Stabilizing Wellbores in Unconsolidated, Clay-Laden Formations

Abstract

Stabilizing Wellbores in Unconsolidated, Clay-Laden Formations Philip D. Nguyen; Philip D. Nguyen Halliburton Search for other works by this author on: This Site Google Scholar Ron G. Dusterhoft; Ron G. Dusterhoft Halliburton Search for other works by this author on: This Site Google Scholar Syed A. Ali; Syed A. Ali ChevronTexaco EPTC Search for other works by this author on: This Site Google Scholar Russell R. Lockman Russell R. Lockman Halliburton Search for other works by this author on: This Site Google Scholar Paper presented at the SPE International Symposium and Exhibition on Formation Damage Control, Lafayette, Louisiana, February 2004. Paper Number: SPE-86559-MS https://doi.org/10.2118/86559-MS Published: February 18 2004 Cite View This Citation Add to Citation Manager Share Icon Share Twitter LinkedIn Get Permissions Search Site Citation Nguyen, Philip D., Dusterhoft, Ron G., Ali, Syed A., and Russell R. Lockman. "Stabilizing Wellbores in Unconsolidated, Clay-Laden Formations." Paper presented at the SPE International Symposium and Exhibition on Formation Damage Control, Lafayette, Louisiana, February 2004. doi: https://doi.org/10.2118/86559-MS Download citation file: Ris (Zotero) Reference Manager EasyBib Bookends Mendeley Papers EndNote RefWorks BibTex Search Dropdown Menu toolbar search search input Search input auto suggest filter your search All ContentAll ProceedingsSociety of Petroleum Engineers (SPE)SPE International Conference and Exhibition on Formation Damage Control Search Advanced Search ProposalThis paper presents results of laboratory and field testing performed to investigate the feasibility and effectiveness of applying a one-component, low-viscosity consolidation material to stabilize or strengthen the unconsolidated formation sand surrounding a wellbore and overcome the effects of cyclic loading, while minimizing any reduction of its original permeability. Treatment fluid volumes, overflush fluid, and the chemical composition of the consolidation material were found to directly impact the consolidation performance and the retained permeability of the treated formation sand. The treatment renders formation fines immobile so that migration and plugging do not occur.This study has determined that application of a consolidation material containing a specific solvent chemistry for clay-laden sands has resulted in excellent strengths even at high clay contents. This new finding indicates that the new approach allows the consolidation material to be drawn onto the mineral surfaces, resulting in very minimal loss in effective porosity. Scanning electron micrographs of the consolidated core material clearly reveal the entrapment of fines as the consolidation material formed a thin film on the mineral surfaces, resulting in very little damage to the porosity and permeability of the formation.Results of field testing indicate that the consolidation treatment effectively stops the production of formation sand and fines while maintaining the production of the wells at desirable flow rates. The technique provides a very attractive alternative to conventional sand control completions in lower quality reservoirs as well as an effective thru-tubing completion alternative.IntroductionWhen a wellbore or a perforation tunnel is introduced into a friable sand formation, a plastic zone develops and formation failure may follow. Production and cyclic loading are significant reasons why the plastic failure zone expands into the formation. Formations that are considered soft or poorly consolidated are often plagued by formation sand production. Production of formation sand or fines can result in plugged gravel packs, screens, perforations, tubulars, surface flow lines, and surface equipment, as well as cause lost production and, in extreme cases, wellbore failure.Previous Consolidation SystemsResin consolidation of the unconsolidated, near-wellbore region is often applied by injecting curable resin directly into the formation to stabilize and prevent the production of formation sand. More often, resin consolidation is performed in wells where completions using gravel packing and sand control screens have been deemed to be unattractive economically.Furfuryl alcohol or furan resin systems have commonly been used to provide consolidation in unconsolidated formations to help prevent formation sand production.1–6 An external activator, typically an acid catalyst, is often applied to activate the resin after it has been injected into the formation. A typical procedure involves:Injecting a preflush treatment fluid to condition the rock matrix,Injecting the resin to coat the loosely packed sand or weakly consolidated rock matrix,Injecting a spacer fluid to separate the resin from the activator, andInjecting an overflush activator solution or an acid catalyst, which causes the polymerization of the resin Keywords: overflush, resin, reservoir, brazo river sand pack, permeability, completion installation and operations, resin treatment, 325-mesh silica flour, strength, wellbore design Subjects: Wellbore Design, Hydraulic Fracturing, Reservoir Fluid Dynamics, Wellbore integrity, Perforating, Flow in porous media, Completion Installation and Operations, Completion Operations This content is only available via PDF. 2004. Society of Petroleum Engineers You can access this article if you purchase or spend a download.