Read Perdido Norte Pipeline Project text version

Markham TXP-2 Cryogenic Plant

Presented by: Brian Perilloux, P.E. Williams Midstream

© 2009 The Williams Companies, Inc. All rights reserved.

Markham TXP-2 Cryogenic Plant

Disclaimer

Any information presented herein should not be regarded as the official position of Williams Midstream. The data presented is based on publicly available information, including information about the Shell Perdido development and the Williams' Markham project. Information was also obtained from internet websites such as the MMS website, etc.

© 2009 The Williams Companies, Inc. All rights reserved.

Markham TXP-2 Cryogenic Plant

Top 10 reasons to be on a project team... with credit to David Letterman

10 Project teams are a great way to make new friends 9 All projects are easy, and they don't have cost, schedule or technical risks anyway 8 They always have all the processes and procedures we need in place 7 Resource Constraints? Just an opportunity to train the next generation of engineers 6 Project teams never encounter adversity 5 All projects are easy, regardless of size or complexity...right? 4 When all else fails, project teams have magic as a backup 3 Donuts at meetings... enough said 2 Things "dropped through the crack"...No worries, the operations guys can fix anything, and they don't mind fixing it anyway 1 Cost overruns? No problem; you have all those new friends you've made who love you now

© 2009 The Williams Companies, Inc. All rights reserved.

Markham TXP-2 Cryogenic Plant

Plant Statistics

· · Markham TXP2 is a 200 MMSCFD cryogenic NGL recovery plant. The plant is being built to process additional offshore production gathered by the Williams' gas gathering system in the Western GoM. Gas is delivered to the plant via the WFS gathering pipelines and pipelines owned by Williams Gas Pipes (formerly Transco). Plant was designed and built by Azota Gas Processing, Ltd. utilizing the GSP process originally developed by Ortloff.

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© 2009 The Williams Companies, Inc. All rights reserved.

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Markham TXP-2 Cryogenic Plant

© 2009 The Williams Companies, Inc. All rights reserved.

Markham TXP-2 Cryogenic Plant

Ortloff GSP Process

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© 2009 The Williams Companies, Inc. All rights reserved.

Markham TXP-2 Cryogenic Plant

· The benefit of a GSP process as compared to that of traditional 1970's cryogenic plant is higher C2 and C3 recoveries and better CO2 tolerance without adding more horsepower. · In the GSP process, a portion of the feed gas is condensed, sub-cooled and flashed to the upper section of the demethanizer, which is the basic difference. · Ultimately, ethane continues to be the most efficient feed stock to make ethylene and ultimately polypropylene, which is purpose for achieving a higher recovery margin.

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© 2009 The Williams Companies, Inc. All rights reserved.

Markham TXP-2 Cryogenic Plant

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TXP2 (Train 2) is being built on the site of TXP1 (Markham TXP1 was commissioned in 2001). An early phase of the project was to add a post-boost compressor station consisting of two (2) Saturn driven compressors to minimize the residue compression HP when making part-flow HP deliveries. The post-boost compressors are conveniently located near the inlet and residue pipelines. Objectives in the design of Markham TXP2: · High reliability · Autonomous operation (from TXP1) · Cost conscious design · High C2 (ethane) recovery · CO2 tolerant · Low fuel cost (commensurate to similar GSP plants)

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© 2009 The Williams Companies, Inc. All rights reserved.

Markham TXP-2 Cryogenic Plant

Challenges and Mitigation

· · · ·

Autonomous operation ­ Used separate utility and control

systems with few exceptions such as the flare system

Site size constraints ­ Purchased and additional 10 acres Wetlands encroachment ­ Preserved the area deemed as

wetlands

Amine system utilization (How to use an amine system good for a

nominal 300 MMSCFD to support 2 plants totaling 500 MMSCFD capacity) ­ The design incorporated split of the inlet gas flow, and used a "mixing" tube to re-mix the inlet gas after treating 300 MMSCFD. The inlet stream can be remixed to proportionally lower the total CO2, or used to minimize CO2 levels in one train while processing un-treated gas in the other train.

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© 2009 The Williams Companies, Inc. All rights reserved.

Markham TXP-2 Cryogenic Plant Markham TXP-2 ­ Autonomous Design

· Divided the facility into three (3) "plants"

· · · Inlet treating (amine) Cryo train 1 Cryo train 2

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Shared systems

· · The original train 1 flare system was modified to operate autonomously with TXP1 and/or TXP2 TXP1 has a "hot oil" system for waste heat recovery. There is sufficient heat to supply the trim reboiler in train 1.

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Interconnected systems

· · · Fuel gas from one train can backup the other Instrument air from either train can back up the other Future crossover connections from TXP1 Residue compressor to TXP 2 Residue compressor 10

© 2009 The Williams Companies, Inc. All rights reserved.

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© 2009 The Williams Companies, Inc. All rights reserved.

Markham TXP-2 Cryogenic Plant

© 2009 The Williams Companies, Inc. All rights reserved.

Markham TXP-2 Cryogenic Plant

Cryo Piping Compressor Building

Expander Skid

Interconnecting Pipe Rack

© 2009 The Williams Companies, Inc. All rights reserved.

Markham TXP-2 Cryogenic Plant

Control System FAT

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© 2009 The Williams Companies, Inc. All rights reserved.

Markham TXP-2 Cryogenic Plant

Speed-to-Market is key, but you must build a fuel-efficient high ethane recovery plant at a very competitive capital cost.

© 2009 The Williams Companies, Inc. All rights reserved.

Markham TXP-2 Cryogenic Plant

© 2009 The Williams Companies, Inc. All rights reserved.

Markham TXP-2 Cryogenic Plant

Conclusions

The former slide is a chart from the MMS 2009 interim report of 2008 highlights. It's clear that a shorter development time is now prevalent in deepwater, and the deepwater oil discoveries tend to produce rich associated gas streams. The gas processing industry must keep up with these trends, and Williams is prepared to do just that.

© 2009 The Williams Companies, Inc. All rights reserved.

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