GHG Report Template for CSA Standards GHG CleanProjects ...
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GHG Report Template for CSA Standards GHG CleanProjects® Registry
Version 1.0 – September 2009
GHG Report Template for
CSA Standards GHG CleanProjects® Registry
Carlos Lleras Restrepo Hydroelectric Power Plant
Report Version 3.0, February 2020
1.1. Relevance ................................................................................................................. 2
1.2. Completeness ........................................................................................................... 2
1.3. Consistency .............................................................................................................. 2
1.4. Accuracy .................................................................................................................. 2
1.5. Transparency ............................................................................................................ 3
1.6. Conservativeness ..................................................................................................... 3
2. Project description ........................................................................................................... 3
2.1. Project title ............................................................................................................... 3
2.2. The project´s purpose(s) and objective(s) are .......................................................... 3
2.3. Expected lifetime of the project ............................................................................... 3
2.4. Type of greenhouse gas emission reduction or removal Project ............................. 3
2.5. Legal land description of the project or the unique latitude and longitude ............. 4
2.6. Conditions prior to project initiation ....................................................................... 4
2.7. Description of how the project will achieve GHG emission reductions or removal
enhancements...................................................................................................................... 5
2.8. Project technologies, products, services and the expected level of activity ............ 6
2.9. Total GHG emission reductions and removal enhancements, stated in tonnes of CO2
e, likely to occur from the GHG project (GHG Assertion) ................................................ 8
2.10. Identification of risks ............................................................................................. 10
2.11. Roles and Responsibilities ..................................................................................... 10
2.12. Any information relevant for the eligibility of the GHG project under a GHG
program and quantification of emission reductions ......................................................... 10
2.13. Summary environmental impact assessment ......................................................... 15
2.14. Relevant outcomes from stakeholder consultations and mechanisms for on-going
communications ................................................................................................................ 16
2.15. Detailed chronological plan ................................................................................... 17
3. Selection and Justification of the Baseline Scenario ..................................................... 19
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4. Inventory of sources, sinks and Reservoirs (SSRs) for the project and baseline .......... 22
5. Quantification and calculation of GHG emissions/removals ........................................ 24
6. Monitoring the Data information management system and data controls .................... 27
7. Reporting and verification details ................................................................................. 32
1 . 1 . R e l e v a n c e
The sources selected for this project are the CO2 emissions associated with the generation of
electricity in the National Interconnected System (SIN) of Colombia, for the electric power
that is instead provided by the Carlos Lleras Restrepo Hydroelectric Power Plant. For more
details, refer to the section 4 Inventory of sources, sinks and Reservoirs (SSRs) for the project
and baseline.
The methodology selected was the ACM0002- Grid-connected electricity generation from
renewable sources, version 19.0, of the Clean Development Mechanism (CDM),
complemented with CDM TOOL07 – Tool to calculate the emission factor for an electricity
system, version 07.0 and TOOL05 – Baseline, Project and/or leakage emissions from
electricity consumption and monitoring of electricity generation, version 03.0.
These were selected because they fit the project type and are in accordance with the
requirements of Colombian regulations. (See 2.12 Any information relevant for the eligibility
of the GHG project under a GHG program and quantification of emission reductions). As for
the applicability of the methodology and the tool, please see Table 8, Table 9 and Table 10
for the justification. No deviations to the methodology and tools were presented.
1 . 2 . C o m p l e t e n e s s
The project considers all the energy dispatch to the national grid, measured at the final point
where the commercial frontier of the project is located. All sources of emissions identified
by the methodology were considered and no other relevant sources were identified. For more
details, refer to section 4 Inventory of sources, sinks and Reservoirs (SSRs) for the project
and baseline.
1 . 3 . C o n s i s t e n c y
The calculations are in line with the CDM methodology for projects for renewable energy.
Emission factors for the alternate sources of energy were taken from the Colombian
governmental entity Mining-Energy Planning Unit (UPME) for the National Interconnected
System (SIN). It is shown that the level of service is equivalent between the baseline and
project scenarios in section 3.1 Same type and level of service. Also, the consistency of the
baseline definition with the baseline requirements stated in the Resolution 1447 of 2018 is
described.
1 . 4 . A c c u r a c y
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The measurement methods used to obtain and manage the information related to electricity
generation are reliable, which reduces the propagation of uncertainty in the calculation. The
use of the emission factor for the SIN published by the corresponding official entity ensures
the reliability of the calculation.
1 . 5 . T r a n s p a r e n c y
An example calculation is provided (see section 5.5) with the sources of the emission factors,
the data of the operation of the project and the formulas used, and greater detail of the
calculations is reported in the file CarlosLlerasRestrepo_2019 Rev.xlsx
1 . 6 . C o n s e r v a t i v e n e s s
In the face of uncertainty, conservative assumptions will be applied regarding the emission
reductions.
2 . P r o j e c t d e s c r i p t i o n 2 . 1 . P r o j e c t t i t l e
Carlos Lleras Restrepo Hydroelectric Power Plant
2 . 2 . T h e p r o j e c t ´ s p u r p o s e ( s ) a n d o b j e c t i v e ( s ) a r e
The purpose of the project is the implementation and operation of a run-of-river hydroelectric
power plant connected to the Colombian national grid.
The Carlos Lleras Restrepo Hydroelectric Power Plant (hereafter “the Project”) is an electric
power generation project, but it also contributes to decrease the national emissions of carbon
dioxide through the substitution of polluting fuels as a source of electric power generation.
With its multiple benefits, it contributes to the conservation and protection of the Aburrá
River basin. With respect to the environmental effects, the Project has a minimum
environmental impact thanks to its characteristics of being a run-of-river intake project with
no dam.
The project owner Hidroelectrica del Alto Porce S.A.S. E.S.P. (Hidralpor) seeks to verify the
emission reductions of this project to use part of them to access the exemption from taxes on
imported equipment and machinery, applicable to exporters of certified carbon emission
reductions, according to the law 788 of 2002. The rest of the credits will be used in the
Colombian carbon market created after the implementation of the national carbon tax. Any
such verified emission reduction will not be used in any other context as GHG emission
compensation and will be cancelled or retired in the originating carbon standard.
2 . 3 . E x p e c t e d l i f e t i m e o f t h e p r o j e c t
The lifetime of the hydroelectric power plant is 50 years.
The lifetime of the emission reduction project is 10 years, from 22 November 2015 to 21
November 2025.
2 . 4 . Ty p e o f g r e e n h o u s e g a s e m i s s i o n r e d u c t i o n o r r e m o v a l P r o j e c t
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CDM Sectoral scope 01 – energy Industries (renewable / non-renewable sources)
2 . 5 . L e g a l l a n d d e s c r i p t i o n o f t h e p r o j e c t o r t h e u n i q u e l a t i t u d e a n d
l o n g i t u d e
The Project is located on the right margin of the Aburrá River, which is also called the
Medellín River upstream and the Porce River downstream, in the municipalities of Girardota,
Barbosa and Santo Domingo; department of Antioquia, Colombia.
Intake: 6 28 40.09 N, 75 16 38.96 W
Turbine house and discharge: 6 31 13.46 N, 71 15 06.84 W
Girardota Substation: 6 22 58.28 N, 75 27 18.31 W
The owner of the Carlos Lleras Restrepo Hydroelectric power plant is Hidralpor S.A.S. E.S.P.
2 . 6 . C o n d i t i o n s p r i o r t o p r o j e c t i n i t i a t i o n
Prior the project, there was no hydroelectric power plant where the Project is located. There
were several discharge points to the river upstream and downstream, two of them from local
water systems, and two of them from two existing run-of-river power plants that take water
from other rivers. Also a dam is located downstream for hydrogeneration. The following
illustration shows the relative location of the previously existing discharges and dam to the
Project.
Figure 1 Other uses and discharges near the project location
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Table 1 Aburrá river neighboring hydroelectric plants characteristics
Hydroelectric
plant
Capacity Beginning of
operation
Company Source of
information
La Tasajera 306 MW 1993 EPM EPM website1
Montañitas 19.9 MW 2000 Celsia Celsia website2
Porce II 405 MW 2001 EPM XM website3
2 . 7 . D e s c r i p t i o n o f h o w t h e p r o j e c t w i l l a c h i e v e G H G e m i s s i o n r e d u c t i o n s
o r r e m o v a l e n h a n c e m e n t s
Most of Colombia’s electricity comes from hydroelectric plants, especially those that use
dams. At the time this project was implemented, authorities in Colombia were promoting the
incorporation of thermal generation plants as a backup for the scenarios where extreme
weather conditions lead to low levels in dams or rivers. In fact, in Colombia, there is a
relevant concept that can be understand as “firm energy”; this was defined in the CREG
Resolution 071 of 2006 as the effective capacity of power generation plants to provide energy
to the national system continuously and independently of the weather or system conditions
throughout the year. This definition was made to enhance the reliability of the system. “Firm
energy” requirements give priority to large hydroelectric power plants with reservoirs and
thermal power plants, which are less vulnerable to weather variations that have caused
shortages in the Colombian grid under drought conditions on various occasions.
In the absence of the project, some more GHG- intensive generation plants were likely to
supply the electricity, for example a mixture of thermal plants and other hydroelectric plants.
In fact, thermal net effective generation capacity has increased about 11% between 2015 and
2019 (see Figure 2).
1 https://www.epm.com.co/site/home/institucional/nuestras-plantas/energia/centrales-hidroelectricas#undefined
2 https://www.celsia.com/es/centrales-hidroelectricas
3 http://paratec.xm.com.co/paratec/SitePages/generacion.aspx?q=capacidad
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Figure 2 Thermal effective generation capacity. 2015-2019. Prepared by the authors, data source: XM.
The GHG reductions achieved by the Carlos Lleras Restrepo hydroelectric plant result from:
- Reductions in the use of fossil fuels that would be used in the case thermal plants supply
the electricity;
-Although it is not accounted for, the absence of a dam may prevent methane emissions
because of the degradation of organic matter in the repressed water in case a dam-based
hydroelectric plant supplies the electricity.
2 . 8 . P r o j e c t t e c h n o l o g i e s , p r o d u c t s , s e r v i c e s a n d t h e e x p e c t e d l e v e l o f
a c t i v i t y
The project consists of a run-of-river hydroelectric power station with an effective capacity
of 78.2 MW, flow design of 75 m3/s and a power house with two Francis turbines. Carlos
Lleras Restrepo hydroelectric power plant has a gross head of 130.3 m, a lateral intake
structure, and sand traps designed to remove particles larger than 0.3 mm in order to protect
the turbines. From the intake structure, the water flows by tunnel to the powerhouse.
The project has a surface powerhouse located on the right margin of the Aburrá River. The
turbined waters are discharged directly into the Aburrá River through two independent
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suction tubes, reaching a tank controlled by a weir, which guarantees the submergence of the
turbines.
Table 2 Technical specifications of the project
Element Unit Value/Description
1. General specifications
Effective Capacity MW 78.2
Design flow m3/seg 75
Gross head meters 130.3
2. Diversion Works (L-W-H)
Flood Spillway meters 42x20x5.4
Download Fund meters 20x5x5
Intake Structure meters H=4.8 y W=5.7
Sand traps meters 34x8x3.6
Cargo Tank 57x10x13
Canal gate and Ecological Flow 1x1 /H-Wl
3. Power House (L-W-H)
Dimensions meters 55.35x17.1x12.5
4. Electro-mechanical equipment
Francis turbines (2), nominal capacity kW 40.43
Crane bridge T 100
Transformers kV 13.8
Sub-station Type External encapsulated
The project includes the connection to the National Interconnected System (SIN). The
connection is via a 33.4 km long 110 kV transmission line whose gateway is located at the
power house and who end point is the Girardota substation, property of Empresas Públicas
de Medellín (EPM).
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Figure 3 Carlos Lleras Restrepo Hydroelectric Power Plant diagram
The expected level of activity is based on the information of the generation of previous years,
maintenance plans, and operational conditions of La Tasajera Hydroelectric Plant (see Figure
1).
Table 3 Expected level of activity
PROJECTED GENERATION
MWH
2020 453,740
2021 453,740
2022 453,740
2023 453,740
2024 453,740
2025 453,740
The Project received the National Engineering Prize in 2016 for its high quality, run-of-river
design and implementation. Co-benefits of the Project include the cleaning and oxygenation
of the Aburrá River that has resulted in recovery of the river ecosystem downstream of the
project. This is evidenced by an increase in the presence of fauna including fish and reptiles,
documented in the biannual reports of environmental monitoring.
2 . 9 . To t a l G H G e m i s s i o n r e d u c t i o n s a n d r e m o v a l e n h a n c e m e n t s , s t a t e d i n
t o n n e s o f C O 2 e , l i k e l y t o o c c u r f r o m t h e G H G p r o j e c t ( G H G A s s e r t i o n )
Table 4 Emission reductions of the project
Year Estimated GHG emission reductions or
removals (tCO2)
22 November 2015 – 31 December 2015 12,619
1 January 2016 – 31 December 2016 139,991
1 January 2017 – 31 December 2017 167,979
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1 January 2018 – 31 December 2018 163,958
1 January 2019 – 31 December 2019 162,629
1 January 2020 – 31 December 2020 173,631
1 January 2021 – 31 December 2021 173,631
1 January 2022 – 31 December 2022 173,631
1 January 2023 – 31 December 2023 173,631
1 January 2024 – 31 December 2024 173,631
1 January 2025 – 21 November 2025 155,078
Total 1,677,365
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2 . 1 0 . I d e n t i f i c a t i o n o f r i s k s
Table 5 Project risks and mitigation strategies
Risk Mitigation strategy
High wear of components in contact
with water
Preventive maintenance and hard coating
Damage, break downs or collapse of
an electric tower or line
Preventive maintenance every 6 months, corrective
maintenance and frequent visual inspections
Accumulation of sediments in the
desander
Two of the eight are cleaned daily to evacuate
sediments
Lightning bolt in the electric line Pole to ground tests, lightning rods installed in the
beginning and end points
Non-compliance with the
regulations
Periodical review of regulations in force and
evaluation of compliance.
Non-compliance with the “firm”
energy commitment
Maintenance plans, buy third party electricity to
supply the obligations contracted.
2 . 1 1 . R o l e s a n d R e s p o n s i b i l i t i e s
Organization name Hidroeléctrica de Alto Porce S.A.S. E.S.P - Hidralpor S.A.S.
E.S.P
Role in the project Project proponent.
Contact person Luis Miguel Isaza Upegui
Title Manager
Address Calle 11 #98-07 Of. 201A, Bogotá, Colombia
Telephone +57 1 328 9770
Email [email protected]
2 . 1 2 . A n y i n f o r m a t i o n r e l e v a n t f o r t h e e l i g i b i l i t y o f t h e G H G p r o j e c t
u n d e r a G H G p r o g r a m a n d q u a n t i f i c a t i o n o f e m i s s i o n r e d u c t i o n s
2.12.1. Compliance with the requirements of the GHG CleanProjects Registry
The project complies with the requirements of the GHG CleanProjects Registry and
demonstrates compliance with ISO 14064-2, as described in sections 1.1 to 1.6 and
throughout this report. The verification report that accompanies the current report will
demonstrate further the conformity of the project with the requirements of the GHG
CleanProjects registry.
2.12.2. Context of the mitigation project
The Nationally Determined Contribution (NDC) of Colombia, presented in 2015, envisages
a unilateral and unconditional goal of mitigation of 20% of GHG emissions from the
business-as-usual (BAU) scenario in 2030. The goal was defined against the BAU scenario
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that was projected based on the national GHG Inventory of 2010, applying economic and
other assumptions. In this way, the year 2010 was defined as the "baseline year" of the
country, therefore, any activity that was implemented in previous years and reduced
emissions, is already embodied in the baseline and cannot be considered as "mitigation"
action for verification.
This situation is confirmed in decree 926 of 2017, Chapter 2, article 2.2.11.2.1, paragraph 1,
"Only reductions of GHG emissions and removals generated from 1 January 2010 may be
submitted." This project was implemented in 2015 and represents an activity different from
the BAU of the National Interconnected System (SIN).
Resolution 1447 of 2018 of the Ministry of Environment and Sustainable Development
(MADS) also defines the additionality criteria for sectoral GHG mitigation projects in article
37. Particularly:
Table 6 Compliance Analysis: Requirements of resolution 1447 of 2018
Criteria of 2018 resolution 1447 article 37 Project Compliance
GHG emissions reductions or removals are
considered additional when the head of the
sectoral mitigation project demonstrates that
they would not have occurred in the absence
of the GHG Mitigation initiative and which
generate a net benefit to the atmosphere with
respect to their baseline.
As presented in section 3, the choice and
justification of baseline is demonstrated,
which is different from the activity of the
initiative, and section 5 evidences the net
benefit to the atmosphere generated
compared to the baseline.
Likewise, GHG removals are considered to
be additional when they result from the
implementation of forestry GHG removal
activities, which are developed in areas other
than natural forest and that demonstrate the
positive net change of carbon deposits in the
area of development of the activity and other
criteria of additionality defined by the
Ministry of Environment and Sustainable
development.
Not applicable
Reductions in emissions or removals of GHG
resulting from compensation activities of the
biotic component resulting from the impacts
of projects, works or activities within the
framework of environmental licenses,
concessions, applications for single-use
permits of forest resources for land use
change, and the application for definitive
extractions of national and regional forest
reserves, are not considered additional.
Not applicable
Emissions reductions or GHG removals are
not considered to be additional when they are
Not applicable
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the product of preservation and restoration
activities in strategic areas and ecosystems
that access payments for environmental
services of GHG reduction and capture
according to what is established in chapter 8
of title 9 of Part 2 of Book 2 of Decree 1076
of 2015.
The reductions or removals of GHG
generated from the date of completion of the
legal terms of the compensations referred to
in this article, or the termination of payments
for environmental services of GHG reduction
and capture, shall be deemed to be additional.
Not applicable
The owners of sectoral GHG mitigation
projects must apply in all their actions and
procedures the additionality criteria set out in
this article, in complement to the
additionality criteria established by the GHG
certification program or carbon standard to
which it is subscribed.
The GHG CleanProjects Registry
certification program establishes the use
of the analysis of alternatives and
barriers to justify the selection of the
baseline scenario. In section 3, we
present the identification and selection
of baseline, meeting the criteria
established by the GHG certification
program.
Article 221 of Law 1819 of 2016 established the national carbon tax which began validity
from 1 January 2017. According to its regulation in Sole Statutory Tax Decree 1625 of 2016,
the tax is charged to the purchaser of fuel in proportion to its equivalence in tonnes of CO2e
generated from combustion. The rate is fixed per tonne of CO2e according to the carbon
content of the fossil fuel.
Since the dispatch of Decree 926 of 2017, a non-causation procedure for the national carbon
tax exists. It is possible to avoid the payment of the tax by means of the neutralization of the
GHG emissions associated with the use of the fuel, by verified GHG emissions reductions.
To avoid the payment of the tax, the purchaser of the fuel must inter alia show the declaration
of verification of the emissions reductions, issued by a verification body accredited under the
standard ISO 14065, equivalent to the quantity of fuel in question.
The requirements described by the decree for the characteristics of the emission reductions
that are valid for the non-causation of the tax, include:
Table 7 Compliance Analysis: Requirements of decree 926 of 2017
Requirement of decree 926 of 2017 Project Compliance
The mitigation initiative must be
developed in the national territory.
The project takes place in the national
territory (near the municipalities of
Girardota, Barbosa and Santo Domingo,
Antioquia).
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The initiative must be formulated and
implemented through a certification
program or carbon standard that has a
public registration platform.
The project is formulated through the GHG
CleanProjects Registry certification
program, which has a public registry.
Have been implemented following a
methodology, either from a certification
program or carbon standard, or from the
clean development mechanism.
The project is implemented from a clean
development mechanism methodology
(details below).
Do not come from activities that are
developed by the mandate of an
environmental authority.
The project is a voluntary activity.
Be certified by the certification program or
carbon standard and duly cancelled within
it.
The project will request certification by
GHG CleanProjects Registry and cancel
any reduction unit prior to use for non-
causation of the national carbon tax.
2.12.3. Applicability of the selected methodology and tool
As for the methodology and tool selected, the following table of applicability is presented
Table 8 Applicability analysis of the methodology: ACM0002 Version 19.0
Applicability
This methodology is applicable to grid-connected
renewable energy power generation project activities
that:
(a) Install a Greenfield power plant;
…
Achieved, the project
consists of the installation of
a Greenfield power plant,
option (a)
The methodology is applicable under the following
conditions:
(a) The project activity may include renewable energy
power plant/unit of one of the following types: hydro
power plant/unit with or without reservoir, wind power
plant/unit, geothermal power plant/unit, solar power
plant/unit, wave power plant/unit or tidal power
plant/unit;
…
Achieved, condition (a) is
fulfilled because the project
is a hydro power plant
without reservoir.
In case of hydro power plants, one of the following
conditions shall apply:
(a) The project activity is implemented in existing single
or multiple reservoirs, with no change in the volume of
any of the reservoirs; or
…
(a) The project consists of a
run-of-the river plant, so it
does not use a reservoir for
generation, thus, there is no
change in the volume of any
reservoir.
In the case of integrated hydro power projects, project
proponent shall:
(a) Demonstrate that water flow from upstream power
plants/units spill directly to the downstream reservoir and
Not applicable, the project
consists of a single power
plant, not an integrated hydro
power project.
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that collectively constitute to the generation capacity of
the integrated hydro power project; or
…
The methodology is not applicable to:
(a) Project activities that involve switching from fossil
fuels to renewable energy sources at the site of the project
activity, since in this case the baseline may be the
continued use of fossil fuels at the site;
(b) Biomass fired power plants/units.
Not applicable
In the case of retrofits, rehabilitations, replacements, or
capacity additions, this methodology is only applicable if
the most plausible baseline scenario, as a result of the
identification of baseline scenario, is “the continuation of
the current situation, that is to use the power generation
equipment that was already in use prior to the
implementation of the project activity and undertaking
business as usual maintenance”.
Not applicable, the project
consists of a Greenfield
power plant
Table 9 Applicability analysis of the methodological TOOL07 Version 07.0
Applicability
This tool may be applied to estimate the OM, BM and/or
CM when calculating baseline emissions for a project
activity that substitutes grid electricity that is where a
project activity supplies electricity to a grid or a project
activity that results in savings of electricity that would
have been provided by the grid (e.g. demand-side energy
efficiency projects).
Achieved, the project
activity supplies electricity
to the national grid.
Under this tool, the emission factor for the project
electricity system can be calculated either for grid power
plants only or, as an option, can include off-grid power
plants. In the latter case, …
Emission factor is calculated
for grid- connected power
plants only.
In case of CDM projects the tool is not applicable if the
project electricity system is located partially or totally in
an Annex I country.
Not applicable, the project
electricity system is located
in Colombia, a non-Annex I
country
Under this tool, the value applied to the CO2 emission
factor of biofuels is zero.
UPME calculates the
emission factor for biofuels
following the tool.
Table 10 Applicability analysis of the methodological TOOL05 Version 03.0
Applicability
If emissions are calculated for electricity consumption,
the tool is only applicable if one out of the following
Not applicable, the tool isn’t
used for electricity
consumption.
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three scenarios applies to the sources of electricity
consumption:
(a) Scenario A: Electricity consumption from the grid.
The electricity is purchased from the grid only, and either
no captive power plant(s) is/are installed at the site of
electricity consumption or, if any captive power plant
exists on site, it is either not operating or it is not
physically able to provide electricity to the electricity
consumer;
(b) Scenario B: Electricity consumption from (an) off-
grid fossil fuel fired captive power plant(s). One or more
fossil fuel fired captive power plants are installed at the
site of the electricity consumer and supply the consumer
with electricity. The captive power plant(s) is/are not
connected to the electricity grid; or
( c) Scenario C: Electricity consumption from the grid
and (a) fossil fuel fired captive power plant(s). One or
more fossil fuel fired captive power plants operate at the
site of the electricity consumer. The captive power
plant(s) can provide electricity to the electricity
consumer. The captive power plant(s) is/are also
connected to the electricity grid. Hence, the electricity
consumer can be provided with electricity from the
captive power plant(s) and the grid.
This tool can be referred to in methodologies to provide
procedures to monitor amount of electricity generated in
the project scenario, only if one out of the following three
project scenarios applies to the recipient of the electricity
generated:
(a) Scenario I: Electricity is supplied to the grid;
(b)Scenario II: Electricity is supplied to
consumers/electricity consuming facilities; or
(c) Scenario III: Electricity is supplied to the grid and
consumers/electricity consuming facilities.
Achieved, the project
scenario consists of
electricity supplied to the
grid, (a) Scenario I.
This tool is not applicable in cases where captive
renewable power generation technologies are installed to
provide electricity in the project activity, in the baseline
scenario or to sources of leakage. The tool only accounts
for CO2 emissions.
Not applicable, the tool is
used for monitoring
procedures not for
accounting CO2 emissions.
2 . 1 3 . S u m m a r y e n v i r o n m e n t a l i m p a c t a s s e s s m e n t
In line with the environmental legislation in Colombia, the project received the following
environmental license:
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- Resolution 130AN-1108-12109 of 2 August 2011, in which the environmental license is
conferred to MINCIVIL S.A. by CORANTIOQUIA (Autonomous Regional Corporation
of the center of Antioquia)
- Resolution 130AN-1111-12821 of 22 November 2011 in which the environmental
license is transferred to HIDRALPOR S.A.S. E.S.P.
- Resolution 1206-13256 of 22 July 2012, in which the environmental license is modified
in 4 subsections related to:
o Increase of the flow concession
o Measures for conservation of native plants
o Responsibilities for deficiencies in water supply to the surrounding community
o Allowance of activities like fuel and lubricants supply if specific requirements
and procedures are followed.
The table below describes the principal environmental impacts relevant during the operation
of the project, according to the Resolution N° 0355 of 18 February 2010.
Impact Description
Erosive process Will occur in the Medellín river, in the zones of the intake,
tunnels, turbine house and access roads.
Increase sediment in the
streambed
In the Medellín river
Physical and chemical
changes in water quality
In the Medellín River
Flow reduction In the Medellín river due to exploitation for energy
generation
Changes in hydrobiological
resources
In the Medellín River
Loss of plant coverage 16.5 m3 in Barbosa and 20.5 m3 in Santo Domingo, for
the intake, tunnels, pipelines, access roads and turbine
house.
Habitat disturbance Due to loss of plant coverage
2 . 1 4 . R e l e v a n t o u t c o m e s f r o m s t a k e h o l d e r c o n s u l t a t i o n s a n d
m e c h a n i s m s f o r o n - g o i n g c o m m u n i c a t i o n s
When the initial community consultation took place on 23 October 2010 and later the
community meeting on 19 and 20 May 2012 to start the civil works, the principal concerns
about the project were:
Table 11 Concerns and responses to the community related to the project
Community concern Hidralpor Response
Quantity of the water sources Previous geotechnical and geological
studies were made to prevent that situation.
The tunnel cladding prevents infiltrations.
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Use of local work force Explained the characteristics of quantity of
the labor force needed, especially for the
construction phase and also the type of
documents required.
Wear of the existing road infrastructure due
to transportation of machinery
Existing infrastructure was evaluated and no
problems were identified.
Petition to receive support from
HIDRALPOR to develop some community
projects
Although most of those projects were the
responsibility of the state, Hidralpor was
willing to support projects in articulation
with local institutions.
Effects on tourism The brook Aguas Claras, the principal
touristic place, will not be affected by the
project.
Also, Hidralpor established Community Attention Offices to attend community inquiries
during the construction phase:
- Zona Molino Viejo at the point PR12+000 of the road number 6205 at the left margin of
the brook Quebrada Aguas Claras
- Zone of adequation and construction of civil works for water collection in Vereda
Popalito
- School Las Beatrices
Furthermore, before the project started, it received two verifications related with special
communities:
- Verification of the existence of ethnic groups: The Resolution 000000099 of the Ministry
of the Interior confirmed on 19/10/2011 that there is no presence of ethnic groups in the
areas influenced by the project.
- Verification of the existence of indigenous communities: INCODER (Colombian
institute for rural development) in a communication on 13/12/2011 (Oficio No.
20111126897) declared that the areas influenced by the project does not interfere with
indigenous territories.
In the operation phase, the mechanisms for on-going communication are as follows:
- Point of attention in person at the power house.
- Telephone hotlines: phone numbers are available at community schools and the town hall
of Barbosa.
- Meetings are held with Communal Action Boards upon request.
No complaints related to the operation of the project have been received.
2 . 1 5 . D e t a i l e d c h r o n o l o g i c a l p l a n
Table 12 Detailed chronological plan
Activity Date Evidence
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Initial communities
stakeholder consultation
23/10/2010 Socialización comunidad
Etapa EIA.pdf
Environmental license 02/08/2011 Res. 130AN-1108-12109
de Ago 02_11 (Licencia
Ambiental CLLR).pdf
Stakeholder consultation 19/10/2011 Mininterior Resolucion 19
octubre 2011 No existencia
Resguardos.pdf
13/12/2011 Certificacion INCODER-
dic13-2011.pdf
Request for letter of no-
objection from DNA of
Colombia for emission
reductions projects that opt for
the CDM
30/01/2012 Solicitud Carta de No
Objecion30-01-2012.pdf
Reception of the response to
the request for letter of no-
objection from DNA of
Colombia
23/02/2012 Respuesta de MMA a
solicitud de No Objecion 23
-02-2012.pdf
Start of construction 18/05/2012 Acta de Liquidación Carlos
Lleras.pdf
Meeting with communities
when the construction started
19-20/05/2012 Socialización comunidad
Etapa EIA.pdf
Request for letter of national
approval from DNA of
Colombia for the CDM
10/07/2012 comunicacion MDL
100712.pdf
Hiring of the CDM validation
entity (DNV-CUK)
06/09/2012 Contrato DNV firmado 6-
09-2012.pdf
Reception of the first response
to the request for letter of
national approval from DNA
of Colombia
12/09/2012 Minambiente carta
aprobacion Nacional 11 sep
2012.pdf
Response to the request for the
letter of approval from DNA
of Colombia
18/09/2012 Recurso de Reposicion al
MinAmbiente Ver Final
Sep 17_12.docx
Reception of the second
response to the request for
letter of national approval
from DNA of Colombia
29/10/2012 Carta Minambiente sobre
MDL 22-10-2012.pdf
CDM PDD posted for
international stakeholder
consultation
30/10/2012– 28/11/2012 CDM website
CDM prior consideration
notification
06/12/2012 Prior consideration Carlos
Lleras.pdf
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Request for National approval
letter
19/02/2013 Minambiente feb19-
2013.pdf
End of the contract with DNV-
CUK
21/06/2013 Comunicacion Jun 19-13
Rpta Arias JUNIO 21-
2013.pdf
Response to requirements in
the process of receiving the
national approval letter
08/07/2013 Comunicacion Respuesta
Requerimiento
Minambiente Jul 8-13.docx
First temporary Import
Declaration for components
eligible for VAT exclusion of
imported equipment for being
a carbon credit exporter
30/01/2014 3. Declaracion de
importacion Embarque No
9.pdf
End of construction 28/05/2015 Acta de Liquidación Carlos
Lleras.pdf
Start of test operation 28/08/2015 RE 201544011821-1 -
Aplazamiento del Programa
de Pruebas.pdf
Start of commercial operation
(Start date)
22/11/2015 Declaración de Operación
Comercial Central CLLR
Radicada.pdf
Signing of ERPA 13/11/2018 Disponible en oficinas de
Hidralpor
Application for VAT
exclusion of imported
equipment for being a carbon
credit exporter
10/12/2018 26. HIDRALPOR Res
00953 IVA.pdf
Expiry of first temporary
Import Declaration for
components eligible for VAT
exclusion of imported
equipment for being a carbon
credit exporter
29/01/2019 Five years after date of
temporary import
declaration
Signing of addendum to
ERPA
29/03/2019 Disponible en oficinas de
Hidralpor
Approval of VAT exclusion of
imported equipment for being
a carbon credit exporter
31/05/2019 26. HIDRALPOR Res
00953 IVA.pdf
3 . S e l e c t i o n a n d J u s t i f i c a t i o n o f t h e B a s e l i n e S c e n a r i o According to ACM0002 version 19.0, the baseline scenario for a Greenfield power plant is:
electricity delivered to the grid by the project activity would have otherwise been generated
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by the operation of grid-connected power plants and by the addition of new generation
sources, as reflected in the combined margin calculations.
At the time the project was conceived, Colombia had adopted an increased reliance on
thermal-based generation capacity. After severe droughts registered during the 1990s (i.e.
1992, 1997) that caused power shortages with associated forced rationing, the national
system encouraged the development of more thermal generation capacity, specifically with
the intention of increasing the share of “firm” capacity and enhancing the system’s reliability.
Colombia’s important fuel reserves and the need to guarantee electricity supply through a
more balanced mix between thermal and hydroelectric generation supported the trend
towards increased thermal power capacity.
A barrier assessment table is made to clearly define that the delivery of electricity by grid-
connected power plants is the most possible scenario in the absence of the project activity.
Table 13 Description of project alternatives and barrier identification
Alternative Description of the measure Identified barrier
Grid - connected
power plants
(existing and new
generation)
Hidralpor does not install the
Project power plant and other
plants would supply power to
the grid
None
Thermal power
plants
Hidralpor installs a thermal
power plant instead of the
project. This type of plant is
based on the combustion of
fossil fuels.
Environmental impact, cost and
company know-how
Hydropower
plant with
reservoir
Hidralpor installs a hydropower
plant with a reservoir to store
water and have a more stable
generation.
Cost and some climate
vulnerability
Run-of-river
hydropower
plant (Project)
Install and operate a run-of-river
hydropower plant without any
reservoir.
Cost, maintenance and
operational, and significant
climate vulnerability
Table 14 Barrier analysis
Alternative Economic
barrier
Mainte-
nance and
operational
barrier
Cultural
barrier
Enviro-
nmental
barrier
Climate
Barrier
Grid -
connected
power
plants
Not
occurring
Not
occurring
Not
occurring
Not
occurring
Not
occurring
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(existing
and new
generation)
Thermal
power
plants
Low Significant Not
occurring
Very
significant
Not
occurring
Hydropowe
r plant with
reservoir
Significant Not
occurring
Not
occurring
Significant Significant
Run-of-
river
hydropower
plant
(Project)
Significant Significant Not
occurring
Low Very
significant
While economical barriers apply both to thermal and hydropower plants, run-of-river
facilities have more economic risks due to its higher climate vulnerability. These can be
overcome by applying the national and international incentives associated with GHG
mitigation projects, namely the VAT exclusion of imported equipment for being a carbon
credit exporter and the carbon credit sales revenues.
Furthermore, run-of-river hydroelectric plants face operational and maintenance barriers due
to the flow of sediments and particulate material that degrade the generation equipment and
cause turbulence, affecting generation capacity. The Carlos Lleras Restrepo plant is the first
run-of-river hydroelectric power plant developed by Hidralpor S.A.S. E.S.P. and has faced
such barriers in its design and operation. To address and mitigate these barriers once the
Project began operation, Hidralpor has undertaken scientific investigation projects with
support of Colciencias, a national government entity that promotes scientific, technological
and innovation development in the country.
3.1. Same type and level of service
The same type and level of service from the SIN is available prior to and after operation of
the Project plant. The UPME (Mining and Energy Planning Unit) published official data of
the maximum demand and net effective capacity for the years 2014 and 2015. The net
effective capacity is on average 1.6 times the electricity demand. The following figure shows
that a significant increase in the net effective capacity occurred in October 2014 of 832 MW,
which is more than 10 times the installed capacity of the project that started operation in
November 2015. As such, the level of service of the SIN was the same with and without the
installation and operation of the hydropower plant Carlos Lleras Restrepo, which was not
essential for compliance with the electricity demand of the country from the national grid.
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Figure 4 Maximum demand vs Net Effective Capacity of electricity system in Colombia. Source: UPME
3.2. Compliance with Resolution 1447 of 2018, article 35.
Article 35 of the resolution states that the baseline must be established according to the
reference scenario published by the MADS or approved by the Intersectoral Commission of
Climate Change. However, no such relevant reference scenario has been established. The
next option is to define the baseline pursuant to the methods of the national GHG inventory
in case there is information available at the higher methodological level according to IPCC
guidelines. For the inventory category regarding this project emission sources, 1A1a, the Tier
2 methodologies for CO2 were applied and the source of information is the FECOC, a
database elaborated by the UPME and MADS. However, Tier 3 methods are not applied.
Therefore, the baseline is determined according to the SIN emission factors published by the
UPME, which are calculated using the same emission factors used to elaborate the national
GHG inventory and site specific fuel consumption and electricity generation data to which
UPME has access.
3.3. Compliance with ISO 14064 requirements
There is excellent data availability to define the baseline scenario, also the sources of
information are reliable and no limitations on data were identified.
4 . I n v e n t o r y o f s o u r c e s , s i n k s a n d R e s e r v o i r s ( S S R s ) f o r t h e
p r o j e c t a n d b a s e l i n e 4.1. Project boundary
The spatial extent of the project boundary includes the project power plant/units and all
power plants/units connected physically to the electricity system that the Project power plant
is connected to.
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The greenhouse gases and emission sources included in or excluded from the project
boundary are identified in line with the CDM methodology ACM0002 and are shown as
follows.
Table 15 Emission sources included in of excluded from the project boundary
Source Gas Included Justification/Explanation
Bas
elin
e
CO2 emissions from
electricity generation in
fossil fuel fired power plants
that are displaced due to the
project activity
CO2 Yes Main emission source
CH4 No Main emission source
N2O No Main emission source
Other No There aren´t other GHG
associated with this source
Pro
ject
N/A CO2 No
There are not any GHG
associated with the operation of
the project activity
The methodology covers the following project emissions that do not apply to the Carlos
Lleras Restrepo hydroelectric power plant:
- For dry or flash steam geothermal power plants, emissions of CH4 and CO2 from non-
condensable gases contained in geothermal steam
- For binary geothermal power plants, fugitive emissions of CH4 and CO2 from non-
condensable gases contained in geothermal steam
- For binary geothermal power plants, fugitive emissions of hydrocarbons such as n-butane
and isopentane (working fluid) contained in the heat exchangers
- CO2 emissions from combustion of fossil fuels for electricity generation in solar thermal
power plants and geothermal power plants
- For hydro power plants, emissions of CH4 from the reservoir
Table 16 Controlled, affected and related sources of the project
Source Gas
How the GHG SSR change from the
baseline scenario to the project?
Controlled Not relevant N/A There is no related emissions source
relevant to the project activities
Affected
Emissions avoided from
power plants that are more
intensive in GHG emissions
CO2
The operation of the project prevents the
energy supply by plants that are
connected to the national grid that are
fossil fuel-based
Related Not relevant N/A There is no related emissions source
relevant to the project activities
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4.2. Process flow diagrams
Figure 5 Baseline flow diagram
Figure 6 Project flow diagram
5 . Q u a n t i f i c a t i o n a n d c a l c u l a t i o n o f G H G e m i s s i o n s / r e m o v a l s 5.1. Estimation of baseline emissions
Baseline emissions are calculated according to equation 11 of the ACM0002
𝐵𝐸𝑦 = 𝐸𝐺𝑃𝐽,𝑦 × 𝐸𝐹𝑔𝑟𝑖𝑑,𝐶𝑀,𝑦
Where:
𝐵𝐸𝑦 = Baseline emissions in year y (t CO2/yr)
𝐸𝐺𝑃𝐽,𝑦 = Quantity of net electricity generation that is produced and fed into
the grid as a result of the implementation of the CDM project activity
in year y (MWh/yr)
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𝐸𝐹𝑔𝑟𝑖𝑑,𝐶𝑀,𝑦 = Combined margin CO2 emission factor for grid connected power
generation in year y calculated using the “TOOL07: Tool to calculate
the emission factor for an electricity system” (t CO2/MWh)
For a Greenfield power plant like Carlos Lleras Restrepo hydropower plant, the quantity of
net electricity produced and fed into the grid corresponds to the electricity produced by the
new facility.
𝐸𝐺𝑃𝐽,𝑦 = 𝐸𝐺𝑓𝑎𝑐𝑖𝑙𝑖𝑡𝑦,𝑦
Where
𝐸𝐺𝑃𝐽,𝑦 = Quantity of net electricity generation that is produced and fed into
the grid as a result of the implementation of the CDM project activity
in year y (MWh/yr)
𝐸𝐺𝑓𝑎𝑐𝑖𝑙𝑖𝑡𝑦,𝑦 = Quantity of net electricity generation supplied by the project
plant/unit to the grid in year y (MWh/yr)
According to the methodology ACM0002 version 19.0, section 5.2.1 paragraph 22, the
baseline emissions factor is calculated according to the latest version of the TOOL07, and
this report uses the corresponding official national data. For the combined margin CO2
emission factor, official national figures calculated by the UPME are applied.
5.2. Estimation of project emissions
Project emissions are calculated according to equation (1) of ACM0002 version 19, as
follows:
𝑃𝐸𝑦 = 𝑃𝐸𝐹𝐹,𝑦 + 𝑃𝐸𝐺𝑃,𝑦 + 𝑃𝐸𝐻𝑃,𝑦
Where:
𝑃𝐸𝑦 = Project emissions in year y (t CO2e/yr)
𝑃𝐸𝐹𝐹,𝑦 = Project emissions from fossil fuel consumption in year y (t CO2/yr)
𝑃𝐸𝐺𝑃,𝑦 = Project emissions from the operation of dry, flash steam or binary
geothermal power plants in year y (t CO2e/yr)
𝑃𝐸𝐻𝑃,𝑦 = Project emissions from water reservoirs of hydro power plants in year
y (t CO2e/yr)
For Carlos Lleras Restrepo hydropower project 𝑃𝐸𝐹𝐹,𝑦, 𝑃𝐸𝐹𝐹,𝑦, and 𝑃𝐸𝐺𝑃,𝑦 are zero, because
the project doesn’t involve fossil fuel consumption, operation of geothermal power plants or
a water reservoir.
Furthermore, ACM0002 version 19.0, section 5.4.1 paragraph 36 states that for all renewable
energy power generation project activities, emissions due to the use of fossil fuels for the
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backup generator can be neglected. The Project has two backup generators, located at the
intake site and at the powerhouse.
One other use of fossil fuel was identified associated with the Project: a dump truck is used
for transporting solid waste recovered by the filters at the intake area to the landfill at a
distance of 5 km. The emissions from the dump truck are not accounted for since they are
minuscule.
Also, at the intake as well as at the powerhouse, there are meters for electricity consumption
by the offices, and this consumption is billed to Hidralpor as an end user. The associated
emissions are not accounted for since they are minuscule.
5.3. Leakage
No leakage emissions are considered. The emissions potentially arising due to activities such
as power plant construction and upstream emissions from fossil fuel use (e.g. extraction,
processing, transport etc.) are neglected.
5.4. Calculation of net emission reductions
The project emission reductions are calculated according to ACM0002 equation (17), as
follows:
𝐸𝑅𝑦 = 𝐵𝐸𝑦 + 𝑃𝐸𝑦
Where:
𝐸𝑅𝑦 = Emission reductions in year y (t CO2e/yr)
𝐵𝐸𝑦 = Baseline emissions in year y (t CO2e/yr)
𝑃𝐸𝑦 = Project emissions in year y (t CO2e/yr)
5.5. Example calculation
Baseline emissions
Description Parameter Unit 2016
Quantity of net electricity generation
supplied by the project EGfacility,y MWh 349,107
Combined margin CO2 emission factor for
grid EFgrid,CM,y tCO2/MWh 0.401
Baseline emissions BEy tCO2 139,991.9
𝐵𝐸2016 = 349,107 𝑀𝑊ℎ ∗ 0.401𝑡𝐶𝑂2
𝑀𝑊ℎ= 139,991 𝑡𝐶𝑂2
Project emissions
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Description Parameter Unit 2016
Emissions from fossil fuel consumption PEFF,y MWh -
Emissions from the operation of dry, flash
steam or binary geothermal power plants PEGP,y tCO2/MWh -
Emissions from water reservoirs of hydro
power plants PEHP,y MWh -
Project emissions PEy tCO2/MWh -
𝐸𝑅2016 = 139,991 𝑡𝐶𝑂2 − 0 𝑡𝐶𝑂2 = 139,991 𝑡𝐶𝑂2
6 . M o n i t o r i n g t h e D a t a i n f o r m a t i o n m a n a g e m e n t s y s t e m a n d
d a t a c o n t r o l s 6.1. Monitored parameters
The methodological TOOL05 “Baseline, project and/or leakage emissions from electricity
consumption and monitoring of electricity generation”, version 03.0 is used to determine the
monitoring plan.
Table 17
Data / Parameter: 𝐸𝐹𝑔𝑟𝑖𝑑,𝐶𝑀,𝑦
Data unit: tCO2/MWh
Description: Combined margin emission factor for the grid in year y
Source of data National emission factor published in Resolutions by the UPME, related
to the calculation of the combined margin emission factor, using the
procedures in the “Tool to calculate the emission factor for an electricity
system”.
Values applied: Year EF - tCO2/MWh
2015 0.388
2016 0.401
2017 0.367
2018 0.380
2019 0.381
2020-2025 0.383
Measurement
methods and
procedures:
The UPME page is reviewed annually to determine whether the official
value has been updated
Monitoring
frequency
Annually
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QA/QC
procedures:
The value applied is compared against the value of the previous year and
in case of notable differences, investigate the presence of errors/justify the
observed change
Purpose of data Baseline emission calculation
Any comment: For the year y of the project, the national emission factor of the year y-1
is applied, because usually the official value of the year y is published the
last month of the year y+1.
Table 18
Data / Parameter: 𝐸𝐺𝑓𝑎𝑐𝑖𝑙𝑖𝑡𝑦,𝑦
Data unit: MWh
Description: Quantity of electricity generated and supplied by the project power plant
to the grid in year y
Source of data Measurements archived by Hidralpor
Values applied: Year MWh
22/11/2015 - 31/12/2015 32,525
2016 349,107
2017 457,710
2018 431,470
2019 426,847
2020-2024 (yearly) 453,740
1/1/2025-21/11/2025 405,258
Measurement
methods and
procedures:
Use of a bidirectional electricity meter at the point where energy is
dispatched to the national grid.
Monitoring
frequency
Hourly, aggregated annually
QA/QC
procedures:
According to Resolution of the CREG 038 of 2014:
There must be a backup meter of the same specifications of the
principal meter
The measuring system must have a maximum total percentage
error of 0.1%
A third party entity (Telmetergy) is responsible for the measurement and
is certified to assesses the energy production by remote measurements.
Purpose of data Baseline emission calculation
Any comment: -
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6.2. Monitoring Plan
I. Methods
The following figure presents the general process for monitoring and reporting data relevant
for the operation of the Project. The principal actors described in the figure are:
- CGM: Measurement Management Center (in Spanish Centro de Gestión de Medidas).
For this project, the CGM is the company Telmetergy
- ASIC: Manager of the System of Commercial Interchanges (In Spanish, Administrador
del Sistema de Intercambios Comerciales). For this project the ASIC is the company XM.
- Boundary agent: The company responsible for the energy generation. In this project, the
company Hidralpor S.A.S. E.S.P.
Figure 7 Monitoring scheme.
The point of measurement is located at the Girardota substation, where the electricity is
dispatched to the national grid. There is a principal and a backup meter. Both are bidirectional
and measure both supply to and consumption from the grid.
The reading and recording of the meter data are done via 3G mobile communication by the
CGM, who collects the information and reports it via web service to the ASIC. Every day,
the CGM makes a generation report. The report must have the measurements of the principal
and backup meters of the real energy generation and consumption.
Then, the ASIC publishes the following information in the web service:
- Boundary code
- Boundary agent
- Net readings reported by the principal and backup meter
- Results of the validations of format and coherence of the measurements
- Number of days of failure
- Type of failure
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Furthermore, every measuring system of a power plant that is dispatching energy to the
national grid must have an Equipment Record, where the information related to the generator,
technical characteristics of the measuring system, communication interface, maintenance and
calibration procedures are described.
II. Roles and Responsibilities
Table 19 Roles and responsibilities in the monitoring plan
Role Responsibilities Competences Responsible
Boundary Agent Define the responsible
party for measuring.
Define for XM who may
access the meter.
Information storage.
Expertise in
electricity
generation and
dispatch
Owner of the
power plant:
Hidralpor S.A.S.
E.S.P.
Reading and
reporting the
primary data
Meter readings.
Reports to the XM
commercial demand
application.
Keep documented
procedures.
QA/QC assurance.
Expertise in the
measurement
procedures of
electrical energy.
Expertise in
electricity dispatch
measurement
regulations.
GCM: Telmetergy
Supervision of
the electricity
generation of the
power plant
Receive the generation
data.
Publish electricity
generated in its
informational platform.
Collection and payment
of the energy services
Expertise in the
measurement
procedures
processes of
electrical energy.
Expertise in
electricity dispatch
measurement
regulations.
Management of
generation of
electricity data.
ASIC: XM
Calibration and
maintenance
Maintenance and
calibration of the
measuring system.
Expertise in
electricity
measurement and
equipment.
Hidralpor
electrical engineer
III. Supervision and accountability
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According to CREG Resolution 038 of 2014
- Meters must allow local download of measurement data.
- Measuring systems must include the infrastructure for safe remote readings.
- The responsible party for the generation must keep data for at least two years.
- Local supervision, remote measurement and configuration of meter parameters must
have at least two levels of access and passwords for each user. Hidralpor determines
who may access to the meter and notifies the list of users to XM. XM defines
passwords and level of access given.
- Telmetergy has access to read the measurement, set parameters, and restoration of
equipment.
- The Grid Operator verifies the technical requirements of the measuring system.
- The CGM sends annually a report to the ASIC.
- When the principal meter fails, the data is taken from the readings of the backup
meter.
IV. Procedures for quality control and assurance and internal auditing
Data collected as part of the monitoring system will be archived in digital form and stored
for at least two years after the end of the emission reduction crediting period.
According to CREG Resolution 038 of 2014
- All elements of the measuring system must have a compliance certificate issued by a
national accredited entity.
- Meters must be calibrated by accredited laboratories before commissioning.
- Meters must be re- calibrated after any repair or intervention and every two years.
The periodic calibration must be certified by the ASIC.
- There must be detailed and documented procedures for data protection.
- The ASIC publishes the data received for verification and validation purposes in the
web application.
- Maintenance of measuring systems is done every two years, applying specific
procedures defined by the boundary agent.
- The ASIC web application verifies the coherence of the measurements when received
from the CGM.
- The ASIC must contract a five-year verification of the commercial boundaries.
- The CGM makes a daily analysis, evaluating coherence by comparing to typical or
historical values, tendency, seasonality and backup measurements.
Hidralpor receives a report from Telmetergy related to the power plant generation and each
month makes a cross check between this information and the information published by XM.
Telmetergy has the following procedures:
- Telemetering procedure
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- Procedure for validation and review of readings
- Procedure for validation by readings from the software Primeread
- Control procedure for database access
V. Correction procedures in non-conformity events
In case there is inconsistency between the information of the reports of Telmetergy and the
information published by XM, an agent of Hidralpor (Eudora) makes the corresponding claim
and follow-up to the ASIC.
When a failure is reported, there is a lapse of 15 calendar days to repair or replace the
equipment of the measuring system.
The CGM keeps contingency plans for reestablishment of the information systems and data
bases.
VI. Sampling methods
The monitoring plan does not apply sampling methods.
7 . R e p o r t i n g a n d v e r i f i c a t i o n d e t a i l s This report was prepared in accordance with ISO 14064-2 and the requirements of GHG
CleanProjects®. According to decree 926 of 2017, an accredited Verifier entity under the ISO
14065 standard was selected. The verification entity is an independent third party.
7.1. Monitoring period
For this document, emission reductions are reported from 01 January 2019 to 31 December
2019. A reduction of 162,629 tCO2 is claimed during this period.
7.2. Description of the implementation status of the project
The operation of the power plant has remained in continuous operation since the project
started its commercial phase. The events that affected generation temporarily during the
operation are described in the file “Eventos de geneación CLLR 2019”.
The monitoring system is presented in the following diagram.
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Figure 8 Carlos Lleras Restrepo hydroelectric generation – Monitoring period 2015-2018
7.3. Methodology deviations
Baseline emissions as well as project emissions are calculated according to the methodology.
7.4. Project description deviations
For this period, the parties involved, the project borders, the technologies employed, the
monitoring methods and the design of the mitigation project in general remain in accordance
with the description in the project report.
On 24 July 2018 the principal meter was tested in situ. On 25 July, the backup meter was
tested in situ. On these dates, the electricity generation data were taken from the readings of
the meter that was in normal service.
For calibration frequency of the electricity meter, CREG Resolution 038 establishes a
periodicity of two years. However, calibrations were done prior to entering into service in
May 2015 and the next one on July 2018. This did not affect the measurements, though,
because the July 2018 calibrations found both meters to be in satisfactory working order.
The total time out of service of each of the two units of the generation plant is taken into
account in the measurements of electricity generation, and therefore is accounted for
accurately in the emission reduction calculations.
7.5. Monitored parameters
Table 20
Data / Parameter: 𝐸𝐹𝑔𝑟𝑖𝑑,𝐶𝑀,𝑦
Data unit: tCO2/MWh
Description: Combined margin emission factor for the grid in year y
Measure/
calculated/ default:
Calculated, annually, by the UPME
Source of data National emission factor published in Resolutions by the UPME, related
to the calculation of the combined margin emission factor, using the
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procedures in the “Tool to calculate the emission factor for an electricity
system”.
Values of
monitored
parameter:
Year EF - tCO2/MWh
2015 0.388
2016 0.401
2017 0.367
2018 0.380
2019 0.381
Monitoring
equipment:
Not applicable
Measuring/
Reading/ recording
frequency:
Measuring: Not applicable
Reading: Annually
Recording: Annually
Calculation
method (if
applicable):
“Tool to calculate the emission factor for an electricity system”.
QA/QC
procedures:
The value applied was compared against the value of the previous year
and no notable differences were observed.
Purpose of data: Baseline emission calculation
Any comment: For the year y of the project, the national emission factor of the year y-1
is applied, because usually the official value of the year y is published the
last month of the year y+1.
Table 21
Data / Parameter: 𝐸𝐺𝑓𝑎𝑐𝑖𝑙𝑖𝑡𝑦,𝑦
Data unit: MWh
Description: Quantity of electricity generated and supplied by the project power plant
to the grid in year y
Measured/
calculated/ default:
Measured
Source of data: Measurements of the electricity meter archived by Hidralpor.
This information is also publicly available from the following website:
www.xm.com.co >Portal BI > Oferta > Histórico de oferta
Where daily generation data for each year is available for each generator.
Values of
monitored
parameters:
Year MWh
22/11/2015 - 31/12/2015 32,525
2016 349,107
2017 457,710
2018 431,470
2019 426.847
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Monitoring
equipment:
Principal Meter
- Type: Bidirectional energy and power quality meter
- Model: ION 8650A
- Accuracy: According to meter type 0.2S
- Serial: MW-1407A572-01
- Calibration frequency: According to Resolution CREG 038 of
2014, every two years.
- Date of last calibration:
o 26/07/2018 – Laboratory of calibration and test of gas and
energy meters - Empresas Públicas de Medellín E.S.P.
o 25/05/2015 – Laboratory of calibration of gas and energy
meters – Empresas Públicas de Medellín E.S.P.
Backup Meter
- Type: Bidirectional energy and power quality meter
- Model: ION 8650A
- Accuracy: According to meter type 0.2S
- Serial: MW-1407A570-01
- Calibration frequency: According to Resolution CREG 038 of
2014, every two years.
- Date of last calibration:
o 26/07/2018 – Laboratory of calibration and test of gas and
energy meters - Empresas Públicas de Medellín E.S.P.
o 25/05/2015 – Laboratory of calibration of gas and energy
meters – Empresas Públicas de Medellín E.S.P.
Measuring/
Reading/ recording
frequency:
Measuring: Every 15 minutes
Reading: Every 60 minutes
Recording: Download information at least daily.
Reporting: Every morning Telmetergy sent a report to Hidralpor S.A.S.
E.S.P. with the generation of the previous day.
Calculation
method (if
aplicable):
Convert data in kWh to MWh.
QA/QC
procedures:
Telmetergy:
- Applied their procedure for validation and review of the readings,
which is a verification of data before it is reported to XM.
- Applied their procedure for validation by readings primeread
software, which consist on the comparison of data from (i) in situ
downloaded data, (ii) database information and (iii) downloaded
data from XM.
- Daily they sent a report directly to Hidralpor S.A.S E.S.P. with the
energy generated the day before.
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o The reports analyzed generation data, commercial activity
and climate conditions important for the power generation
activity.
Hidralpor:
- Monthly checked for consistency the data reported by Telmetergy
against the commercial data reported by XM.
XM:
- Received the report of the energy generated, and verified
coherence of the readings of the principal and backup meters
Purpose of data Baseline emission calculation
Any comment: -
7.6. Emission reduction calculation
For more detail information see the file CarlosLlerasRestrepo_2015-2018_v1.xlsx
Baseline Emissions
Description Parameter Unit Year
22/11/2015 -
31/12/2015 2016 2017 2018
2019
Quantity of net
electricity
generation
supplied by the
project
EGfacility,y MWh 32,525 349,107 457,710 431,470
426,847
Combined margin
CO2 emission
factor for grid
EFgrid,CM,y tCO2
/MWh 0.388 0.401 0.367 0.38
0.381
Baseline emissions BEy tCO2 12,619 139,991 167,979 163,958 162,629
Project Emissions
Description Parameter Unit Year
22/11/2015 -
31/12/2015 2016 2017 2018
2019
Emissions from fossil fuel
consumption PEFF,y tCO2 - - - -
Emissions from the operation of
dry, flash steam or binary
geothermal power plants PEGP,y tCO2 - - - -
Emissions from water reservoirs
of hydro power plants PEHP,y tCO2 - - - -
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Project emissions PEy tCO2 - - - -
Emission reductions
Description Parameter Unit Year
22/11/2015 -
31/12/2015 2016 2017 2018
2019
Emission
reductions EGfacility,y tCO2 12,619 139,991 167,979 163,958
162,629
7.7. GHG Assertion
Year
Estimated
baseline
emissions or
removals (tCO2e)
Estimated project
emissions or
removals (tCO2e)
Estimated
leakage
emissions
(tCO2e)
Estimated net GHG
emission reductions
or removals (tCO2e)
22/11/2015 -
31/12/2015
12,619
- -
12,619
2016 139,991 - - 139,991
2017 167,979 - - 167,979
2018 163,958 - - 163,958
2019 162,629 162,629
Total 647,176 - - 647,176
7.8. Verification process
This report was prepared in accordance with ISO 14064-2 and the requirements of GHG
CleanProjects®. According to decree 926 of 2017, an accredited Verifier entity under the
ISO 14065 standard was selected. Ruby Canyon Engineering, Inc., hereafter RCE, who is
an independent third party, conducted the verification process from January 25 to March 23,
2020.
The verification included the development of a COI form to identify any potential conflict of
interest. RCE developed a risk-based verification plan that included a strategic review, risk
assessment and sampling plan. The sampling plan included assessment of project boundaries,
the GHG management systems, information control systems, quality assurance (QA)
procedures, application of emissions factors, and GHG emission reductions calculations. All
verification activities were directed through the desktop review. Upon review of the
documentation, RCE submitted on round of findings. Hidralpor´s team attended all
clarification and documentation requests. RCE’s independent peer reviewer conducted a
review of the GHG Report and Assertion, verification procedures, sampling plan, findings,
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Verification Report and Verification Statement. The Verification Report was issued March
23 after the exit meeting was held.