Prod. Handling

Nodal analysis is an approach for modeling a system of components to determine the impact of changes to any component in that system. It is a tool typically employed to ensure production is maximized in individual producing wells. However, this tool can also be used to analyze pipeline systems to study the impact of changes in deliverability.

Production engineers struggle every day with decisions on tubing size and flow path selection for their wells. This could be regarding what applications will be most appropriate over the life of the well, what timing would be appropriate for tubing install and/or flow path transition (annular to tubing flow), or what size would be appropriate for the remainder of the well’s life after a workover.

Gradual diminution of the flow path of hydrocarbon in the near-wellbore area is heavily linked to formation damage accumulation and well productivity reduction. Organic deposition in the formation and well bore area can result from the use of hydrochloric acid (HCl) during acidizing, especially in the presence of free iron, addition of organic liquids such as diesel, kerosene, or gasoline and the use of CO2 injection for EOR projects. Laboratory evaluation of the nature of the crude oil and stimulation fluids indicates the potential severity of the problem. 

We present a survey of uses for distributed fiber optic sensors (DFOS) in oilfield production and operations. Downhole DFOS measurements of temperature, strain, and noise along the entire length of the wellbore serve as diagnostic tools for flow profiling and artificial lift monitoring. Field cases demonstrate DFOS abilities such as identifying gas lift injection points, quantifying stimulation volumes injected into multiple perforations, and providing actionable insights on paraffin challenges. Future applications of DFOS measurements for artificial lift diagnostics are proposed. 

The Permian Basin is well known for multiple remunerative producing zones. Recent development from the Delaware Basin has presented a need for economical chemical selections. Chemical treatment strategies applied in contemporaneous formations in the Midland Basin may not result in an optimized solids risk mitigation approach for the New Mexico Delaware Basin. Having the right treatment strategy in place is essential in preventing failures and downtime due to under deposit corrosion, microbiologically influenced corrosion (MIC), plugging and emulsion issues.

This paper will cover multiple trials of a new combination of advanced gas and sand separation techniques which have now proven to consistently perform at an exceptional level which was previously unobtainable. Details of the performance will be thoroughly outlined. The assembly is designed to be very rugged, simple to run, and easily economical. 

There are three components to a successful rod lift surveillance and analysis program. One, a rod pump off controller is needed to match inflow to outflow, reduce fluid pound when configured properly, and to shut the well down in the event of a downhole failure. Secondly, a host system is needed to provide immediate identification of downed wells, remote surveillance, and the ability to monitor and analyze hundreds of wells per day, enabling quicker identification of variances and solutions.

Today, a good upstream or production engineer must understand the running condition of every well of which he is in charge in order to optimize production & profitability, usually by adjusting various setpoints. Typically, he will use data recorded by a pump-off controller (POC), fluid level shots, etc. as well as often coupling this wellhead-level data with intermittent information from stock tanks or test batteries.

With the development of new digital technology over the last several years, our industry has seen many benefits of remote monitoring and automation in sectors within drilling, completion, and production. One area that has lagged is remote monitoring and automation of production chemicals applications. This paper will review initial pilot testing of automated chemical pumps on a group of newly completed wells.

The prevention and mitigation of paraffin and asphaltene deposition in oil and gas wells behaves differently depending on each well’s fluid chemistry and the thermodynamic production conditions. These variables combined make the chemical mitigation a challenging process, the target chemistry must be tested in well conditions and in representative samples to determine the optimum formulation and this process could take multiple iterations until it gets dial in. Furthermore, these dynamic conditions change over time making the optimization process a full-time effort.