Near-wellbore placement of small (sand consolidation) treatments

Journal Article · Thu Nov 01 04:00:00 EST 1984 · J. Pet. Technol.; (United States)

DOI:https://doi.org/10.2118/10177-PA· OSTI ID:5914960

Davies, D R; Hayelaars, A M.P.M.; Roberts, D L

Placement experiments in a full-scale sandpack model as well as small-scale experiments in a transparent sector model have shown that the placement profile of a high-viscosity (sand-consolidating) fluid is superior to that of a low-viscosity fluid owing to a more stable injection-front during displacement, reduced dilution of the consolidation fluid by the pore fluid, less movement under the influence of gravity after placement, more event placement across zones containing many perforations, and elimination of pore fluid entrapment between different perforations. Experiments have shown that movement of the injected fluids under the influence of gravity can be described by dimensionless groups. Mixing between injected and pore fluid in a porous medium was shown to be independent of injection rate and to decrease with increasing viscosity of the injected fluid. The data discussed in this paper can be used to estimate the effectiveness of sand-consolidation treatments in the field.

• Research Organization: Koninklijke/Shell EandP Laboratory
• OSTI ID: 5914960
• Journal Information: J. Pet. Technol.; (United States), Journal Name: J. Pet. Technol.; (United States) Vol. 36:12; ISSN JPTJA
• Country of Publication: United States
• Language: English

Related Subjects

02 PETROLEUM
020300* -- Petroleum-- Drilling & Production
DISPLACEMENT FLUIDS
DISTRIBUTION
EFFICIENCY
ENGINEERING
ENHANCED RECOVERY
FLUID FLOW
FLUID INJECTION
FLUIDS
HYDRAULIC CONDUCTIVITY
MATHEMATICAL MODELS
MISCIBLE-PHASE DISPLACEMENT
OIL WELLS
POROSITY
RECOVERY
RESERVOIR ENGINEERING
RESERVOIR ROCK
SAND CONSOLIDATION
SIMULATION
STIMULATION
VISCOSITY
WELL STIMULATION
WELLS