Quantification of Viscoelastic Effects of Polyacrylamide Solutions

Heemskerk, J.F.; Rosmalen, R. Janssen–van; Janssen-van, R. Rosmalen; Holtslag, R.J.; Teeuw, D.

doi:10.2118/12652-ms

Cited by 80 publications

(43 citation statements)

References 14 publications

(1 reference statement)

Supporting

Mentioning

Contrasting

Order By: Relevance

“…9). This behavior has been consistently reported by experimentalists in the literature for the past 40 years (Jennings et al 1971;Maerker 1975;Heemskerk et al 1984;Seright 1991b;Seright et al 2011). Oddly, a misconception persists that HPAM solutions show only Newtonian or shear-thinning behavior in porous media-not shear thickening (Lake 1989).…”

Section: Rheology In Porous Media Mechanical Degradation and Injectsupporting

confidence: 83%

“…Shear thickening in porous media has been attributed to increased stresses and energy expenditure associated with disentanglement and elongation of coiled HPAM molecules as they flow through the sequentially contracting/dilating flow paths within porous media. Previous studies of this shear-thickening behavior in porous media focused on solutions with salinities ranging from 3,000 ppm to 50,000 ppm TDS (Jennings et al 1971;Maerker 1975;Heemskerk et al 1984;Seright 1991b;Seright et al 2011). Our study extends conditions in which this behavior has been observed down to only 500 ppm TDS.…”

Section: Rheology In Porous Media Mechanical Degradation and Injectmentioning

confidence: 99%

See 1 more Smart Citation

Effective Propagation of HPAM Solutions Through the Tambaredjo Reservoir During a Polymer Flood

Manichand

Let

Gil³

et al. 2013

SPE Production &Amp; Operations

View full text Add to dashboard Cite

Two new methods were developed for anaerobically sampling polymer solutions from production wells in the Sarah Maria polymer-flood-pilot project in Suriname. Whereas previous methods indicated severe polymer degradation, the improved methods revealed that the polymer propagated intact more than 300 ft through the Tambaredjo formation. Our results may help explain the inconsistency between good production responses and highly degraded polymer observed in many past field projects. Analysis of produced salinity, polymer concentration, and viscosity indicated that the polymer banks retained low salinity and, therefore, high viscosity for much of the way through the Sarah Maria polymer-flood-pilot pattern. A strong shear-thickening rheology was observed for 1,000 ppm and 1,350 ppm hydrolyzed polyacrylamide (HPAM) solutions in porous media, even though the salinity was only 500 ppm total dissolved solids (TDS). Examination of injectivities revealed that these solutions were injected above the formation parting pressure in the Sarah Maria polymer-injection wells. Injectivity was insufficient until fractures were initiated hydraulically; however, the fractures propagated a distance of only approximately 20 ft and did not jeopardize sweep efficiency. In contrast, the short fractures greatly improved polymer injectivity and reduced concern about polymer mechanical degradation.The Sarah Maria Polymer-Flood Pilot Reservoir Description. Staatsolie's Sarah Maria polymer-flooding-pilot project in the Tambaredjo field (Fig. 1) currently has

show abstract

Section: Rheology In Porous Media Mechanical Degradation and Injectsupporting

confidence: 83%

Section: Rheology In Porous Media Mechanical Degradation and Injectmentioning

confidence: 99%

Effective Propagation of HPAM Solutions Through the Tambaredjo Reservoir During a Polymer Flood

Manichand

Let

Gil³

et al. 2013

SPE Production &Amp; Operations

View full text Add to dashboard Cite

show abstract

“…2 of Seright (1991)]. The low-viscosity shear-thickening fl uid in Table 4 was based on a 1-million-dalton HPAM and a Heemskerk model (Heemskerk 1984) that provided resistance factors of ≈7 at low fl ux and 20 at 1,000 ft/D. The high-viscosity shear-thickening fl uid was based on a 26-million-dalton HPAM and a Heemskerk model that provided resistance factors of ≈100 at low fl ux and 1,000 at 100 ft/D [ Fig.…”

Section: Impact Of Rheologymentioning

confidence: 99%

Potential for Polymer Flooding Reservoirs with Viscous Oils

Seright

2010

SPE Reservoir Evaluation &Amp; Engineering

142

View full text Add to dashboard Cite

This paper examines the potential of polymer flooding to recover viscous oils, especially in reservoirs that preclude the application of thermal methods. A reconsideration of enhanced-oil-recovery (EOR) screening criteria revealed that higher oil prices, modest polymer prices, increased use of horizontal wells, and controlled injection above the formation parting pressure all help considerably to extend the applicability of polymer flooding in reservoirs with viscous oils. Fractional-flow calculations demonstrated that the high mobile-oil saturation, degree of heterogeneity, and relatively free potential for crossflow in our target North Slope reservoirs also promote the potential for polymer flooding. For existing EOR polymers, viscosity increases roughly with the square of polymer concentration-a fact that aids the economics for polymer flooding of viscous oils. A simple benefit analysis suggested that reduced injectivity may be a greater limitation for polymer flooding of viscous oils than the cost of chemicals. For practical conditions during polymer floods, the vertical sweep efficiency using shear-thinning fluids is not expected to be dramatically different from that for Newtonian or shear-thickening fluids. The overall viscosity (resistance factor) of the polymer solution is of far greater relevance than the rheology.

show abstract

“…The experimental data were fitted to the classic Rouse model. 13 In this model, the polymer molecule is represented as a flexible chain of N beads connected by N-1 elastic springs. When immersed in a solvent fluid, such a model molecule has N-1 relaxation times which are related to the storage and loss moduli as follows:…”

Section: Rheological Measurementsmentioning

confidence: 99%

A Novel Model for Viscoelastic Fluid Flow in Porous Media

Garrouch

Gharbi

2006

All Days

View full text Add to dashboard Cite

TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractSteady-state flow experimental data have been analyzed for two commonly used polymers representing two generic classes: polysaccharides (xanflood), and partially hydrolyzed polyacrylamides (pusher-700) flowing inside bead packs and Berea sandstone. Oscillatory flow measurements have been used to compute the polymer solution's longest relaxation time (θ f 1 ) which is referred to as the characteristic relaxation time in this paper. Steady-state flow experimental data for the two polymers combined with measured polymer viscous properties have been converted to average shear stress-shear rate data inside porous media. An average power-law exponent ( n ) is therefore obtained for the polymer flow inside porous media.Using θ f 1 and n , rock permeability (k) and porosity (φ) and fluid flow velocity (u), a viscoelasticity number (N v ) is calculated, and found to strongly correlate with the pressure gradient inside porous media. This correlation is the basis for defining a viscoelastic model for polymer flow, analogous to Darcy's law. The proposed model asserts a non-linear relationship between fluid velocity and pressure gradient. It accounts for polymer elasticity, and for pore geometry changes due to molecular adsorption and mechanical entrapment.

show abstract

Quantification of Viscoelastic Effects of Polyacrylamide Solutions

Cited by 80 publications

References 14 publications

Effective Propagation of HPAM Solutions Through the Tambaredjo Reservoir During a Polymer Flood

Effective Propagation of HPAM Solutions Through the Tambaredjo Reservoir During a Polymer Flood

Potential for Polymer Flooding Reservoirs with Viscous Oils

A Novel Model for Viscoelastic Fluid Flow in Porous Media

Contact Info

Product

Resources

About