Development and Field Applications of an Aqueous-Based Consolidation System for Remediation of Solids Production

Villesca, Josue; Hurst, Gary; Bern, P.A.; Nguyen, Philip; Rickman, Richard Dale; Dusterhoft, Ron

doi:10.4043/20970-ms

Cited by 5 publications

(1 citation statement)

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“…In the case of operational feasibility, resins could not be easily embedded in the formation rock. Improper and unsafe aspects of fluid caused by acids and solvents as well as problems such as the application of surface equipment and pumping systems are among the other constraints of using resin materials (Villesca et al 2010). Regarding the limited time of pumping, injection of highly viscous resin solutions into the formation leads to unsatisfactory operation of the formations with permeability less than 50 mD (Sydansk 1988).…”

Section: Introductionmentioning

confidence: 99%

Polyacrylamide hydrogel application in sand control with compressive strength testing

2018

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Sand production is one of the major problems in sandstone reservoirs. Different mechanical and chemical methods have been proposed to control sand production. In this paper, we propose a chemical method based on using polyacrylamide/ chromium triacetate hydrogel to investigate sand production in a synthetic sandpack system. To this end, a series of bulk experiments including the bottle test and rheological analysis along with compression tests were conducted. Experimental results indicated that the compressive strength of the sandpack was increased as much as 30 times by injecting 0.5 pore volume of hydrogel. Also, it was found that the increases in cross-linker and polymer concentrations exhibited a positive impact on the compressive strength of the sandpack, mostly by cross-linker concentration (48 psi). Hydrogel with a higher value of cross-linker could retain its viscoelastic properties against the strain which was a maximum of 122% for 0.5 weight ratio of cross-linker/polymer. The presence of salts, in particular divalent cations, has a detrimental effect on the hydrogel stability. The maximum strain value applied on hydrogel in the presence of CaCl 2 was only about 201% as compared to 1010% in the presence of distilled water. Finally, thermogravimetric analysis and its derivative showed that the hydrogel could retain its structure up to 300°C. The results of this study revealed the potential application of the hydrogel to control sand production.

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Section: Introductionmentioning

confidence: 99%

Polyacrylamide hydrogel application in sand control with compressive strength testing

2018

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Advanced Sand Control Chemistry to Increase Maximum Sand Free Rate with Improved Placement Technique - A Case Study

Mason

Shamma²,

Petegem³

et al. 2014

SPE Annual Technical Conference and Exhibition

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The reliability of the production is essential in offshore operations. Producing a well at its maximum rate is important everywhere. This is often compromised by having sand and fines production which not only plugs the wells and reduce production rate but also erode the equipment and settle in surface vessels. This paper describes a case history where an operator was faced with a well that was rate limited because of fines and sand production. An advanced sand control chemistry system was proposed and a treatment was designed. In April 2013, the treatment was performed by bullheading down the production tubing using rate diversion. Extensive engineering was involved in the candidate selection and planning the operational aspects of the treatment. The execution of the treatment was divided into stages – sand clean out, performing step rate test, pre-job modeling and pumping the treatment as per the design. After the treatment, the well was flowed and tested at almost three times the original maximum sand-free rate (MSFR) at an increased choke without sand production. The well has now been flowing for more than a year, at significantly higher rate than the previous MSFR sand free. This paper describes the chemistry of the sand conglomeration, design consideration, execution and the effect on well performance.

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Successful Field Application of Aqueous-Based Formation Consolidation Treatment Implemented in Nile Delta, Egypt

et al. 2014

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Sand production can be challenging for many operators in unconsolidated formations. The production of formation sand and fines can cause erosion damage to both surface and downhole equipment, resulting in major well intervention and sand disposal costs. Conventional resin consolidation systems have been successfully used to prevent solids production in short, homogenous intervals. However, resin consolidation attempts in longer intervals have resulted in erratic success rates, which could be attributed to a lack of complete and uniform treatment of the entire interval length. A recently developed aqueous-based resin (ABR) system has helped provide effective and efficient treatment of significantly longer intervals, has improved health, safety, security, environmental (HSSE) compatibility, and can help improve various operational considerations. This paper discusses results of laboratory testing and the subsequent successful treatment using the ABR system within a well located in Nile Delta, which was the first attempt of its kind in Egypt. Sieve analysis revealed unsorted formation sand, which usually requires a gravel pack completion, rather than a standalone screen; however, because of limitations with respect to wellbore diameter (5 in.), it was difficult to complete the well using conventional gravel pack completion methods. Additionally, the well had a history of unsuccessful treatment using a non-resin product, which modifies the surface potential charges of the sand grains and reduces the repelling forces between them. The well was still producing sand after that treatment; thus, the decision was made to treat the interval using the ABR system. Thereafter, hydrocarbon production, at a rate of 5.5 MMscf/D, was monitored and sand production from the well decreased by more than 95%, with no impairment to hydrocarbon production.

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Development and Field Applications of an Aqueous-Based Consolidation System for Remediation of Solids Production

Cited by 5 publications

References 1 publication

Polyacrylamide hydrogel application in sand control with compressive strength testing

Polyacrylamide hydrogel application in sand control with compressive strength testing

Advanced Sand Control Chemistry to Increase Maximum Sand Free Rate with Improved Placement Technique - A Case Study

Successful Field Application of Aqueous-Based Formation Consolidation Treatment Implemented in Nile Delta, Egypt

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