REGIONAL LANDFILL PROJECTS IN CHILE

Transcription

1 VER+ MONITORING REPORT REGIONAL LANDFILL PROJECTS IN CHILE CDM registration reference number 1435 Monitoring period VER+: 16 December 2007 to 3 July 2008 Date of report: 30 March 2009 Version 2 1

2 INDEX PREAMBLE... 3 OBJECTIVES GENERAL PROJECT ACTIVITY INFORMATION Title of the project activity CDM registration date, crediting period and monitoring period Contact details Description of the project activity Real project implementation Baseline and monitoring methodology Changes against the PDD MONITORING OF THE PROJECT ACTIVITY Monitoring equipment Data logging technology Data transmission and processing Data validation and storage Managerial responsibilities Quality assurance and quality control Training of monitoring personnel Calibration and maintenance Changes against the PDD: calibration of the gas analyzer FORMULAS AND PARAMETERS USED FOR CALCULATIONS Formulas Parameters MONITORED AND CALCULATED DATA Monitored data Calculated data Calculation results

3 Preamble Format: Values are presented in International System of Units Dates are presented in the format dd/mm/yyyy Significant figures use three decimals Abbreviations: CDM VER+ GHG LFG Clean Development Mechanism Verified Emission Reductions Plus Greenhouse gas Landfill gas Objectives The purpose of this Monitoring Report is to quantify the amount of Greenhouse Gas Emission Reductions achieved, in tons of carbon dioxide equivalent (tco 2 eq), to be certified by the Designated Operational Entity as per the Kyoto Protocol and CDM Modalities Procedures requirements (decision 17.CP7). 1. General project activity information 1.1. Title of the project activity Project #1435: Regional landfill projects in Chile 1.2. CDM registration date, crediting period and monitoring period Registration date: 4 July 2008 Crediting period: 4 July July 2018 Monitoring period: 16 December July Contact details Stephane Vidaillet / Anne-Sophie Zirah Director of carbon finance / CDM project manager LFG Carbon Trading 4, rue de la Presse 1000 Brussels, Belgium 3

4 1.4. Description of the project activity The project activity is to build, operate and maintain a landfill gas (LFG) collection and flaring system on Viñita Azul landfill in Copiapo (Region III), Lajarilla landfill in Viña del Mar (Region V) and Leña Dura landfill in Punta Arenas (Region XII), Chile. The equipment to be employed includes, inter alia: a gas collection network, permeable pipes, and vertical gas wells and/or horizontal trenches a high temperature enclosed flare monitoring and control systems to measure the actual flow and composition of the LFG civil works Viñita Azul Lajarilla Leña Dura Figure 1.1 Location of the project activity 1.5. Real project implementation The project activity has been implemented on the landfills of Lajarilla and Leña Dura. Gas collecting system 4

5 The LFG collection system is composed of a network of vertical wells and interconnected pipes. The Lajarilla landfill network also includes horizontal trenches. Figure 1.2 LAYOUT DIAGRAM LEÑA DURA Figure 1.3 LAYOUT DIAGRAM LAJARILLA 5

6 The following pictures illustrate elements of the collecting system: Figure 1.4 Pipes Figure 1.5 Well head Figure 1.6 Well head (Leña Dura) Figure 1.7 Main collector 6

7 Figures 1.8 and 1.9 Horizontal trench at Lajarilla Degassing unit The degassing station includes a blower that produces suction for the extraction of the LFG. The LFG extracted is fed into a high temperature flare which enables the methane contained in the LFG to be completely oxidized by the flaring process. The system is equipped with a monitoring unit to measure the flow, the pressure and the temperature. At Lajarilla, the equipments are connected to the public electricity grid to satisfy their energy needs. At Leña Dura, a diesel generator is used for electricity supply. The technology employed in the project activity is the HOFGAS extracting and flaring station developed by the Swiss company Hofstetter Umwelttechnik. We use the complete extracting and flaring unit with the following particulars: the complete degassing unit is built in a ventilated container, providing securities against any weather or burglary risks and which would prove beneficial for noise reduction; safe and low emission combustion is guaranteed by a high temperature flare; safety devices: o EEX motor o flame arrester o slam shut valve o burner control with UV detector. The main elements of the unit are: a flare station a pump station a monitoring unit 7

8 Figure Degassing Unit Figure 1.11 Degassing station (Leña Dura) 1.6. Baseline and monitoring methodology Methodology ACM0001 version 05, Consolidated baseline and monitoring methodology for landfill gas project activities, has been applied to this project Changes against the PDD Implementation of the project activity took place on two sites, Leña Dura and Lajarilla, whereas three sites were included in the registered PDD. Besides, the degassing plant of Lajarilla is currently under commissioning, hence VER+ resulting from LFG destruction at Lajarilla are not considered in the present Monitoring Report. 8

9 2. MONITORING OF THE PROJECT ACTIVITY 2.1. Monitoring equipment The flare unit of Leña Dura was installed on 15/12/2007. It is equipped with the following instruments to capture the required monitoring data: Instrument Data monitored Manufacturer and model Serial number Flowmeter LFG flare,y Volume of gas sent to the flare Elster-Instromet Turbine meter SM-RI-X-K Thermometer T Temperature of the LFG Jumo Type EBL 160 AF Pressure sensor P Pressure of the LFG Rosemount Type 2088 Smart /0 4/07 Gas analyzer w CH4,y Fraction of methane in LFG NUK GAE Thermocouple T flare Temperature of the flare Jumo Type S Electricity meter EC y Electricity consumed by the equipment Landis + Gyr ZMD120ASer Figure 2.1 Gas flow sensor Figure 2.2 Pressure, temperature and flow control 9

10 Figure 2.3 Gas analyzer Figure 2.4 Electricity meter Note that flare efficiency has not been monitored during the first monitoring period. A default flare efficiency ratio has been applied to VER+ calculations. Data measured by the instruments is gathered in a data collecting system called Memograph with a Readwin2000 software for the visualization of the registered data. The Memograph enables to read graphics, event lists (e.g. alarms) etc Data logging technology The data from the instruments will be collected in MemoGraph (type: Visual Data Manager, Provider: Endress+Hauser), equipped with a Compact Flash card of 256 MB for the archive. The unit comes also with a preinstalled copy of software ReadWin2000 (from Endress+Hauser), that is used for the configuration and display of the MemoGraph. The system also offers 2 different ways of communication for output: - USB Interface - Modem transmission, using either protocol RS232, protocol RS485 or Ethernet Interface The MemoGraph is secured by means of a seal so the displayed value is true and protected against manipulation. The Monitoring unit collects the following parameters from the flare unit every minute (see Memograph output table 4.1): - Date & Hour:Min of the measure - Status validity of the measure - Average Gas Pressure in degree in mbar. - Methane concentration (CH 4 ). - Normalized gas Flow in Nm 3 /h. - Oxygen concentration (O 2 ). 10

11 - Average Gas Temperature in degree Celsius. - Average Flare Temperature in degree Celsius. The data are recorded on spreadsheet file with a predefined format. The file is then directly used for the monitoring report Data transmission and processing All parameters mentioned above are processed according to the following methodology: a) Automatic transmission: The MemoGraph is configured to communicate data by modem once a day. The results are sent using a direct dedicated phone line to a dedicated server machine that is physically installed in the office of Bionersis in Santiago de Chile. The Monitoring Director checks that this process is working correctly. b) Manual transmission: If automatic transmission fails, the Monitoring Director dials directly into the monitoring unit to collect the data. c) Physical Logging: If manual transmission fails, the Monitoring Director send a technician physically on site to retrieve the data from the monitoring unit using the USB interface. These data are then sent back to the office and recorded on the server. d) If all options above do not work, the following procedures will be used: 1. If data can be retrieved subsequently, they will be reintegrated on the server. 2. If data cannot be retrieved, no emissions reductions will be claimed for the period of data failure Data validation and storage Monitored values are controlled at 3 stages: A first control happens on site, when collecting data and reporting events Then a second check takes place at the time of uploading values to the server machine and to the on-line database The final validation is the responsibility of the monitoring director who analyses the events, cross-check the consistency of data and eventually take action if necessary Data calculations and storage Data transmitted by ReadWin is systematically exported to Excel (.xls format) and Real SQL Database (.rsd format) on a weekly and a monthly basis Data from ReadWin and data exports are stored physically on the disk of the server machine A daily backup of the server is done 11

12 Weekly and monthly calculations are uploaded on a secured on-line database (restricted access) A copy of the backup on a portable electronic storage device is held securely at the Bionersis office in Santiago. Copies of the files will be stored up to two years after the end of the crediting period of the project Managerial responsibilities The CDM aspects of the project are managed by the Director of Carbon Finance of LFG Carbon Trading SA, based in Belgium. The Director of Carbon Finance supervises the CDM Project Manager who is in charge of validation and verification activities (PDD writing and preparing the monitoring report). It is the ultimate responsibility of the Director of Carbon Finance to ensure the content of the monitoring report is correct at the time of requesting issuance. The monitoring plan is the responsibility of the Monitoring Director of the project, who reports to the Director of Carbon Finance for CDM matters (collection and storage of monitoring data) and to the Chief of Operations for operational matters. The Monitoring Director is accountable for the monitoring activities, the logging and record keeping of all monitored data. The Maintenance Director supervises the calibration and maintenance procedures. Maintenance programs are carried out on site by the Field Technician, who also makes sure the monitoring tools are operating correctly. CEO Bionersis S.A. Paris, France COO Bionersis Chile SA Santiago, Chile Director of Carbon Finance LFG Carbon Trading Brussels, Belgium Maintenance Director Bionersis Chile SA Santiago, Chile Monitoring Director Bionersis Chile SA Santiago, Chile CDM Project Manager LFG Carbon Trading Brussels, Belgium Field Technician Bionersis Chile SA On site, Chile Figure 2.5 Managerial organization 12

13 2.6. Quality assurance and quality control The monitoring report is the responsibility of the Director of Carbon Finance. As such, he will be allowed to control consistency of monitored data by any means, such as on-site audit, visual control of data existence on the server, cross-checking of data on the server with data provided by the Field Technician and/or the Maintenance Director and/or the Monitoring Director. Proper management processes and systems records will be kept by the monitoring director. The auditors can require copies of such records to judge compliance with the required management systems Training of monitoring personnel Employees involved in the monitoring were trained externally (17/12/2007) and internally (20/01/2008) on the following topics: Review of equipment and captors Calibration requirement Configuration of monitoring equipment Maintenance requirement 2.8. Calibration and maintenance Maintenance includes all preventive and corrective actions that aim at ensuring the good functioning of equipment, for instance: Functioning check up: visual control of the equipment state and of parameters allowing to identify a malfunctioning, Registration of operating settings, Cleaning up the equipment and the sensors, Adding lubricant, Replacement and change of defective parts of the dispositive, etc. Example: maintenance of the flare includes inter alia changing starting electrodes and UV lights, check and clean engine valve, check the insulating ceramics. Calibration of equipment consists in verifying, by comparison with a standard, the accuracy of a measuring instrument. The critical maintenance and calibration frequency and procedures are detailed below: 13

14 A) Flow meter The flow meter is subject to a regular maintenance and calibrated once a year by an external certified company. B) Gas analyzer The gas analyzer is calibrated by comparison with canisters of calibrated gases purchased from a certified gas supplier. This calibration was not done every month as stated in the monitoring plan of the PDD therefore the conservative approach was used (cf. 2.9). The maintenance of the gas analyzer consists in checking filters, ventilation system, thermostat, lights, pipe, emptying the condensate deposit, etc. The maintenance program is performed every week. C) Temperature and pressure of the LFG The temperature and pressure sensor calibration are calibrated annually. D) Temperature of the flare The thermocouple will be checked annually by an independent third-party E) Electricity meters The reading from electricity meters will be cross-checked annually with the invoices from and the national grid company or fuel supplier. Calibration frequency: every 5 years. General malfunction of equipment If the equipment (flow meter, gas analyzer, gauge, controller, MemoGraph, etc.) fails, the equipment supplier will be immediately notified. If possible, repairs will be carried out. If the damaged equipment cannot be repaired, it will be replaced at the earliest by the same or an equivalent unit. In some cases, portable tools will be used in order to carry out daily monitoring of the missing parameter(s). This data will be recorded on paper Changes against the PDD: calibration of the gas analyzer The PDD contains a few inconsistencies related to maintenance and calibration frequency and program. For instance, according to sections B.7.1 and B.7.2, the gas analyzer should be subject to a monthly maintenance, a monthly calibration and an annual calibration Maintenance and calibration: definition and frequency As stated in 2.8, the gas analyzer is calibrated by comparison with canisters of calibrated gases purchased from a certified gas supplier. This calibration ought to be done at least every 3 months. The maintenance of the gas analyzer consists in checking filters, ventilation system, thermostat, lights, pipe, emptying the condensate deposit, etc. The maintenance program is done every week. Hence, maintenance is performed weekly and calibration is done quarterly. 14

15 Actual implementation Since January 2008 the gas analyzer has been checked as part of a weekly maintenance program. Nevertheless, the gas analyzer was calibrated only on 10/04/2008, 29/08/2008 and 19/09/2008. In order to be conservative and because the PDD was not clear, we have applied a deviation to CER calculations to correct the lack of monthly calibration of the gas analyzer. Deviation Gas preparation was requested to AGA SA in early January 2008, nevertheless, the gas patron (44.9% CH 4 and 46.1% CO 2 ) was received only in March Hence, the first calibration performed by an external accredited company (High Solutions) took place on April 10. Results show that there is a deviation with respect to the gas certificate. This deviation was applied to the date, taking as reference the calibration date and the error for each calibration report. Therefore, we have applied the following deviations in order to adjust CER calculations for the first monitoring period: o From 16/17/2007 to 09/04/2008, calculations take into account a percentage of deviation of 5.3% o From 10/04/2008 to 03/07/2008, calculations take into account a percentage of deviation of 3.1%. These percentages of deviations can be considered acceptable as we were conservative in applying maximum error for the above-mentioned period. 15

16 3. FORMULAS AND PARAMETERS USED FOR CALCULATIONS 3.1. Formulas Emissions reduction (ERy) As specified by the methodology ACM0001 version 5, the CO 2 e emissions reduction shall be calculated as follows: ER y = (MD project,y MD reg,y) * GWP CH4 + EL y * CEF electricitry,y ET y * CEF thermal,y Where: ER y Emission reduction in a given year y, in tonnes of CO 2 equivalent (tco 2 e) MD project,y Amount of methane that would have been destroyed/combusted by the project activity during the year, in tonnes of methane (tch 4 ) MD reg,y Amount of methane that would have been destroyed/combusted during the year in the absence of the project, in tonnes of methane (tch 4 ) GWP CH4 Global Warming Potential value for methane for the first commitment period is 21 tco 2 e/tch 4 EL y Net quantity of electricity exported during year y, in megawatt hours, in MWh CEF electricity,y CO 2 emissions intensity of the electricity displaced, in tco 2 e/mwh ET y Incremental quantity of fossil fuel, defined as difference of fossil fuel used in the baseline and fossil fuel used during project, for energy requirement on site under project activity during the year y, in TJ CEF thermal,y CO 2 emissions intensity of the fuel used to generate thermal/mechanical energy, in tco 2 e/tj No energy is produced in the project activity, and since there is no methane destroyed for electricity or thermal energy generation, all the methane destroyed is the one destroyed by flaring, the above formulae can be simplified as follows: ER y = (MD flare,y MD reg,y) * GWP CH4 Methane destroyed by flaring (MDflare) MD flare,y = (LFG flare,y * w CH4 * D CH4) (PE flare,y / GWP CH4) Where: LFG flare,y Quantity of landfill gas flared during the year measured in cubic meter (Nm 3 ) w CH4 Average methane fraction of the landfill gas (m 3 CH 4 /m 3 LFG) D CH4 Methane density in tch 4 /m 3 CH 4 PE flare,y Project emissions resulting from flaring of the residual gas stream in year y (tco 2 ) 16

17 GWP CH4 Global warming potential of methane (tco 2 /tch 4 ) Methane destroyed in the absence of the project (MDreg) MD reg,y = MD flare * AF Where AF is an adjustment factor set to 4%. Project emissions resulting from flaring (PEflare,y) During the considered monitoring period, continuous monitoring of the methane destruction efficiency of the flare (flare efficiency η flare,h ) was not available; hence we have applied the following default values, in accordance with the Tool to determine project emissions from flaring gases containing methane: 0% if the temperature in the exhaust gas of the flare (T flare ) is below 500 C for more than 20 minutes during the hour h. 50%, if the temperature in the exhaust gas of the flare (T flare ) is above 500 C for more than 40 minutes during the hour h, but the manufacturer s specifications on proper operation of the flare are not met at any point in time during the hour h. 90%, if the temperature in the exhaust gas of the flare (T flare ) is above 500 C for more than 40 minutes during the hour h and the manufacturer s specifications on proper operation of the flare are met continuously during the hour h. The manufacturer s specifications that is applied is the condition on LFG flow: LFG flare,h > 40 m3/h. A 90% flare efficiency is the only value that happened to apply during the crediting period. Project emissions resulting from electricity consumption (PEPR,y) Electricity supply to Leña Dura, comes from diesel generators. According to methodology AMS-I.A, a default emission factor (EF CO2 or CEF electricity ) of 0.8 tco 2 /MWh can be applied to calculate project emissions resulting from electricity consumption. PE PR,y = EL PR,y * CEF electricity Where: EL PR,y CEF electricity Quantity of electricity consumed by the project activity during year y (in MWh) CO 2 emission factor for diesel generator systems (in tco 2 /MWh) 17

18 3.2. Parameters Fixed parameters applied Parameter Description Value Unit Source GWP CH4 Global warming potential of CH 4 21 tco 2 e / tch 4 IPCC 2006 guidelines CO 2 emissions intensity of the Methodology CEF electricity,y electricity consumed by the project AMS-I.A 0.8 tco activity electricity produced by a 2 e/mwh diesel generator D CH4 Density of methane t CH4 /m 3 CH4 Default AF Adjustment factor 4 % Legal report on regulatory requirements and on-site inspection Monitored parameters included into emission reductions calculations Parameter Description Unit Source LFG flare,y Quantity of landfill gas flared during Nm 3 Flow meter the year y measured in cubic meter w CH4 Average methane fraction of the LFG % (m 3 CH 4 /m 3 LFG) Gas analyzer η flare,h Flare efficiency % Thermocouple EL PR,y Quantity of electricity consumed by Electricity meter MWh the project activity during year y Other monitored parameters Parameter Description Unit Source T gas Temperature of the LFG C Thermometer P Pressure of the LFG mbar Pressure sensor O 2 Concentration of oxygen in LFG % (m 3 O 2 /m 3 LFG) Gas analyzer Regulatory requirements relating to landfill gas projects Laws and regulations 18

19 4. MONITORED AND CALCULATED DATA 4.1. Monitored data Regulatory requirements regarding landfill gas projects Chilean regulations regarding biogas management have been screened in January 2008 and July In January 2008, there were no regulations related specifically with landfill management. A new relevant administrative regulation was enacted in July 2008 by Supreme Decree n 189 of The decree includes interalia new procedures to obtain sanitary permits to develop landfill projects and the obligation to include a landfill gas management system to ensure safety conditions within landfill and surrounding places. Memograph The data collected by the MemoGraph are displayed via ReadWin2000, with a precision of a minute. Though, for practical reasons, monitored data of the period cannot be nested in the monitoring report (table exceeds 130,000 lines), an example of the Memograph output is presented below for 2 minutes: Table Example: Leña Dura, 1 st March :00:00 and 00:01:00 Pressure CH Date Time State 4 Flow (mbar) (%) (Nm 3 /h) O 2 (%) Tflare ( C) Tgas ( C) 01/03/08 00:00:00 OK , /03/08 00:01:00 OK , Calculated data Methane destroyed by the project activity: MDflare The average methane fraction of the landfill gas in the hour h (w CH4,h ) is calculated from the average methane fraction of the landfill gas every minute compounded with the LFG flow in the same minute. LFG flare,h is the average flow of LFG in the hour h. For practical reasons, only 2 examples are presented in the table below: Table Example: Leña Dura, 1 st March :00 and 1:00 Date/Time w CH4,h (%) LFG flare,h (m3) η flare,h MD flare,h (tch 4 ) = LFG flare,h *W CH4,h *η flare,h *D CH4 01/03/2008 0: /03/2008 1:

20 Electricity consumed by the project activity: ELPR,y The quantity of electricity consumed during the period is determined through a physical check on the electricity meter Emission reductions: ER As stated in the above formulae in paragraph 3.1, the emission reductions are calculated as follows: Table Example: Leña Dura, March 2008 MD project (tch 4 ) MD reg (tch 4 ) PE PR (tco 2 e) Leakage Total emission reductions (tco 2 e) MD project = MD flare MD reg = MD project *AF PE PR = EL PR * CEF electricity N/A ER y = (MD project MD reg )*GWP CH4 PE PR , Calculation results Emissions reductions (tco 2 e) Leña Dura Lajarilla Viñita Azul 16/12/ /12/ /01/ /01/ /02/ /02/ /03/ /03/2008 1, /04/ /04/2008 1, /05/ /05/2008 1, /06/ /06/2008 1, /07/ /07/ Total emissions reductions monitoring period 6,