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Innopipe client with eight 8",10" and 12"units in gathering line service along with five 2 and 3" dia. units in use for well-testing in Central East Asia:
The Company commissioned the country's "first in-field flowline water separation system which separates water from the gas streams at the field gathering network rather than at the production facility. This reduces pipeline flow pressure that can lead to higher reservoir flow rates. Three additional separation units have since been installed and are being commissioned. "
Photos
Alaska Installation sends liquids to parallel line to plant
Exterally coated Innopipe ready for installation
In-ground cavern bi-directoinal piggable drip replacement
Sandblasting prep for coating
Inspection of ASME component welds on inspection manway
inspection of pipeline code components
Innopipe Collection Reservoir built to ASME Sec. VIII with inspection manway
Innopipe liquid collection reservoir ready to ship to site
Innopipe Increases Gas Production by Dewatering Gathering lines
Testimonial: Innopipe Well Testing Separator Outperforms Cyclone Separator (Ker West Production Testing)
3″ Innopipe “flowed gas rates of 35 E3m3/d (1.236 MMSCF) with virtually no operational problems”
3″ 1440 psi Innopipe trailer-mounted for gas well testing
In answer to your inquiry regarding the Innopipe unit we use. They are as follows:
– 3˝ x 8˝ Innopipe Sep (2 Phase)
– 8 ˝ Water leg – Sour service 1440 PSI WP
This is a trailer mounted package we use to conduct WGR (Water Gas Ratio) testing for our clients. These units can be tied in either upstream or downstream of the existing meter run (measurement point).
We are using a 2˝ Vortex Meter (digital) for our gas measurement and a Fluid Totalizer (digital) for our fluid measurements. To date we have flowed gas rates of 35 E3m3/d with virtually no operational problems.
The main benefit of the Innopipe design (the engineered slots), is efficient fluid removal at lower pressures. A standard Recycle Cyclone design requires higher flowing pressures (to create cyclone effect) for optimum fluid separation.
Ker West has three (3) portable field units that have been operating for the past ten (10) months. We are confident enough in the quality of the Innopipe Separator that Ker West has recently purchased two (2) additional units.
Yours truly,
C.L. (Kerry) Kerrison
Ker West Production Testing Ltd.
Tower Carry Over Liquids Recovery Case Study
Innopipe solved liquid carry overs for one of Canada’s largest gas producers. Amine and glycol carried over liquids from process towers. In glycol dehydration towers, Industry practice accepts a loss of ~3 lb /MMSCF (2 × 10-4 kg/Nm3 ), but in this case, much greater losses than expected became a significant chemical costs. Sometimes towers see more gas than the original design rate causing carry-overs. As a rule, skid manufacturers recommend conventional treated gas after-scrubbers, but often these are not installed, or don’t function optimally, and on top of that cause an undesired pressure drop with commensurate additional compressor boosting requirements.
See the PDF Copy here: Case Study_Tower Carry Over 20230725
New Design Improves Performance of Gas-Pipeline Drip Separators
A 26-in. piggable drip is installed in 1996 on the Union Gas Ltd. natural gas storage and transmission system at the Dawn compressor station near Chatham, Ont. Union’s system handles more than 1.2 tcf/year of gas, linking natural gas from Western Canadian and US supply basins to central Canadian and Northeast US markets. Click here to enlarge image Canadian gas-plant tests of a new design for in-line gas pipeline liquid separators (“drips”) have shown that efficiency of free liquid separation in a pipeline can be increased by a factor of close to ten.
See PDF copy of Oil & Gas Journal article
External Corrosion As Indicator of the Presence of Internal Liquids in Pipelines
Natural gas transmission pipelines are far more susceptible to external corrosive attack than similar operating oil pipelines. To explain the difference, it is proposed that the internal liquid content of the natural gas transmission pipeline may actually promote corrosive chemical reactions on the outside steel surface of the pipeline.
Innovative Solutions for Liquids Removal in Natural Gas Pipelines
Natural gas pipelines often contain liquids that can interfere with the proper operation of pipeline related equipment such as compressors, regulators, meters, and processing equipment. These liquid contaminants normally include hydrocarbon condensate, lubricating oils, glycols, water, and other chemicals used in the treatment, dehydration or compression of natural gas.
