A dynamic scale location monitor method to predict oilfield blockage during water flooding

Kang, Wanli; Wang, Tongyu; Zhang, Hongwen; Hou, Xiaoyu; Zhang, Xiangfeng; Zhu, Tongyu; Chen, Chao; Yang, Hongbin

doi:10.1016/j.petrol.2020.107168

Cited by 14 publications

(8 citation statements)

References 24 publications

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“…The terms of the m j are in turn m p,q,j = β j 1 RT ∂µ p,j ∂n q,j + 1 (7) Then, the elemental balance (Equation 3b) is also linearized with respect to the working variables n i,j . The correction vector for each phase (∆n j ) must satisfy the following equation:…”

Section: The Modified Rand Methods For Closed Systemsmentioning

confidence: 99%

“…As a consequence, simulators for processes in natural environments ought to have robust and efficient chemical and phase equilibrium (CPE) algorithms, i.e., algorithms that can predict phase behavior with multiple solid and fluid phases in the presence of reactions. Recent examples of applications using such tools for mathematical description include: the study of groundwater [2,3], the simulation of geothermal energy recovery and storage [4,5,6], the study of water compatibility issues [7], the analysis of microbial activity [8], and the modeling of CO 2 underground geological storage (UGS) [9].…”

Section: Introductionmentioning

confidence: 99%

See 1 more Smart Citation

RAND-based geochemical equilibrium algorithms with applications to underground geological storage of CO2

Medeiros

Stenby

Yan

2021

Advances in Water Resources

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Section: The Modified Rand Methods For Closed Systemsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

RAND-based geochemical equilibrium algorithms with applications to underground geological storage of CO2

Medeiros

Stenby

Yan

2021

Advances in Water Resources

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“…Waterflooding in oil industry is essential to oil production, for it supplies producing energy and thus improves the efficiency of development. However, it also brings problems, such as scaling and corrosion, which may pose a big threat to the oilfield system [1].In the injection process, inorganic and organic solids could form in the reservoir, wellbore, surface pipelines, and pump [2,3], thus damaging the formation and reducing production. Moreover, equipment is likely to be impaired, which results in a significant rise in production costs [4,5].The precipitation of carbonate and sulfate scale is the main inorganic scales existing in oil reservoirs and producing wells [6,7].…”

Section: Introductionmentioning

confidence: 99%

Theoretical and Experimental Antiscaling Performance Study of Several Inhibitors to Prevent Barium Sulfate Formation during Water Injection in Oil Reservoirs

2023

Geofluids

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One of the hazards from mineral precipitation during oilfield production is scaling, which mainly manifests in the following three aspects: it leads to reduction in permeability, in deliverability, and in water intake capacity of reservoir; the flowing area of pipeline shrinks, which could elevate the fluid flow resistance and even lead to well shut; and scaling could also contribute to pressure loss and may cause tube blasting when it is serious. Therefore, scaling not only improves production costs but also poses a serious threat to production safety. The injection of scale inhibitors in the process of water flooding is the main method to combat scale build-up. Efficiency of inhibitor or adsorption between inhibitor and scale is the key factor that determines success or failure of the scale inhibitor squeeze treatments. Previous studies have confirmed that interaction between the inhibitor and the scale surface plays an important role in scale prevention and control. Although many studies have been carried out on inhibitor efficiency and inhibition mechanism, a comprehensive understanding of inhibitor-scale interaction is yet available and the adsorption behavior between inhibitor and scale surface requires further research. Thereupon, this study presents performance evaluation and computational study of three inhibitors, including EDTMPS, DTPMP, and DTPA-5Na based on the scaling prediction result of the Huaqing oilfield. It was found that BaSO4 was the main type of scaling and the antiscaling performance of the three inhibitors was experimentally displayed as DTPA-5Na > DTMP > EDTMPS at the concentration from 40 mg/L to 120 mg/L. SEM micrographs of BaSO4 surfaces in the absence and presence of inhibitors at the concentration of 80 mg/L showed that the inhibitors obviously influenced the process of crystal growth of BaSO4 by lattice distortion and chelate effect. In addition, density functional theory (DFT) calculations unraveled that adsorption capacity of inhibitors interacting with three surfaces of BaSO4 increased in the order of DTPA-5Na > EDTMPS > DTPMP. DPTA-5Na was likely to be chemisorbed on the surfaces of BaSO4 while DTPMP and EDTMPS tended to be adsorbed on (210) and (001) surfaces of BaSO4 by chemical and physical effect, respectively. Calculation of difference charges and DOS analysis indicated that DTPA-5Na interacted with BaSO4 by combining atoms of oxygen and sodium to form new chemical bonds while EDTMPS and DTPMP interacted with BaSO4 by combining hydrogen and oxygen atoms to form physical bonds. The research results can provide a better understanding of the interaction between inhibitors and scale surfaces and can also lay scientific foundation for barite scale prevention and further development of inhibitors.

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“…The increase in permeability resistance is substantially greater than that of the high-permeability layer for the same injection volume. The injection pressure increases with the amount of adsorbed polymer in the reservoir. − To prevent polymer loss owing to reservoir fractures, the injection pressure must be lower than the fracturing pressure. Consequently, in the case of continuous polymer injection, once the injection pressure exceeds the top limit, the adsorption pressure difference in each layer at the injection end progressively decreases, and the injectivity of the polymer injection well gradually diminishes and even approaches zero.…”

Section: Introductionmentioning

confidence: 99%

Mechanistic Study on the Decrease in Injectivity during Salt-Resistant Polymer Flooding

et al. 2022

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According to numerous laboratory experiments and field applications, polymer flooding can effectively modify the liquid absorption profile and increase the sweep efficiency, thereby enhancing the oil recovery. However, long-term injection of polymers decreases the effective permeability of the reservoir and plugs the formation pores, resulting in irreversible reservoir damage. In the development process, polymer types and concentrations must be selected according to the reservoir to avoid problems such as plugging of the formation pores. This study was aimed at clarifying the degree of plugging and the injection limit of the reservoir when a salt-resistant polymer (SRP) is used in production processes of the Daqing Oilfield. To this end, oil displacement experiments, dynamic and static adsorption experiments, and SEM observations were performed using representative reservoir fluid and core samples. The static adsorption of “medium-molecular” SRP reached equilibrium after 36 h, and the saturated adsorption capacity was 3.56 mg/g, which was approximately 2–5 times the dynamic adsorption capacity. For medium-molecular SRP, with a molecular mass of 7 million, the lower limit of the core permeability was 20–40 mD. When the permeability was less than 100 mD, the SRP concentration injected into the core could not exceed 900 mg/L. The oil displacement capacity of SRP decreased owing to the macromolecular hydration radius and the strong aggregation effect of SRP. Polymer adsorption and the retention of sand-carrying critically decreased water permeability. This study provides insights into SRP flooding under different geological conditions in the Daqing Oilfield and can help clarify the molecular mass and concentration of polymers with changes in the reservoir conditions.

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A dynamic scale location monitor method to predict oilfield blockage during water flooding

Cited by 14 publications

References 24 publications

RAND-based geochemical equilibrium algorithms with applications to underground geological storage of CO2

RAND-based geochemical equilibrium algorithms with applications to underground geological storage of CO2

Theoretical and Experimental Antiscaling Performance Study of Several Inhibitors to Prevent Barium Sulfate Formation during Water Injection in Oil Reservoirs

Mechanistic Study on the Decrease in Injectivity during Salt-Resistant Polymer Flooding

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