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Houston, TX, United States

Khanmamedov T.K.,TKK Company | Weiland R.H.,Optimized Gas Treating Inc.
Sulphur 2013 29th International Conference and Exhibition | Year: 2013

Patented HIGHSULF™ technology is one of the most effective methodologies for acid gas enrichment (AGE) and tail gas treatment (TGTU), and it can be highly beneficial when applied to shale gas treatment as well. Based on the use of generic N-methyldiethanolamine (MDEA), the technology enriches weak acid gas sulphur recovery unit (SRU) feed to much higher H2S concentrations than conventional AGE. Distinct from all known AGE schemes, HIGHSULF also allows effective control of H2S concentration in the feed and more reliable operation of the SRU. This leads to more stable and efficient operation of the SRU and a higher level of sulphur recovery. A new member of the family of HIGHSULF technologies, called HIGHSULF PLUS" is discussed by comparison with conventional AGE units. Also, a synergistic effect observed when HIGHSULF PLUS is applied to the amine section of a TGTU is discussed. In this application, HIGHSULF-PLUS reduces the level of H2S going to the incinerator, increases H2S concentration in acid gas, and substantially reduces cooling requirements for the lean amine in the trim cooler and the condenser of the regenerator. In hot climates it can be very difficult to achieve low enough lean amine temperatures using ambient air. HIGHSULF PLUS is one of the best ways to solve this problem. Simulation and design numbers for a commercial unit are presented for discussion.

Khanmamedov T.K.,TKK Company | Weiland R.H.,Optimized Gas Treating Inc.
Hydrocarbon Engineering | Year: 2010

The Shell Claus offgas treating (SCOT) process has emerged as the standard treatment processes, allowing reduced sulfur emissions in the tail gas from Claus sulfur recovery units (SRU). The new alternative HIGHSULF strategy has inspired others to extend the use of this simple concept for amine units. The concept and strategy are very similar where the objective is to create absorber conditions such that the absorber is seeing a gas phase much richer in H 2S. This allows it to send a rich amine more heavily loaded H 2S to the regenerator, and the regenerator produces an acid gas feed much richer in H2S to the SRU at a lower total volume flow rate. This is considered as an extended use of HIGHSULF with two feeds to the absorber and its application for tail gas treating unit (TGTU).

Sridhar U.M.,Covestro LLC | Govindarajan A.,Optimized Gas Treating Inc. | Rhinehart R.R.,Oklahoma State University
ISA Transactions | Year: 2015

This work reveals the applicability of a relatively new optimization technique, Leapfrogging, for both nonlinear regression modeling and a methodology for nonlinear model-predictive control. Both are relatively simple, yet effective. The application on a nonlinear, pilot-scale, shell-and-tube heat exchanger reveals practicability of the techniques. © 2015 ISA.

Optimized Gas Treating Inc. | Date: 2012-02-07

Computer software for engineering design of gas treating plants.

Weiland R.H.,Optimized Gas Treating Inc. | Hatcher N.A.,Optimized Gas Treating Inc.
Hydrocarbon Engineering | Year: 2011

The instabilities caused in amine plants are analyzed highlighting the cause of failure through a series of case studies. A case involves the removal of 5% CO2 to less than 10 ppm using 30 wt% MEA and a 20 tray contactor. The response curve shown reveals a much more sudden transition from lean end to rich end pinch conditions than shown by methyl diethanolamine (MDEA). A another example uses a 33 wt% MDEA with 7 wt% piperazine solvent to remove CO2 from raw gas containing 20% CO2 down to a few ppm. Gas pressure is 16 bar (g). A 1% decrease in solvent rate from 89% to 88% of design flow is simulated to cause a thousand fold increase in CO2 content from below 1 ppm to 2000 ppm. It is therefore concluded that the performance of amine plants can be limited not only by thermodynamics, hydraulics, and corrosion.

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