Pipeline Quality Natural Gas from Digesters

Guild Molecular Gate Technology

Guild Associates, Inc

Guild Products to the Natural Gas Industry

• CO2 Removal units

• N2 Rejection units

• Dehydration units

– Water vapor removal

• Sorbead “Quick-Cycle” dew point control units

– Water and heavy hydrocarbon removal systems

• NGL Removal for CARB standards

• Compressors

Guild Projects

2005N2 & CO21050West Virginia13

2005N2 & CO2550SPEC #2 - WV12

2005N2 & CO21050Virginia11

2005N2 & CO2300SPEC #1 - OH10

2006N2 & CO2700Kentucky9

2005N2 & CO21400Virginia8

2004N2 & CO22100Indiana7

2004N2 & CO21750Illinois6

2004N2 & CO21050Kentucky5

2003CO2 7000California4

2003N2 & CO2700Texas3

2002CO2 700California2

2002N2 & CO2140Ohio1

Start-upSeparationFeed Rate SCFMLocationUnit

Guild Projects (Digesters in Blue / Landfill in Yellow)

Uni t L o c a t i o nF e e d R a t e M M

S C F D Status Separa t ion Star t -up

14 SPEC #3 - ID 3 4 7 Operat ing C O 2 May 2006

15 Virginia 6 9 4 4 Operat ing N 2 & C O 2 J a n . 2 0 0 7

16 West V i rg in ia 1 0 4 2 Operat ing N 2 & C O 2 J a n . 2 0 0 7

17 S P E C # 4 - W V 1 0 4 2 R e a d y t o S h i p C O 2 T B D

18 UK 8 3 3 Operat ing N 2 & C O 2 May 2008

19 West V i rg in ia 6 9 4 R e a d y t o S h i p C O 2 T B D

20 P e n n s y l v a n i a 1 3 8 9 Operat ing N 2 & C O 2 May 2008

21 S P E C # 5 - I D . 3 4 7 Operat ing C O 2 May 2008

22 S P E C # 6 - I L . 3 4 7 Operat ing N 2 & C O 2 May 2007

23 Cal i fornia 1 0 0 7 Operat ing C O 2 May 2008

24 W a s h i n g t o n 5 6 2 5 Operat ing N 2 & C O 2 D e c e m b e r 2 0 0 8

25 T e n n e s s e e 8 3 3 Operat ing N 2 & C O 2 O c t o b e r 2 0 0 8

26 West V i rg in ia 5 9 0 R e a d y t o S h i p N 2 & C O 2 D e c e m b e r 2 0 0 8

27 Br i t i sh Co lumbia 8 3 3 On-Si te for s tar t -up C O 2 N o v e m b e r 2 0 0 8

28 Cal i fornia 2 2 6 4 On-Si te for s tar t -up N 2 & C O 2 M a r c h 2 0 0 9

29 Cal i fornia 8 3 3 Fabr ica t ion N 2 & C O 2 Feb 2009

30 P e n n s y l v a n i a 5 0 0 0 R e a d y t o S h i p N 2 & C O 2 J u n e 2 0 0 9

31 T e x a s 1 2 5 0 D e s i g n C O 2 J a n u a r y 2 0 1 0

Ohio < 1 0 0 S C F M Operat ing C O 2 M a r c h 2 0 0 9

Other Separations

2009Dehydration1250West Virginia14

2009Dehydration1400Pennsylvania13

2007Dehydration700Illinois12

2009Dehydration700West Virginia11

2006Dehydration1050Virginia10

2006Dehydration700Kentucky9

2006Dehydration1050Virginia8

2006Dehydration7000Virginia7

2005Dehydration1400Virginia6

2004Dehydration1750Illinois5

2004Dehydration150Kentucky4

2009C4+ Removal3100Brazil3

2007C2+ Removal3500California2

2009C3+ Recovery140Kentucky1

Start-upSeparationFeed Rate SCFMLocationUnit

Other Separations

Flow Balance

Guild PSAAnd Vacuum

Pump

TAIL GAS3 psigCO2, H2S, H2OLost Hydrocarbons

FEED C1 CO2 H2S H2O

90 psig PRODUCT Pipeline Pressure CO2 = 1 to 2% H2S = < 4 ppm H2O = 7 lb/MM SCF

100 psig0 psig

Process Steps – Digester Gas

Feed Compression

GuildPSA

Product Compression(if required)

Tail GasTo Flare

CO2

H2SH2O

FEED

Sales GasCO2 = 1 to 2%

AdsorptionFlow

UpwardCO2H2SH2O

Small Methane Purge

RegenFlow

Down-ward

“Tail Gas”Vacuum Pump

Process Steps

Typical Material Balance (Methane Recovery 90% / Adjustable)

By Difference< 20 ppb~ 10 ppmSiloxanes

1391000609HHV BTU/FT3

Wet7 lb/MM SCFSaturatedH2O

0.88< 4 ppm0.40H2S

85.921.0039.60CO2

13.2099.0060.00C1

Composition, Mol %

150100100Temperature, F

390100Pressure, psig

4555100Flow

Tail GasSales GasFeed

Pipeline Acceptance

• Intrepid Technology and Resources, ID (Two units)

– Extensive testing of product stream purity

– Quality accepted by Intermountain Gas Company

– Sales also accepted as CNG meeting DOT regulations

– Removes 40% CO2 to <2%, Dehydrates, Removes 4000 ppm to < 4 ppm.

• BioEnergy Solutions, CA (Vintage Dairy)

– Sales to PG&E pipeline

– Removes 30 to 40% CO2 to <1%, Dehydrates, A few hundred ppm H2S removed to < 4 ppm

• Newark WWTP (Ohio)

– Producing pipeline quality gas

Project Optimization

• H2S

– May or may not require treatment.

– Can treat on tail gas stream (preferred) or feed stream

– Options: No Treatment, Digester Additives, Biological Treatment,Sulfatreat / Iron Sponge, Liquid Redox

• Tail Gas Disposal

– Enclosed thermal oxidizer due to low heating value

– Digester heating possible with combustion of tail gas.

– Recovery of heat from compression or flare. Generally expensiveand limited to larger flows

• Required Pipeline Pressure

– High pressure requires additional compressor

Processing Costs (Product Flow Basis)Product Based Processing Costs, $/MCF

Includes = Feed compression, PSA, Flare, Pipeline Tap, Installation, Power (5 cents/kW), Maintenance, Man-Power

10 year project at 8% Loan

0.00

0.50

1.00

1.50

2.00

2.50

3.00

3.50

4.00

4.50

200 350 500 1000 1800

Feed Flow, SCFM

Gas

Cos

ts, $

/MC

F ($

/MM

BTU

)

Tidelands CO2 Removal System

1 MM SCFD

38% CO2 Removed to <2%

Start-up May 2002

Spec Plant in Transit

Typical Deployment