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Obtaining geophysical data is a time consuming and costly activity. Also, depending on the exploration stage, there is few data available and it is not even possible to obtain new data (for the duration of the bidding phase). One of the general strategies in the industry is to use existing known information from similar reservoirs (analogues) to better determine the missing data, to get more information about the target area. Therefore, the technical team, geologist and reservoir engineers must evaluate all accessible data types such as seismic, well logs, well testing, production data, cores and analogues data available, to make the best technical and business decisions in exploration and production operations process.

To identify some of the concepts in this book, we need to understand play, lead, and prospect.

Exploration is a costly and risky operation as the expenditure associated are generally valued at millions of dollars and every two out of three wells, on average, contain no shows of hydrocarbons. Consequently, the exploration companies need to drill more wells in one area to find an oil or gas discovery, and this might take more years.

This chapter will show some case studies from offshore deepwater oil and gas fields at several depths as well as different field development options such as standalone hosts and tie-backs.

After identifying potentially feasible fields and at the beginning of an oil field development plan, once the oil field dimensions have been allocated, engineers determine the number of wells needed to meet production requirements and the method of extraction of the liquid hydrocarbons.

This chapter is discussing the expenditures associated to all investment (CAPEX) that is made in advance, and the operational expenses (OPEX) that will occur from the first day startup the production until the abandonment day. Roughly numbers will be presented for these expenses in deepwater projects and will see what is the key assumptions must be considered when keying these values to any project. Accessible records that cover these values will be revealed together with the approximation costs and methodology.

This chapter presents upstream production facilities and subsea engineering design of oil-handling systems and along with the capital expenditure costs. Several operations activities will be covered including floating production facilities, tiebacks flow lines, types of hosts, export pipelines, and manifolds. Besides, will know how to choice and consider the optimum facilities and evacuation systems.

Reservoir rock and fluid properties are the vital parameters that control the estimation of the original oil and gas in place and the recoverable oil and gas.

The overall pressure at any formation depth, as a result of the weight of fluid-saturated rock column, is known as overburden pressure, Pov.

Saturation is defined as the ratio of the fluid volume in the porous medium to the pore volume of the rock. That means, saturation is the proportion of interrelated aperture full by a specified phase. For a gas-oil-water system. Therefore, the following formulas show the saturation ratio for every single phase in the porous medium

Currently, there are numerous of authors defined the fracture from a different perspective, However, from the geo-mechanical viewpoint; a fracture is defined as a surface in which a loss of solidity has taken place.

The most prominent features of reservoir rock are porosity, permeability, and fluid saturations. These properties related to the pore media system and its fluid distribution and flow forms. By carrying out laboratory analyses, using core samples, reservoir rock properties can be investigated.

In this chapter will present an overview of unconventional natural resources definitions and assessment. In this chapter will present an overview of unconventional natural resources definitions and assessment. Whereas, a different characterization have been presented to defined most of the unconventional reservoirs.