BEGIN:VCALENDAR VERSION:2.0 METHOD:PUBLISH PRODID:-//Tendenci - The Open Source AMS for Associations//Tendenci Codeba se MIMEDIR//EN BEGIN:VEVENT DESCRIPTION:--- This iCal file does *NOT* confirm registration.\r\nEvent d etails subject to change. ---\r\nhttps://www.spegcs.org/events/3523/\r\n\r \nEvent Title: Northside: Two-stage Compression with Elevated Cooler Disch arge Temperatures Improves Wellsite Gas-Lift Operations: SPE181773\r\nSta rt Date / Time: Mar 14, 2017 11:30 AM US/Central\r\nLocation: Southwestern Energy \r\nSpeaker: William G. Elmer, P.E.\r\nGoogle\r\nhttp://maps.googl e.com/maps?q=10000+Energy+Drive,Spring,Texas,77389\r\n\r\nForecast\nhttp:/ /www.weather.com/weather/monthly/77389\r\n\r\nOpportunities to improve the standard three-stage wellhead gas-lift compressor design for application to unconventional shale reservoirs are presented. A two-stage design is pr esented, with two field installations in theEagle Ford Shale reviewed as a case study.\r\nThe shale revolution began with gas reservoirs, most notab ly the Barnett, and preceded development of shale oil resources. This resu lted in the need for many new compressors, and the rental compressor indus try accelerated production of the standard three-stage compressor. No subs tantive design changes were made, as compressors that could meet either we llhead/gas-lift or gathering applications were preferred due to their vers atility.\r\nAs the shift was made to horizontal oil, problems appeared wit h the standard compressor design in handling natural gas liquids component s (primarily propane, butanes, pentanes, and hexanes plus). The standard d esign provides extra aftercooling, in part to support glycol dehydrator op eration. As a result, these components often condense in compressor gas co olers, resulting in operational and environmental problems including froze n dump lines, heavy tank vapor emissions, and hydrates. Downtime and emiss ions related to these problems contributed to some operators viewing gas-l ift as the artificial lift method of last resort, despite its superior abi lity to handle sand production, deviated wellbores, and high fluid volumes .\r\nThe capabilities of two-stage versus three-stage compressors for gas- lift are compared in the case study. The lower suction pressures afforded by three-stage compression are negligibly beneficial to horizontal shale o il wells, where slugging is an issue, and higher separator pressures are s elected to mitigate slugging and aid liquid displacement from separation e quipment. Additionally, the incremental pressure drop achieved by three-st age compression can provide little production improvement when compared to the total pressure drop from the reservoir to the wellbore. The phase dia gram is used to show the necessity of temperature control on each stage of gas cooling to prevent process problems for gases including NGL component s.--- This iCal file does *NOT* confirm registration.Event details subject to change. ---\r\n\r\n--- By Tendenci - The Open Source AMS for Associati ons ---\r\n UID:uid3523@spegcs.org SUMMARY:Northside: Two-stage Compression with Elevated Cooler Discharge Temperatures Improves Wellsite Gas-Lift Operations: SPE181773 DTSTART:20170314T163000Z DTEND:20170314T180000Z CLASS:PUBLIC PRIORITY:5 DTSTAMP:20240329T063531Z TRANSP:OPAQUE SEQUENCE:0 LOCATION:Southwestern Energy X-ALT-DESC;FMTTYPE=text/html:
The shale revolution beg an with gas reservoirs, most notably the Barnett, and preceded development of shale oil resources. This resulted in the need for many new compressor s, and the rental compressor industry accelerated production of the standa rd three-stage compressor. No substantive design changes were made, as com pressors that could meet either wellhead/gas-lift or gathering application s were preferred due to their versatility.
As the shift was made to horizontal oil, problems appeared with the standard compressor design in handling natural gas liquids components (primarily propane, butanes, penta nes, and hexanes plus). The standard design provides extra aftercooling, i n part to support glycol dehydrator operation. As a result, these componen ts often condense in compressor gas coolers, resulting in operational and environmental problems including frozen dump lines, heavy tank vapor emiss ions, and hydrates. Downtime and emissions related to these problems contr ibuted to some operators viewing gas-lift as the artificial lift method of last resort, despite its superior ability to handle sand production, devi ated wellbores, and high fluid volumes.
The capabilities of two-sta ge versus three-stage compressors for gas-lift are compared in the case st udy. The lower suction pressures afforded by three-stage compression are n egligibly beneficial to horizontal shale oil wells, where slugging is an i ssue, and higher separator pressures are selected to mitigate slugging and aid liquid displacement from separation equipment. Additionally, the incr emental pressure drop achieved by three-stage compression can provide litt le production improvement when compared to the total pressure drop from th e reservoir to the wellbore. The phase diagram is used to show the necessi ty of temperature control on each stage of gas cooling to prevent process problems for gases including NGL components.