Springer Proceedings in Physics, pages 403-410

Study and Application of Solid Dissolving Agent in Water Injection Well

Wei Jiang 1
Chen Huang - 1
Yonggen Yi 1
Xinru Huang 1
Jianwei Wang 2
Cai Xiaojun 3
Ziyi Wei 1
Yubo Lian 1
1
 
Xi’an Changqing Chemical Group Co., Ltd, PetroChina Changqing Oilfield Company, Xi’an, China
3
 
Oil Production Plant 11, PetroChina Changqing Oilfield Company, Xi’an, China
Publication typeBook Chapter
Publication date2024-09-30
SJR0.135
CiteScore0.4
Impact factor
ISSN09308989, 18674941
Abstract
Aiming at the scaling condition of Fuyu oil well in the eighth oil recovery plant of Daqing Oilfields, we selected the excellent amino sulfonic acid, solid hydrochloric acid and complexing agent EDTA as the scale inhibitor formula, and determined that the ratio was 4:1:1. The scale experiment is carried out in the field. When the scale temperature is 60°, the scale removal efficiency can reach more than 90%, and the scale of the former 5 h is faster, and the scale removal rate can reach over 50%. The field test shows that the scaling effect of the scale acid bar formed by the curing process is good, and it effectively solves the serious scaling phenomenon of the water injection pipe column.
Mahmoodi L., Malayeri M.R., Farshchi Tabrizi F.
2022-01-01 citations by CoLab: 16 Abstract  
Scale formation in upstream oil operations may cause lower production rate, higher operational costs and detrimental environmental impacts when hazardous chemical inhibitors should be used to combat scaling. Green scale inhibitors (SI) are also gaining increased attention but their utilization is still a matter of much debate with many open questions to be addressed. In this study, green SIs, i.e., folic acid and inulin were investigated from experimental and theoretical perspectives. In the experimental part, two brines were mixed incompatibly through standard high-temperature static tests i) to examine the performance of green SIs and also ii) to discern their optimum concentrations and pH. Furthermore, SEM (Scanning Electron Microscopy) and EDX (Energy Dispersive X-ray) analyses were carried out to identify mechanisms under which the mitigation of scale precipitation would take place. The results revealed that folic acid and inulin could optimally be applied with concentrations of 450 mg/L (pH = 4) and 600 mg/L (pH = 6), respectively. SEM analyses also showed that the dominant inhibition mechanism for folic acid was crystal modification whereas it was threshold inhibition for inulin. Moreover, based on the extended Derjaguin-Landau-Verwey-Overbeek (XDLVO) theory, the work of cohesion was calculated which confirmed that folic acid and inulin retarded calcite from getting precipitated almost %65 and 54%, respectively. Finally, the performance of a commercial phosphonated SI was also investigated for the sake of comparison with the green SIs which confirmed their comparable efficacy. • Assessment of two green scale inhibitors for utilization at reservoir conditions. • Experimentally optimization of concentration and pH of green scale inhibitors. • Utilization of surface energy theory to calculate the inhibition efficiency. • Comparable efficacy of green scale inhibitors with respect that of commercial one.
Chen J., Chen F., Han J., Su M., Li Y.
2020-05-08 citations by CoLab: 24
Gamal H., Elkatatny S., Al Shehri D., Bahgat M.
Sustainability scimago Q1 wos Q2 Open Access
2020-03-20 citations by CoLab: 10 PDF Abstract  
The oil and gas production operations suffer from scale depositions. The scale precipitations have a damaging impact on the reservoir pores, perforations, downhole and completion equipment, pipeline network, wellhead chokes, and surface facilities. Hydrocarbon production possibly decreased because of the scale accumulation in the well tubular, leading to a well plugging, this requires wells to be shut-in in severe cases to perform a clean-out job. Therefore, scale deposition is badly affecting petroleum economics. This research aims to design a scale dissolver with low cost, non-damaging for the well equipment and has a high performance at the field operating conditions. This paper presents a novel non-corrosive dissolver for sulfate and sulfide composite scale in alkaline pH and works at low-temperature conditions. The scale samples were collected from a production platform from different locations. A complete description of the scale samples was performed as X-ray diffraction (XRD) and X-ray fluorescence (XRF). The new scale dissolver was prepared in different concentrations to examine its dissolution efficiency for the scale with time at low temperatures. The experimental design studied the solid to fluid ratio, temperature, solubility time, and dissolution efficiency in order to achieve the optimum and most economic performance of solubility in terms of high dissolution efficiency with the smallest possible amount of scale dissolver. A solubility comparison was performed with other commercial-scale-dissolvers and the corrosion rate was tested. The experimental work results demonstrated the superior performance of the new scale dissolver. The new scale dissolver showed a solubility efficiency of 91.8% at a low temperature of 45 °C and 79% at 35 °C. The new scale dissolver showed a higher solubility ratio for the scale sample than the ethylenediaminetetraacetic acid (EDTA) (20 wt. %), diethylenetriamine pentaacetic acid (DTPA) (20 wt. %), and HCl (10 wt. %). The corrosion rate for the new non-corrosive dissolver was 0.01357 kg/m2 (0.00278 lb./ft²) which was considered a very low rate and non-damaging for the equipment. The low corrosive effect of the new dissolver will save the extra cost of adding the corrosion inhibitors and save the equipment from the damaging effect of the corrosive acids.
Wei L., Xie J., Yu J., Cai S., Zhang W., Yan H., Ma Z., Su N., Gao M., Liu S., Qin Z.
2019-12-01 citations by CoLab: 2 Abstract  
Abstract In water-injection development, water-sensitive oil deposits are prone to water injection pressure increase and water injection volume decrease, which makes it difficult to complete production and injection allocation. To solve this problem, on the basis of screening traditional anti-expansion unblocking agents, and combined with the performance evaluation of the formula and core experiment, a reasonable improvement scheme was proposed in this paper to develop a new type water-sensitive oil reservoir anti-expansion unblocking agent. The performance evaluation experiment shows that it has an applicable dissolution rate for oil rock samples and can dissolve inorganic salt scale; the anti-expansion rate is up to 90%; the core dynamic evaluation experiment shows that the core permeability can be increased more than double after the injection of the anti-expansion unblocking agent. The new type water-sensitive anti-expansion unblocking agent were used in 7 wells of the site, and all of them have a good effect of water injection pressure decrease and water injection volume increase.
Sajil Kumar P.J.
SN Applied Sciences scimago Q2 wos Q2 Open Access
2019-04-03 citations by CoLab: 23 PDF Abstract  
In this study, corrosiveness and scaling potential of groundwater in the Thanjavur district are evaluated based on the chemical analyses of 34 groundwater samples and GIS-based geostatistical mapping techniques. Total dissolved solid values show that six out of 34 samples exceeded the WHO drinking water standard 1000 mg/L. Piper plot shows that majority of the samples are mixed Ca–Mg–Cl type, Ca–HCO3 type and Na–Cl. The results of the physicochemical parameters were used to calculate the most popular corrosion and scaling indices such as Langelier index (LI), aggressive index (AI), Ryznar index (RI), Puckorius index (PI) and Larson–Skold index (LS). Results of LI show that 41% samples have corroding tendency (LI < 0) and 59% of the samples have scaling tendency (LI > 0). AI has the same result as 41% of the water is moderately corrosive and the remaining has scaling tendency. RI suggests that 88% of the samples have corrosive tendency and 12% have rigorous corrosive tendency. Values of the PI suggest that all the samples were corrosive. Finally, the LS values show that 62% of the samples have scaling tendency and the remaining have corrosion tendency. In general, groundwater in the Thanjavur district shows both corrosive and scaling tendencies, which can cause severe damage to the machineries in the industries. Spatial variation of the corrosive and scaling indices suggests that the central region of the district has more corrosive tendencies and the western and eastern regions have more scaling tendencies.
Wang L., Zhu C., Liu H., Zhao W., Che Y., Zhang Q., Wang L.
2019-01-10 citations by CoLab: 24
Kamal M.S., Hussein I., Mahmoud M., Sultan A.S., Saad M.A.
2018-12-01 citations by CoLab: 207 Abstract  
In oil and gas industry operations, scale deposition on the surface and subsurface production equipment can cause different problems such as formation damage, loss in production, pressure reductions, and premature failure of down hole equipment. Due to geochemical processes between injection water, connate water and rock, the complex composition of reservoir fluids make it difficult to control the inorganic scale formation. Carbonate (calcium), sulfide (iron, zinc), and sulfate (calcium, barium, strontium) scales are more common in oilfield applications. The scale formation depends on several factors that include, but not limited to, temperature, pressures, solution saturation and hydrodynamic behaviour of the flow. This paper reviews different types of scales that are common in oil and gas production operations, their sources and formation mechanisms. The focus of this review is on the different chemicals that are used for the removal of different scales. Hydrochloric acid is one of the classical chemicals used since for most of the mineral scales are soluble in HCl. However, HCl is not environmentally-friendly and causes corrosion and could be very expensive particularly in high-temperature conditions due to the need of using many additives to reduce corrosion. This review discusses several alternatives to HCl that are more environment-friendly in removing oilfield scale deposits. These alternatives are mainly organic acids and chelating agents which have been successfully applied in different fields.
Li N., He D., Zhao L., Liu P.
2016-05-01 citations by CoLab: 4 Abstract  
At present, most oilfields are developed by applying water-flooding technology. However, this technology is often accompanied by inorganic scale deposition on water- and oil-pipe and equipment walls due to the incompatibility between the injection fluid and formation water and for other reasons. Barium and strontium sulfates are highly resistant to the acids that are generally used as scale dissolvers. In this work, a new chelating-agent-based alkaline barium- and strontium-sulfate scale dissolver named SA-209 has been developed. Many of its important parameters such as salt concentration, reaction time, pH value, temperature, etc. that affect de-scaling efficiency are evaluated by experiments and analysis. This dissolver has a high de-scaling rate and low equipment and pipe corrosion, is environment-friendly, and so would have a promising application in oilfields.
Hasson D., Shemer H., Semiat R.
2015-10-09 citations by CoLab: 14

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