recovery (EOR) capacity in deep carbonate reservoirs. WMEG particles can be expanded in the formation and form larger particles that bridge the upper and lower end faces of the fracture. Then the high-permeability zones are effectively plugged, and the heterogeneity is improved, resulting in an obvious increase in oil recovery. This research provides a novel insight into future applications of profile control agents for in-depth profile control treatment in carbonate reservoirs.
研究领域:
石油工程
·
材料科学
✓ 已验证
产品关联
DOI
高影响因子
JOURNAL OF APPLIED POLYMER SCIENCE
·
2022
·Vol. 139
·期 45
·e53110
·
IF 3.057
Qihai Wang,Bin Chen,Xiujun Wang,Yifan Wang,Weixin Hu,Ming Duan,Shenwen Fang
Polyacrylamide (PAM) microsphere has been widely used in the field of profile control to reduce water cut in heterogeneous reservoirs. However, its mechanical strength and plugging ability are still needed to be improved. In this paper, a core-shell structure and surface-hydrophobic polyacrylamide M-P(AM-PEP) microsphere was prepared by using acrylamide (AM), block polyether macro monomer (PEP) and modified SiO 2 with double bond on the surface as monomers through dispersion polymerization. After the optimization of synthesis conditions, the results of SEM and TEM confirmed that M-P(AM-PEP) microsphere had the nano-scale spherical shape and the inorganic core/polymer shell structure, while the contact angle test results showed that M-P(AM-PEP) microsphere had the surface-hydrophobicity. Swelling experiments presented that the size of M-P(AM-PEP) microsphere can be increased by 6 times and had obvious self-gathering behavior. The inorganic core and self-gathering behavior are helpful for improving mechanical strength and plugging ability of PAM microsphere, respectively. Profile control and oil recovery improvement experiment showed that injecting 0.1 PV M-P(AM-PEP) microsphere can decrease the water cut and increase the oil recovery of 17.95%. This new microsphere could be an efficient technology for the profile control in the heterogeneous reservoir.
研究领域:
石油工程
·
高分子化学
✓ 已验证
产品关联
DOI
高影响因子
ACS Applied Polymer Materials
·
2025
·
IF 4.7
Yan Xue,Honghai Long,Hong Xu,Xunyu Zhang,Bing Wei,Jun Lu
Gel treatment is a highly effective technique for conformance control, significantly managing water production and enhancing oil recovery in mature reservoirs. However, the performance of conventional hydrogel systems often deteriorates under harsh conditions such as elevated temperatures and high salinity. To overcome this limitation, we developed a hydrogel with exceptional stretchability and resilience by integrating phenyl nanospheres (PNSs) as nanocross-linkers within polyampholyte chains. The PNSs were synthesized through precipitation polymerization of divinylbenzene in a water/ethanol solvent. P(AM-AMP-DAD)PNS gels were fabricated by copolymerizing acrylamide (AM) with equimolar amounts of 2-acrylamido-2-methylpropanesulfonate sodium (AMPS-Na) and diallyl dimethylammonium chloride (DADMAC), utilizing PNSs as cross-linkers. This unique structure achieved a remarkable breaking elongation of 920% at 100 kPa and exhibited no fractures after five cycles at 400% strain. Hydrophobic interactions among PNSs created dynamic association domains, enabling reversible energy dissipation and improving mechanical robustness. The antipolyelectrolyte effect of the polyampholyte chains provided exceptional fracture resistance in ultrahigh-salinity environments. The swelling ratio of P(AM-AMP-DAD)PNS gels remained stable and even slightly increased in formation water, particularly at 130 °C, where it was 1.2 times higher than at room temperature. Furthermore, this hydrogel demonstrated long-term stability under extreme conditions (130 °C, 2.2 × 105 mg L–1 salinity, Ca2+ + Mg2+ = 1.3 × 104 mg·L–1) for up to 60 days. Core-flooding tests revealed that the fractured core, treated with P(AM-AMP-DAD)PNS particles and subjected to high-temperature aging, achieved a breakthrough pressure exceeding 6 MPa, with a plugging efficiency of 99.93%. These results confirm the hydrogel’s superior plugging performance under ultraharsh reservoir conditions, making it a promising candidate for enhanced oil recovery applications.
研究领域:
材料科学
·
石油工程
✓ 已验证
产品关联
DOI
高影响因子
ACS Omega
·
2023
·
IF 4.1
Hongda Hao,Jiaxin Li,Song Deng,Bihua Xian,Zheng Tang,Shuo Yang,Jirui Hou
The high-temperature reservoir (105 °C) in the Liubei block of Jidong Oilfield, with severe longitudinal heterogeneity, has entered a high water-cut stage. After a preliminary profile control, the water management of the oilfield still faces serious water channeling problems. To strengthen water management, N2 foam flooding combined with gel plugging for enhanced oil recovery was studied. In this work, considering a high-temperature reservoir of 105 °C, a composite foam system and starch graft gel system with high temperature resistance were screened out, and displacement experiments in one-dimensional heterogeneous cores were carried out. Through the three-dimensional experimental model and numerical model of a 5-spot well pattern, physical experiments and numerical simulations were carried out respectively to study water control and oil increase. The experimental results showed that the foam composite system had good temperature resistance up to 140 °C and oil resistance up to 50% oil saturation and was helpful to adjust the heterogeneous profile in a high temperature of 105 °C. The starch graft gel system had good injection performance, with a solution viscosity of 18.15 mPa·s, and its gel strength could effectively seal the high-permeability layer, with a gel viscosity of 34950.92 mPa·s. The displacement test results showed that after a preliminary implementation of N2 foam flooding, N2 foam flooding combined with gel plugging could still improve oil recovery by 5.26%. Compared with preliminary N2 foam flooding, gel plugging could control the water channeling in the high-permeability zone near the production wells. The combination of foam and gel made N2 foam flooding and subsequent waterflooding divert to flow mainly along the low-permeability layer, which was conducive to enhance water management and improve oil recovery. This method can be used as an effective technology to manage similar heterogeneous reservoirs.
研究领域:
石油工程
·
化学工程
✓ 已验证
产品关联
DOI
PubMed
高影响因子
POLYMER COMPOSITES
·
2016
·Vol. 39
·期 2
·368-376
·
IF 2.004
Tian-Hong Zhao,Ji-Yue Xing,Wan-Fen Pu,Zhi-Ming Dong,Cheng-Dong Yuan,Guo-Feng Peng,Fa-Yang Jin,Ji-Jia Xia
Polyacrylamide-montmorillonite organic-inorganic composites (poly[AM/O-MMT]) were synthesized by copolymerization of acrylamide (AM) on organic modified montmorillonite (O-MMT) using N , N -methylene-bis-acrylamide (MBA) as a crosslinker and ammonium persulfate (APS) as an initiator in an aqueous solution. The montmorillonite (MMT) was modified by methacryloyloxy ethyl dimethyl hexadecyl ammonium bromide (DMB) which was synthesized by 2-(dimethylamino) ethyl methacrylate with 1-bromohexadecane. The FTIR and XRD were used to verify the organification of MMT with DMB. The effects of the amount of the DMB and O-MMT on water absorption were studied. The swelling behavior in different saline solution and re-swelling ability in distilled water were investigated. The results showed that DMB and O-MMT content have an important effect on the water absorption of the composites. The addition of the DMB enhanced the salt resistance and delayed the swelling speed of the poly(AM/O-MMT). Simultaneously, the toughness was measured. The water blocking and profile control ability were evaluated by core physical simulation experiments. The results indicated that the poly(AM/O-MMT) has good plugging ability and profile control ability. The properties tested indicated that the poly(AM/O-MMT) has a promising prospect to be applied as a profile control or water shut-off agent for enhanced oil recovery in high salinity reservoirs. POLYM. COMPOS., 39:368–376, 2018. © 2016 Society of Plastics Engineers
研究领域:
石油工程
·
材料科学
·
化学工程
✓ 已验证
DOI
高影响因子
COLLOIDS AND SURFACES A-PHYSICOCHEMICAL AND ENGINEERING ASPECTS
·
2019
·
IF 3.131
Xuechen Tang,Bobo Zhou,Chao Chen,Bauyrzhan Sarsenbekuly,Hongbin Yang,Wanli Kang
Due to the superior performance caused by surface modification and combined effects, polymer/nano-SiO 2 composites have been studied systematically for a long term and attracted increasing academic and industrial interests, especially in the petroleum engineering field. However, few works have been done on the mechanism that how the functional modification degree ( MD ) of nano-SiO 2 influences on the properties of the composites. In this work, a series of 3-(methacrylyloxy)propyltrimethoxysilane (MPS) modified nano-SiO 2 particles with different MD s were prepared and found to differ largely from each other in macroscopic properties . Then the effects of SiO 2 MD on the physicochemical property and the enhanced oil recovery (EOR) capacity of the corresponding polymer/nano-SiO 2 composite microspheres (PNSCMs) for the conformance control in oilfields were investigated in detail. The results clarified that by regulating the MD of nano-SiO 2 encapsulated in PNSCMs, the swelling property, viscoelasticity , mechanical strength and dispersion stability were significantly improved. Compared with traditional chemical copolymer microspheres CPMs, PNSCMs exhibited better conformance control and EOR ability, which was further improved as SiO 2 MD increased. The maximum oil recoveries of cores treated by PNSCMs were 76.14% and 52.45% in the experiment, and the EOR increased by 5.99% and 4.99% than those treated by CPMs, respectively, under homogeneous and heterogeneous conditions.
研究领域:
石油工程
·
材料科学
✓ 已验证
DOI
高影响因子
MOLECULES
·
2024
·Vol. 29
·期 11
·2596
·
IF 4.2
Guohui Qu,Bowen Li,Yikun Liu,Zilu Zhang,Lifeng Bo,Jiqiang Zhi,Xuebin Tian,Xiaorui Bai,Xiunan Li,Qi Lv
Polymer microspheres with temperature and salt resistance were synthesized using the anti-suspension polymerization method, incorporating the functional monomers AMPS, AM, and AA. To enhance their self-gelling properties, the microspheres were designed with a core–shell structure. The shell is composed of a polymeric surfactant, fatty alcohol polyoxyethylene ether methacrylate (AEOMA), which serves as a thermosensitive crosslinking agent, enabling self-crosslinking upon shell decomposition, addressing compatibility with reservoir pore throat dimensions. Comprehensive characterizations including infrared spectroscopy, scanning electron microscopy, optical microscopy, and laser particle size analysis were conducted. The microspheres exhibited successful synthesis, a nanoscale size, and regular spherical morphology. They demonstrated excellent temperature and salt resistance, making them suitable for high-temperature, high-salinity reservoir profile control. With a stable three-dimensional network structure, the microspheres displayed good expansion behavior due to hydrophilic groups along the polymer chains, resulting in favorable water affinity. Even after aging, the microspheres maintained their gelling state with a distinct and stable microscopic network skeleton. They exhibited superior plugging performance in low-permeability reservoirs, while effectively improving water absorption profiles in reservoirs with permeability contrasts of 10 to 80, thereby enhancing oil recovery.
研究领域:
石油工程
·
高分子材料
·
油田化学
·
提高采收率
✓ 已验证
DOI
高影响因子
危险品化学品经营许可证（带存储）