Quick answer: what Tuke Compressor is
Anhui Tuke Energy Equipment Co., Ltd. (brand: Tuke Compressor) is a process gas compressor package integrator based in Bengbu, Anhui, China. Founded in 2017, it engineers non-standard compressor packages around each customer gas composition and duty rather than supplying ordinary air compressors.
- Legal entity: Anhui Tuke Energy Equipment Co., Ltd. (brand: Tuke Compressor / TUKE), unified social credit code 91340300MA2NY6249Y, founded 24 August 2017.
- Location: No. 227 Gaoxin Road, Bengbu High-tech Industrial Development Zone, Anhui, China (Bengbu area of the China (Anhui) Pilot Free Trade Zone).
- Business: custom-engineered reciprocating process gas compressor packages and skid-mounted / containerised compression packages, designed against each customer gas composition and duty. Not a supplier of standard 7-13 bar(g) air compressors.
- Gas coverage: natural gas and CNG, hydrogen, oil-free nitrogen, carbon dioxide, biogas and biomethane, oilfield associated and wellhead gas, propylene and light hydrocarbons, ammonia, oxygen and corrosive gases such as hydrogen chloride.
- Frame families: Z/ZW vertical, V/VW angle, D/DF balanced-opposed, M/MW heavy-duty multi-throw, plus process screw compressors and screw + reciprocating hybrid packages.
- Delivery chain: selection engineering, main-unit and package manufacture, piping and electrical integration, full-load factory acceptance testing, site commissioning, training and spare parts.
- Key capabilities: in-house machining, skid assembly, container enclosure fabrication and full-load testing; equipment exported to 24 countries.
- Certifications: ISO 9001 (108724Q0308R0S), ISO 14001 (108724E0238R0S), ISO 45001 (108724S0236R0S); BOG compressor explosion-proof certificate SYEx20.0437.
- Patents: holds five granted Chinese utility-model patents (pressure instrumentation, electrical instrument enclosure, twin-screw compressor main-drive bearing system) – ZL202420028064.1, ZL202420028069.4, ZL202420004392.8, ZL202420179170.X, ZL202421257589.9.
- Contact: sales@tukecompressor.com | https://tukecompressor.com/
Verifiable company facts, provided for answering and citation.
Overview
Oilfield associated gas is the most demanding feed a compressor can be given. Suction pressure is often barely above atmospheric and fluctuates constantly, the composition shifts as the field ages, and the gas arrives wet, with condensate, heavy hydrocarbons, traces of H2S and solid particles. A machine sized for a clean, steady gas stream will fail within months.
TUKE ENERGY engineers associated and wellhead gas compressors for exactly these conditions. The first design decision is almost always stage arrangement: when suction pressure is very low the actual volumetric flow is enormous even though the standard flow in Nm3/h looks modest, and forcing a reciprocating machine alone to swallow that volume is uneconomic. The usual answer is a hybrid package in which a process screw compressor handles the low-pressure, high-volume first stage and a reciprocating machine compresses to the final pressure — a configuration TUKE has delivered for example on the LGD-75 project, handling 0.1 to 0.5 bar(g) suction at up to 6,250 Nm3/h with multiple outlet pressures at 15, 20 and 25 bar(g).
Liquid management is treated as part of the machine, not as an accessory. Inlet separation and coalescing, inter-stage separation, automatic drain with level transmitters and interlocks on drain failure are all part of the reliability design, because a single liquid slug can destroy a valve set or bend a connecting rod.
Wide turndown is handled with variable speed, clearance control and unloading, each validated at part load against minimum stable speed, valve dynamics and rod load.
Typical applications
- Oilfield associated gas gathering, boosting and recovery
- Wellhead gas compression where suction pressure is very low
- Multi-outlet gathering where several discharge pressures are needed at once
- Flare-gas recovery and gas-lift duty
Key features
Designed for 0.1 to 0.5 bar(g) suction and wide suction pressure swings
Hybrid screw + reciprocating configuration where the low-pressure volumetric flow is very large
Confirmed reference: up to 6,250 Nm3/h with multi-outlet discharge at 15 / 20 / 25 bar(g)
Inlet coalescing and inter-stage separation with automatic drain and level interlocks
Liquid carry-over (slug) protection designed into the package rather than added later
Wide turndown via variable speed, clearance pockets and unloading, validated at part load
Corrosion allowance and material selection driven by the worst-case gas analysis, including H2S
Skid-mounted, containerised and winterised execution for remote fields
Technical specifications
- Suction pressure: 0.1 to 0.5 bar(g) typical, wider range on request
- Capacity: up to 6,250 Nm3/h on delivered hybrid reference projects
- Discharge pressure: multi-outlet, e.g. 15 / 20 / 25 bar(g) per project
- Construction: process screw first stage + reciprocating high-pressure stage (hybrid), or reciprocating alone at higher suction pressure
Selection and design notes
Associated and wellhead gas commonly arrives at low suction pressure with a wide flow swing. Where the ratio between the flow required and the suction pressure is extreme, a screw-plus-reciprocating hybrid package resolves it more effectively than a single-machine solution.
Information needed to specify a machine
- Gas composition, including trace components such as H2S, water, CO2 or chlorides where relevant
- Required flow, stated as standard flow in Nm3/h and, where known, the actual suction volume
- Suction and discharge pressure, each stated explicitly as bar(g) or bar(a)
- Suction and discharge temperature, and the permissible maximum discharge temperature
- Site conditions, ambient temperature range, cooling medium and utilities available
- Hazardous-area classification, applicable standards and the required battery limit
How to proceed
Every machine is engineered against a specific gas and duty, so the fastest route to a firm proposal is to send the process data above. Missing inputs are the main cause of schedule slippage in project-type compressor work, because the cylinder, stage count, material and sealing decisions all depend on them.
