Industries

Midstream Gas Processing

Midstream gas processing sits between the wellhead and the end-use market - conditioning raw natural gas and associated liquids into pipeline-quality gas, NGL products, and specification liquids for sale. The facilities that accomplish this work - gas processing plants, fractionation complexes, compressor stations, treating plants, and dehydration units - are built around fired equipment, waste heat recovery systems, steam generation, and emissions controls that fall squarely within CPE’s engineering practice.

These facilities are often remote, operate continuously with lean maintenance crews, and expand incrementally as production from surrounding wells ramps up. That context - reliability, simplicity, and brownfield adaptability - shapes every engineering decision CPE makes in the midstream sector.

Amine Treating

Amine regeneration is the single largest thermal energy consumer in most gas processing plants. CPE provides engineering for direct-fired reboilers (firetube and cabin-type), steam-heated reboilers, and hot oil-heated reboilers - including burner selection, combustion control, fuel train design per NFPA 86, and tube-side heat flux management to prevent amine degradation from localized overheating. Reboiler tube skin temperatures above approximately 300°F for MEA or 350°F for MDEA cause thermal degradation that produces heat-stable salts, reduces treating capacity, and accelerates corrosion throughout the system. CPE designs reboiler systems that maintain tube skin temperatures within the degradation threshold under all operating conditions - including turndown, startup, and transient conditions.

The acid gas stripped from rich amine must be disposed of - through sulfur recovery, acid gas injection, or incineration. CPE provides acid gas incinerator design including combustion chamber sizing, burner specification for low-Btu acid gas streams, and residence time verification for H₂S destruction efficiency.

Glycol Dehydration

TEG dehydration is the standard process for meeting pipeline moisture specifications, and the glycol reconcentrator is the primary fired equipment in the system. CPE provides reconcentrator design and specification, performance assessment (evaluating glycol purity, firetube fouling, and still column condition), firetube inspection and remaining life analysis, and enhanced stripping system design (Stahl column, stripping gas injection, vacuum regeneration) for applications requiring very low outlet moisture.

Glycol dehydration units emit BTEX stripped from the gas stream along with water vapor, regulated under EPA NESHAP Subpart HH and state air quality programs. CPE designs emissions control systems for glycol unit exhaust - including condensers, flash tank vapor recovery, and thermal oxidizers or enclosed combustors for BTEX destruction.

Line Heaters, Hot Oil Systems, and Process Heaters

Midstream facilities operate a range of fired equipment beyond amine reboilers and glycol reconcentrators. Indirect-fired line heaters prevent hydrate formation upstream of pressure reduction - a single gathering system may operate dozens across wellsite and station locations. CPE provides line heater specification, combustion system design for remote unmanned installations, performance assessment as flowing conditions change with well production, and firetube integrity evaluation.

Gas processing and fractionation facilities use hot oil systems to supply process heat to multiple consumers through an intermediate heat transfer loop. CPE provides thermal fluid heater design and specification, hot oil system layout and temperature control, thermal fluid performance assessment, and fluid selection and management programs. For process heaters on fractionation column reboilers, feed preheat, and product conditioning services, CPE applies the same fired heater engineering discipline - performance assessment, combustion optimization, burner evaluation, and tube life assessment - adapted to midstream operating conditions and fuel gas compositions.

Compressor Stations - Waste Heat Recovery and Power

Natural gas compression is the largest single energy consumer in the midstream sector, and waste heat from compressor drivers represents the most significant heat recovery opportunity. For gas turbine-driven compressors exhausting at 800-1000°F, CPE provides HRSG design (unfired and supplementary-fired), waste heat to power evaluation (steam turbine generators, ORC systems), and exhaust emissions control (SCR, CO oxidation catalyst). For reciprocating engine-driven compressors, CPE designs exhaust heat recovery systems and jacket water heat recovery for facility heating, glycol preheat, or amine solution heating.

Remote compressor stations requiring on-site power generation get CPE’s evaluation of generation options - waste heat to power from driver exhaust, small gas turbine or engine generators, and solar/battery hybrid systems for unmanned stations.

Boiler and Steam Systems

Larger gas processing plants and NGL fractionation complexes may operate boiler houses supplying steam to multiple process users. CPE provides boiler selection and specification, performance assessment and efficiency optimization, multi-boiler load management, and fuel gas quality management - addressing the heavier hydrocarbons, varying Btu content, and potential liquid slugs in midstream fuel gas that affect burner performance.

Many midstream steam systems have been incrementally expanded as processing capacity increased, resulting in undersized headers, inadequate condensate return, excessive venting, and poor trap maintenance. CPE’s assessments quantify the energy and cost impact of these inefficiencies and prioritize corrective actions - including steam distribution, condensate return, trap assessment, feedwater treatment, and insulation surveys.

NGL Fractionation

NGL fractionation plants separate mixed NGL into purity products - ethane, propane, normal butane, isobutane, and natural gasoline - through a series of distillation columns, each requiring a reboiler. CPE provides reboiler design and specification (including the trade-off between direct-fired, steam-heated, and hot oil-heated configurations), performance assessment against current throughput and product specs, and heat integration analysis between columns to reduce total fired duty across the complex. CPE also addresses the boiler house, steam system, hot oil system, and cooling water infrastructure that supports fractionation operations.

Gathering Systems and Wellsite Equipment

The upstream end of the midstream value chain includes large populations of small fired equipment - line heaters, glycol units, separator heaters - dispersed across wide geographic areas. CPE provides standardized designs for equipment deployed across gathering systems, establishing specifications, combustion system standards, and BMS requirements that can be replicated across dozens or hundreds of installations. This standardization reduces per-unit engineering cost, simplifies spare parts inventory, and enables consistent maintenance practices. CPE also helps operators develop system-wide emissions management strategies - standardized burner specifications, BTEX control approaches, and engine emissions compliance programs - that achieve compliance efficiently across the full population.

Emissions Control

Midstream emissions control spans combustion equipment (NOx, CO, VOC from heaters, reboilers, and boilers), compressor engines (lean-burn precombustion chamber optimization, rich-burn NSCR catalyst systems, gas turbine SCR and CO catalyst), glycol unit BTEX and VOC (condensers, flash tank vapor recovery, enclosed combustors), and flare and combustion device design for routine and emergency gas disposal. CPE addresses compliance under NSPS Subparts Dc, JJJJ, KKKK, and OOOOa/OOOOb, NESHAP Subparts HH and ZZZZ, and state oil and gas emissions regulations.

CPE also designs piping, equipment, and operational procedures that minimize fugitive methane emission sources and specifies low-emission alternatives to high-bleed pneumatic devices and gas-driven chemical injection pumps.

Brownfield Engineering and Facility Modifications

Midstream facilities expand incrementally - adding processing trains, compression stages, treating capacity, and fractionation columns as production volumes change. CPE provides 3D laser scanning and reality capture for existing facilities, tie-in engineering for connecting new equipment to pressurized systems without plant shutdown where possible, and capacity assessment and debottlenecking to identify whether existing equipment is adequately sized for current and projected conditions.

Codes, Standards, and Regulatory Familiarity

CPE executes midstream work under ASME Sections I, II, IV, and VIII, ASME B31.3 and B31.8, NFPA 85 and NFPA 86, API 12F, API 12J, API 560, GPSA Engineering Data Book, EPA NSPS Subparts Dc, JJJJ, KKKK, and OOOOa/OOOOb, NESHAP Subparts HH and ZZZZ, PHMSA pipeline safety regulations (49 CFR 191, 192, 195), ISA 84/IEC 61511, and state oil and gas emissions programs.

Why CPE

Midstream gas processing is fired equipment work. The amine reboilers, glycol reconcentrators, line heaters, hot oil systems, and compressor station waste heat recovery installations that define the sector are all combustion and heat transfer equipment - and they require the same engineering rigor as the process heaters and boilers in a refinery or chemical plant. The difference is context: midstream facilities are often remote, lean-staffed, and incrementally expanded, which demands equipment designs that are reliable, maintainable, and adaptable to changing conditions.

The combination of specialist fired equipment engineering, amine and glycol system thermal design, compressor station waste heat recovery, and distributed emissions compliance - delivered by a firm that understands how these facilities actually operate - is what sets CPE apart in the midstream sector.

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