Riverton Power Station

Client: Empire District Electric Co.
Completion Date: 2016
Location: Riverton, Kansas


Burns & McDonnell provided engineer-procure-construct services on a lump-sum basis for conversion of an existing Siemens V84.3A(2) combustion turbine generator to a combined-cycle nominal 250-MW capacity gas-fired power facility. The combined cycle portion of the plant will come online in 2016.

The high efficiency of this configuration will help control fuel costs, lower emissions and ensure reliable energy for our customers. We are proud to continue a long-standing tradition of innovative and economical power generation at Riverton dating back to 1905. — Blake Mertens, Vice President, Energy Supply and Delivery Operations, Empire District Electric Co.

As the EPC contractor, Burns & McDonnell subcontracted the civil, structural, mechanical, electrical and building finishes, while providing the engineering for the project. Burns & McDonnell procured a Siemens ST-700/900 steam turbine, a Nooter/Eriksen triple pressure HRSG, an SPX mechanical draft cooling tower and all associated balance of plant equipment and materials.

The Riverton Power Station is in the unincorporated town of Riverton in Cherokee County, Kansas. The project is an expansion of the existing Riverton Unit 12 combustion turbine to a one-on-one combined cycle unit. The facility has one existing nominal 143-MW Siemens V84.3A(2) combustion turbine generator (CTG), one triple-pressure heat recovery steam generator (HRSG), an axial exhaust condensing steam turbine generator (STG) and associated balance-of-plant equipment. The net electrical output will be a nominal 250 MW at ambient conditions of 96.6° F and 39 percent relative humidity.

For the combined-cycle operating mode, the facility is designed and permitted for unlimited operation on natural gas with an unlimited number of starts annually. The unit is designed for cycling load operation. The CTG will operate at full load in a pseudo simple-cycle mode where steam from the corresponding HRSG bypasses the steam turbine and is dumped to the condenser.

The existing CTG is outdoors. The STG will be indoors with a bridge crane for maintenance. The exhaust of the steam turbine will be directed to a water-cooled condenser. The HRSG will be outdoors and the boiler feed pumps will be inside the integrated generation building. An SCR system will reduce the nitrogen oxide (NOx) level, and an oxidation catalyst will reduce carbon monoxide (CO) and volatile organic compound (VOC) levels.

The circulating water system will use a mechanical draft cooling tower, and the makeup water source will be raw water taken from the Spring River via a screened water supply intake structure. Certain systems, including, but not limited to, service water, potable water, fire protection water supply and demineralized water, will be provided for the combined-cycle unit by either modifying and extending existing systems or by providing new facilities cross-tied with the existing systems. 

One two-winding generator step-up transformer will be provided for the STG. Plant synchronization to the existing 161-kV substation will be accomplished through an owner-supplied high-side breaker for the STG unit. A plantwide distributed control system (DCS) will monitor and control the facility balance of plant equipment. The CTG, HRSG, STG and other balance of plant equipment will be operated primarily from work stations within the facility control room.


  • Engineering
  • Procurement
  • Construction
  • Startup
  • Commissioning
  • Testing


  • Natural gas-fueled
  • HRSG
  • STG
  • Generation building with integrated pipe rack
  • Mechanical draft cooling tower
  • Cooling water river intake structure
  • Electric auxiliary boiler
  • Ammonia unloading and storage