Sand Conglomeration Trial as an Alternative to Sand Control: Case Study from Mahakam Delta, Indonesia

Styward, B.; Wijaya, Ryan; Manalu, Dasa; Wahyudhi, F.; Setiawan, Thomas; Dading, Albert Malvin; Rizal, M. Choirul; Widarena, Tri Maharika; Lukman, Geraldie; Primasari, Indah; Merati, Putu Astari; Hezmela, Rizka; Fuad, Muhammad Busyrol; Nwafor, Chidi; Liu, Hai; Singh, Pratyush

doi:10.2118/191987-ms

Cited by 8 publications

(2 citation statements)

References 5 publications

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“…As the pH of the fluid increases, the critical flow velocity for sand production decreases. When the pH of the fluid reaches 14, the sand production rate can increase sharply (Malau A et al, 2017;Mahmoudi M et al, 2018;Styward B et al, 2018;Wang X, 2018).…”

Section: Geological Factorsmentioning

confidence: 99%

A critical review on analysis of sand producing and sand-control technologies for oil well in oilfields

He,

Pang,

Ren

et al. 2024

Front. Energy Res.

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Sand production in oil wells seriously affects the production of oil and gas in oilfields. Although conventional sand-control techniques can effectively prevent sand production, it may also limit the productivity of oil wells. Fracturing and packing sand control technology changes the distribution of pressure and flow in the wellbore, while foam polymer resin diversion technology reduces the anisotropy of reservoir permeability and increases the area of oil leakage in the reservoir, both achieving the goal of sand control and increased production. The sand-free production rate is successfully increased thanks to zeta potential sand control technology, which modifies the formation’s sand potential and causes the sand to agglomerate without harming the reservoir. This article first looks into the causes of sand production in oil and gas wells before examining the fundamentals, implementation strategies, and effects of traditional sand control techniques, fracturing and filling sand control technology, foam polymer resin diversion technology, and Zeta potential sand control technology. In this article, the experience of sand control technology in actual oil field applications is summarized, explained in detail, and the future development possibilities of sand control technology are discussed.

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Section: Geological Factorsmentioning

confidence: 99%

A critical review on analysis of sand producing and sand-control technologies for oil well in oilfields

He,

Pang,

Ren

et al. 2024

Front. Energy Res.

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“…(3) Incomplete acid flowback in screen tube well section and formation deficit section will lead to screen tube corrosion and affect the effective period of sand control. In order to prolong the effective period of sand control for horizontal wells in unconsolidated sandstone formation and improve the productivity of single wells, it is necessary to analyze the main factors that affect the uniform acid entering into the formation, optimize the balanced acid washing reverse drainage technology on this basis, and improve the production effect of horizontal wells [15][16][17][18][19] .…”

Section: Introductionmentioning

confidence: 99%

Uniform Acid Cleaning Technology and Its Application in Horizontal Wells with Open Hole Screen Tube

Jia,

Cui,

Sui

et al. 2023

J. Phys.: Conf. Ser.

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After the completion of the open hole sieve tube in a horizontal well, it is necessary to replace the slurry and put it into production. Generally, circulating acid outside the tube cannot fully remove mud pollution. The acidification process needs to fully consider the heel effect of horizontal wells. Based on the horizontal pipe flow model and the characteristics of foam diversion, a mathematical model of acid washing suitable for open hole screen horizontal wells is established. Analysis suggests that lower flow rates and higher fluid viscosity during the acid washing process are more conducive to the uniform entry of the plugging solution into the formation. We have designed a uniform liquid mixing equipment with a flow blocking mechanism, and improved the acid washing construction process to achieve negative pressure reverse discharge of acid solution. This process can achieve uniform entry of the unblocking fluid into the formation after passing through the screen gap, and remove the blockage of the mud layer inside and outside the near screen tube. The horizontal wells using this process have a 30% increase in production capacity compared to oil wells in the same block, and the high yield validity period has been extended by 680 days.

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An experimental study of epoxy-based nanocomposite for chemical consolidation in a sandstone reservoir with high clay content

Banashooshtari,

Khamehchi,

Rashidi

et al. 2024

J Petrol Explor Prod Technol

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Sand production poses a substantial challenge in the oil and gas field, particularly in formations lacking the requisite strength to withstand pressure differentials during extraction. Many wells produce much less than their capacity due to the need to mitigate sand production and prevent well completion and wellhead erosion. The choice of sand control method depends on various factors, such as reservoir conditions, operational methods, and economic considerations, encompassing both mechanical and chemical approaches. In response to this challenge, this study investigates the application of a novel polymer nanofluid for chemical consolidation in clay-rich sandstone reservoirs, an area of exploration yet to be fully tapped. The research aims to assess the potential of polymer nanofluids as a promising solution for sand control in clay-rich reservoirs, with the overarching goal of bolstering well productivity and mitigating the adverse impacts of sand production. Conducted at a laboratory scale, the experiments involved the injection of 1 Pore Volume of consolidation fluid into sandstone cores with 15% and 30% clay content. Subsequently, the cores were subjected to reservoir temperature and pressure conditions for a period of 24 h. The obtained results show a significant enhancement in compressive strength, exceeding 700 psi, facilitated by the polymer nanofluid. Furthermore, permeability restoration reached approximately 89%, a notable improvement compared to preceding studies. Moreover, the introduction of foam injection rendered the core surface water-wet, suggesting potential advantages for reservoir management. These findings illuminate the promise of polymer nanofluids as an effective tool for sand control in clay-rich sandstone reservoirs.

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Sand Conglomeration Trial as an Alternative to Sand Control: Case Study from Mahakam Delta, Indonesia

Cited by 8 publications

References 5 publications

A critical review on analysis of sand producing and sand-control technologies for oil well in oilfields

A critical review on analysis of sand producing and sand-control technologies for oil well in oilfields

Uniform Acid Cleaning Technology and Its Application in Horizontal Wells with Open Hole Screen Tube

An experimental study of epoxy-based nanocomposite for chemical consolidation in a sandstone reservoir with high clay content

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