document

Abstract

The potential for hydrocarbon solid formation and deposition adversely affecting flow assurance in deepwater production systems is a key risk factor in assessing deepwater developments. To reduce this risk, a systematic approach to defining and understanding the thermodynamic and hydrodynamic factors impacting flow assurance is required. The development of experimental and simulation techniques to provide this information are a current focus of attention in the reservoir fluid phase behavior community. This paper provides a case study of the various aspects of a state of the art laboratory and simulation assessment for a Gulf of Mexico reservoir crude. The case study illustrates the application of a systematic approach to characterization of the crude and the impact of this knowledge on potential production and flow assurance strategies.

Introduction

Deepwater exploration and development in the Gulf of Mexico and other deepwater offshore areas around the world have become key activities for the majority of oil and gas exploration and production companies. Development activities in the deepwater face significant challenges.¹ Of particular concern, are the effects of produced fluid hydrocarbon solids (i.e. asphaltene, wax, and hydrate) and their potential to disrupt production due to deposition in the production system. It is noted that the deposition of inorganic solids arising from the aqueous phase (i.e. scale) also poses a serious threat to flow assurance. Scaling issues are beyond the scope of this paper and have not been considered in this work.