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INVESTIGATING THE FINANCIAL CLOSE OF PROJECTS WITHIN THE SOUTH AFRICAN
RENEWABLE ENERGY INDEPENDENT POWER PRODUCER PROCUREMENT PROGRAMME
I.J. Pieters1, M. Lotz1,2 & A.C. Brent3*
1Graduate School of Technology Management
University of Pretoria, South Africa
Ian.pieters@aurecongroup.com
2Enterprise Governance and Compliance
Nedbank Ltd, South Africa
marcol@nedbank.co.za
3Department of Industrial Engineering and
The Centre for Renewable and Sustainable Energy Studies (CRSES),
University of Stellenbosch, South Africa
acb@sun.ac.za
ABSTRACT
South Africa may have a generation capacity shortage in the near future. The Renewable
Energy Independent Power Producer Procurement Programme (REIPPPP) is playing an
important role in creating generation capacity to fulfil future demand requirements. This
investigation focused primarily on identifying the problems that have been experienced
with projects in the programme (e.g., to reach financial close). The research showed that
there is good alignment between the requirements in the request for proposals and those
from financiers. Several issues caused delays in projects reaching financial close. However,
respondents to this study indicated that the REIPPPP is well thought out and that several
problems are being addressed successfully.
OPSOMMING
Suid-Afrika kan in die nabye toekoms ’n tekort aan elektrisiteit opwekkingsvermoë ervaar.
Die regering se onafhanklike kragopwekkers groenkrag-aankoopprogram – of te wel die
REIPPPP – speel ’n belangrike rol in die skep van opwekkingsvermoë om aan toekomstige
aanvraag vereistes te voldoen. Hierdie navorsing het primêr gefokus op die identifisering
van die probleme wat ondervind is deur projekte in die program – spesifiek met finansiële
sluiting. Dié navorsing toon dat daar ’n goeie korrelasie tussen die vereistes van die
regering – in die navrae na voorstelle – en dié van finansierders is. Verskeie probleme het
vertragings in finansiële sluiting van projekte veroorsaak. Tog dui respondente van hierdie
studie aan dat die program goed deurdag is en dat verskeie probleme suksesvol aangespreek
word.
1 The author was enrolled for an M Eng (Project Management) degree in the Graduate School of
Technology Management, University of Pretoria
* Corresponding Author
South African Journal of Industrial Engineering November 2014 Vol 25(3), pp 57-68
1 INTRODUCTION
In the last decade, a need has been identified for the development of additional electricity
generation capacity in South Africa [1]. The need for this development originates from a
shortage of generation capacity based on the projected electrical load growth over the next
15 to 20 years [2] and the low electricity reserve margin [1, 3]. To help address this
problem, the Department of Energy (DoE), with the assistance of the National Treasury, has
implemented the Renewable Energy Independent Power Producer Procurement Programme
(REIPPPP). One of the aims of this programme is to accelerate the implementation of local
renewable energy (RE) generation. In 2012, the first REIPPPP projects in the programme
reached financial close. However, these projects have encountered many problems and
delays in reaching financial close. Examining these projects can provide much learning,
which could prove valuable in streamlining the execution of similar future projects.
Eskom, South Africa’s main electricity utility, has increased electricity tariffs significantly
in recent years in order to fund new generation capacity. The country has historically had
relatively low prices for electricity [1]; however, these low prices did not make sufficient
provision for the capital costs necessary to expand generation capacity [4]. Despite the
recent increases in electricity tariffs, South Africa still has relatively low price electricity,
which has, to some extent, restricted the creation of new generation capacity by Eskom or
through independent power producers (IPPs) [3]. Eskom has estimated that current
electricity tariffs are still almost 30 per cent below what is needed to cover its costs,
including those for the required capacity expansion, as put forward in its Integrated
Resource Plan (IRP) [2, 4].
Pegels [1] states that the South African electricity sector faces three main challenges:
1. An undersupply of electricity: South Africa has a narrow reserve power margin, and
the IRP has projected that the electricity demand will double in the next 20 years.
2. Funding problems for Eskom: Eskom will need an estimated ZAR 300 billion to upgrade
and expand electrical infrastructure, but they are underfunded.
3. High greenhouse gas (GHG) emissions due to the country’s largely fossil fuel-based
generation capacity. GHGs are a climate change driver, and can lead to environmental
damage.
De Beer [5] adds to this, indicating that market constraints as a result of the absence of
market reform – for example, the establishment of an independent system and market
operator – is also a major restriction that is often overlooked.
1.1 The South African stance on green growth
South Africa accounted for 37 per cent of Africa’s CO2 emissions from fuel combustion in
2010, due to the high percentage of electricity produced by coal-fired power stations [6,
7]. The country needs to focus on reducing its reliance on coal to reduce anthropogenic
GHG emissions from the power sector. There is also pressure from the international
community to move towards cleaner forms of energy. In 2009, during the 15th Conference
of the Parties (COP 15) meeting, South Africa committed to limit the growth of GHG
emissions to 34 per cent by 2020 and 42 per cent by 2025, relative to business as usual
(BAU) [7]. Investment in the development of RE generation capacity is thus needed.
Although RE plays a limited role in mitigating climate change, other aspects support its
implementation. Aspects particularly relevant to South Africa are [8]:
• RE contributes to the reduction of other pollutants and related risks arising from
conventional energy sources.
• RE contributes to increased energy security and reduces fossil fuel dependence.
• RE hedges against the volatility and long-term increases of fossil fuel prices.
• RE contributes to developing local employment.
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1.2 Historical renewable energy (RE) barriers in South Africa
In the South African context, factors that may inhibit the development of RE projects can
be summarised as:
• The lack of a formal and coherent approach to energy technology assessment from a
sustainability perspective [9].
• The country’s abundant coal reserves, and a historical bias towards using coal
generation [1].
• Until recently, confusing and out-dated legislation and policy around these projects
[3, 10].
• The difficult of obtaining funds due to the perceived high risks of these projects [1].
To promote RE development, the National Energy Regulator of South Africa (NERSA) initially
looked at using a Renewable Energy Feed-in Tariff (REFIT). This would allow IPPs to cover
costs and receive a reasonable return on investment. In 2011, however, the REFIT
programme was abandoned [11] and replaced with the Renewable Energy Bidding (REBID)
programme, or REIPPPP.
The REIPPPP was officially launched in August 2011. It requires prospective IPPs to submit a
bid with a proposed tariff for Eskom (the buyer). The bid also has to include details on the
proposed delivery of social and economic development for South Africans through their
projects. Only after social and economic development plans are found to be sufficient will
projects be adjudged on feasibility and tariff [11].
The bidding qualification and evaluation criteria are set out in the request for qualification
and proposals for new generation capacity, also known as the REIPPPP Request for
Proposals (RFP) [12]. Bids are assessed on the basis of compliance in two criteria
categories: qualification criteria, and evaluation criteria. The programme is being executed
in ‘bid windows’ and has set milestones for potential bidders [13]. However, these
milestones have been moved regularly.
1.3 Objectives of this paper
The third round of bidding in the REIPPPP is complete, and the first and second round
projects have reached financial close. Government is also now planning to convert the
REIPPPP into a rolling programme [14]. This, in conjunction with the problems that have
thus far been encountered by developers, warrants further investigation. It is thus the ideal
time to examine the projects involved in the REIPPPP that have been successfully brought
to financial close.
The associated research questions that this paper aims to address, within the context of the
REIPPPP, are the following:
• How good is the alignment between REIPPPP project selection requirements and the
requirements of financiers?
• What is required from financiers, before funding for a project within the REIPPPP is
approved?
• Why were REIPPPP projects delayed in reaching financial close?
2 PROJECT FINANCE
Project finance is based on the principle that lenders provide a loan for the development of
a project, taking into consideration the project’s risks and the cash flow projections.
Lenders have no recourse, or only limited recourse, to the developer of a project should
the project fail [15]. This is important for project development in emerging markets, where
lenders often have to rely on guarantees, long-term off-take agreements, and other
contractual agreements as security [15, 16].
59
The most important factors that lenders consider in assessing the financability of an IPP
project are the power purchase agreement (PPA), engineering procurement and
construction (EPC) agreement, operations and maintenance (O&M) agreement, technology
risks, and market risks [16]. Lenders also prefer a full EPC contract with a single point of
responsibility2 and a risk allocation between the developer and the contractor that satisfies
the lender [15, 17]. According to Yescombe [16], financial close is reached when all project
contracts, financing documentation, and agreements have been signed, and all conditions
from the lenders have been fulfilled or waived. In general, lenders for REIPPPP projects
require the following [18]:
• A fixed project completion date;
• A fixed project cost;
• Limited technology risk;
• Guarantees of the project output;
• Liquidated damages for delays and project performance;
• Some form of security from the contractor; and
• Restrictions on contractors’ ability to claim extensions of time and additional costs.
Considering all the required documentation, the period between signing the loan
documentation and reaching financial close can be lengthy, and developers need to ensure
that the process is managed effectively to avoid delays [16].
3 RESEARCH METHODOLOGY
A case study emerged as the preferred strategy. Unfortunately, case studies have
traditionally been viewed as lacking reliability and validity when compared with other
research methods. Flyvbjerg [19], however, indicates that these are common
misconceptions, and argues the following (emphasis added):
• Context-dependent knowledge is more valuable than theoretical knowledge.
• Formal generalisation is overvalued in research, while the individual example is
underestimated.
• The case study has no greater bias toward verification of the researcher’s
preconceived notions than other methods of inquiry.
• The case study is useful for both generating and testing of hypotheses.
• Good case studies should be read as narratives in their entirety, in order to
understand the context of the case.
These arguments support the notion that case studies can contribute valuable, valid, and
reliable information to any field of study. To enhance the quality of the research further,
tactics to address the four research quality tests [20] were considered in the research
design:
1. Construct validity: multiple sources of evidence were used to achieve data
triangulation.
2. Internal validity: pattern-matching was performed on the data collected.
3. External validity: the domain in which the study’s findings can be generalised is
clearly defined.
4. Reliability: a case study protocol was used and a chain of evidence was maintained.
Yin [20] states that multiple cases provide analytic benefits and more powerful conclusions
than a single case. With this argument in mind, it was decided that case studies would be
performed on several REIPPPP projects that have reached financial close. To increase the
2 Although in some renewable energy projects the EPC contract is sometimes split into an Equipment
EPC contract (e.g., wind turbines) and a Balance of Plant EPC contract (e.g., civil and electrical
works) [16].
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external validity of the research further, an embedded case study design was used. For this
purpose, the projects were analysed from various points of view.
To address the research questions and to assess the key requirements that play a role in
bringing REIPPPP projects to financial close, a framework of themes that have been
identified was created. The framework for organising a case study serves as a good analytic
strategy [21]. From the literature that was studied, it was deduced that bid selection
criteria, project financing structures, and requirements to reach financial close would be
important areas to investigate. The problems encountered in the REIPPPP were identified
as another important area to investigate. The following themes then formed the basis for
this case study:
• Lenders’ bankability criteria versus RFP qualification and evaluation criteria.
• Structuring of financing for RE projects.
• Requirements for reaching financial close.
• Problems and delays encountered in the REIPPPP.
By analysing each of these gaps, redundancies and circular conditions between the lenders’
bankability criteria and the RFP qualification and evaluation criteria could be identified to
generate answers for the research questions.
3.1 Embedded research methodologies
The embedded case study design readily lends itself to mixed methods research. Using
mixed methods can allow researchers to address more complicated research questions and
collect richer evidence than a single method [20].
For this particular case study approach, semi-structured interviews were used. The unit of
analysis for the semi-structured interviews was the projects within the REIPPPP. The
projects were analysed from various points of view to increase further the external validity
of the research. These included:
• Project developers who are participating in the REIPPPP;
• Commercial banks and development finance institutions (DFIs) that are providing debt
to REIPPPP projects; and
• Local experts and consultants on RE in South Africa.
3.2 Case study selection
This study selected the projects that were chosen as preferred bidders in the first two
rounds of bidding in the REIPPPP. Although this selection ensured that the events were
current, it also meant that there was a scarcity of academic literature specific to the
programme. Many of the developers and lenders who were identified to participate in the
study were unavailable for interviews, due to their participation in the third round of
bidding. Another issue that presented itself was the confidential nature of the information
that was requested from participants. Several parties who were approached declined to
participate because of this. It was agreed with interviewees that no confidential
information would be shared in the research, and that no specific views and comments
would be attributed to any individual or company.
Thus no information in this article can be attributed to a specific project due to the
confidential nature of the subject matter. Some indication of typical projects that were
studied should be given for the research to deliver valid results, which can be interpreted
within the correct boundaries. Typical projects that were studied are then as follows:
• Typical large onshore wind farms (70 MW to 150 MW): an example of such a plant is
the Tsitsikamma Community Wind Farm, a 95 MW plant situated in the Eastern Cape
Province that comprises 31 wind turbine generators.
61
• Typical small onshore wind farms (10 MW to 70 MW): an example of such a plant is the
Dassiesklip Wind Energy Facility, a 27MW plant situated in the Western Cape Province
that comprises nine wind turbine generators and uses an area of 350 hectares.
• Typical small solar photovoltaic (PV) plants (5 MW to 30 MW): an example of such a
plant is the Greefspan PV Power Plant, an 11MW plant situated in the Northern Cape
Province that comprises approximately 45 000 solar PV panels and uses an area of 44
hectares.
Figure 1 is a graphic representation of the case study design that was used. The figure
indicates the context in which each selected embedded unit of analysis was studied.
Figure 1: Research case study design
4 RESULTS: DATA GATHERED AND ANALYSIS
4.1 Lenders’ bankability criteria versus RFP qualification and evaluation criteria
The respondents all agreed that the REIPPPP and RFP were well-developed and formulated
through wide consultation with various stakeholders. In general, the majority of the
respondents agreed that there is a high degree of alignment between the criteria set out in
the RFP and the bankability criteria of lenders. The conservative approach of the DoE in the
RFP is aligned with the approach of lenders. The RFP created a good framework wherein
the developers had to structure the project and formed a base from which lenders could
assess projects. The lenders’ criteria, however, elaborate on the RFP criteria and are much
more onerous and extensive. Overall, it can be deduced that while the RFP looks for an
indication of the ‘degree of readiness’ of each project, which includes financing
arrangements, contracts, regulatory issues, and feasibility work, the lenders focus much
more on the degree of risk associated with each project.
4.1.1 Legal criteria, land acquisition, and use permitting
Lenders were of the opinion that the amount of legal and regulatory documentation
required for a bid submission was reasonable, although they were aware that the
documentation that is required is extensive and time-consuming. This perception can be
attributed to the reduction of risk in the projects when legal requirements are fulfilled. On
the other hand, developers were of the opinion that the extent of legal and regulatory
requirements was too burdensome for a bid submission. They did, however, understand the
necessity for the comprehensive requirements, as they ensure that a preferred bidder will
have a project that is ready to be executed. This perception can also be attributed to the
amount of risk and development costs associated with fulfilling these requirements. This
correlates well with a study of the regulatory processes in the REIPPPP [22], which states:
Research space: Renewable Energy Independent Power Producer Procurement Programme
Case Study 1:
Onshore wind generation
Case Study 2:
Solar PV generation
Unit of analysis 1.1
Typical large onshore
wind farms (70 MW-
150 MW), for
example:
•Cookhouse Wind
Farm – 135 MW
•Tsitsikamma
Community Wind
Farm – 95 MW
Unit of analysis 1.2
Typical small onshore
wind farms (1 MW-70
MW), for example:
•Dassiesklip Wind
Energy Facility –
27 MW
Unit of analysis 2.1
Typical small solar PV
plants (5 MW-30 MW),
for example:
•Greefspan PV
Power Plant – 11
MW
•Aries Solar Energy
Facility – 10 MW
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“A number of developers felt that the RFP was too detailed and required
developers to be too advanced in securing all the eventual regulatory
requirements for the projects. However, they acknowledged that they
understood why this was done and did accept that it reduced the risks of
projects failing after being selected.”
First-time participants experienced some problems with identifying the necessary permits
and authorisations that needed to be obtained. The RFP listed some requirements, but it
was not clear exactly what was needed in addition. The identification of all other
regulatory requirements was left to the developers.
4.1.2 Technical criteria
Developers experienced the technical requirements in the RFP and from the lenders as
reasonable. Lenders wanted much more detail, which developers expected. Detailed
technical data decreased the perceived risk of a project. Lenders particularly focused on
the production estimates, equipment, and EPC conditions. Lenders were looking for
minimal risk on the projects, while the RFP was looking for a viable project.
There were some concerns about the geographic distribution of the IPPs. Grid capacity
limitations could affect the feasibility of projects due to the concentration of plants in
certain areas. This concern might, however, gradually disappear as obvious RE locations are
taken up and developers are forced to look at more difficult areas.
4.1.3 Economic development criteria
Several issues were mentioned when it came to the economic development criteria.
Although the criteria are easily measurable, there were some concerns about the
specifications on local content and local community shareholding.
The need for certain percentages of South African ownership, black ownership, and local
content decreased the bankability of projects to some extent. This was because the
requirements were difficult to comply with and created extra risk (or perceived risk) for
the projects. Some developers felt that these criteria would not achieve the desired
objectives.
The local content requirements generally increased the EPC costs, and may have a more
significant impact on the EPC costs as they increase. This is in conflict with the aim to
decrease the cost of RE. The lack of manufacturing capacity in the country, along with the
lack of clear specifications about how far down the supply chain content would need to be
local, also created some problems. For instance, is it sufficient that wind turbine towers
are manufactured locally from imported steel?
It was also pointed out by some respondents that if government wants to achieve the
economic development goals of the REIPPPP, the weighting of these criteria would have to
be much higher in bid selection. It was felt that developers who attempted to achieve the
economic development requirements did not receive enough benefit from this. This was
because price was too heavily weighted in the selection criteria.3
4.1.4 Environmental consent criteria
In general, the environmental criteria were perceived as reasonable and well-managed. The
process did not allow developers to take any shortcuts. This correlates with PDG’s [22]
findings that many developers did not raise major problems with the Environmental Impact
Assessment (EIA) process. In general, the national Department of Environment Affairs (DEA)
dealt with most projects, and their authorisation processes were generally in line with the
legislated time frames.
The EIA process generally lasted about 14 months, which is in line with the National
Environmental Management Act’s (NEMA) requirements for a full EIA, which stipulates that
it should last 12 months. For wind farms specifically, 12 months had to be allocated to bird
3 Price had a weighting of 70 per cent and economic development 30 per cent in the RFP [12].
63
and bat monitoring. Detailed information was required before site layouts would be
approved. Some wind farms had to amend the micro-siting to accommodate bird and bat
migratory paths, for example.
In addition to the RFP requirements, some developers had to confirm that they comply with
the Equator Principles (EP) [23]. Three of South Africa’s major banks are members of the EP
Association. Members only provide project finance to projects that meet the requirements
of the ten EP. The EIA needs some adjustment before being accepted by lenders if it does
not align with the EP.
4.1.5 Financial and price criteria
The project cost and tariff were probably the most important aspect for all parties
involved. The DoE (through the RFP price caps) is attempting gradually to decrease the
tariffs as competition in the industry increases. Project developers are attempting to
maximise their returns while keeping the proposed tariffs at a competitive level. Lenders
are looking for a realistic tariff that will expose the projects to the least amount of risk.
Complications were experienced due to the tariff that had to be finalised for the bid
submission. The period from preferred bidder selection to financial close generally lasted
six months to a year. Unfortunately, for the first two rounds during this period, the global
economy worsened, which meant that EPC prices increased significantly.
Problems also occurred when finalising EPC contracts from the heads of terms (HoT)
provided for bid submission. Respondents highlighted this as one of the major causes of
delays in reaching financial close. This problem was compounded by the RFP preventing
changes in EPC contractors after bid submission. EPC prices increased due to the delays and
restrictions, and had a major impact on the achievable internal rate of return (IRR) for
projects. This caused some projects to become financially marginal.
4.2 Structuring of financing for renewable energy projects
The lenders primarily controlled the structuring of financing for the projects. They
generally followed international best practices for financing RE projects, although the
approach, especially for the first round, might have been much more conservative. Typical
financial parameters, as provided by the respondents, are shown in Table 1.
Table 1: Typical financial parameters for REIPPPP projects
Parameter
Typical range
Debt/ equity ratio
70/30 – 80/20
Loan term
15-17 years
Debt service coverage ratio (DSCR)4
1.35-1.25 annual DSCR
1.15-1.2 dividend lock-up DSCR
1.05-1.1 project default DSCR
Type of lender
Single commercial lender
IRR
15-20%
Weighted average cost of capital
(WACC)
10-12% (Johannesburg interbank agreed rate [JIBAR] used
as base)
The debt/equity ratio and debt service coverage ratio (DSCR)4 required on a project
improved as the appetite of lenders to participate in the REIPPPP increased. The first round
projects were mainly financed at a debt/equity ratio of 70/30. As the perceived risk of
these projects declined and market competitiveness increased, debt was increased to
4 Annual DSCR is the ratio between the annual available cash to service the annual debt and the annual
debt. Dividend lock-up DSCR is the DSCR below which dividend distributions are prevented. Project
Default DSCR is the DSCR below which the lender can take over control of the project or require all
debt to be repaid.
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80/20. In some instances, 5 per cent mezzanine5 loans were provided (debt/equity ratio of
75/5/20) to increase the attractiveness of a project and allow the developers to bid a lower
tariff; loan terms also increased. First round projects were financed with a loan term of 15
years, while later projects received terms of up to 17 years. The annual DSCR could go as
low as 1.25 for some projects, while the projects’ default DSCR could go as low as 1.05.
During the discussions, it became clear that a single lender was preferred over multiple
lenders (and syndicated loans). Multiple lenders were, however, necessitated sometimes by
the size and risk of a project. DFI funding appeared to be rare in the projects evaluated.
Many developers felt that DFI interest rates were high, and that the requirements to obtain
DFI funding were too burdensome.
Development costs for the projects, usually around ZAR 10-20 million, had to be carried by
the developers. This high cost was mainly ascribed to the amount of detail needed by bid
submission. These high development costs presented high risk to developers, especially due
to the possible losses that would have to be endured if a bid were not selected. These high
risks and costs meant that new, smaller, or less sophisticated development companies could
not easily compete with well-funded and experienced bidders.
4.3 Requirements for reaching financial close
The requirements for reaching financial close on the REIPPPP projects seem quite clear.
They are no different from any other project-financed project. However, the process of
achieving these requirements is extremely challenging. Identifying and obtaining all the
necessary documentation in a reasonable time proved to be difficult for most respondents,
especially for first-time participants.
Apart from all the RFP and regulatory requirements, lenders and equity investors were
concerned mostly about the long-term viability and credibility of any original equipment
manufacturer (OEM) or EPC contractor on the projects. A result of this was that lenders
required strict EPC and equipment guarantees. One respondent pointed out that these
guarantees were more expensive than international norms. Some of the guarantees that
were required included:
• A parent company guarantee from equity providers;
• Performance guarantees and parent company guarantees from the EPC contractor; and
• EPC payment guarantees from equity and debt providers.
Lenders also required a wrapped EPC contract with one party responsible for delivering
guarantees. This could mainly be ascribed to the degree of risk that the lenders were
willing to be exposed to. OEMs generally do not prefer this arrangement, as they would
ideally want only to supply equipment without getting too deeply involved in the projects.
According to DLA Cliffe Dekker Hofmeyer [17], the following is included in the requirements
to reach financial close:
• Power Purchase Agreement (PPA) with Eskom;
• Implementation Agreement (IA) with the DoE;
• Transmission Agreement or Distribution Agreement (as relevant);
• Direct Agreement; and
• Fully termed EPC and O&M contract.
Not including the problems with the EPC contract finalisation, respondents generally did
not experience any issues with the above-mentioned agreements.
5 The use of a mezzanine facility increases the DSCR to a more acceptable level, as the DSCR is only
calculated using the senior debt. Mezzanine facilities are more expensive than senior debt, but
cheaper than equity.
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4.4 Problems and delays encountered in the REIPPPP
Several problems and delays were experienced in bringing the REIPPPP projects to financial
close. In spite of the well-thought-out and highly successful programme, some issues are
still being addressed. The evaluation of the comprehensive bid documentation put strain on
the DoE and created delays in the programme. Some developers mentioned that the limited
number of local and suitably-qualified resources, especially law firms and banks, were
sometimes overloaded. This was due to the amount of work that had to be completed on
multiple projects, in a short time, to accomplish the target dates.
Eskom grid connection issues were a major cause of delays. Eskom timelines (up to 24
months) impacted EPC prices and construction interest. This reduced the incentive to
complete projects earlier than the schedules. The costing provided by Eskom was also
problematic. Bidders usually had to submit a bid with a grid connection cost estimation
from Eskom, which was around 60 per cent accurate. A price from Eskom that was 80 per
cent accurate would usually cost around ZAR 2-2.5 million. This created a major risk for
developers who had to finalise the tariff on a 60 per cent accurate grid connection price.
The water use licence application frustrated many developers. This could only be obtained
from the Department of Water Affairs (DWA) after selection as a preferred bidder. Detailed
designs had to be submitted for each water crossing in the plant, and these designs were
done at great cost and risk for the developers.
The level of detail required in a bid created the problem of high development costs, which
needed to be carried at risk. The respondents indicated that too much detail on certain
aspects of the projects was required at the bidding stage. This caused four problems:
1. Bidders were struggling to get complete information for bid submission.
2. Delays in bidding dates caused many developers to run out of funding, and led other
interested parties to look elsewhere for better opportunities.
3. New and smaller development companies could not easily compete with well-funded
and experienced bidders.
4. The amount of documentation that had to be reviewed in the preferred bidder
selection process put huge pressure on the selection timelines and resources.
Lastly, some respondents identified the risk of selling the power that is produced to Eskom
alone as a major issue. The risk lies in that if the PPA of any producer is retracted for any
reason, they will not be able to sell the power elsewhere. This problem increases the risk in
all projects, and consequently has an impact on interest rates provided by lenders.
5 CONCLUSION
The REIPPPP bidding is becoming increasingly competitive. This is, to a certain degree,
nullifying the need for tariff price caps in the RFP. Lenders are also gaining confidence in
the programme, and seem to have a growing appetite for participation in REIPPPP projects.
During the latest bidding round, lenders were offering more competitive financing
structures, and developers accepted lower returns, resulting in more competitive bidding
for these projects and lower RE tariffs. Many respondents were of the opinion that the RE
tariffs have reached optimum levels and are unlikely to continue decreasing. The DoE has at
least reached one goal in achieving low and competitive RE electricity prices.
This study attempted to answer the following research questions:
• How good is the alignment between REIPPPP project selection requirements and the
requirements of financiers?
• What is required from financiers before funding for a project within the REIPPPP is
approved?
• Why were REIPPPP projects delayed in reaching financial close?
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5.1 Alignment of REIPPPP selection requirements and the requirements of financiers
The respondents indicated that there is good alignment between the requirements in the
RFP and the requirements from financiers. The RFP was formulated through wide
consultation with industry players and international advisors, and is evolving with each
round. The entire process was widely complimented by respondents, which shows that it is
gaining the confidence of developers and lenders. There are, however, some issues that can
be addressed, and some streamlining of the process is needed.
The detailed requirements at bid submission fit well with the risk averseness of lenders and
ensure that sound projects are selected. Conversely, the level of investment that is needed
pre-bid poses a problem for some developers. Developers feel that they are exposed to
huge risk and financial loss if they are not selected as a preferred bidder.
5.2 Requirements of financiers for funding a project within the REIPPPP
Apart from the agreements, permits, and authorisations required, lenders were mostly
concerned about their exposure to risk on projects. This meant that detailed due diligence
work was completed on each aspect of a project by independent lender advisors. Most of
the information required at bid submission was more stringently verified and assessed by
lenders. Lenders also required strict EPC and equipment guarantees, including parent
company and performance guarantees. In finalising these contracts, lenders attempted to
limit their exposure to risk as far as possible. As lenders gained more confidence in the
process, stringent lender requirements were relaxed to some extent, especially with regard
to debt/equity ratios and loan terms. This allowed projects to be structured more
competitively with regard to financing.
5.3 Delays in reaching financial close for REIPPPP projects
The entire process was governed by milestone dates that were set by the DoE. These dates
were extended on several occasions, but several other issues also caused delays in the
financial close timeline for projects. The finalisation of EPC contracts, grid connection
timelines provided by Eskom (up to 24 months), and the water use licence application
process were some of the main causes of delays, especially for first-time participants in the
programme. Experienced developers who were aware of what was needed could, however,
manage the process to avoid these problems.
6 RECOMMENDATIONS FOR FURTHER RESEARCH
Several opportunities for further research have arisen from this study. Such research is
especially important to streamline and improve the REIPPPP process further:
• Tariff finalisation timing: Research regarding the timing of fixing the proposed tariff is
required. At present this happens at bid submission, but the developers are then
exposed to EPC price variations, grid connection price variations, and exchange rate
fluctuations. A possible solution is to use a stage-gate selection process. During the
first stage of selection, bids will be evaluated on feasibility merit. During the second
selection stage, projects will be evaluated on price and economic development
criteria.
• Economic development criteria weighting: Uncertainty exists surrounding the
weighting of economic development criteria, specifically local content requirements,
against price. Presently, price has a weighting of 70 per cent versus the 30 per cent
for economic development. Research is needed to ascertain what would add more
value to the South African economy: increasing local manufacturing capabilities or
decreasing the price of electricity?
• Grid location of generation plants: The issue of geographical generation distribution
can become a major one if not addressed. Geographically, South Africa already has
very centralised generation. This has a significant impact on the reliability and
stability of the national grid. Research is needed to establish which geographical areas
in South Africa would benefit from local generation.
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• PPA terms: Two possible areas for research regarding PPAs in the REIPPPP have been
identified. There is a research opportunity in determining what the optimum duration
of a PPA would be. Currently, the PPAs are only valid for 20 years after COD, but the
plant life of a project can be significantly longer. Another research opportunity lies in
determining the implications of selling electricity into the Southern African power
pool (SAPP) instead of only to Eskom. This would present many opportunities to
developers, but could also create some problems with wheeling electricity through the
Eskom grid.
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