Chemical Sand Consolidation as an Effective Alternative to Conventional Sand Control Methods in Ecuador

Abstract

This paper shows the results from chemical sand consolidation treatments used in the M1 sandstone as the main sand control method. For a successful implementation of this technique a workflow that combines field data, temperature modeling, laboratory analysis, petrophysics and geomechanics has been developed. Production results reports zero to near zero sand production with almost no impact on well productivity. Pre job design steps used to secure a consolidated reservoir after the treatment are described. Temperature is a key parameter to model since the resin is temperature activated. Laboratory tests and simulated temperature defines the curing time. A step rate test is used to calculate the injectivity index and evaluate the need for an acid stimulation treatment before the consolidation system is pumped into the well. This test is repeated after curing time to evaluate any possible impact on productivity. Determination of the Unconfined Compressive Strength (UCS) of the consolidation sand and critical sand production rate are also included in the analysis to understand sand production potential in the field. Chemical sand consolidation consists of two main components, resin and hardener. The consolidation fluid along with a pre-flush and an over-flush have typically been pumped into the well using production tubing. This sand control method has been proven to be relatively low in cost compared to other sand control techniques and the treatment can be performed in a relatively short period of time. These two characteristics and the positive production results observed thus far makes this technique attractive for upcoming sand control completions with unconsolidated reservoirs with similar characteristics to the M1 sandstone. In addition, conventional sand control methods rely on a particle size distribution (PSD) from a representative core sample for a successful implementation whereas chemical sand consolidation system is PDS independent.

Chemical sand production control: a review of materials, methods and characterization

“…Compared to conventional dense resins, the pores of the porous polyurethane provide seepage channels that limit permeability reduction . Many field applications have shown that resin injection for sand production control can effectively improve reservoir mechanical properties and reduce sand production (El-monier et al, 2013;Shang et al, 2019;Izurieta et al, 2020;Mahardhini et al, 2021;Zaitoun et al, 2022;Miri et al, 2023;Peerakham et al, 2023;Stephen Babagbemi et al, 2023).…”

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

“…On the other hand, production factors are closely related to mining methods, production pressure differences, mining speeds, and wellbore design. Unreasonable mining methods, excessive production pressure differences, or excessively fast mining speeds can all increase the scouring force of fluids on the particles of the reservoir framework, leading to sand production (Izurieta A et al, 2020;Ayazi P et al, 2021;Hasmin et al, 2022a;Mandhari S et al, 2022).…”

“…In its application, there are two common forms: sand control pipe technology and improved sand control pipe technology -gravel packing technology for pipe strings. The former mainly establishes a sand barrier within the wellbore using sand control pipes, while the latter primarily relies on the compaction of gravel between the sand control pipe and the casing to block the flow of ceramsite, and also uses sand control pipes within the wellbore for sand prevention (Hurt R S and Germanovich L N, 2012;Dong, C., et al, 2016;Safaei, A., et al, 2023b).…”

A Review on Chemical Sand Production Control Techniques in Oil Reservoirs

“…This method also causes a sharp decline in permeability due to filling the porous media around the wellhead. In earlier methods, known as underground methods, the injection process occurs in three stages . First, some soluble monomers are injected into the formation to fill the space between the sands.…”

“…In earlier methods, known as underground methods, the injection process occurs in three stages. 155 First, some soluble monomers are injected into the formation to fill the space between the sands. In the second stage, an inert fluid is injected to move the monomers through the pores into the formation and prevent the blockage of these porous media.…”