Las Gallinas Valley Sanitation District Biogas Utilization Evaluation. LGVSD Board Meeting Presentation April 24, 2014

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1 Las Gallinas Valley Sanitation District Biogas Utilization Evaluation LGVSD Board Meeting Presentation April 24,

2 Introductions 2

3 Agenda/Meeting Objectives Project Vision Scope of Work Overview of Biogas Technologies Evaluation Results Recommendations Questions and Answers 3

4 Project Vision The Las Gallinas Valley Sanitary District (LGVSD ) wastewater treatment plant needs to upgrade its aged cogeneration system by 2016 to meet new air quality standards (BAAQMD Rule ) Evaluate biogas utilization alternatives to understand the long range option that best addresses economic, environmental, technical and social drivers

5 Scope of Work Task 1 - Biogas Utilization Technologies Evaluation Task 2 - Assess Existing Biogas Handling and Digester Heating Systems for each option Task3 - Cogeneration Third Party Development and Operations Review Deliverables Technical Memorandum details the findings of Tasks 1-3 Meetings Kickoff with Staff/Site Inspection Final presentation to review study findings 5

6 Overview of Biogas Utilization Technologies 6

7 Potential uses for Biogas CHP Heat Only Power Only Natural Gas 7

8 LGVSD Biogas Utilization Options 1. Refurbishment of existing cogeneration system, including gas cleanup 2. Gas cleanup and new internal combustion engine(s) 3. Gas cleanup and microturbines 4. Gas cleanup and on-site fuel cell 5. Gas scrubbing and compression for natural gas fueling station for fleet vehicles 6. Gas scrubbing for injection to the natural gas pipeline 7. Demolish existing cogeneration system & install 2 nd boiler 8

9 Refurbishment of Existing Cogeneration System Existing engine will not meet BAAQMD Rule (Jan 2016) Engine is over 20 years old Engine manufacturer (Waukesha) will not guaranty engine exhaust can be cleaned to meet rule. Any engine exhaust cleaning system will need to be frequently replaced Replacement engine parts will become difficult to obtain Alternative not considered for detailed evaluation

10 New Internal Combustion Engine Cogeneration System Engines that can meet BAAQMD Rule are much larger than existing engine Smallest available engine is three times larger than existing Not enough biogas is produced to run the engine Alternative not considered for detailed evaluation

11 Microturbine Cogeneration System System Overview

12 Microturbine Cogeneration System Currently available microturbine sizes match the projected biogas quantity at the plant. Two turbines at 52 kw output each Microturbines can operate below the BAAQMD required emissions standards Sufficient space is available at the site to install a system Microturbines provide a source of heat for the digester, existing boiler provides redundancy 400,000 Btuh total heat output Alternative considered for detailed evaluation

13 Microturbine Cogeneration System Site Layout GAS COMPRESSION/ SILOXANE REMOVAL H 2 S REMOVAL CHILLER EXISTING GAS STORAGE MICROTURBINES PRIMARY DIGESTER

14 14

15 Microturbine Cogeneration System Advantages Are available in size ranges ( kw) for small gas flows or small capacity plants. Can be used in conjunction with other biogas usage strategies and/or several turbines for various gas flow strategy or maintenance redundancy. Compact size and light weight. Lower maintenance costs compared to internal combustion engines due to small number of moving parts. No cooling required. Produce moderate levels of NOx and CO exhaust emissions. Are relatively quiet and suitable for outdoor installation without adding a separate building. Disadvantages Low electrical and thermal efficiencies compared to other CHP technologies. Require significant fuel gas cleanup including H 2 S, siloxanes, and moisture. Require high pressure fuel ( psig) which requires fuel compression. Warm weather (above 59 o F) reduces power generation and fuel efficiency. Due to issues with fuel treatment, thus far have not demonstrated a long service life. Currently, only one viable manufacturer of microturbines Capstone Turbine Corporation.

16 Fuel Cells Operational Overview

17 Fuel Cells LGVSD WWTP biogas production is insufficient for utilization in a fuel cell. The smallest currently available fuel cell is rated for 300 kw, followed by a 1500 kw unit. Very high construction and O&M costs for fuel cells, including requirement for a high level of biogas conditioning.

18 Fuel Cells LGVSD WWTP biogas production is insufficient for utilization in a fuel cell. The smallest currently available fuel cell is rated for 300 kw, followed by a 1500 kw unit. Very high construction and O&M costs for fuel cells, including requirement for a high level of biogas conditioning. Capital costs (>$4 million) Not enough biogas produced to run smallest available fuel cell. Alternative not considered for detailed evaluation

19 Compressed Natural Gas (CNG) Vehicle Fill Station Biogas would be cleaned to remove contaminants and carbon dioxide Gas would be compressed and stored on site Fill station to fuel CNG vehicles Priority of biogas goes to boiler first Alternative considered for detailed evaluation

20 Compressed Natural Gas (CNG) Vehicle Fill Station Two scenarios calculated Assume all gas can be utilized (117 gallons equivalent gasoline/day) Assume 20 gallons equivalent gasoline used per day Assuming all gas can be used is highly unrealistic 20 gallons per day consumption may also be optimistic Based on relatively small service area (few miles driven each day)

21 CNG Vehicle Fill Station Site Layout

22 22

23 Compressed Natural Gas (CNG) Vehicle Fill Station Advantages Fuel self generation would hedge against rising and uncontrollable fossil fuel costs. Cleanest vehicle fuel compared to conventional and other substitute fuels. Use of biomethane is very visible to the public. Use of biomethane is potentially politically advantageous. Potential for construction project funding under various State and Federal programs (AB 118, AB 32, and Renewable Fuel Standard 2). Eligible for Federal fuel credits (RINs). Biomethane as transportation fuel should command a premium tied to carbon credit trading under the Low Carbon Fuel Standard. Biogas used in vehicle fueling can have as low as 88% methane (relatively lower than that required for injection into gas grid). Disadvantages Requires a natural gas fueled fleet preferably nearby. Requires special infrastructure for fueling vehicles and/or accommodating increased traffic to the treatment plant for fleet fueling. Requires a long term commitment to the converted fleet vehicles. Requires significant high pressure onsite fuel storage. Conversion of CNG vehicles is up to 50% more than the price of a new vehicle cost. No heat or power for plant use is recovered. Current grant funding oriented towards projects large enough to compete in the California biofuels marketplace or projects without regulatory drivers.

24 Natural Gas Pipeline Injection Biogas would be cleaned to remove contaminants and carbon dioxide and compressed to gas main pressure Pipeline required from WWTP to PG&E gas main Requires PG&E furnished interconnect station Priority of biogas goes to boiler first Average biomethane output to pipeline 22,400 cu. ft / day Alternative considered for detailed evaluation

25 NG Pipeline Injection Site Layout LGVSD Plant Location APPROXIMATE ALIGNMENT OF GAS MAIN INTERCONNECT STATION

26 Natural Gas Pipeline Injection Advantages Eligible for Renewable Energy Credits (RECs) per the Energy Policy Act of 2005 and the CA Renewables Portfolio Standard. Enables users to participate in Self Generation Incentive Program. PG&E Gas Rule 21 has been revised to include a new subsection that describes the requirements for biomethane injection into PG&E s pipeline system as directed by the California Public Utilities Commission. Generally safe to operate since there are few pieces of equipment. Disadvantages Requires extremely clean gas. Not economically viable when the cost of natural gas is lower than the cost of electricity for the total demand of each at the facility. Up to about 12 percent of the biogas methane is lost depending on the purification process selected. Energy cost savings are significantly reduced due to the energy required to compress the gas. Only one other wastewater utility in CA currently producing pipeline gas Require additional biogas sampling and testing. Very high construction and O&M paid to PG&E No heat or power for plant use is recovered

27 Remove Existing Engine Demolish existing IC engine Add backup boiler and flare for redundancy Add biogas cleaning system for boilers Replace biogas storage unit Alternative considered for detailed evaluation

28 Evaluation Results 28

29 Evaluated Alternatives Remove Existing IC Engine Microturbines Compressed Natural Gas Vehicle Fueling Station Natural Gas Pipeline Injection Refurbishment of existing cogeneration system New internal combustion engine(s) Fuel cell 29

30 Economic Parameters Infrastructure Capital Cost Digester gas output 50,000 cu. ft./day Cost of power - $0.09/kW-hr avg = $26.38/MBtu Cost of natural gas - $1.00/therm (100,000 Btu) = $10/MBtu Cost of vehicle fuel - $2.50/GGE = $21.92/MBtu Operations and maintenance (O&M) costs Plant heat demand 400,000 Btuh avg = 17,500 cu. ft. DG/day Parasitic costs: H2S removal Siloxane removal Moisture removal CO2 removal Gas compression 30

31 Net Energy Production Alternative Remove Existing IC Engine (add boiler) Electrical Output (Btuh) Thermal Output (Btuh) Biomethane Produced (Btuh) 0 400,000 0 Microturbines 350,000 (104 kw) 400,000 0 CNG Vehicle Fill Station 0 400, ,000 (Up to 117 gallons gasoline equivalent) Pipeline Injection 0 400, ,000 (22,400 cu. ft. / day) 31

32 Biogas Alternatives Cost Summary Alternative Construction Cost Annual O&M Present Worth Total Present Worth Remove Existing IC Engine ($1,580,000) ($380,000) ($1,960,000) Microturbines ($2,200,000) $100,000 ($2,100,000) CNG Vehicle Fill Station ($2,900,000) $400,000 / ($1,360,000) ($2,500,000) / ($4,260,000) Pipeline Injection ($8,400,000) ($500,000) ($8,900,000)

33 Biogas Alternatives Cost Summary Microturbines CNG Vehicle Fill Station (low) CNG Vehicle Fill Station (high) Pipeline Injection Remove Existing IC Engine $0 ($2,000,000) ($4,000,000) Annual O&M Present Worth Construction Cost ($6,000,000) ($8,000,000) ($10,000,000)

34 Non-Cost Factor Evaluation Decision matrix of non-cost factors created and filled in by LGVSD staff and board members Ranking of factors averaged among respondents and weighted score calculated Engineer evaluated each biogas technology alternative for a 1 to 10 score of each non-cost factor Engineers score for each non-cost factor was multiplied by LGVSD weighted score. Non-cost factor scores for each alternative added up for final non-cost factor score 34

35 Sample Criteria Ranking/Weighting Criterion Score 35 Criterion Odor Safety&Health Consistent with community values GHG Criteria air pollutants Net renewable energy generation Proven technology Permitability Site impacts O&M Expertise System Longevity System Cost Ongoing O & M Costs A B C D E F G H I J K L M Odor emissions A A B C D E F G H I J K L M 1 Safety&Health B B B B B B B B B B B B B 13 Consistent with community values C C D E C G H I J K L M 3 GHG offsets D D E D G H I J K L M 4 Criteria air pollutant emissions E E E G H I J K L M 5 Net renewable energy generation F F G H I J K L M 2 Proven technology G G H I J G G G 9 Long Term Permitability H H H H H H H 12 Site impacts I I I I I I 11 O&M Expertise J J J J J 10 System Longevity K K K M 7 System Cost L L M 6 Ongoing O & M Costs M M 8

36 Non-Cost Factor Evaluation Weighted Score LGVSD WEIGHTING SCORE Factor Avg. Score Safety & Health 14.5 Long Term Permitability 12.4 O&M Expertise 11.8 Site impacts 10.9 Proven technology 10.0 System Longevity 10.0 Net renewable energy generation 8.2 Criteria air pollutant emissions 7.9 GHG offsets 7.6 Consistent with community values 4.2 Odor emissions

37 Non-Cost Factor Evaluation Engineers Score Microturbines NG Vehicle Fill Station Pipeline Injection Remove IC Engine Non-Cost Factor Score Notes Score Notes Score Notes Score Notes Safety & 9 Fewest amount Health of equipment 8 5 Low, based on increased vehicle traffic 9 Low amount of equipment Long Term Permitability 6 Strict air standards for stationary fuel burning equipment 6 Generally unregulated now, so future regulations are unknown 8 9 Backup equipment only O&M Expertise 8 3 rd party maintenance Site impacts 6 Similar to current cogeneration, but less noise and greater footprint 8 3 rd party maintenance 4 Location for vehicles to park while filling will disrupt site 8 3 rd party maintenance 6 No combustion emissions and less noise 8 Same as existing equipment 7 Same as existing equipment Proven technology System Longevity New concept; only one example in CA 8 Same as existing equipment 6 Turbines will wear faster than other alternatives 37

38 Non-Cost Factor Evaluation Engineers Score Microturbines NG Vehicle Fill Station Pipeline Injection Non-Cost Factor Score Notes Score Notes Score Notes Score Notes Net renewable 7 Good efficiency 4 Inherent losses 4 Inherent losses energy decrease decrease generation efficiency efficiency Criteria air pollutant emissions 8 Low emissions meet permit requirements GHG offsets 8 Utilizes all gas generated to make either electricity or heat Consistent with community values Odor emissions 5 Methane slip from CO 2 scrubber must be either vented or flared 6 Does not fully utilize gas available 6 5 Does not fully utilize gas available 5 Methane slip from CO 2 scrubber must be either vented or flared 5 Does not fully utilize gas available; use of gas by downstream users not traceable 5 Does not fully utilize gas available Remove IC Engine 3 Only generates heat with biogas 3 Most gas burned in flare; higher emissions than engine burned gas 3 Most gas burned in flare 1 Decrease in goals for biogas usage Total Weighted Points

39 Non-Cost Factor Evaluation Final Score 800 Non-cost Factor Scoring 700 SCORE Odor emissions Consistent with community values GHG offsets Criteria air pollutant emissions Net renewable energy generation System Longevity Proven technology Site impacts O&M Expertise Long Term Permitability Safety&Health Microturbines NG Vehicle Fill Station Pipeline Injection Remove IC Engine 39

40 Biogas Utilization Recommendations 40

41 Advantages and Disadvantages Summary - Microturbines Advantages Produces approximately same amount of electricity as current IC engine system Clean burning technology Lower cost than CNG vehicle fill station and pipeline injection All biogas would be utilized when system is not down for equipment maintenance Majority of biogas would still be utilized Disadvantages Additional equipment to maintain that LGVSD staff is unfamiliar with Significant capital cost 41

42 Advantages and Disadvantages Summary CNG Vehicle Fill Station Advantages LGVSD could self support its own CNG vehicle fleet fueling needs Clean burning technology Disadvantages Cost to convert or purchase fleet of CNG vehicles is high Unlikely that biogas would be fully utilized, resulting in increased flaring of biogas Possible significant impacts to site and safety due to increased vehicle traffic Access for non LGVSD may be undesirable due to increased safety and security risk LGVSD would be responsible for ensuring gas quality and be responsible for damages if quality was not met Cost of CNG produced is higher than cost at commercial fill station Reduces the amount of electricity generated on site 42

43 Advantages and Disadvantages Summary NG Pipeline Injection Advantages Minor impacts to the facility site and operations All biogas would be utilized when system is not down for equipment maintenance Disadvantages Extremely high capital and O&M costs Reduces the amount of electricity generated on site Would be the first biogas injection system with PG&E 43

44 Advantages and Disadvantages Summary Remove IC Engine Advantages Lowest cost High non cost factor score Simple to operate Minor impacts to the facility site and operations Could be expanded in the future if additional uses of heat are found Little to no issues obtaining an air emissions permit Least amount of maintenance required Disadvantages Reduces the amount of beneficial biogas utilization No on site power generation Additional biogas would be flared 44

45 Recommendations Install a microturbine system, or Remove existing IC engine system now and add microturbines in the future 45

46 Further Action Recommendations Before any final decisions are made regarding further development of any alternative described above, the following actions are recommended: Confirm the biogas production values with longer term trending data Test the biogas for siloxane levels and confirm the methane and hydrogen sulfide content Confirm the acceptability of the proposed equipment locations Decide if a new gas storage tank is desired Sensitivity analysis on the non-cost factors decision analysis 46

47 Questions and Answers 47

48 Additional Slides (If Time) 48

49 Project Delivery and Operations Options 49

50 Project Delivery Options Public Development and Operations Also known as Design / Bid / Build Traditional project delivery method Third Party Private Development Also known as Design / Build Engineering and construction as single contractor Public/Private Partnership Development and/or Operation The skills and assets of public and private entities are shared in delivering a service or facility An economic motivation for both the public and private entity to participate in the partnership must be present 50

51 Project Delivery Options Design/Bid/Build Advantages Disadvantages Project requirements are defined by owner and engineer Linear process takes time with less opportunity for schedule acceleration Can work toward preferred equipment Reduced collaboration between designer, contractor and operator Independent contracts for engineering and construction Relies on engineer s estimate to fund program Legal and widely used in all states and municipalities Owner warrants design document Well understood and time-tested process Less opportunity for cost savings Owners, regulatory agencies, and the public usually accept the results Owner deals with disputes, change orders and may delay project completion. 51

52 Project Delivery Options Design/Build Advantages Disadvantages Single point of responsibility Limited input from Owner after 30% design Provides early fixed price with reduced design cost Less Owner control over final construction details Performance warranty for design/builder Limited oversight by Independent Owner's agent Risk transfer to design/builder Design drawings are not as detailed Collaboration between designer and builder Costs beyond lump sum unknown to owner Time savings, shorter schedule due to reduced design and early start construction 52

53 Project Delivery Options Public/Private Partnership Advantages Disadvantages Single point of responsibility Limited input from Owner after initial concept design Provides early service fee price Complex negotiations Service performance warranty Limited oversight by Independent Owner's agent Risk transfer to PPP provider State laws vary on whether this can be done Owner is hands-off of the long term performance and operations, other than service requirements Limited input from Owner after initial concept design Requires performance guaranties by Owner for the minimum amount of gas produced with penalties if they are not met Could be conflicts over the amount of heat required by the plant and who would supply the heat 53

54 Project Delivery Options Recommendations Option Design/Bid Build Design/Build Public Private Partnership Microturbines Yes (1 st Choice) Yes (2 nd Choice) No CNG Fueling Yes (1 st Choice) Yes (2 nd Choice) No PG&E Pipeline injection Yes (1 st Choice) Yes (2 nd Choice) PG&E ICE Removal with Boiler/Flare installation Yes (1 st Choice) Yes (2 nd Choice) No 54

55 Benefit to Cost Ratio 400 Benefit to Cost Ratio Microturbines CNG Vehicle Fill Station (low) CNG Vehicle Fill Station (high) Pipeline Injection Remove IC Engine Non-cost factor score divided by total present worth (in millions of dollars) for each alternative 55

56 PG&E Pipeline Injection AB 1900 opens the door for injecting biogas into PG&E s gas network Interviewed PG&E Factors for injection of biogas into a PG&E gas line Biogas must be scrubbed to pipeline quality Pipeline operating pressure must be matched Volume/flow to be injected relative to pipeline s capacity Pipeline flow schedules may vary on various times and days of the week; storage may be needed PG&E builds, owns and operates interconnection station Supplier responsible for all actual capital costs and formula-based O&M costs Until cost allocation rulemaking is completed by CPUC, all project costs are charged to the developer Supplier will obtain all rights-of-way, permits, and easements needed for lateral pipeline, interconnection station, and access road 56

57 PG&E Pipeline Injection Capital Costs $15K initial pipeline system study $50K initial engineering and preliminary cost estimate $2.5M high level cost estimate to build station (variable) $875K state and federal taxes = 35% of interconnection station capital cost $30K interconnection station property acquisition ($5/sf) $360K lateral pipeline design and construction (3000 at $120/sf) $640K biogas conditioning, compression and preparation equipment O&M Costs Either 0.50% of interconnection station development cost per month, or One-time, up-front charge of the station s NPV historically 78% of station s capital cost $1.95M PG&E has never executed an agreement with a POTW Point Loma POTW in Southern California 57

58 Fuel Cells Advantages Produce exceptionally low levels of NOx, SOx, and CO exhaust emissions. Are frequently exempt from air permitting. Have very high electrical power efficiency. Generate less GHGs than ICEs due to better efficiency. Are extremely quiet. Are suitable for unattended operation. Disadvantages High construction and maintenance costs. Require high levels of system redundancy for fuel conditioning to remove all contaminants. Require highly specialized contract maintenance and servicing. Cell stacks have short lives; typically 5 years or less, with high replacement costs. Produce less recoverable heat than internal combustion engines. Have a long start up time. Supplemental natural gas would need to be purchased to operate a single unit. Susceptible to periodic shut downs during warm weather, unless equipped with a load bank. Continuously consume fresh water. Emerging technology. 58

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