Testing page for app

For the past 17-plus years, it has been my privilege to serve as your JPT Technology Editor. After growing up in the oil patch as the son of a sales engineer for a major service company, I have spent all but a couple of years of my adult life as an oily.

A mobile system has been developed that mixes consistent solutions of powder-based friction reducers (FRs) at the wellsite and adds them to hydraulic fracturing fluid.

This is the teaser.

This paper discusses scaling up the high-resolution geological model and specific problems encountered by the study team in the Greater Burgan field.

Looking back through previous editions of this article, I note that, in 2011, I wrote, “there’s a growing tendency in some quarters to use very simple models.” That may be true, but there is also a growing tendency among vendors to offer models with more and more features.

Large volumes of gas can be produced at high rates with conventional horizontal- or vertical-well configurations for long periods of time from some methane-hydrate accumulations by means of depressurization-induced dissociation.

Initializing a reservoir simulator requires populating a 3D dynamic-grid-cell model with subsurface data and fit-for-purpose interrelational algorithms. In practice, these prerequisites rarely are satisfied fully.

High-reliability gas lift flow-control devices (GLFCDs) enable gas lift for wells with the potential for H2S in the produced gas and where casing is not qualified for H2S service.

Artificial-lift reliability is strongly influenced by how well the equipment is selected, designed, and operated for its particular application. The required artificial-lift knowledge is more than simply entering data into a software program or taking one class on the subject.

Recently, Quicksilver Resources and Eni E&P, through its subsidiary Eni US Operating, began a common effort to optimize production and lift costs in the Alliance shale-gas field in the prolific Barnett shale play in Texas.