【正文】 deployment process to achieve this has been assimilated and is now being reproduced in many other similar fields across North America. The paper will indicate some of the areas where this bination of technology and supporting change management will be expanded in the future.1Parallel Numerical Reservoir Simulations of Nonisothermal Compositional Flow and ChemistryThis paper describes an efficient numerical scheme for nonisothermal positional flow coupled to chemistry. An iterative implicitpressure/explicitposition (IMPEC) method is applied to solve the flow problem using a volumebalanceconvergence criterion. A backwardEuler mixed finiteelement method (FEM) with lowestorderRT0elements is applied to solve the pressure equation, and a ponent local masspreserving explicit scheme is used to update concentrations. Chemical reactions are solved using explicit RungeKutta (RK) ordinarydifferentialequation (ODE) integration schemes. A higherorder Godunov method and a backwardEuler mixed FEM are applied for thermal advection and conduction, respectively, in a timesplit scheme.One of the major applications of the method is in the modeling of fieldscale carbon dioxide (CO2) sequestration as an enhancedoilrecovery (EOR) process or for containment in deep saline aquifers where chemical reactions and temperature variations may have an effect on the flow and transport of CO2. Leakage patterns when CO2is injected near leaky abandoned wells, the displacement of methane from depleted gas reservoirs, and accurate modeling of geochemical reactions involving injected CO2are other applications of interest.Results of a benchmark problem in multiphase flow with several hydrocarbon ponents in formations with highly heterogeneous permeability on very fine grids, as well as a largescale parallel implementation of modeling CO2sequestration, are presented to justify the practical use of the model. A parallel efficiency of approximately 80% was observed on up to 512 cores in the benchmark study. Results from a problem simulating injection of CO2in deep aquifers including nonisothermal and chemical effects are also presented. The results indicate a good agreement of the solutions with published data, where available.Numerical modeling and simulation of CO2sequestration plays a major role in future site selections and in designing storage facilities for effective CO2containment. The main contribution of this paper lies in providing a parallel and efficient method of simulating challenging positional flow problems, such as in the study of CO2sequestration, as well as flow coupled to thermal and geochemical effects.14. Chemical Osmosis, Shale, and Drilling FluidsThis paper describes continuing efforts to develop a waterbased drilling fluid that will provide the osmotic membrane behavior and wellbore stability of an oilbased drilling fluid. A porepressuretransmission technique in use for several years as a tool to measure osmotic behavior has been refined for improved measurement of changes in shale permeability and pore pressure in response to interaction with drilling fluids. Conventional invertemulsion and waterbased drilling fluids containing selected additives were tested with outcrop and preserved shale specimens using an innovative screening method.Observed pressure differences across each shale specimen were pared with the values predicted by osmotic theory. From this parison, an empirical concept of membrane efficiency was developed. Three distinct types of membranes are postulated to describe the interaction of various drilling fluids with shales. Type 1 membranes are generally characterized by coupled flows of water and solutes between fluid and shale. Type 2 membranes greatly reduce the nearwellbore permeability of shale and restrict the flow of both water and solutes. Type 3 membranes transport water more selectively, but shale permeability and fluid chemistry may alter performance measurements. Invertemulsion fluids tend to form efficient, Type 3 membranes。 however, under certain conditions, these fluids can yield lower capillary pressures than described previously and invade the interstitial fabric of highpermeability shales.Several waterbased mud formulations were prepared that achieve approximately onequarter to onehalf the measured osmotic pressure of a typical oilbased mud (OBM). Fluid additives that supplement or reinforce a Type 1 membrane, such as saccharide polymers (especially in bination with calcium, magnesium, or aluminum salts), can induce relatively high efficiencies. As expected, fluids that form a Type 2 membrane, such as silicate and aluminate muds, provide the highest membrane efficiencies.