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Technical Requirements for Connecting Solar Power Plants to Electricity Networks
By Omar H. Abdalla and Azza A.A. Mostafa
Submitted: February 27th 2019Reviewed: July 8th 2019Published: November 27th 2019
Home > Books > Innovation in Energy Systems - New Technologies for Changing Paradigms
This chapter discusses basics of technical design specifications, criteria, technical terms and equipment parameters required to connect solar power plants to electricity networks. Depending on its capacity, a solar plant can be connected to LV, MV, or HV networks. Successful connection of a medium-scale solar plant should satisfy requirements of both the Solar Energy Grid Connection Code (SEGCC) and the appropriate code: the Electricity Distribution Code (EDC) or the Grid Code (GC) as the connection level apply. Connection of a large-scale solar plant to the transmission network should satisfy the requirements of both SEGCC and GC. For Small-Scale Photovoltaic (SSPV), the connection should satisfy both the SSPV Connection Code and the EDC. The objectives are to establish the obligations and responsibilities of each party; i.e. operators and all network users, thus leading to improved security, higher reliability and maintaining optimal operation. The technical specifications include permitted voltage and frequency variations in addition to power quality limits of harmonic distortion, phase unbalance, and flickers. Operational limits and capability requirements will be explained and discussed. Solar power grid connection codes of Egypt are explored first. Finally, brief comparisons of PV codes and related codes of UK, Germany, USA, and Egypt are presented.
PV power plants
grid connection codes
technical requirements and criteria
electricity networks
Omar H. Abdalla*
Helwan University, Egypt
Azza A.A. Mostafa
South Cairo Electricity Distribution Company, Egypt
*Address all correspondence to: ohabdalla@ieee.org
Innovation in Energy SystemsNew Technologies for Changing ParadigmsEdited by Taha Selim Ustun
Innovation in Energy Systems - New Technologies for Changing Paradigms
Edited by Taha Selim Ustun
The share of renewable resources for generating electric energy is increasing worldwide to cope with increasing demand. Current generation expansion plans of various countries expect increasing share of renewable energy resources in the electricity generation mix. By 2020, utilities set a target to reach a ratio of 20% renewable energy of the total energy required for electricity generation. Other utilities forecasted a higher share reaching about 50% by 2050. Wind energy and solar energy are the most promising resources and proven to be efficient in real applications with decreasing competitive costs of generated electric energy. The increasing share of renewable energies to be integrated to electric power systems has resulted in technical issues such as power quality requirements, capacity limits, safety measures, security, protection systems, synchronization process, lower system inertia, etc.
Electricity regulator authorities and electric utilities have issued necessary regulation rules for connecting sources of renewable energy to power networks at distribution and transmission levels according to the source capacity. A general overview of grid connection codes for integrating photovoltaic (PV) power plants to grids is presented in [1]. It presents a useful survey of grid codes, regulations, and technical requirements for connecting PV systems to low-voltage and medium-voltage networks, including issues of power quality and anti-islanding. An interesting guide dealing with PV interconnection requirements [2] has been developed and issued by the Interstate Renewable Energy Council, North Carolina Solar Center, USA. The guide covers all steps required for connecting a small-scale renewable energy system to the electricity network, including technical, contractual, rates, and metering issues. PV connection codes to medium-voltage power grid in Germany are discussed in [3]. A comparison of the processes of connecting PV systems in Germany and California is explored in [4]. Standards developed by the Institution of Engineering and Technology (IET) named "Code of Practice for Grid Connected Solar Photovoltaic Systems" are available in [5]. In South Africa, the National Energy Regulator has approved the "Grid Connection Code for Renewable Power Plants Connected to the Electricity Transmission System or the Distribution System" as detailed in [6]. Generally, utilities around the world either modify their grid codes to include technical requirements for integrating renewable energy resources to grids or issue separate but complementary codes for renewable resources.
This chapter describes the technical design specifications and criteria, technical terms, and equipment parameters for successful connection and operation of medium- and large-scale solar energy systems to the electricity networks in Egypt. The aim is to provide basic information and background on the technical design specification and criteria, in addition to technical terms and equipment parameters that are required to connect solar power plants to the electricity networks. Connection and successful operation of a solar power plant must satisfy the requirements of the Solar Energy Grid Connection Code (SEGCC) [7], and in the meantime the solar energy producer should comply with the requirements of the Electricity Distribution Code (EDC) [8]/Grid Code (GC) [9], according to the case of connection the MV distribution network/the HV transmission network.
The SEGCC specifies the special requirements for connecting both Medium-Scale Solar Plants (MSSPs) and Large-Scale Solar Plants (LSSPs) to the distribution networks or to the transmission network according to the capacity of the solar power plant. The capacity of MSSPs' range is from 500 kW to less than 20 MW. The LSSP range is greater than or equal to 20 MW. MSSPs may be connected either to the MV distribution networks or to the HV transmission networks. However, LSSPs are normally connected to the HV or extra-HV transmission networks. Successful integration of a MSSP shall comply with the technical requirements of both the SEGCC and the EDC, when connected to the distribution networks (or the GC when connected to the transmission network level). Similarly, the connection of a LSSP to the HV/EHV transmission networks shall satisfy the technical requirements of both the SEGCC and the GC. Technical requirements and terms stipulated in these codes should be clearly understandable in order to properly implement the rules and procedures of theses codes.
The EDC consists of the technical regulation rules and procedures to control technical and legal relationships between the licensed distribution system operator (DSO) and all users of the distribution network. The GC specifies the rules and procedures in order to control technical and legal relationships between the transmission system operator (TSO) and the users of the transmission network. The aim of the codes is to ascertain the obligations and responsibilities of each partner, i.e., TSO, DSO, and all users, namely, electricity producers, bulk-load customers, MV/LV subscribers, etc. This will result in maintaining optimal power system operation, enhanced system security, and higher reliability.
The stipulated technical specifications of connecting MSSPs and LSSPs to the distribution networks or to the transmission network comprise the permitted limits of voltage and frequency variations in addition to power quality evaluation criteria such as limits of phase unbalance, limits of total and individual harmonic distortions, and limits of flicker severity. Operational limits and capability of solar power plants will be explained and discussed in this chapter.
It is important to mention here that the technical requirements for connecting small-scale photovoltaic (ssPV) systems to the low-voltage distribution networks are specified in the ssPV connection code [10]. Even though the ssPV code is considered to be all the complementary documents that involve compulsory requirements for a LV subscriber seeking installation of ssPV system, the subscriber shall also satisfy the technical requirements of the EDC. For more details, interested readers may refer to [11] for exploring technical background of connecting ssPV systems to LV distribution networks in Egypt.
The remainder of the chapter is structured as follows: Section 2 discusses briefly basic solar energy systems; Section 3 presents the codes of connecting solar power plants to electric grids in Egypt; Section 4 describes the technical requirements and criteria for connecting medium- and large-scale solar parks to the MV distribution networks or to the HV/EHV transmission networks; Section 5 briefly reviews terms and criteria of power quality referred to in the SEGCC; Section 6 presents comparisons of some rules of PV grid connection codes of three countries, namely, the UK, Germany, and Egypt; Section 7 summarizes the main conclusions and recommendations; and the Appendix at the end of the chapter lists the main IEC technical specification standards for solar park grid connection codes.
2. Solar energy: a brief introduction
Solar energy is the radiant light and heat from the Sun that is harnessed using solar heating, photovoltaics (PV), concentrated solar power (CSP), solar architecture, and artificial photosynthesis. Solar power is the conversion of the energy from sunlight into electricity, either directly using PV, indirectly using CSP, or a combination. The Sun is 1.3914 million km in diameter, and the radiated electromagnetic energy rate is 3.8 × 1020 MW. Table 1 shows yearly renewable energy (RE) resources and human consumption. Figure 1 shows the world annual solar insolation [12].
Yearly RE resources and human use of energy (EJ)
Solar energy 3,850,000
Wind energy 2250
Biomass energy (potential) Circa 200
Primary energy use (in year 2016) Circa 557
Electricity generation (in year 2016) Circa 89
Annual renewable energy resources and human use of energy.
Exajoule (EJ) = 1018, J = 278 TWh.
Annual solar insolation worldwide [12].
As shown in Figure 1, Egypt is one of the countries that possess the highest solar insolation. Figure 2 shows the average direct solar radiation in kWh/m2/day in various regions in Egypt [11]. It can be noted that the southern regions have higher solar radiation than northern coastal regions. The region which has the highest solar radiation (>9.0 kWh/m2/day) is shown in yellow in the figure.
Egypt solar atlas [13].
Figure 3 shows the existing 1500 MW solar PV power plant located in Tengger Desert in China. It has been considered the largest PV power park in the world until now. Currently, Egypt is constructing a solar power plant of 1800/2000 MW in Benban near Aswan [13]. It will comprise 40 PV stations of about 50 MW each. Figure 4 shows an aerial view of part of the Benban PV solar power park [14]. Upon completion, Benban will be the worlds' largest PV power plant without energy storage.
1500 MW Tengger Desert solar power plant in China.
Aerial view of under construction Benban PV power plant in Egypt [14].
Recent high concentration PV system is being developed by the IBM and the Air Light Energy Solutions using a parabolic dish to concentrate sunlight up to 2000 times onto new triple junction solar PV system. Each small (1 × 1 cm) chip can convert 50 W at 80% conversion efficiency, using liquid cooling process. Figure 5 shows the concept of this new PV technology employing a tracking system to follow the sun.
High-concentration PV system [15]. Image: www.airlightenergy.com/
Figure 6 shows the existing world's largest CSP plant (Ivanpah) located in California, in the Desert of Nevada in the USA. The installed capacity of this CSP plant is 392 MW [16]. The plant was commissioned in year 2014. Other larger CSP plants are currently under development in different countries. For example, Morocco's Ouarzazate solar power plant [17] will deliver about 580 MW of power once it is accomplished in year 2020. Also, Dubai authorities approved a CSP project to generate 1000 MW by 2020 and to be upgraded to 5000 MW by 2030.
Ivanpah: the largest CSP plant in the world [16].
Figure 7 shows the existing world's largest parabolic-trough solar energy generating systems located in Mojave Desert in California, USA. Its capacity is 354 MW and includes 1600 acres. It was built in stages (1984–1990). The average capacity factor of this solar power plant is about 21%.
Largest parabolic-trough concentrated solar system.
The concept of the solar updraft tower power plant (or solar chimney) [18] is shown in Figure 8. The solar chimney comprises four main parts, namely, the air collector, a tall tower, wind turbines, and an electric generator. The collector is suspended above the ground at a height of 2–20 m surrounding the tower. The solar radiation incident on the collector warms the air beneath the collector and makes it hotter than the outside air. The warmed air is drawn up through the tower, passing the wind turbine which is installed at the bottom of the tower base. The motion of air rotates the turbine and its associated electric generator.
Concept of solar chimney.
Compared to PV systems, the solar chimney has the advantage of the possibility of operation 24 h a day even after sunset, thus overcoming the intermittency drawback of solar power. The available warm air beneath the collector can continuously operate the wind turbine and electric generator at night.
Figures 9 and 10 show the development of global solar energy generation from photovoltaic and concentrated solar power plants, respectively, up to year 2035 [19].
Global energy generation from PV systems [19].
Global energy generation from CSP plants [19].
3. Grid connection codes of solar power plants in Egypt
Two codes have been issued in Egypt for connecting solar power plants to electricity networks:
The first one is ssPV code which stipulates the special requirements for the connecting small-scale photovoltaic systems (with rating < 500 kW) to low-voltage distribution networks [10].
The second is the Solar Energy Grid Connection Code (SEGCC) which stipulates the technical requirements for connecting medium-scale (with capacity 500 kW to less than 20 MW) and large-scale (with capacity greater than or equal to 20 MW) solar power plants to the medium-voltage distribution networks or to the transmission grid.
The Grid Code (GC) in Egypt [9] defines the extra-high voltage (EHV) levels to be above 132 kV, the high voltage (HV) from 33 kV up to 132 kV, and medium voltage (MV) from 11 kV up to 22 kV. The solar plant grid connection codes are related to the following codes:
The Electricity Distribution Code (EDC) [8] which sets out the rules and procedures to regulate the relationship between the distribution utilities and users of the electricity distribution networks.
The Egyptian Transmission System Code, commonly known as the "Grid Code" [9]. It sets out technical and legal relationships between the transmission system operator and the users of the transmission grid. The users are electricity production companies, distribution system companies, and bulk customers who are directly supplied from the transmission grid, etc.
In addition to the above codes, there is the "Wind Farm Grid Connection Code" [20] which concerns with the rules and procedures for connecting wind energy conversion systems to the transmission grid. The above five codes are shown in Figure 11. For instance, the wind grid farm connection code and the Grid Code are two complementary codes that should be fulfilled for connecting a wind farm to the transmission system.
Association of various codes in Egypt.
The solar energy code and the Grid Code are two complementary technical documents that should be satisfied for connecting a solar power plant to the grid. The aim of the solar energy grid connection code is to stipulate the technical requirements for connecting solar energy resources either new or modified to the grid, so that security and quality of the grid are guaranteed.
The solar energy grid connection code specifies the special requirements for connecting solar energy plants to the MV distribution networks or HV/EHV transmission network. The technical requirements include permitted limits of voltage and frequency variations in addition to power quality limits such as of phase unbalance limits, harmonic distortion limits, and flicker severity limits. The code specifies also the operational limits of solar power plants to be integrated into the grid, plant capability requirements, active and reactive power control systems, safety measures, protection settings, synchronization, etc. The solar energy connection code shall apply to all medium-scale and large-scale solar power plants (either PV parks or solar thermal power plants) to be connected to the transmission grid. For connecting small-scale PV systems with capacity <500 kW to the LV distribution networks, we refer the reader to the small-scale PV (ssPV) code [10].
4. Solar energy grid connection requirements
4.1 Point of common coupling
The "point of common coupling (PCC)" is a point at which solar power plant is connected to the grid. It is sometimes called the "grid connection point (GCP)." The PCC is usually the connection point at the high-voltage terminals of the generator step-up transformer; it is generally located at the grid side of the isolating switch between the solar power plant and the grid. Normally, the solar energy grid connection code specifies the following technical requirements at the PCC.
4.2 Range of voltage
The grid-connected solar power plant shall be able to deliver its actual active power when the voltage at the point of common coupling remains within the ranges shown in Table 2. If required by the transmission system operator, the solar plant shall be also capable of automatically disconnecting from the grid at specified voltages.
Range of voltage (pu)
Time of operation
0.85–1.10 Unlimited
1.10–1.15 30 min
Range of voltage at the PCC.
4.3 Frequency range
In the case of a deviation of the grid frequency from its permissible value, the solar power plant shall perform as follows:
If the frequency is <50 Hz, the solar plant shall continue injecting active power until the frequency reduces below 47.5 Hz.
For over-frequency between 50 and 50.2 Hz, the solar power plant shall maintain the 100% of active power.
If the frequency is >50.2 Hz, the solar power plant shall inject active power up to 51.5 Hz.
4.4 Starting up solar power plants
The solar power plant shall only be connected to the power grid if the frequency and the voltage at the PCC are within the limits given in Table 3 or as otherwise stated in the Connection Agreement (CA) between the transmission system operator and the owner of solar power plant.
Frequency 48.0 Hz ≤ f ≤ 51.0 Hz
Voltage 0.90 u ≤ U ≤ 1.10 pu
Limits of voltage and frequency during the start-up of a solar plant.
During the start-up of a solar power plant, the active power increasing rate shall not exceed 10% (of the rated active power of the plant) per minute.
4.5 Power quality requirements
The solar plants connected to the power grid shall endeavor to maintain the quality of the voltage waveform at the PCC. The solar power plants shall comply with the requirements specified in Section 5.3 of the Performance Code of the Grid Code and/or the related part in the Electricity Distribution Code.
4.6 Harmonic distortion
The maximum harmonic distortion levels at the PCC which are attributable to the solar power plant shall obey the stipulations in the IEEE Standard 519-1992 as specified in Section 5.3.7 of Performance Code and/or the applicable section in the Electricity Distribution Code.
It is well known that a linear load, such as incandescent lamps or heaters, draws electric current from the source proportional to the applied voltage, while a nonlinear load such as an adjustable-speed drive draws currents apart from the voltage wave. The current of the nonlinear load comprises odd harmonics (third, fifth, seventh, etc.). The distortion effect of the third harmonic component is shown in Figure 12. Components of harmonic currents will interact with source currents, thus causing voltage harmonics. The voltage harmonic components are superimposed on the fundamental voltage component leading to a distorted voltage waveform. It may be mathematically described by the Fourier form Eq. (1):
Effect of the third harmonic.
ft=αo+∑n=1∞αncosnωot+∑n=1∞bnsinnωotE1
α0=1T∫0Tftdt+DCcomponentE2
αn=2T∫0TftcosnωotdtE3
bn=2T∫0TftsinnωotdtE4
The total harmonic distortion in voltage (THDv) and current (THDi) are defined as follows:
THDν=V22+V32+V42+V52+.…V1E5
THDi=i22+i32+i42+i52+…I1E6
The flow of harmonic currents in electrical equipment can cause problems such as heating of equipment, overloading neutral line, wrong tripping of circuit breakers, increasing skin effect, etc. Hence, electricity codes specify appropriate limitations on the total and individual harmonics in the grids. The solar energy grid connection code defines the limits of the individual and total harmonic distortion of voltage and current waveforms at the PCC as listed in Tables 4–7 in accordance with the IEEE Standard 519-1992. The updated version of this standard (IEEE Standard 519-2014) has introduced new two rows as given in Tables 4 and 7. We recommend using the updated version of the standard.
Level of voltage
Harmonic voltage distortion level (%)
Odd harmonic limits
Total harmonic limits
V ≤ 1 kV 5.0 8.0
1 kV < V ≤ 69 kV 3.0 5.0
69 kV < V ≤ 161 kV 1.5 2.5
V > 161 kV 1.0 1.5
The first row for (V ≤ 1 kV) has been introduced in the IEEE Standard 519-2014.
Limits of harmonic voltage distortion.
Short circuit ratio
Maximum integer harmonic current distortion as percentage of IL
Odd harmonic distortion**
ISC/IL
≥11 to <17
≥17 to<23
<20* 4.0 2.0 1.5 0.6 0.3 5
20 < 50 7.0 3.0 2.5 1.0 0.5 8
50 < 100 10.0 4.5 4.0 1.5 0.7 12
100 < 1000 12.0 5.5 5.0 2.0 1.0 15
>1000 15.0 7.0 6.0 2.5 1.4 20
Harmonic current distortion for transmission voltage level 69 kV and below.
All power generation equipment is limited to these values of current distortion, regardless of actual ISC/IL.
The limits of even harmonics are 25% of the corresponding limits of odd harmonics listed in the table.
where ISC = the maximum short-circuit current at the PCC; IL = the maximum demand load current (fundamental frequency component) at the PCC.
<20* 2.0 1.0 0.75 0.3 0.15 2.5
20 < 50 3.5 1.75 1.25 0.5 0.25 4
50 < 100 5.0 2.25 2.0 0.75 0.35 6
100 < 1000 6.0 2.75 2.5 1.0 0.5 7.5
>1000 7.5 3.5 3.0 1.25 0.7 10
Harmonic current distortion for transmission voltage level above 69 kV up to 161 kV.
where, ISC = the maximum short-circuit current at the PCC; IL = the maximum demand load current (fundamental frequency component) at the PCC.
<25* 1.0 0.5 0.38 0.15 0.1 1.5
<50 2.0 1.0 0.75 0.3 0.15 2.5
≥50 3.0 1.5 1.15 0.45 0.22 3.75
The first row for (<25*) has been added in IEEE Standard 519-2014
Harmonic current distortion for transmission voltage level above 161 kV.
It should be noted that the harmonic distortion level may exceed the levels listed in the above tables for a period no longer than 30 s provided that such increases in harmonic distortion level do not compromise service to the users or cause damage to any equipment in the grid as determined by the TSO.
It should be also noted that the updated version IEEE Standard 519-2014 specifies the width of the window for measuring the harmonics to be 10 cycles in the 50 Hz systems, i.e., 200 ms window, as follows:
For very-short time harmonic measurements, use the following equation:
Fn,νs=115∑i=115Fn,i2E7
For short time harmonic measurements, use the following equation:
Fn,sh=1200∑i=1200Fnνs,i2E8
The system owner/operator should limit the line-to-neutral voltage harmonics at the PCC as follows:
The values of the daily 99th percentile very-short time (which is 3 s in the 50 Hz systems) should be <1.5 times the values given in the tables.
The values of the weekly 95th percentile short time (10 min) should be less than the values given in the tables.
For the current harmonic distortion Tables 5–7, the following points are applicable:
The daily 99th percentile very-short time harmonic currents should be <2 times the values listed in the tables.
The weekly 99th percentile short time harmonic currents should be <1.5 times the values given in the tables.
The weekly 95th percentile short time harmonic currents should be less than the values given in the tables.
4.7 Limits of flicker severity
Table 8 shows the limits of the flicker severity produced by a solar energy power plant at the PCC as per recommendations of the IEC 61000-3-7.
Short-term (10 min) Pst ≤ 0.35
Long-term (2 h) Plt ≤ 0.25
Levels of flicker severity at the PCC.
Voltage flicker at the PCC is produced by voltage variations caused by a load such as an arc furnace when spectral characteristics of the voltage variations is in the range of a fraction of a cycle per second to about one third of the system frequency. It is a characteristic where a high-frequency (ωo) sinusoid is modulated by a low-frequency sinusoid (ωf).
In mathematical form
vt=1+VfcosωftVmcosω0tE9
Intensity of flicker is given by
F=VfVm=SscfSscE10
where Sscf is the short-circuit power (in MVA) at the electrode tip; SSC is the short-circuit power (in MVA) at the PCC.
A flicker meter has been developed by the IEC to measure flicker severity in terms of fluctuating voltage magnitude and its corresponding frequency of fluctuations. The meter employs a software technique to convert measured voltage fluctuations to the following statistical quantities:
Short-term flicker severity (PST)
Long-term flicker severity (PLT)
The flicker meter takes measurements automatically at 10-min intervals. The PST is calculated every 10 min. The flicker severity indicator PST which has a value of 1 is the level of visual flicker severity at which 50% of people would perceive flicker in a 60 W incandescent lamb. The long-term flicker severity PLT is a combination of 12 PST measurement values of 10 min each.
4.8 Limits of voltage unbalance
The voltage unbalance in the three-phase system is defined as the difference between the highest and lowest line voltage divided by the average line voltage of the system. Solar power plants shall be able to withstand voltage unbalance not exceeding 2% for at least 30 s as stipulated in part 5.3.5 of Section 5 (Performance Code) of the Grid Code and/or the relevant section in the Distribution Code.
A three-phase system is balanced if the three-phase voltages have the same amplitude and are phase-shifted by 120° with respect to each other. Otherwise, the three-phase system is unbalanced. Figure 13 shows the voltage waveforms of an unbalanced three-phase system.
Voltage waveforms of unbalanced three-phase system.
The mathematical relationships between the symmetrical components of system voltages (V0 − V1 − V2) and the phase components (VA − AB − VC) are given in Eqs. (11) and (12):
V0V1V2=131111aa21a2aVAVBVCE11
a=ej120E12
V0 = zero-sequence component; V1 = positive-sequence component; V2 = negative-sequence component.
According to the EN-50160 and IEC-61000-3-x Standards, the voltage unbalance (V2U) is defined as
V2U%=V2V1×100E13
The above standards define the following limits of voltage unbalance:
V2U<1% forHVE14
V2U<2% forMV&LVE15
The voltage unbalance is measured as 10-min average value with an instantaneous maximum of 4%. Voltage unbalance may also be defined [21]:
IEEE definition of voltage unbalance
%Pvu=Maximum deviation from averageVphAverageVphE16
In Eq. (16) only magnitudes are considered.
NEMA defines the same formula but considers line voltages.
Approximate formula
%VU=82×V2abe+V2bce+V2caeAverageVline×100E17
Subscript e means deviation from average. The causes of unbalance include generators; transformers; unbalanced impedances of long, non-transposed low-voltage lines; unbalanced load currents; single-phase loads on three-phase systems; etc. Unbalance can adversely affect motors and transformers by increasing heat and reducing their efficiencies.
4.9 Limits of voltage fluctuations
Voltage fluctuations, at the PCC of a solar power plant, can occur due to switching operations inside the solar plant elements such as transformers, capacitor banks, connection circuit, etc., resulting from inrush currents. These voltage fluctuations shall be up to 3% of nominal voltage provided that the fluctuations do not compose any risk to the grid or other connected users in the view of the TSO.
4.10 Control of active power
Figure 14 shows the ranges of voltage, frequency, and time periods within which the solar power plant shall continue delivering actual active power to the grid at the PCC. For grid frequencies in the range from 50.2 to 51.5 Hz, the solar power plant should reduce its active output power consistent with Eq. (18) and Figure 15 providing that the voltage is within the range 0.9–1.1 pu:
Voltage, frequency, and time ranges of solar plant operation.
∆P=0.4×PM×∆FperHZE18
where PM is the actual output power before the frequency of the grid exceeds 50.2 Hz; ΔF is the actual frequency minus 50.2 Hz.
Also, in this frequency range (i.e., 50.2–51.5 Hz) and the voltage ranges (0.85–0.9 pu) or (1.1–1.15 pu), the operation with reduced active power shall be limited to 30 min. The increasing or decreasing ramp of power will be performed in steps of a 10% (each) of the maximum power.
Reduction in active power due to over-frequency.
4.11 Control of reactive power
The solar power plant must be able to control reactive power at the PCC in a range of 0.95 lagging power factor to 0.95 leading power at the maximum active power of the plant and in consistent with Figure 16 for the MSSPs and Figure 17 for the LSSPs. The solar power plant must be able to perform reactive power control as follows:
Set-point control of reactive power (Q)
Set-point control of power factor
Fixed power factor
Characteristic: power factor as a function of active power output of the solar power plant, i.e., cos φ (P)
Characteristic: reactive power as a function of voltage, i.e., Q (V)
P-Q capability chart for MSSPs.
P-Q capability chart for LSSPs.
The solar power plant must possess an input signal for a set-point value at the PCC in order to control the reactive power or power factor of the plant. It is able to receive the set point within reactive power accuracy of 1 kVAr. The set-point signal will be provided by the TSO through verbal communication or SCADA, whichever is available. The solar power plant must follow the set-point signal of the TSO within 1 min. When the solar power plant operates at an active power output below its rated capacity, it shall be able to be operated in every possible operating point in the P-Q capability chart for plant size MSSP as shown in Figure 16 and LSSP as shown in Figure 17. It should be noted that for LSSPs, even at zero active power output, reactive power injection at the PCC shall fully correspond to the P-Q capability chart taking into account the power requirements of auxiliary services, transformers' losses, and solar plant cabling.
The maximum values of the capacitive and inductive reactive power in Figures 16 and 17 are calculated from the nominal generation capacity of the solar power plant and the power factor limit of 0.95 leading and lagging. Using capacitors and/or reactors to meet the requirements of the P-Q chart at the PCC is acceptable.
4.12 Low fault ride through (LVRT)
The SEGCC stipulates that, in case of a grid fault, the grid-connected solar power plant has to remain connected to the grid when the positive-sequence voltage at the PCC is above the curve shown in Figure 18. This defines the ability of the solar power plant to ride through the grid fault without disconnection from the grid. If all line-to-line voltages are below the curve shown in Figure 18, the solar power plant shall disconnect from the grid.
Low voltage ride-through curve of solar plants.
During this temporary voltage sag, the solar power plant must satisfy the following reactive power (or reactive current) requirement: in the case of a three-phase fault, the solar power plant must be able to inject reactive current in accordance with the curve shown in Figure 19, and satisfying Eqs. (19) and (20) for the time period of 250 ms started at the beginning of the fault and continue until clearing the fault.
Requirement of reactive current injection during the fault (k = 2).
Figure 19 shows the minimum reactive current required for the solar power plant during the fault. It is represented as the ratio of the reactive current to the nominal plant reactive current against the voltage drop which is represented as the ratio of the actual voltage to the nominal voltage at the PCC. All currents and voltages are in pu.
The following Eqs. (19) and (20) describe the required injected current during the fault:
ΔIBIN=k×ΔUrUNE19
ΔU=U−UOE20
If ∆U≥0.1,then∆Ur=∆U−0.1
If −0.1<∆U<0.1,then∆Ur=0
If ∆U≤−0.1,then∆Ur=∆U+0.1
If ∆U≤−0.6,then∆IB=−1pu
where UN = the rated voltage; IN = the rated current; U = the voltage during the fault; ΔIB = the required reactive current change during the fault; U0 = the voltage pre the fault; ΔUr = the related change in the voltage during the fault.
In Eq. (19), the factor k shall be adjustable within the range of 0–4. In the case of unsymmetrical faults, it is not permitted to feed reactive currents to the grid during a fault which will cause rise to voltages higher than 110% of the nominal voltage at the PCC in the non-faulty phases. After fault clearance, the active power output from the solar power plant must reach the same value as that of pre-fault value within a period of 10 s after clearing the fault, and the reactive power consumption of the solar power plant must be less than or equal to the reactive power consumption before occurrence of the fault.
5. Comparison of solar energy grid connection codes
Solar energy grid connection codes may be issued as national standards in various countries or by transmission and distribution system operators [22]. These solar energy grid connection codes may be included in the relevant codes or issued separately as a complementary part. For example, the German Association of Energy and Water Industries issued new grid codes for integration of generating power plants to medium-voltage networks. Directives have been released in Germany for connecting electric generation power plants to medium-voltage and low-voltage grids [3]. The directives were based on the results of developing the German Grid Code for integrating renewable power plants into the high-voltage electricity grid [23]. The scope of the directives includes wind power plants, hydroelectric plants, PV solar generating systems, and combined heat and power plants.
In the UK, the Operations Directorate of Energy Networks Association has issued the Engineering Recommendation G83 [24] titled "Recommendations for connecting small-scale type tested embedded generators (up to 16 A/phase, i.e., 11.04 kW three-phase) in parallel with LV distribution systems." The Engineering Recommendation G59 [25] deals with generating plants greater than 11.04 kW up to 50 kW (three-phase). The rules of these engineering recommendations are applicable to all generation power plants irrespective of the type of electric generator and equipment employed for converting energy source into electricity.
The technical and design criteria required for connecting all types of distributed generation power plant are generally set out in the "Distribution Planning and Connection Code" of the UK distribution code [26] and in the "Connection Conditions Code" of the UK Grid Code [27].
In the USA, code standards, guides, and rules for PV systems are available [28, 29, 30, 31, 32]. The IEEE has issued a number of standards for integration of distributed energy resources (DERs) into power grids. The IEEE-1547 Standard series concerns with connecting DERs, including PV systems, among others, to electric power systems. The IEEE-2030 series of standards is issued to help implement communications and information technologies to enhance integration of DER with the grid. The National Electrical Code (NEC) Article 690 addresses safety standards for installing PV systems. Other NEC articles may also be applicable to PV installations. The Underwriters Laboratories (UL) Standard-1741 concerns with DER equipment including inverters, converters, and controllers. Standards and technical requirements for solar equipment, installation, etc. are available as guides for states and municipalities [28]. A joint report produced by the North American Electric Reliability Corporation (NERC) and the California Independent System Operator (CAISO) provides information to maintain power system reliability while integrating variable energy resources, mainly wind and PV systems [29]. Large PV power plants are normally connected to the transmission grid [30]. Recently in 2019, the National Renewable Energy Laboratory (NREL) published two useful guide books for DER interconnection including current practices and emerging solutions [31] and permitting guide book for small solar systems [32].
As discussed in detail in previous sections of this book chapter, electricity authorities in Egypt have issued complementary documents to the Grid Code and distribution code for connecting solar systems to grids.
Comparisons of some rules in PV grid connection codes of Germany [1, 3, 22], the UK [1, 22], [24, 25, 26, 27], the USA [28, 29, 30, 31, 32], and Egypt [7, 8, 9, 10, 11], [33] are presented here. The comparisons include power and frequency control rules and reactive power control rules. Detailed comparisons are available in [1, 3, 22].
5.1 Active power and frequency control
The main reason for the active power control is to ensure a stable frequency. Table 9 summarizes the comparison between active power and frequency control rules in the relevant PV grid connection codes of the four countries, the UK, Germany, the USA, and Egypt.
Requirements in the code
UK Distribution Code Be able to control the active power for frequency regulations (installed capacity 50 MW)
Germany grid codes for connecting PV systems to the medium-voltage power grid Be capable of operation at reduced power output (if PCC rated voltage 10 kV)
In above system frequency of 50.2 Hz, all generators have to reduce their output power with a gradient of 40%/Hz of the instantaneous available power
The output power of the generator is only allowed to increase again as soon as the frequency reduces below 50.05 Hz
CAISO, USA It is required that the solar plant be capable of providing a frequency response with 5 and 3% droop settings through its governor-like control loop. The definition of the PV plant droop control is the same as that of conventional generating units:
1Droop=∆P/Prated∆F/60Hz
The dead band of the droop curve is ±36 mHz
Egyptian Solar Energy Plants Grid Connection Code For grid frequencies in the range from 50.2 to 51.5 Hz, the solar plant has to reduce active power (installed capacity from 500 to 50 MW)
The output power must be reduced by
ΔP = 0.4 × PM × (Δf/Hz)
The output power is allowed to increase again as soon as the frequency is below 50.2 Hz
Comparison of active power and frequency control.
5.2 Reactive power control
Consumption and generation of reactive power must be matched in order to maintain a stable system voltage. Table 10 presents comparison of reactive power control requirements in PV grid connection codes.
Germany grid codes for connecting PV systems to the medium-voltage power grid In the event of voltage drop of more than 10% the reactive current contribution of at least 2% of the rated current per percent of the voltage drop, the facility must be capable of feeding the required reactive power within 20 ms
USA: requirements for reactive power control of PV power plants FERC Order 661-A may be applied to PV power plants, and the required power factor range is ±0.95 measured at the Point of Interconnection (POI). It is also required that the PV power plant be capable of providing sufficient dynamic voltage support to guarantee reliability and safety of the system
CAISO reactive power requirement stipulates a voltage operation window for PV power plants to provide reactive power at 0.95 pf lagging when voltage level at the POI is within 0.95–1 pu. Also, the PV plant should be able to absorb reactive power at 0.95 pf leading when voltage level at the POI is within the range of 1–1.05 pu
Egyptian Solar Energy Plants Grid Connection Code For three-phase faults, the solar power plant must inject reactive current for a time period of 250 ms after the beginning of the fault until fault clearance
For unsymmetrical faults, it is not permissible that during the duration of the fault, reactive currents be fed into the grid which will give rise to voltages higher than 110% nominal voltage in non-faulty phases at the grid connection point
Reactive power of the solar power plant must be equal to or below the consumption of reactive power before the fault
Egyptian Technical Requirements for Connecting Small-Scale PV (ssPV) Systems to Low-Voltage Distribution Networks "Power factor: The ssPV shall not inject reactive power into the utility network, while the drain of reactive power shall be limited to a power factor of 0.9. This limit applies unless otherwise agreed upon with the utility."
The ssPV consumes reactive power
Comparison of reactive power control.
6. Conclusions and recommendations
This chapter has explored technical design specifications, criteria, technical terms, and equipment parameters required to connect Medium-Scale and Large-Scale Solar Plants (MSSP and LSSP) to the electricity networks. The specifications, terms, and parameters have been extracted from the connection code of the MSSP and LSSP, Electricity Distribution Code, and Grid Code. Technical background of these specifications has been discussed in detail. Comparisons of some important rules in the PV grid connection codes of the UK, Germany, the USA, and Egypt have been described. The technical specifications and design criteria presented here are of great importance for planning, design, installations, testing, commissioning and operation, and engineers working in the field of connecting MSSP and LSSP systems to the transmission or distribution grids.
It is recommended to refer to the full versions of the concerned codes to comply with detailed grid connection requirements and successful operation of the solar power systems. Academic researchers are advised to follow the requirements of utility codes in performing research works related to integrating solar power plants into grids.
In the stages of designing, manufacturing, and installation of the solar power plant components, relevant international standards must be satisfied. As an example in Egypt, various IEC standards used for these purposes are listed in Table 11. All components shall meet the ranges and the operational requirements stipulated in the MSSP and LSSP solar plant connection codes. The solar power plant should be equipped with a synchronizing unit with a proper phase-locked loop to keep the inverter synchronized with the grid to deliver the right amount of power within permissible operational frequency and voltage variations. The rating and short-circuit duties of the switchgear shall comply with the Grid Code requirements. The power transformer efficiency shall be greater than or equal to 96%.
Solar plant components
Power transformer IEC Standard 60076
IEC Standard 60085 for electrical insulation and
IEC Standard 60214 for tap changer
AC switchgear IEC Standard 62271
Inverter IEC Standard 62109-2
IEC Standard 62116
Cabling and accessories in the site IEC Standard 60227 series for LV (below 1 kV)
IEC Standard 60502 series for HV installations
All relevant components IEC Standard 60068-2 series for basic environmental tests, at least for IEC Standard 60068-2/1 cold, /2 dry, /14 change of temperature, and /30 damp heat
Site implementation IEC Standard 60,364 series
IEC standards for components of solar power plants in Egypt.
To enable visibility and control, the solar power plant shall be equipped with monitoring and security facilities having remote access communications means. The remote monitoring and controlling, telecommunications equipment, and the communication links shall comply with the requirements of the Grid Code and the distribution code as requirements of relevant case. The SEGCC contains details of specifications of real-time data, measuring, monitoring, and control equipment. The measurements include active power (kW), reactive power (kVAr), active energy (kWh), reactive energy (kVArh), voltages, currents, frequency, solar irradiance, temperature, and voltage and current harmonic distortions (THDv and THDi). The solar power plant shall provide all status signals, including transformer tap position, circuit breakers, disconnectors and earth switches, telecommunication alarms, protection signals at the grid side, inverter, etc. Also, set points of active power, reactive power, or power factor shall be indicated.
Technology solutions which shall be implemented in measuring, monitoring, and control of the solar power plants are described in detail in the SEGCC. The grid protection settings in the solar plants must comply with the requirements stipulated in the SEGCC, unless otherwise agreed with the transmission system operator. At the PCC, the grid protections shall be in compliance with the protection code of the Grid Code [9].
2.Solar energy: a brief introduction
3.Grid connection codes of solar power plants in Egypt
4.Solar energy grid connection requirements
5.Comparison of solar energy grid connection codes
6.Conclusions and recommendations
Omar H. Abdalla and Azza A.A. Mostafa (November 27th 2019). Technical Requirements for Connecting Solar Power Plants to Electricity Networks, Innovation in Energy Systems - New Technologies for Changing Paradigms, Taha Selim Ustun, IntechOpen, DOI: 10.5772/intechopen.88439. Available from:
Innovation in Energy Systems
Energy Return on Investment Analysis of a Solar Photovoltaic System
By Harpreet Kaur and Inderpreet Kaur
Advanced Communication and Control Methods for Future SmartgridsEdited by Taha Selim Ustun
Advanced Communication and Control Methods for Future Smartgrids
The Optimal Operation of Active Distribution Networks with Smart Systems
By Bogdan Constantin Neagu, Gheorghe Grigoraş and Ovidiu Ivanov

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To find other places to visit, reviews, and tourist information, read Pelling online trip maker .
Bengaluru to Pelling is an approximately 7-hour combination of flight and taxi. You can also drive; or do a combination of train and taxi. In October, daytime highs in Pelling are 36°C, while nighttime lows are 24°C. Cap off your sightseeing on the 2nd (Wed) early enough to go by car to Gangtok.
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To find reviews, ratings, and other tourist information, you can read our Gangtok day trip website .
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Why – and How – to Get Preapproved for a Car Loan – It's easy to get preapproved for a car loan with credit unions. If you have no idea what your credit score is or what kind of loan you could get, prequalification is a low-risk way to find out. It.
Army releases results of Fort Drum courts-martial – a reduction in rank to E-1 and a bad-conduct discharge. Sgt. James N. Costigan was convicted Jan. 29 of aggravated sexual contact with a child under 12 years old. He was sentenced to 36 years'.
PDF Other than Honorable Discharges – 1 In this document, the phrase "other than honorable discharge" refers to specific the administrative military discharge "under other than honorable conditions." Thus, this term does not encompass punitive discharges (dishonorable discharges, bad-conduct discharges, or officer dismissals), or other types of military discharges.
How to Fix a Bad Conduct Discharge From the Military – Even smaller numbers of military servicemembers receive punitive discharges such as bad conduct or dishonorable discharges. Punitive military discharges usually result in the loss of most or all veterans' benefits. DD Form 293. Bad conduct discharges are only given to military members as a result of special or general courts martial.
Veterans Discharge Upgrade Manual – Yale Law School – may only issue a Bad Conduct Discharge. Only a general court-martial can issue a. Dishonorable Discharge. Courts-martial do not have the.
Royal Navy Ships of World War 1 – logbooks – 3. Beaufort W eather Codes. Compiled by DJ_59 . This is a list of weather codes (used worldwide until computers had the system changing over to numbers) developed for the Royal Navy in.
Bad Conduct Discharge – milsurps.com – · A Bad Conduct discharge is often preceded by time in military prison. Virtually all veteran's benefits are forfeited if discharged due to Bad Conduct. Sounds like dishonorable conditions to.
Retired At 40: How Much Is A Military Pension Worth? – My. – A few weeks ago I was reading an article in Money magazine about a couple who retired at 40. While they do live frugally in relatively low-cost St. Louis, the primary reason they were able to retire is that they each served for 20 years in the military and now receive a pension of $58,500 per year.
Practically speaking, what are the repercussions of being. – The Bad Conduct Discharge is only passed on to enlisted military members and is given by a court-martial due to punishment for bad conduct. A Bad Conduct discharge is often preceded by time in military prison. Virtually all veteran's benefits are forfeited if discharged due to Bad Conduct. Dishonorable Discharge If the military considers a.
PDF PROTECTED VETERAN DEFINITIONS – University of Utah – Veteran who, while serving on active duty in the U.S. military ground, naval, or air service, participated in a United states military operation for which an Armed Forces service medal was awarded pursuant to Executive order 12985 (61 fed. Reg. 1209).
Prosecuting War Criminals Would Be A Lot Easier If Not For The United States' Resistance – Therefore the Allies created the first-ever international criminal tribunals created to punish violations of the laws of armed conflict: the International Military Tribunal. and a sweeping.
Definition of a Veteran | Mass.gov – Definition of a Veteran-Eligibility. To be eligible for veterans' benefits, one must be a "veteran" or a dependent of a "veteran" under M.G.L. c. 4, sec. 7, cl. 43rd as amended by the Acts of 2005, ch. 130.. for training in the Army or Air National Guard or active duty for training as a Reservist in the Armed Forces of the United States.
What is a Veteran? The Legal Definition – VA.org – Here is the definition of a US Veteran: Under federal law, a veteran is any person who served honorably on active duty in the armed forces of the United states. discharges marked "general and under honorable conditions" also qualify."
Definition of UNITED STATES DEPARTMENT OF VETERANS AFFAIRS. – UNITED STATES DEPARTMENT OF VETERANS AFFAIRS. Arm of the federal government that provides military benefits to veterans. SECRETARY FOR THE DEPARTMENT OF WAR government. This officer is appointed by the president. He is required to perform and execute. SECRETARY OF STATE OF THE united states government.
Mission Accomplished'? Trump Boasts of Being Boon for Military – During the State of the Union address, Mr. Trump said that after years of seeing the United States "treated very unfairly by NATO," he was forcing other nations in the military alliance to pay their.
Do You Qualify For Veteran Benefits? – thebalancecareers.com – There is no standardized legal definition of "military veteran" in the United States. Veteran benefits weren't created all at one time. They've been added one at a time for more than 200 years, and each time Congress passed a new law authorizing and creating a new veteran benefit, it included eligibility requirements for that particular benefit.
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6 Steps of the Mortgage Loan Process: From Pre-Approval to. – A loan pre-approval sets you up for a smooth home buying experience. A few things have changed since the real estate meltdown a few years ago. For purchase transactions, real estate agents will first want to know if you can get a loan.
Successfully Navigate the Mortgage Process | Credit.com – This article is part of a series on getting a home loan. Read part one: How to Get Pre-Approved for a Home Loan.. There's a lot involved in the mortgage process and what you need to know to get your home loan approved.
Bad Credit Loans Made Easier by Pre-Approval – MortgageLoan – Before a lender will pre-approve you for a bad credit loan, your credit and income information must be verified. A small fee is usually charged for this service, and once you're approved, you'll receive a letter that states the loan amount and the length of time that the offer will remain open.
How to Get Prequalified for a Home Loan | PrimeLending – What do you think your credit score is?. Knowing the loan amount you could qualify for will tell you how much home you. **A pre-qualification is not an approval of credit, and does not signify that underwriting requirements have been met.
Home Buying: Can we get pre-qualified without pulling credit. – Pre-approved means clients already submitted their necessary documents to the lender and have their credit pulled and therefore, pre-approved for a specific amount of loan. pre-qualified means lenders just take your verbal information and qualify you to a certain loan amount.
Mortgage Basics: How To Get A Mortgage – Once you've learned the terminology and figured out how much you can afford to spend on a new house, the next thing you will need to do is get a mortgage. reading, check out How Credit Cards Affect.
How Long Does It Take to Get a Mortgage Loan Approved. – How Long Does It Take to Get a Mortgage Loan Approved? by Faith O ; Updated September 11, 2017 The mortgage loan application and approval process requires a number of steps, which can typically be completed in one to two months, with the exception of those borrowers who have some extenuating credit, income or other financial circumstances.
How Long Does Pre-Approval Take To Enter Into Purchase. – GCA – This BLOG On How Long Does Pre-Approval Take To Enter Into Purchase Contract Was Written By Alex Carlucci of Gustan Cho Associates The Pre-Approval stage is the most important stage in the mortgage loan application and mortgage loan approval process.
How long to get a TSA Pre-Check? – Rick Steves Travel Forum – How long to get a. Please sign in to post. How long to get a TSA Pre-Check? Jump to bottom. Posted by reillyfram on 05/29/16 07:27 pm.. Does anyone know if it's a lifetime approval or if it's like Global Entry, with a limited time? Posted by Ann.
Getting Medical Pre-approval or Prior Authorization – Getting Medical Pre-approval or prior authorization. health insurance companies use the prior authorization or pre-approval process to verify that a certain drug, procedure, or service is medically necessary BEFORE it is done (or the prescription is filled).This is extremely important for people to know, especially people being treated for cancer.
How I Got Approved For Global Entry in Just 20 Days! – How I Got Approved For Global Entry in 20 Days. After I applied online and was awaiting "Conditional Approval," I was concerned about how long the process was going to take. I was hoping I would get my Global Entry card in time to use it for my March trip to Morocco, but I had resigned.
How Long Does a Home Loan Approval Process Take? – "Ideally, it should take a minimum of one week to get complete approval however. You can also achieve this by requesting a pre-approval from your bank to determine how much you qualify for. "When.
How Long Does it Take an FHA Loan to Close? – FHAHandbook.com – Some borrowers apply for an FHA loan before they have found a house, meaning they get pre-approved first and then start shopping for a home. This is a wise.
The Ultimate Guide to TSA Pre-Check | LoungeBuddy – If you do get approved for TSA Pre-Check, you can choose to receive your Known traveler number (ktn) either through the mail or online. When booking flights from airports that support Pre-Check, be sure to do so with an airline that TSA Pre-Check covers, and be sure to enter in your KTN.


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Some users are stuck in Windows 10 S Mode hell – but Microsoft is working on a fix
By Matt Hanson 2019-08-02T09:32:33Z
Some people are reporting that they can't upgrade
(Image credit: Shutterstock)
There are reports that some people are getting stuck in Windows 10 S Mode and are unable to upgrade to the full version of Windows 10.
Windows 10 S Mode is a version of Windows 10 that ships with certain devices, like the Surface Go, and only allows users to download apps through the Microsoft Store, and not from websites.
How to install Windows 10 via USB or DVD
How to update drivers in Windows 10
How to activate Windows 10
While Microsoft argues that Windows 10 S Mode helps protect people – as you shouldn't be able to download malicious software from the internet while using it – most people find being confined to the Microsoft Store frustrating, especially as not every program has a version available as a Microsoft Store app (also known as a UWP or Universal Windows app).
The saving grace of Windows 10 S Mode was that it's supposed to be relatively easy to switch to the full version of Windows 10 – but people on Reddit, Twitter and Microsoft's own support forums have been complaining that they cannot switch out of Windows 10 S Mode.
Like a bat out of S Mode
Usually, the process of leaving Windows 10 S Mode is to go through the Microsoft Store (of course), where the option to upgrade to full Windows 10 will be there.
However, people are reporting that the 'Switch out of S Mode' page isn't loading – instead, the Microsoft Store is showing a blank screen.
It's this kind of unreliability which makes people keen to leave Windows 10 S Mode and never use the Microsoft Store again.
The good news is that Microsoft is aware of the problem. Windows Latest got in contact with Microsoft Support, and was told that: "Microsoft is aware that some users are unable to upgrade to Pro Edition or switch out of S mode as a result of this blank page. We are investigating the cause and when a resolution is available the Store will update without any user action necessary."
So, a fix is coming, but Microsoft notes that: "There is no current estimate on when this condition will be resolved." Essentially, if you're stuck in Windows 10 S Mode hell, you might be there for a little while longer.
These are the best laptops in 2019
See more Operating systems news


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Tamar / March 30, 2016
BY TAMAR NEUMANN: It's been over ten years since Joseph and the Amazing Technicolor Dreamcoat has been performed on the Orpheum stage, but it's finally back! If you've been waiting these ten long years for this particular touring Broadway show to return to the Orpheum, your wait is over—and I think you will find yourself satisfied with the results. This being a Broadway on Hennepin production (presented by Hennepin Theatre Trust) you will find yourself dazzled by powerful singing, twirling dancers, live musicians, and a light show that sometimes blinds but mostly keeps the show exciting.
The JOSEPH Company in "Jacob & Sons". Photography: Daniel A. Swalec
For those of you unaware, the story is that same story you found yourself learning in Bible school. Yes, Joseph is that Joseph, the one who gets sold into Egypt and then rises to the occasion and lives happily ever after. This production is directed and choreographed by Andy Blankenbuehler and stars Laura Helm as the Narrator and JC McCann as Joseph. This being a Broadway touring show, everyone in the show is professional and impressive. Helm stands out as the Narrator. She brings sass and charm to the show. McCann is her equal in voice and talent. He carries the show as Joseph and manages to portray the right amount of humility and strength for the role.
In a show that packs a number of strong performances, one of the best comes in Act Two by Peter Surace who plays Simeon during the song Those Canaan Days. For some reason he appears to be Russian (this is unexplained—perhaps the music just implies a Russian sound or the director decided one of the brothers should represent some diversity), but he does a tremendous job singing and drawing the crowd into his own little farcical world. While there were many funny moments, Surace's was the crowd favorite.
JC McCann as Joseph and the JOSEPH Company in "Joseph's Coat" . Photography: Daniel A. Swalec
Blankenbuehler made a number of interesting decisions in this production including starting and ending with a modern twist. It mostly worked, although the application of Joseph's dreams to my own dreams didn't really sit comfortably with me. He also allowed more characters to sing, which created some funny moments (Potiphar's song) and he ended with a Joseph Megamix. Each of the choices helped to update this production and add a little more fun for a current audience. While this story is obviously timeless, (since it was written thousands of years ago and is still being told and turned into mega-musicals) it doesn't hurt to do some updates every now and then.
Of course this is a musical, so there are plenty of cheesy moments, some crowd interactions, and lots of over the top singing, dancing, and acting. But all musical lovers out there will appreciate the style as it stays true to its own genre. And when it comes to a fun night of music, theatre, and dancing you can't go very wrong with this production. You will find yourself laughing along with the characters, feeling bemused by the lights, and getting all the songs stuck in your head. Because, just like Joseph in the Bible, this Joseph knows how to rise to the occasion.
Joseph and the Amazing Technicolor Dreamcoat. March 29-April 3, 2016. Hennepin Theatre Trust's Orpheum Theatre, 910 Hennepin Ave, Minneapolis, MN. Tickets: Starting at $39; purchase tickets at 1.800.859.SHOW (7469) or hennepintheatretrust.org
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March 30, 2016 in Reviews. Tags: andy Blankenbuehler, Broadway, Hennepin Theatre Trust, joseph, joseph and the amazing technicolor dreamcoat, Orpheum Theatre
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Q: Importing a Function in Python: ImportError "moduleX has no attribute Y" I'm attempting to import a function defined in another file into the one I am working in.
The function I'm trying to import is in a file called ParallelEqns.py and looks like:
import sys
import numpy as np
import scipy as sp
import sympy as sym
import matplotlib.pyplot as plt
import os

def ParDeriv(x,p):
    derivative = []
    for k in range(nS):
        test = x[(k-1)%nS]*(x[(k+1)%nS] - x[(k-2)%nS]) - x[(k)%nS] + p
        if k == 0:
            derivative = test
        else:
            derivative = np.vstack([derivative, test])
    return derivative

The file I'm working in looks like:
import sys
import numpy as np
import scipy as sp
import sympy as sym
import matplotlib.pyplot as plt
import os

from ParallelEqns import ParDeriv

That gives me an error of "cannot import name 'ParDeriv'"
If I change the file to:
import sys
import numpy as np
import scipy as sp
import sympy as sym
import matplotlib.pyplot as plt
import os

import ParallelEqns

ParDeriv = ParallelEqns.ParDeriv

I get an error that says "module 'ParallelEqns' has no attribute 'ParDeriv'"
I've checked that both files are in the same directory. I'm not sure what I'm doing wrong here
%%%%%%%%%%%%%%%%%%%%%%%%%%%%%%%%%%%%%%%%%%%%%%%%
Edit: I've answered my own question by closing everything down and restarting python. It looks like I needed to restart python after creating the ParallelEqns.py file for it to correctly import

A: It turns out I just needed to restart python as I had created the file that I was trying to import after starting up python. Once I did that it worked out

redpajama_set_name: RedPajamaStackExchange


The new SD ovens are manufactured exclusively in stainless steel and are especially suitable for installation in kitchens where the ember is not required to be in sight of customers. The new doors are completely insulated and provide a high level of comfort in the kitchen, decreasing the temperature in front of the oven. On the other hand, their cleaning does not require any special attention and can be cleaned like any other stainless steel kitchen element.


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"Austria on Friday became the first Western democracy to announce that it would mandate Covid vaccinations for its entire adult population as it prepared for a nationwide lockdown starting Monday. ...The extraordinary measure by Austria, which only days ago separated itself from the rest of Europe by introducing a lockdown for the unvaccinated, who are driving a surge of infections, made for another alarming statement about the severity of the fourth wave of the virus in Europe, now the epicenter of the pandemic." —The New York Times
As we approach the new year, countries around the world are now experiencing the next phase of the globalist agenda. For instance, Austria just became the first European nation to impose a mandatory vaccination policy across its adult population while simultaneously entering their fourth national lockdown. Beginning February 1, 2022, those without the COVID jab in that country will be excluded from partaking in all basic functions of society, including buying and selling. Germany has also just announced that they will be entering a national lockdown, imposed very strictly on their unvaccinated population (see here). At the same time, India, which has the world's largest population, has recently passed a new law prohibiting anyone from buying fuel and food unless they can show proof of vaccination (see here).
Of course, if you've been following this blog than you shouldn't be surprised to learn that "no jab, no job" laws are cropping up in the UK, Canada, and Australia, where segregation and loss of human freedom is now the new norm. In New Zealand, however, these latest set of laws have taken a sharp turn for the worst, as Kiwis (New Zealanders) are now being prohibited from attending all "faith-based gatherings" (Churches) unless they can show proof of vaccination (see here).
But make no mistake, the US isn't too far behind on any of these new and unraveling set of restrictions. And to be sure of this, President Biden just announced his plan to further tighten travel regulations in the US in response to the new "omicron" COVID variant, whilst not ruling out the "possibility" of diving into mandatory vaccination with the rest of the world (see here and here).
The obvious fact is that the Beast system has officially arrived and the world's citizens are being plunged into the terrifying reality of the antichrist's reign. Are you ready for what's ahead?! The purpose of this blog is to ensure that you can be by offering useful guidance for physical and spiritual preparedness designed to equip you for the days ahead.


Here are Sample projects and project ideas for elementary, secondary and peparatory school students.
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MVC Mine
8,74 km SE from Rancagua, Chile
Colihues Km.13, Requínoa – Casilla 637
Mines & projects in Chile
Mine Type Tailings
Hydraulic mining
Sulfuric acid (reagent)
Concentrate leach
Latest News Amerigo Reports 2020 Annual Production Results and Provides 2021 Guidance January 14, 2021
Source: p. 9
Amerigo Resources Ltd. 100 % Indirect
Minera Valle Central, S.A. 100 % Direct
Minera Valle Central, S.A. (MVC) is a wholly owned subsidiary of Amerigo Resources Ltd. (Amerigo).
The historic Cauquenes and Colihues tailings impoundments are man-made deposits that were generated as sites for the containment of tailings produced during the processing of copper-molybdenum ore at the El Teniente mine owned by Codelco.
El Teniente Tailings
MVC currently receives approximately 130,000 tonnes per day of Fresh Tailings from El Teniente's Colon concentrator. The Fresh Tailings are transported via gravity to MVC via a 36 km long concrete open channel launder.
MVC's contract with El Teniente provides for the supply of Fresh Tailings up to the year 2037. Details are provided in Section 19.0. Every year, MVC receives an updated life of mine plan from DET and uses this plan to estimate the quantity and quality of Fresh Tailings available to be processed at MVC. Due to volumetric transport constraints in the tailings channel launder to the Caren impoundment, there is insufficient capacity to simultaneously process both Fresh Tailings and Cauquenes tailings at their maximum rates. Surplus Fresh Tailings material is planned to bypass MVC's mill and be deposited into the voids created in the Colihues and Cauquenes impoundments.
A total of 856 million tonnes of Fresh Tailings at a grade of 0.110% Cu and 0.008% Mo is planned to be delivered to MVC's processing facility.
Colihues Tailings
Extraction of material from the Colihues deposit ceased in 2015 and is planned to recommence in 2031 when the Cauquenes deposit is depleted. Tailings in the Colihues deposit were extracted at a nominal rate of 35,000 tonnes per day via a hydraulic monitoring system using high pressure water guns operating at 30 bar. The flow of water at high pressure water is directed onto the surface of the tailings in a sweeping motion in such a way as to create a ditch on the surface. The monitors work horizontally and vertically, operated by remote control using a hydraulic system of electronic valves that allow them to rotate and advance. A single monitoring unit is capable of sustaining a production rate of 8,000 to 10,000 tonnes per day. Mining bench heights are 10m high and access ramps are created to relocate the hydraulic monitors. The depth of the Colihues tailings deposit is approximately 50 m requiring four mining benches. The slurry drains to the center of the sump by gravity and is channelled by the ditches made by the monitor. The slurry has a density of approximately 45% solids and is pumped to the processing plant by means of vertical 150 kW sump pumps and 350 kW horizontal booster pumps, via 10" high density polyethylene (HDPE) pipelines. The operation of four hydraulic monitors and two sumps is necessary. In order to sustain a production rate of 35,000 tonnes per day.
A portion of the Colihues tailings deposit is submerged under water. To enable extraction to commence, zones have to be isolated with impermeable barriers and dewatered prior to extraction. A spillway facility has to be maintained to allow for excess rainfall to be released. Colihues is planned to be separated into four zones: I, II, III and IV (see figure 16-6). In 2016, Colihues zones I and III were depleted and zones IV and II are available for future extraction. Tailings will not be extracted at the margins of the deposit, at the interface of the tailings with the original ground surface level, safety barriers at the dam walls and the tailings left in-situ for internal water barriers. A total of 46 million tonnes at a grade of 0.323% Cu is not currently in MVC's mine plans. This tonnage has been removed from the Colihues in-situ resource and a total of 98 million tonnes at a grade of 0.230% Cu and 0.010% Mo is planned to be delivered to MVC's processing facility.
Cauquenes Tailings
The first phase of the Cauquenes expansion project was completed in 2015 enabling extraction of material from the Cauquenes deposit into the existing MVC process facility. The processing rate from 2019 onward is planned to be 62,500 tpd and extraction of the Cauquenes deposit is anticipated to be complete in 2031. Tailings are extracted from the Cauquenes deposit via a hydraulic monitoring system similar to Colihues. The general method of operation is as follows:
• Construct a sump in the tailings deposit and install vertical slurry pumps
• Commence extraction down to 10m using hydraulic monitors and allow slurry to drain to sump
• Pump tailings to the plant at a density of 43% solids
• Reposition the monitors sequentially away from the sump to advance the extraction.
This procedure is repeated until the bottom of the tailings deposit is reached, approximately 50m deep. Safety zones are maintained near the walls to ensure the integrity of the walls.
Due to volumetric transport constraints in the tailings channel launder to the Carén impoundment, MVC is not expected to be able to simultaneously process the Fresh Tailings and Cauquenes tailings at their maximum rates. The sum of the feed streams will exceed the capacity of the Carén tailings channel, which is limited to 181,000 tonnes per day (equivalent to approximately 65 million tonnes per year). Therefore the surplus fresh tailings are planned to be discarded and deposited into the voids created in the Colihues and Cauquenes impoundments.