Testing page for app

The evolution of horizontal drilling and multistage completions has changed matrix stimulation from the “more acid, better result” belief to effective lateral distribution and deeper penetration with less acid.

When a new horizontal well in Asia was incapable of unassisted flow, coiled tubing (CT) was selected for the perforation and stimulation intervention. Mechanical isolation was required to ensure that the stimulation fluids entered only the new zones.

Plug-and-abandonment (P&A) operations can be expensive, leading to negative net present value. Historically, P&A operations in the North Sea—estimated to hold some 3,000 wells of declining production—were performed with either drilling or workover rigs.

The complete paper describes a recent directional coiled-tubing drilling (DCTD) job completed for an independent operator in the Appalachian Basin.

Fluids introduced into a reservoir for stimulation typically take the path of least resistance and, therefore, frequently go into areas with open flow paths. In many cases, those areas are not the targets of stimulation.

A horizontal-steam-injection pilot project has been under way for the last 4 years in the Kern River heavy-oil field in the southern San Joaquin Valley of California.

In the complete paper, a new, fully coupled implicit tool was used to model an onshore Omani asset with multiple reservoirs, each featuring different fluids and multiple networks.

A single-well polymer-injection and back-production test has been performed in an oil and gas field offshore Norway. The objective of the test was to verify at field conditions the properties measured in the laboratory for the biopolymer schizophyllan.

CO2 injection is a successful EOR technology that has been deployed extensively in the Permian Basin. Further expansion of CO2 EOR has been limited by the availability of affordable CO2 rather than the existence of suitable target reservoirs. This situation may be about to change.

This paper presents work performed to characterize the probability of collapse as a function of reservoir-abandonment pressure using reliability-based design (RBD).