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\begin{document}
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\input{murks}
\titelen{A Post-Attack Recovery Architecture for Smart Electricity Meters}
\titelde{Eine Architektur zur Kontrollwiederherstellung nach Angriffen auf Smart Metering in Stromnetzen}
\typ{Masterarbeit}
\grad{Master of Science (M. Sc.)}
\autor{Jan Sebastian Götte}
\gebdatum{\rule{2cm}{12pt}} % Geburtsdatum des Autors
\gebort{\rule{3cm}{12pt}} % Geburtsort des Autors
\input{private-data.tex}
\gutachter{Prof. Dr. Björn Scheuermann}{Prof. Dr.-Ing. Eckhard Grass}
\mitverteidigung
\makeTitel
\selbstaendigkeitserklaerung{\today}
\vfill
\selectlanguage{english}
{\center{
\begin{minipage}[t][10cm][b]{\textwidth}
    \center{\ccbysa}

    \center{This work is licensed under a Creative-Commons ``Attribution-ShareAlike 4.0 International'' license. The
    full text of the license can be found at:}

    \center{\url{https://creativecommons.org/licenses/by-sa/4.0/}}

    \center{For alternative licensing options, source files, questions or comments please contact the author at
    \texttt{masterarbeit@jaseg.de}}.

    \center{This is version \texttt{\input{version.tex}\unskip} generated on \today. The git repository can be found at:}

    \center{\url{https://git.jaseg.de/master-thesis.git}}
\end{minipage}
}}
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% Hier folgt die eigentliche Arbeit (bei doppelseitigem Druck auf einem neuen Blatt):
\tableofcontents
\newpage

\chapter{Introduction}

In the power grid, as in many other engineered systems, we can observe an ongoing diffusion of information systems into
industrial control systems. Automation of these control systems has already been practiced for the better part of a
century.  Throughout the 20th century this automation was mostly limited to core components of the grid. Generators in
power stations are computer-controlled according to electromechanical and economic models. Switching in substations is
automated to allow for fast failure recovery. Human operators are still vital to these systems, but their tasks have
shifted from pure operation to engineering, maintenance and surveillance\cite{crastan03,anderson02}.

With the turn of the century came a large-scale trend in power systems to move from a model of centralized generation,
built around massive large-scale fossil and nuclear power plants, towards a more heterogenous model of smaller-scale
generators working together. In this new model large-scale fossil power plants still serve a major role, but two new
factors come into play. One is the advance of renewable energies. The large-scale use of wind and solar power in
particular from a current standpoint seems unavoidable for our continued existence on this planet. For the electrical
grid these systems constitute a significant challenge. Fossil-fueled power plants can be controlled in a precise and
quick way to match energy consumption. This tracking of consumption with production is vital to the stability of the
grid. Renewable energies such as wind and solar power do not provide the same degree of controllability, and they
introduce a larger degree of uncertainty due to the unpredictability of the forces of nature\cite{crastan03}.

Along with this change in dynamic behavior, renewable energies have brought forth the advance of distributed generation.
In distributed generation end-customers that previously only consumed energy have started to feed energy into the grid
from small solar installations on their property. Distributed generation is a chance for customers to gain autonomy and
shift from a purely passive role to being active participants of the electricity market\cite{crastan03}.

To match this new landscape of decentralized generation and unpredictable renewable resources the utility industry has
had to adapt itself in major ways. One aspect of this adaptation that is particularly visible to ordinary people is the
computerization of end-user energy metering. Despite the widespread use of industrial control systems inside the
electrical grid and the far-reaching diffusion of computers into people's everyday lives the energy meter has long been
one of the last remnants of an offline, analog time. Until the 2010s many households were still served through
electromechanical Ferraris-style meters that have their origin in the late 19th
century\cite{borlase01,ukgov04,bnetza02}.  Today under the umbrella term \emph{Smart Metering} the shift towards fully
computerized, often networked meters is well underway. The roll out of these \emph{Smart Meters} has not been very
smooth overall with some countries severely lagging behind. As a safety-critical technology, smart metering technology
is usually standardized on a per-country basis. This leads to an inhomogenous landscape with--in some instances--wildly
incompatible systems.  Often vendors only serve a single country or have separate models of a meter for each country.
This complex standardization landscape and market situation has led to a proliferation of highly complex, custom-coded
microcontroller firmware. The complexity and scale of this--often network-connected--firmware makes for a ripe substrate
for bugs to surface.

A remotely exploitable flaw inside a smart meter's firmware\footnote{
    There are several smart metering architectures that ascribe different roles to the component called \emph{smart
    meter}. Coarsely divided into two camps these are systems where all metering and communication functions reside
    within one physical unit and systems where metering and communication functions are separated into two units called
    the \emph{smart meter} and the \emph{smart meter gateway}\cite{stuber01}. An example for the former are setups in
    the USA, an example of the latter is the setup in Germany. For clarity, in this introductory chapter we use
    \emph{smart meter} to describe the entire system at the customer premises including both the meter and a potential
    gateway.
} could have consequences ranging from impaired billing functionality to an existential threat to grid
stability\cite{anderson01,anderson02}. In a country where meters commonly include disconnect switches for purposes such
as prepaid tariffs a coördinated attack could at worst cause widespread activation of grid safety systems by repeatedly
connecting and disconnecting megawatts of load capacity in just the wrong moments\cite{wu01}.

Mitigation of these attacks through firmware security measures is unlikely to yield satisfactory results. The enormous
complexity of smart meter firmware makes firmware security extremely labor-intensive. The diverse standardization
landscape makes a coördinated, comprehensive response unlikely.

In this thesis, instead of focusing on the very hard task of improving firmware security we introduce a pragmatic
solution to the--in our opinion likely--scenario of a large-scale compromise of smart meter firmware. In our proposal
the components of the smart meter that are threatened by remote compromise are equipped with a physically separate
\emph{safety reset controller} that listens for a reset command transmitted through the electrical grid's frequency and
on reception forcibly resets the smart meter's entire firmware to a known-good state.  Our safety reset controller
receives commands through Direct Sequence Spread Spectrum (DSSS) modulation carried out on grid frequency through a
large controllable load such as an aluminum smelter. After forward error correction and cryptographic verification it
re-flashes the meter's main microcontroller over the standard JTAG interface.

In this thesis, starting from a high level architecture we have carried out extensive simulations of our proposal's
performance under real-world conditions. Based on these simulations we implemented an end-to-end prototype of our
proposed safety reset controller as part of a realistic smart meter demonstrator. Finally we experimentally validated
our results and we will conclude with an outline of further steps towards a practical implementation.

\chapter{Fundamentals}

\section{Structure and operation of the electrical grid}

Since this thesis is filed under \emph{computer science} we will provide a very brief overview of some basic concepts of
modern power grids.

\subsection{Structure of the electrical grid}

The electrical grid is composed of a large number of systems such as distribution systems, power stations and substations
interconnected by long transmission lines. Mostly due to ohmic losses\footnote{
    Power dissipation of a resistor of resistance $R [\Omega]$ given current $I [A]$ is $P_\text{loss} [W] =
    U_\text{drop} \cdot I = I^2 \cdot R$. Fixing power $P_\text{transmitted} [W] = U_\text{line} \cdot I$ this yields a
    dependency on line voltage $U_\text{line} [V]$ of $P_\text{loss} =
    \left(\frac{P_\text{transmitted}}{U_\text{line}}\right)^2 \cdot R$. Thus, ignoring other losses a $2\times$ increase
    in transmission voltage halves current and cuts ohmic losses to a quarter. In practice the economics are much more
    complicated due to the cost of better insulation for higher-voltage parts and the cost of power factor compensation.
}
the efficiency of transmission of electricity through long transmission lines increases with the square of
voltage\cite{crastan01,simon01}. % simon01: p. 425, 9.4.1.1, crastan p.55, 3.1
In practice economic considerations take into account a reduction of the considerable transmission losses (about
\SI{6}{\percent} in case of Germany\cite{destatis01}) as well as the cost of equipment such as additional transformers
and the cost increase for the increased voltage rating of components such as transmission lines. Overall these
considerations have led to a hierarchical structure where large amounts of energy are transmitted over very long
distances (up to thousands of kilometers) at very high voltages (upwards of \SI{200}{\kilo\volt}) and voltages get lower
the closer one gets to end-customer premises. In Germany at the local level a substation will distribute
\SIrange{10}{30}{\kilo\volt} to large industrial consumers and small transformer substations which converting this to
the \SI{400}{\volt} three-phase AC households are usually hooked up with\cite{crastan01}.

\subsubsection{Transmission lines, bus bars and tie lines}

The number one component of the electrical grid are transmission lines. Short transmission lines that tightly couple
parts of a substation are called \emph{bus bars}. Transmission lines that couple otherwise independent grid segments are
called \emph{tie lines}. A tie line often connects grid segments operated by two different operators e.g.\ across a
country border.

In mathematical analysis \emph{short} transmission lines can be approximated as a simple lumped-component
RLC\footnote{Resistor-inductor-capacitor.} circuit. In longer lines the effect of wave propagation along the line has to
be taken into consideration. In the lumped model the transmission line is represented by a circuit of one or two
inductors, one or two capacitors and some resistors. This representation simplifies analysis. For \emph{long}
transmission lines above \SI{50}{\kilo\meter} (cable) or \SI{250}{\kilo\meter} (overhead lines) this approximation
breaks down and wave propagation along the line's length has to be taken into account. The resulting model is what RF
engineering calls a transmission line and models the line's parasitics\footnote{Stray capacitance, ohmic resistance and
stray inductance.} as being uniformly distributed along the length of the line. To approximate this model in
lumped-element evaluations the line is represented as a long chain of small lumped-component RLC sections. This complex
structure makes simulation and analysis more difficult in comparison to short lines\cite{crastan01}.

Almost all transmission lines used in the transmission and distribution grid use three-phase alternating current (AC).
Long-distance overland lines are usually implemented as overhead lines due to their low cost and ease of maintenance.
Underground cables are much more expensive because of their insulation and are only used when overhead lines cannot be
used for reasons such as safety or aesthetics. In specialized applications such as long, high-power undersea cables
high-voltage DC (HVDC) is used. In HVDC converter stations at both ends of the line convert between three-phase AC and
the line's DC voltage.  These converter stations are controlled electronically and do not exhibit any of the mechanical
inertia that is characteristic for rotating generators in a power plant. Since HVDC re-synthesizes three-phase AC from
DC at the receiving end of the line it can be used to couple non-synchronous grids. This allows for additional degrees
of control over the transmission of power compared to a regular transmission line. These technical benefits are offset
by high initial cost (mostly due to the converter stations) leading to HVDC being used in specific situations
only\cite{crastan03}.

\subsubsection{Generators}

Traditionally all generators in the power grid were synchronous machines. A synchronous machine is a generator whose
copper coils are wound and connected in such a way that during normal operation its rotation is synchronous with the
grid frequency. Grid frequency and generator rotation speed are bidirectionally electromechanically coupled. If a
generator's angle of rotation would lag behind the grid it would receive electrical energy from the grid and convert it
into mechanical energy, acting as a motor--When the machine leads it acts as a generator and is braked.  Small
deviations between rotational speed and grid frequency will be absorbed by the electromechanical coupling between both.
Maintaining optimal synchronization over time is the task of complex control systems inside power stations' speed
governors\cite{simon01,crastan01}.

Nowadays besides traditional rotating generators the grid also contains a large amount of electronically controlled
inverters. These inverters are used in photovoltaic installations and other setups where either DC or non-synchronous AC
is to be fed into the grid. Setups like these behave differently to rotating generators. In particular \emph{inertia} in
these setups is either absent or a software parameter. This potentially reduces their overload capacity compared to
rotating generators. The fundamentally different nature of electronically controlled inverters has to be taken into
account in planning and regulation\cite{crastan03}.

\subsubsection{Switchgear}

In the electrical grid switches perform various roles. The ones a computer scientist would recognize are used for
routing electricity between transmission lines and transformers and can be classified into ones that can be switched
under load (called load switches) and ones that can not (called disconnectors). The latter are used to ensure parts of
the network are free from voltage e.g.\ during maintenance. The former are used to re-route flows of electrical
currents. A major difference in their construction is that in contrast to disconnectors load switches have built-in
components that extinguish the high-power arc discharge that forms when the circuit is interrupted under load\footnote{
    While an arc discharge is considered a fault condition in most low-voltage systems including computers, in energy
    systems it is often part of normal operation.
}. Beyond this there are circuit breakers.  Circuit breakers are safety devices that even under failure conditions can
still switch at several times the circuit's nominal current. They are activated automatically on conditions such as
overcurrent or overvoltage. Finally, fuses can be considered non-resettable switches. The fuse in a computer power
supply is barely more than a glass tube with some wire in it that is designed to melt at the designated current. In
energy systems fuses are often much more complex devices that in some cases utilize explosives to quickly and decisively
open the circuit and extinguish the resulting arc discharge\cite{nelles01,crastan01,simon01}.
% disconnect switches, fuses, breakers -> crastan 1 (ch. 8)

\subsubsection{Transformers}

Along with transmission lines transformers are one of the main components most people will be thinking of when talking
about the electrical grid. Transformers connect grid segments at different voltage levels with one another.  In the
distribution grid transformers are used to provide standard end-user voltage levels to the customer (e.g. 230/400V in
Europe) from a \SIrange{10}{25}{\kilo\volt} feeder. In places that use overhead wiring to connect customer households
this is the role of the pole-mounted gray devices the size of a small refrigerator that are characteristic for these
systems. Transformers can also be used to convert between buses without a fourth neutral conductor and buses with one.

Transformers are large and heavy devices consisting of thick copper wire or copper foil windings arranged around a core
made from thin stacked, insulated iron sheets. The entire core sits within a large metal enclosure that is filled with
liquid (usually a specialized oil) for both cooling and electrical insulation. This cooling liquid is cooled by radiator
fins on the transformer enclosure itself or an external heat exchanger. Depending on the design cooling may rely on
natural convection within the cooling liquid or on electrical pumps\cite{crastan01,simon01}.

Transformers come in a large variety of coil and wiring configurations. There exist autotransformers where the secondary
is part of the primary (or vice-versa) that are used to translate between voltage levels without galvanic isolation at
lower cost. Transformers used in parts of the electrical grid often have several taps and include \emph{tap changers}. A
tap changer is a system of mechanical switches that can be used to switch between several discrete transformer ratios to
adjust secondary voltage under load\cite{simon01}. Tap changers are used in the distribution grid to maintain the
specified voltage tolerances at the customer's connection.

\subsubsection{Instrument transformers}

While operating on the exact same physical principles instrument transformers are very different from regular
transformers in an energy system. Instrument transformers are specialized low-power transformers that are used as
transducers to measure voltage or current at very high voltages. They are part of the control and protection systems of
substations\cite{crastan01}.

\subsubsection{Chokes}

Chokes are large inductors. In power grid applications their construction is similar to the construction of a
transformer with the exception that they only have a single winding on the core. They are used for a variety of
purposes. A frequent use is as a series inductor on one of the phases or the neutral connection to limit transient fault
currents.  In addition to this inductors are also used to tune LC circuits. One such use are Petersen coils, large
inductors in series with the earth connection at a transformer's star point that are used to quickly extinguish arcs
between phase and ground on a transmission line. The Petersen coil forms a parrallel LC resonant circuit with the
transmission line's earth capacitance. Tuning this circuit through adjusting the Petersen coil reduces earth fault
current to a level low enough to quickly extinguish the arc\cite{simon01}.

\subsubsection{Power factor correction}

Power factor is a power engineering term that is used to describe how close the current waveform of a load is to that of
a purely resistive load. Given sinusoidal input voltage $V(t) = V_\text{pk} \sin \paren{\omega_\text{nom} t}$ with
$\omega_\text{nom} = 2 \pi f_\text{nom} = 2 \pi \cdot \SI{50}{\hertz}$ being the nominal angular frequency, the current
waveform of a resistor with resistance $R \left[\Omega\right]$ according to Ohm's law would be $I(t) = \frac{V(t)}{R} =
\frac{1}{R} V_\text{pk} \sin\paren{\omega_\text{nom} t}$. In this case voltage and current are perfectly in phase, i.e.
the current at time $t$ is linear in voltage at constant factor $\frac{1}{R}$.

In contrast to this idealized scenario reality provides us with two common issues: One, the load may be reactive.  This
means its current waveform is an ideal sinusoid, but there is a phase difference between mains voltage and load current
like so: $I(t) = \frac{V(t)}{R} = \frac{1}{\left|Z\right|} V_\text{pk} \sin\paren{\omega_\text{nom} t + \varphi}$. $Z$
is the load's complex impedance combining inductive, capacitive and resistive components and $\varphi$ is the phase
difference between the resulting current waveform and the mains voltage waveform. Examples of such loads are motors and
the inductive ballasts in old fluorescent lighting fixtures.

The second potential issue are loads with a non-sinusoidal current waveform. There are many classes of these but the
most common one are the switching-mode power supplies (SMPS) used in most modern electronic devices.. Most SMPS have an
input stage consisting of a bridge rectifier followed by a capacitor that provide high-voltage DC power to the following
switch-mode convert circuit. This rectifier-capacitor input stage under normal load draws a high current only at the
very peak of the input voltage sinusoid and draws almost zero current for most of the period.

These two cases are measured by \emph{displacement power factor} and \emph{distortion power factor} that when combined
yield the overall true power factor. The power factor is a key quantity in the design and operation of the power grid.
As a variable in the operation of electrical grids it is also referred to as \emph{VAR} after its is unit Volt-Ampère
Reactive.  A high power factor (close to $1.0$, i.e.\ an in-phase sinusoidal current waveform) yields lowest
transmission and generation losses.  If reactive power generation and consumption are mismatched and power factor is
low, high currents develop that lead to high transmission losses.  For this reason grids include circuits to compensate
reactive power imbalances\cite{crastan01}. These circuits can be as simple as inductors or capacitors connected to a
power line but often can be switched to adapt to changing load conditions. Static var compensators are particularly
fast-acting reactive power compensation devices whose purpose is to maintain a constant bus voltage\cite{rogers01}.

\subsubsection{Loads}

Lastly, there is the loads that the electrical grid serves. Loads range from mains-powered indicator lights in devices
such as light switches or power strips weighing in at mere Milliwatts to large smelters in industrial metal production
that can consume a fraction of a gigawatt all on their own. 

\subsection{Operational concerns}
\subsubsection{Modelling the electrical grid}

Modelling performs an important role in the engineering of a reliable power infrastructure. The grid is a complex,
highly dynamic system. To maintain operational parameters such as voltage, grid frequency and currents inside their
specified ranges complex control systems are necessary. To design and parametrize such control systems simulations are a
valuable tool.  Using model calculations the effects of control systems on operational variables such as transmission
efficiency or generation losses can be estimated. Model simulations can be used to identify structural issues such as
potential points of congestion. The same models can then be used to engineer solutions to such issues, e.g.\ by
simulating the effect of a new transmission line.

There are several aspects under which the grid or parts of the grid can be simulated. There are static analysis methods
such as modal analysis that yield information on problematic electromechanical oscillations by computing the eigenvalues
of a large system of differential equations describing the collective behavior of all components of the grid. Modal
analysis is one example of simulations used in grid planning. Modal analysis is used in decisions to install additional
stabilization systems in a particular location.  In contrast to static analysis, transient simulations calculate an
approximation of the time-domain behavior of some variable of interest under a given model. Transient simulations are
used e.g.\ in the design of control systems.  Finally, power flow equations describe the flow of electrical energy
throughout the network from generator to load. Numerical solutions these equations are used to optimize control
parameters to increase overall efficiency.

% TODO decide what of this to keep.
% \subsubsection{Generator controls}
% \subsubsection{Load shedding}
% \subsubsection{System stability}
% \subsubsection{Power System Stabilizers}

\section{Smart meter technology}

Smart meters were a concept pushed by utility companies throughout the early 21st century. Smart metering is one component of the
larger societal shift towards digitally interconnected technology. Old analog meters required that service personnel
physically come to read the meter. \emph{Smart} meters automatically transmit their readings through modern
technologies. Utility companies were very interested in this move not only because of the cost savings for meter reading
personnel: An always-connected meter also allows several entirely new use cases that have not been possible before. One
often-cited one is utilizing the new high-resolution load data to improve load forecasting to allow for greater
generation efficiency. Computerizing the meter also allows for new fee models where electricity cost is no longer fixed
over time but adapts to market conditions. Models such as prepayment electricity plans where the customer is
automatically disconnected until they pay their bill are significantly aided by a fully electronic system that can be
controlled and monitored remotely\cite{anderson02}. A remotely controllable disconnect switch can also be used to coerce
customers in situations where that was not previously economically possible\footnote{
    The Swiss association of electrical utility companies in Section 7.2 Paragraph (2)a of their 2010 white paper on the
    introduction of smart metering\cite{vseaes01} cynically writes that remotely controllable disconnect switches ``lead
    a new tenant to swiftly register'' with the utility company. This white paper completely vanished from their website
    some time after publication, but the internet archive has a copy.
}. Figure \ref{fig_smgw_schema} shows a schema of a smart metering installation in a typical household\cite{stuber01}.

\begin{figure}
    \centering
    \includegraphics[width=\textwidth]{resources/smgw_usage_scenario}
    \vspace*{1cm}
    \caption{A typical usage scenario of a smart metering system in a typical home. This diagram shows a gateway
    connected to multiple smart meters through its local metrological network (LMN) and a multitude of devices on the
    customer's home area network (HAN). A solar inverter and an electric car are connected through a controllable local
    systems (CLS) adaptor.}
    \label{fig_smgw_schema}
\end{figure}

To the customer the utility of a smart meter is largely limited to the convenience of being able to read it without
going to their basement. In the long term it is said that there will be second-order savings to the customer since
electricity prices adapting to the market situation along with this convenience will lead them to consume less
electricity and to consume it in a way that is more amenable to utilities, both leading to reduced
cost\cite{borlase01,bmwi03,anderson02}.

Traditional Ferraris counters with their distinctive rotating aluminum disc are simple electromechanical devices. Since
they do not include any semiconductors or other high technology that might be prone to failure a cheap Ferraris-style
meter can last decades. In contrast to this, smart meters are complex high technology. They are vastly more expensive to
develop in the first place since they require the development and integration of large amounts of complex, custom
firmware. Once deployed, their lifetime is limited by this complexity. Complex semiconductor devices tend to fail, and
firmware that needs to communicate with the outside world tends to not age well\cite{borkar01}.  This combination of
higher unit cost and lower expected lifetime leads to increased costs per household. This cost is usually shared between
utility and customer.

As part of its smart metering rollout the German government in 2013 had a study conducted on the economies of smart
meter installations. This study came to the conclusion that for the majority of households computerizing an existing
Ferraris meter is uneconomical. For larger consumers or new installations the higher cost of installation over time is
expected to be offset by the resulting savings in electricity cost\cite{bmwi03}.

\subsection{Smart metering and Human-Computer Interaction}

A fundamental aspect in realizing many of the cost and energy savings promised by the smart metering revolution is that
it requires a paradigm shift in consumer interaction. Previously most consumers would only confront their energy use
when they receive their monthly or yearly electricity bill. A large part of the cost savings smart meters promise over
traditional metering infrastructure\footnote{ We are excluding savings from Demand-Side Response (DSR) implemented
through smart meters here: Traditional ripple control systems already allowed for these\cite{dzung01}, and due to the
added cost of high-power relays many smart meters do not include such features.  } critically depend on the consumer
regularly interacting with the meter through an in-home display or app, then changing their behavior. We live in an era
where our attention is already highly contested. A myriad of apps and platforms compete for our attention through our
smart phones and other devices. Introducing an entirely new service exerting cognitive pressure into this already
complex battleground is a large endeavour. On the one hand it is not clear how this new service would compete with
everything else. On the other hand if it does manage to capture our attention and lead us to modify our behavior, what
are the side effects? For instance an in-home display might increase financial anxiety in economically disadvantaged
customers.

Human Computer Interaction research has touched the topic of smart metering several times and has many insights to offer
for technologists\cite{pierce01,rodden01,lupton01,costanza01,fell01}. An issue pointed out in \cite{rodden01} is that at
least in some countries consumers fundamentally distrust their utility companies. This trust issue is exacerbated by
smart meters being unilaterally forced onto consumers by utility companies. Much of the success of smart metering's
ubiquitous promises of energy savings depends on consumer coöperation. Here, the aforementioned trust issue calls into
question smart metering's chances of long-term success.

As \cite{pierce01} pointed out smart metering developments could benefit greatly from early involvement of HCI research.
HCI research certainly would not have overlooked entire central issues such as privacy as it happened in the dutch
case\cite{cuijpers01}. The current corporate-driven approach to a technological advance forced through national
standardization bears a risk of failing to meet its ostensible objectives for consumers. The role of consumers and the
complex socio-technological environment posed by this new technology is not seriously considered in the standardization
process. While certainly no one will admit to outright ignoring consumers in smart meter standardization, their role is
largely limited to the occasional public consultation. At the same time the standards are written by technologists--it
seems largely without input on their practicality or socio-technological implications from fields such as HCI.
% TODO citation? too much burn?

\subsection{Common components}
\label{sm-cpu}

Smart meters usually are built around an off-the-shelf microcontroller (microcontroller unit, MCU). Some meters use
specialized smart metering system-on-chips (SoCs)\cite{ifixit01} while others use standard microcontrollers with core
metering functions implemented in external circuitry (cf.\ Section \ref{sec-easymeter} where we detail the meter in our
demonstration setup).  Specialized SoCs usually contain a segment LCD driver along with some high-resolution
analog-to-digital converters for the actual measurement functions. In many smart meter designs the metering SoC is
connected to another full-featured SoC acting as the modem. At a casual glance this might seem to be a security measure,
but it is be more likely that this is done to ease integration of one metering platform with several different
communication stacks (e.g.\ proprietary sub-gigahertz wireless, power line communication (PLC) or Ethernet). In these
architectures there is a clear line of functional demarcation between the metering SoC and the modem. As evidenced by
over-the-air software update functionality (see e.g.\ \cite{honeywell01}) this does not however extend to an actual
security boundary. 

Energy usage is calculated by measuring both voltage and current at high resolution and then integrating the
measurements. Current measurements are usually made with either a current transformer or a shunt in a four-wire
configuration. Voltage is measured by dividing input AC down with a resistor chain. Both are integrated digitally using
the MCU's time base as a reference.

Whereas legacy electromechanical energy meters only provided a display of aggregate energy use through a decimal counter
as well as an indirect indication of power through a rotating wheel one of the selling points of smart meters is their
ability to calculate advanced statistics on energy use. These statistics are supposed to help customers better target
energy conservation measures\cite{bmwi03}.

Smart meters can perform additional functions in addition to pure measurement and data aggregation. One is to serve as a
gateway between the utility company's control systems and large controllable loads in the consumer's household for
Demand-Side Management (DSM)\cite{borlase01}.  In DSM the utility company can control when exactly a high-power device
such as a water storage heater is switched on. To the customer the precise timing does not matter since the storage
heater is set so that it has enough hot water in its reservoir at all times. The utility company however can use this
degree of control to reduce load variations during peak times. The efficiency gains realized with this system translate
into lower electricity prices for DSM-enabled loads for the customer. Traditionally DSM was realized on a local level
using ripple control systems. In ripple control control data is coded by modulating a carrier at a low frequency such as
\SI{400}{\hertz} on top of the regular mains voltage. These systems require high-power transmitters at tens of kilowatts
and still can only bridge regional distances\cite{dzung01}.

Another important additional function is that some smart meters can be used to remotely disconnect consumer households
with outstanding bills. Using euphemisms such as \emph{utility revenue protection}\cite{kamstrup01} or \emph{reducing
nontechnical losses}\cite{brown01} while cynically claiming \emph{Consumer Empowerment}\cite{kamstrup01} these systems
allow an utility company to remotely disconnect a customer at any time\cite{anderson01}.  Whereas before smart metering
this required either additional hardware or an expensive site visit by a qualified technician smart meters have ushered
in an era of frictionless control\footnote{ Note that in some countries such as the UK non-networked mechanical
prepayment meters did exist. In such systems the user inserts coins into a coin slot that activates a disconnect switch
at the household's main electricity connection.  These systems were non-networked and did not allow for remote control.
A disadvantage of such systems compared to modern \emph{smart} systems are the high cost of the coin acceptor and the
overhead of site visits required to empty the coin box\cite{anderson02}.  }.

\subsection{Cryptographic coprocessors}

Just like in legacy electricity meters in smart meters physical security is still a key component of the overall system
design. Since in both types of meter cost depends on physical quantities being measured at the customer premises
customers can save cost in case they are able to falsify the meter's measurements without being
detected\cite{anderson02}. For this reason both types of meters employ countermeasures against physical intrusion.
Compared to high-risk devices such as card payment processing terminals or ATMs the tamper proofing used in smart meters
is only basic\cite{anderson02}. Common measures include sealing the case by irreversibly ultrasonically welding the
front and back plastic shells together or the use of security seals on the lid covering the input and output screw
terminals.  The common low-tech attack of using magnets to saturate the current transformer's ferrite cores is detected
using hall sensors\cite{anderson02,anderson03,itron01,hager01,easymeter01}.  German smart metering standards specify the
use of a smartcard-like security module to provide transport encryption and other cryptographic
services\cite{bsi-tr-03109-2,bsi-tr-03109-2-a}. During our literature review we did not find many references to similar
requirements in other national standards, though this does not mean that individual manufacturers do not use smartcards
for engineering reasons or due to pressure from utilities. The limited documentation on meter internals that we did find
such as \cite{ifixit01,bigclive01,eevblog01} suggests where no such regulation exists manufacturers and utilities likely
choose to forego such advanced measures and instead settle on simple software implementations.

\subsection{Physical structure and installation}

Smart meters are installed like traditional electricity meters. In Japan this means they are usually installed on an
exterior wall and need to be resistant against weather and extreme environmental conditions (direct sunlight, high
temperature, high humidity). In Germany the meter is always installed either indoors or in an outdoor utility closet
that is sealed to keep out the weather. In most countries the meter is connected through large integrated screw
terminals. In the US meters compliant with the domestic ANSI C12 standard are round and plug into a large socket that is
wired into the house or apartment's electrical connection.

Modern smart meters are usually made with plastic cases. Ferraris meters often used cases stamped from sheet metal with
glass windows on them. Smart meters now look much more like other modern electronic devices. A common construction style
is to separate the case into front and back halves with both clipped or ultrasonically welded together. Ultrasonic
welding gives a robust, airtight interface that cannot easily be separated and reconnected without leaving visible
traces, which helps with tamper evidence properties. As an industry-standard process common in various consumer goods
ultrasonic welding is a cheap and accessible technology\cite{easymeter01,ifixit01}.

Communication interfaces sometimes are brought out through regular electromechanical connectors but often also are
optical interfaces. A popular style here is to use a regular UART connected to an LED/phototransistor optocoupler
mounted on the side of the case. The user interface is usually limited to an LCD display. For cost and ingress
protection smart meters rarely use mechanical buttons. Some smart meters use a phototransistor mounted behind the
faceplate that can be activated with a flashlight as a crude contact-less input device\cite{easymeter01}.

All meters provide several options for security seals to be installed to detect opening of the meter or access to its
terminal block. The shape and type of these security seals varies. Factory-installed seals are used to detect tampering
of the meter itself while seals made by the utility during meter installation are used to guard the meter's terminal
block and detect attempts at by-passing\cite{czechowski01}.

\section{Regulatory frameworks around the world}

Smart metering regulation varies from country to country as it is tightly coupled to the overall regulation of the
electrical grid. The standardization of the physical form factor and metrological parameters of a meter is usually
separate from the standardization of its \emph{smart} functionality. Most countries base the standard for their meters'
outwards-facing communication interface on a family of standards unified under the IEC as DLMS/COSEM. Employing this
base protocol ountry-specific standardization only covers which precise variant of it is spoken and what features are
supported.

\subsection{International standards}

The family of standards one encounters most in smart metering applications are IEC 62056 specifying the Device Language
Message Specification (DLMS) and the Companion Specification for Electronic Metering (COSEM). DLMS/COSEM are
application-layer standards describing a request/response schema similar to HTTP. DLMS/COSEM are mapped onto a
multitude of wire protocols. They can be spoken over TCP/IP or mapped onto low-speed UART serial interfaces
\cite{sato01,stuber01}.  Besides DLMS/COSEM there are a multitude of standards usually specifying how DLMS/COSEM are to
be applied.

DLMS/COSEM show some amount of feature creep. They do not adhere to the age-old systems design adage that a tool should
\emph{do one thing and do it well}. Instead they try to capture the convex hull of all possible applications. This led
to a complicated design that requires extensive additional specification and testing to maintain interoperability. In
particular in the area of transport security it becomes evident that the IEC as an electrical engineering standards body
stretched their area of expertise where resorting to established standard protocols would have led to a better
outcome\cite{weith01}. Compared to industry-standard transport security the IEC standards provide a simplistic key
management framework based on a static shared key with unlimited lifetime and provide sub-optimal transport security
properties (e.g.\ lack of forward-secrecy)\cite{khurana01,sato01}.

\subsection{The regulatory situation in selected countries}

In this section we will give an overview of the situation in a number of countries. This list of countries is not
representative and notably does not include any developing countries and is geographically biased. We selected these
countries for illustration only and based our selection in a large part on the availability of information in a language
we can read. We will conclude this section with a summary of common themes.

\subsubsection{Germany}

Germany standardized smart metering on a national level. Apart from the calibration standards applying to any type of
meter smart meters are covered by a set of communications and security standards developed by the German Federal Office
for Information Security (BSI). Germany mandates smart meter installations for newly constructed buildings and during
major renovations but does not require most legacy residential installations to be upgraded. This is a consequence of a
2013 cost-benefit analysis that found these upgrades to be uneconomical for the majority of residential
customers\cite{bmwi03,bmwi1,bmwe01,brown01}.

The German standards strictly separate between metering and communication functions. Both are split into separate
devices, the \emph{meter} and the \emph{gateway} (called \emph{smart meter gateway} in full and often abbreviated
\emph{SMGW}). One or several meters connect to a gateway through a COSEM-derived protocol. The communication interface
between meter and gateway can optionally be physically unidirectional. An unidirectional interface eliminates any
possibility of meter firmware compromise. The gateway contains a cryptographic security module similar to a
smartcard\cite{mahlknecht01} that is entrusted with signing of measurements and maintaining an authenticated and
encrypted communication channel with its authorities. Security of the system is certified according to a Common Criteria
process.

The German specification does not include any support for disconnect switches as they are common in some other countries
outside of demand-side management. It only does not prohibit the installation of one behind the smart meter
installation. This makes it theoretically possible for a utility company to still install a disconnect switch to
disconnect a customer, but this would be a spearate installation from the smart meter. In Germany there are significant
barriers that have to be met before a utility company may cut power to a household\cite{delaw01}. The elision of a
disconnect switch means attacks on German meters will be limited in influence to billing irregularities and attacks
using DSM equipment such as water storage heaters that represent only a fraction of overall load.

\subsubsection{The Netherlands}
The Netherlands were early to take initiative to roll out smart metering after its recognition by the European
Commission in 2006\cite{cuijpers01,ec04}. After overcoming political issuses the Netherlands were above the European
median in 2018, having replaced almost half of all meters\cite{cuijpers01,ec03}. Dutch smart meters are standardized by
a consortium of distribution system operators. They integrate gateway and metrology functions into one device. The
utility-facing interface is a IEC DLMS/COSEM-based interface over cellular radio such as GPRS or LTE\cite{aubel01}. Like
e.g.\ the German standard, the Dutch standard precisely specifies all communication interfaces of the
meter\cite{dsmrp3}. Another parallel is that the Dutch standard also does not cover any functionality for remotely
disconnecting a household. This absence of a disconnect switch limits attacks on Dutch smart meters, too to causing
billing irregularities.

\subsubsection{The UK}

The UK is currently undergoing a smart metering rollout. Meters in the UK are nationally standardized to provide both
Zigbee ZSE-based and IEC DLMS/COSEM connectivity. UK smart metering specifications are shared between electrical and gas
meters. Different to other countries' specifications the UK national specifications require electrical meters to have an
integrated disconnect switch and gas meters to have an integrated valve.  In Northern Ireland most consumers use prepaid
electricity contracts\cite{anderson02}.  Prepayment and credit functionality are also specified in the UK's national
smart metering standard, as is remote firmware update functionality\cite{ukgov02}. Outside communications in these
standards is performed through a gateway (there called \emph{communications hub}) that can be shared between several
meters \cite{ukgov01,ukgov02,ukgov03,brown01,sato01}. The combination of both gas and electricity metering into one
family of standards and the exceptionally large set of \emph{required} features make the UK regulations the maximalist
option among the regulations in this section. The mandatory inclusion of both disconnect switches and remote
connectivity up to remote firmware update make it an interesting attack target\cite{anderson01}.

\subsubsection{Italy}

Italy was among the first countries to legally mandate the widespread installation of smart meters in households. Italy
in 2006 and 2007 by law set a starting date for the rollout in 2008\cite{brown01}. The Italian electricity market was
recently privatized. While the wholesale market and transmission network privatization has advanced the vast majority of
retail customers continued to use the incumbent distribution system operator ENEL as their supplier\cite{ec03}. This
dominant position allowed ENEL to orchestrate the large-scale rollout of smart meters in Italy. Almost every meter in
Italy had been replaced by a smart meter by 2018\cite{ec03}. An unique feature of the Italian smart metering
infrastructure is that it relies on Power Line Communication (PLC) to bridge distances between meters and cellular radio
gateways\cite{gungor01}.

\subsubsection{Japan}

Japan is currently rolling out smart metering infrastructure. Compared to other countries in Japan significant
standardization effort has been spent on smart home integration\cite{usitc01,sato01,brown01}. Japan has domestic
standards under its Japanese Industrial Standards organization (JIS) that determine metrology and physical dimensions.
Tokyo utility company TEPCO is currently rolling out a deployment that is based on the IEC DLMS/COSEM standards suite
for remote meter reading in conjuction with the Japanese ECHONET home-area network protocol. Smart meters are
connected to TEPCO's backend systems through the customer's internet connection, sub-gigahertz radio based on 802.15.4
framing, regular landline internet or PLC\cite{toshiba01,sato01}.

A unique point in the Japanese utility metering landscape is that the current practice is monthly manual readings. In
Japan residential utility meters are usually mounted outside the building on an exterior wall and every month someone
with a mirror on a long stick will come and read the meter. The meter reader then makes a thermal paper print-out of the
updated utility bill and puts it into the resident's post box. This practice gives consumers good control over their
consumption but does incur significant personnel overhead.

\subsubsection{The USA}

In the USA the rollout of smart meters has been promoted by law as early as 2005. The US electricity market is highly
complex with states having significant authority to decide on their own policies\cite{brown01}. Originally different
from the IEC standards used in large fraction of the rest of the world the USA developed their own domestic set of
standards for smart meters under the Americal National Standards Institute (ANSI)\cite{sato01}. Today ANSI is converging
with the IEC on the protcol layer. An obvious feature of ANSI-standard meters is that they are round and plug into a
wall-mounted socket while IEC devices are usually rectangular and connected directly to the mains wiring through large
screw terminals\cite{ifixit01}.

\subsection{Common themes}

Researching the current situation around the world for the above sections we were able to distill some common themes.
First, smart metering is slowly advancing on a global scale and despite significant reservations from privacy-conscious
people and consumer advocates it seems it is here to stay. Still, there are some notable exceptions of countries that
have decided to scale-back an ongoing rollout effort after subsequent analysis showed economical or other
issues\footnote{cf.\ the Netherlands and Germany}.

\subsubsection{The introduction of smart metering}

The smart meter rollout is largely driven by utility companies. Utility companies field a variety of arguments for the
rollout. The most prominent argument is a general increase in energy-efficiency along with a reduction of emissions.
This argument is based on the estimation that smart metering will increase private customers' awareness of their own
consumption and this will lead them to reduce their consumption. The second highly popular argument for smart metering
is that it is necessary for the widespread adoption of renewable energies. This argument again builds on the trend
towards green energy to rationalize smart metering. Interestingly this argument is often formulated as an inevitability
instead of a choice.

Academic reception of smart metering is dyed with an almost unanimous enthusiasm. In particular smart meter
communication infrastructure has received a large amount of research
attention\cite{dzung01,gungor01,kabalci01,lloret01,mahmood01,yan01,anderson01,anderson02}. Outside of human-computer
interaction claims that smart meters will reduce customer energy consumption have often been uncritically accepted. 

\subsubsection{Standardization and reality of smart devices}

Regulators, utilities and academics meet in their enthusiasm on the issue of smart home integration of smart metering. A
feature of many concepts is that the meter acts as the centerpiece of a modern, fully integrated smart
home\cite{aubel01,geelen01,bsi-tr-03109-1,abdallah01}. The smart meter serves as a communication hub between a new class
of grid-aware loads and the utility company's control center. Large (usually thermal) loads such as dishwashers,
refrigerators and air conditioners are expected to intelligently adapt their heating/cooling cycles to better match
the grid's supply. A frequent scenario is one in which the meter bills the customer using near-real time pricing, and
supplies large loads in the customer's household with this pricing information. These loads then intelligently schedule
their operation to minimize cost\cite{sato01}. At the time between 2000 and 2005 when smart metering proposals were
first advanced this vision might have been an effect of the \emph{law of the instrument}\cite{kaplan01,anderson02}. Back
then outside of specialty applications household devices were not usually networked\cite{merz01}. Smart meters at the
time may have seemed to be the obvious choice for a smart home communications hub.

From today's perspective, this idea is obviously outdated. Smart \emph{things} now have found their way into many homes.
Only these things are directly interconnected through the internet--foregoing the home-area network (HAN) technologies
anticipated by smart metering pioneers. The simple reason for this is that nowadays anyone has Wifi, and Wifi
transceivers have become inexpensive enough to disappear in the bill of materials (BOM) cost of a large home device such
as a washing machine. Smart meters are usually situated in the basement--physically far away from most of one's devices.
This makes connecting them to said devices awkward and connecting them via the local Wifi lends the question why the
smart devices should not simply use the internet directly.

Connecting things to a smart meter through a local bus is academically appealing. It promises cost-savings from a
simpler physical layer (such as ZigBee instead of Wifi) and it neatly separates concerns into home infrastructure and
the regular internet. Communication between smart meter and devices never leaves the house. This promises tolerance to
utility backend systems breaking. It also physically keeps communication inside the house, bypassing the utility's eyes
improving both customer privacy and agency. The presently popular model of a device as simple as a light bulb proxying
its every action through a manufacturer's servers somewhere on the public internet is in stark contrast to this
scenario. Alas, the reason that this model is as popular is that in most cases it simply works. Device manufacturers
integrate one of many off-the-shelf Wifi modules. The resulting device will work anywhere on earth\footnote{For some
places channel assignments may have to be updated. This is a configuration-level change and in some devices can be done
by the end-user during provisioning.}. A HAN-connected device would have several variants with different modems for
different standards. Some might work across countries, but some might not. And in some countries there might not even be
a standard for smart grid HANs.

Looking at the situation like this begs the question why this realization has not yet found its way into mainstream
acceptance by smart metering implementors. The customer-facing functionality promised through smart meters would be
simple to implement as part of a now-standard \emph{Internet of Things} application. An in-home display that shows
real time energy consumption and cost statistics would simply be an Android tablet fetching summarized data from the
utility's billing backend. Custom hardware for this purposes seems anachronistic today. Demand-side response by large
loads would be as simple as an HTTPS request with a token identifying the customer's contract that returns the
electricity price the meter is currently charging along with a recommendation to switch on or off. It seems the smart
home has already arrived while smart metering is still getting off the starting blocks\cite{anderson02}.
% TODO is this too critical? Is maybe the modern smart home compatible with smart meters? Is maybe the local-only path
% of data, avoiding utility clouds a design feature? (may be true in DE, NL, probably not anywhere else)

\section{Security in smart distribution grids}

The smart grid in practice is nothing more or less than an aggregation of embedded control and measurement devices that
are part of a large control system. This implies that all the same security concerns that apply to embedded systems in
general also apply to most components of a smart grid. Where programmers have been struggling for decades now with input
validation\cite{leveson01}, the same potential issue raises security concerns in smart grid scenarios as well\cite{mo01,
lee01}.  Only, in smart grid we have two complicating factors present: Many components are embedded systems, and as such
inherently hard to update. Also, the smart grid and its control algorithms act as a large (partially-)distributed
system making problems such as input validation or authentication harder\cite{blaze01} and adding a host of distributed
systems problems on top\cite{lamport01}.

Given that the electrical grid is essential infrastructure in our modern civilization, these problems amount to
significant issues in practice. Attacks on the electrical grid may have grave consequences\cite{anderson01,lee01} while
the long maintenance cycles of various components make the system slow to adapt. Thus, components for the smart grid
need to be built to a much higher standard of security than most consumer devices to ensure they live up to well-funded
attackers even decades down the road. This requirement intensifies the challenges of embedded security and distributed
systems security among others that are inherent in any modern complex technological system. The safety-critical nature
of the modern smart metering ecosystem in particular was quickly recognized by security experts\cite{anderson01}.

A point we will not consider in much depth in this work is theft of electricity. An incentive for the introduction of
smart metering that is frequently cited in utility industry publications outside of a general public's view is the
reduction of electricity theft\cite{czechowski01}.  Academic publications tend to either focus on other benefits such as
generation efficiency gains through better forecasting or rationalize the consumer-unfriendly aspects of smart metering
with ``enormous social benefits''\cite{mcdaniel01}. They do not usually point out the economical incentive such
\emph{revenue protection} mechanisms provide\cite{anderson01,anderson02}.

\subsection{Privacy in the smart grid}

A serious issue in smart metering setups is customer privacy. Even though the meter ``only'' collects aggregate energy
consumption of a whole household this data is highly sensitive\cite{markham01}. This counterintuitive fact was initially
overlooked in smart meter deployments leading to outrage, delays and reduced features\cite{cuijpers01}. The root cause
of this problem is that given sufficient timing resolution these aggregate measurements contain ample entropy. Through
disaggregation algorithms individual loads can be identified and through pattern matching even complex usage patterns
can be discerned with alarming accuracy\cite{greveler01}. Similar privacy issues arise in many other areas of modern
life through pervasive tracking and surveillance\cite{zuboff01}. What makes the case of smart metering worse is that
even the fig leaf of consent such practices often hide behind does not apply here. If a citizen does not consent to
Google's privacy policy Google says they can choose not to use their service. In today's world this may not be a free
choice thereby invalidating this argument but it is at least technically possible. Smart metering on the other hand is
mandated by law and depending on the law a customer unwilling to accept the accompanying privacy violation may not be
able to evade it\cite{bmwi04}.

\subsection{Smart grid components as embedded devices}

A fundamental challenge in smart grid implementations is the central role smart electricity meters play. Smart meters
are used both for highly-granular load measurement and (in some countries) load switching\cite{zheng01}.  Smart
electricity meters are effectively consumer devices. They are built down to a certain price point that is measured by
the burden it puts on consumers. The cost of a smart meter is ultimately limited by it being a major factor in the
economies of a smart meter rollout\cite{bmwi03}.  Cost requirements preclude some hardware features such as the use of a
standard hardened software environment on a high powered embedded system (such as a hypervirtualized embedded linux
setup) that would both increase resilience against attacks and simplify updates. Combined with the small market sizes in
smart grid deploymentsthis results in a high cost pressure on the software development process for smart electricity
meters.  Most vendors of smart electricity meters only serve a handful of markets. A large fraction of smart meter
development cost lies in the meter's software. Landis+Gyr, a large manufacturer that makes most of its revenue from
utility meters in their 2019 annual report write that they \SI{36}{\percent} of their total R\&D budget on embedded
software (firmware) while spending only \SI{24}{\percent} on hardware R\&D\cite{landisgyr01,landisgyr02}.  There exist
multiple competing standards applicable to various parts of a smart electricity meter and most countries have their own
certification regimen\cite{cenelec01}. This complexity creates a large development burden for new market
entrants\cite{perez01}.

\subsection{The state of the art in embedded security}

Embedded software security generally is much harder than security of higher-level systems. This is due to a combination
of the unique constraints of embedded devices: Among others they are hard to update and usually produced in small
quantities. They also lack capabilities compared to full computers. Processing power is limited and memory protection
functions are spartan. Even well-funded companies continue to have trouble securing their embedded
systems. A spectacular example of this difficulty is the recently-exposed flaw in Apple's iPhone SoC first-stage ROM
bootloader\footnote{
    Modern system-on-chips integrate one or several CPUs with a multitude of peripherals, from memory and DMA
    controllers over 3D graphics accelerators down to general-purpose IO modules for controlling things like indicator
    LEDs. Most SoCs boot from one of several boot devices such as flash memory, Ethernet or USB according to a
    configuration set by pin-strapping configuration IOs or through write-only fuse bits.

    Physically, one of the processing cores of the SoC (usually one of the main CPU cores) is connected such that it is
    taken out of reset before all other devices, and is tasked with enabling and configuring all other peripherals of
    the SoC. In order to run later intialization code or more advanced bootloaders, this core on startup runs a very
    small piece of code hard-burned into the SoC in the factory. This ROM loader initializes the most basic peripherals
    such as internal SRAM memory and selects a boot device for the next bootloader stage.

    Apple's ROM loader measures only a few hundred bytes. It performs authorization checks to ensure only software
    authorized by Apple is booted. The present flaw allows an attacker to circumvent these checks and boot their own
    code on a USB-connected iPhone.  This compromises Apple's chain of trust from ROM loader to userland right at its
    root. Since this is a flaw in the factory-programmed first stage read-only boot code of the SoC it cannot be patched
    in the field.
}, that allows a full compromise of any iPhone before the iPhone X. iPhone 8, one of the affected models, was still
being manufactured and sold by Apple until April 2020.  In another instance in 2016 researchers found multiple flaws in
the secure-world firmware used by Samsung in their mobile phone SoCs.  The flaws they found were both severe
architectural flaws such as secret user input being passed through untrusted userspace processes without any protection
and shocking cryptographic flaws such as
CVE-2016-1919\footnote{\url{http://cve.circl.lu/cve/CVE-2016-1919}}\cite{kanonov01}.  And Samsung is not the only large
multinational corporation having trouble securing their secure world firmware implementation. In 2014 researchers found
an embarrassing integer overflow flaw in the low-level code handling untrusted input in Qualcomm's QSEE
firmware\cite{rosenberg01}. For an overview of ARM TrustZone including a survey of academic work and past security
vulnerabilities of TrustZone-based firmware see \cite{pinto01}.

For their mass-market phones these companies have R\&D budgets that dwarf some countries' national budgets.  If even
they have trouble securing their secure embedded software stacks, what is a smart meter manufacturer to do? If a
standard as in case of the German one requires IP gateways to speak TLS, a protocol that is notoriously tricky to
implement correctly\cite{georgiev01}, the manufacturer is short on options to secure their product.

Since thorough formal verification of code is not yet within reach for either large-scale software development or code
heavy in side-effects such as embedded firmware or industrial control software\cite{pariente01} the two most effective
measures for embedded security are reducing the amount of code on one hand, and labor-intensively reviewing and testing
this code on the other hand. A smart meter manufacturer does not have a say in the former since it is bound by the
official regulations it has to comply with, and will likely not have sufficient resources for the latter. We are left
with an impasse: Manufacturers in this field likely do not have the security resources to keep up with complex standards
requirements. At the same time they have no option to reduce the scope of their implementation to alleviate the burden
on firmware security.

\subsection{Attack avenues in the smart grid}

If we model the smart grid as a control system responding to changes in inputs by regulating outputs, on a very high
level we can see two general categories of attacks: Attacks that directly change the state of the outputs, and attacks
that try to influence the outputs indirectly by changing the system's view of its inputs. The former would be an attack
such as shutting down a power plant to decrease generation capacity\cite{lee01}. The latter would be an attack such as
forging grid frequency measurements where they enter a power plant's control systems to provoke the control systems to
oscillate\cite{kosut01,wu01,kim01}.

\subsubsection{Communication channel attacks}

Communication channel attacks are attacks on the communication links between smart grid components. This could be
attacks on IP-connected parts of the core network or attacks on shared busses between smart meters and IP gateways in
substations. Generally, these attacks can be mitigated by securing the aforementioned communication links using modern
cryptography. IP links can be protected using TLS, and more low-level busses can be protected using more lightweight
Noise\cite{perrin01}-based protocols.

Cryptographic security transforms an attackers ability to read and manipulate communication contents into a mere denial
of service attack. Thus, in addition to cryptographic security safety under DoS conditions must be ensured for continued
system performance under attacks. This safety property is identical with the safety required to withstand random outages
of components, such as communication link outages due to physical damage from storms, flooding etc\cite{sato01}. In
general attacks at the meter level are hard to weaponize.  Meters primarily serve billing purposes.  The use of smart
meter data for load forecasting is not yet common practice.  Once it is this data will only be used to refine existing
forecasting models that are based on aggregate data collected at higher vantage points in the distribution grid. This
combination of smart metering data with more trusted aggregate data from sensors within the grid infrastructure limits
the potential impact of a data falsification attack on smart meters. It also allows the utility to identify potentially
corrupt meter readings and thus detect manipulation above a certain threshold.  In order for an attack to have more
far-reaching consequences the attacker would need to compromise additional grid infrastructure\cite{kim01,kosut01}.

\subsubsection{Exploiting centralized control systems}

The type of smart grid attack most often cited in popular discourse, and to the author's knowledge the only type that
has so far been carried out in practice, is a direct attack on centralized control systems. In this attack, computer
components of control systems are compromised by the same techniques used to compromise any other kind of computer
system such as spearfishing, exploiting insecure services running on internet-exposed ports and using one compromised
system to compromise other systems on the same ostensably secure internal network. These attacks are very powerful as
they yield the attacker direct control over whatever outputs the compromised control systems are controlling. If an
attacker manages to compromise the right set of control computers, they may even be able to cause physical
damage\cite{lee01}.

Despite their potentially large impact, these attacks are only moderately interesting from a scientific perspective. For
one, their mitigation mostly consists of a straightforward application of decades-old security best practices.  Though
there is room for the implementation of genuinely new, power systems-specific security systems in this field, the general
state of the art is lacking behind other fields of embedded security. From this background low-hanging fruit should take
priority\cite{heise02}.  Given political will these systems can readily be fortified. There is only a comparatively
small number of them and having a technician drive to every one of them in turn to install a firmware security update is
feasible.

\subsubsection{Control function exploits}

Control function exploits are attacks on the mathematical control loops used by the centralized control system. One
example of this type of attack are resonance attacks as described in \cite{wu01}.  In this kind of attack, inputs from
peripheral sensors indicating grid load to the centralized control system are carefully modified to cause a
disproportionately large oscillation in control system action. This type of attack relies on complex resonance effects
that arise when mechanical generators are electrically coupled. These resonances, colloquially called ``modes'', are
well-studied in power system engineering\cite{rogers01,grebe01,entsoe01,crastan03}.  Even disregarding modern attack
scenarios, for stability electrical grids are designed with measures in place to dampen any resonances inherent to grid
structure. These resonances are hard to analyze since they require an accurate grid model and they are unlikely to be
noticed under normal operating conditions.

Mitigation of these attacks can be achieved by ensuring unmodified sensor inputs to the control systems in the first
place. Carefully designing control systems not to exhibit exploitable behavior such as oscillations is also possible but
harder.

\subsubsection{Endpoint exploits}

The one to us rather interesting attack on smart grid systems is someone exploiting the grid's endpoint devices such as
smart electricity meters.  These meters are deployed on a massive scale, with at least one meter per household on
average\footnote{Households rarely share a meter but some households may have a separate meter for detached properties
such as a detached garage or basement.}.  Once compromised, restoration to an uncompromised state can be difficult if it
requires physical access to thousands of devices in hard-to-access locations.

By compromising smart electricity meters, an attacker can forge the distributed energy measurements these devices
perform. In a best-case scenario, this might only affect billing and lead to customers being under- or over-charged if
the attack is not noticed in time. In a less ideal scenario falsified energy measurements reported by these devices
could impede the correct operation of centralized control systems.

In some countries such as the UK smart meters have one additional function that is highly useful to an attacker: They
contain high-current disconnect switches to disconnect the entire household or business in case electricity bills are
left unpaid for a certain period. In countries that use these kinds of systems on a widespread level, the load
disconnect switch is controlled by the smart meter's central microcontroller. This allows anyone compromising this
microcontroller's firmware to actuate the disconnect switch at will.  Given control over a large number of
network-connected smart meters, an attacker might thus be able to cause large-scale disruptions of power
consumption\cite{anderson01,temple01}.  Combined with an attack method such as the resonance attack from \cite{wu01}
that was mentioned above, this scenario poses a serious threat to grid stability.

In places where Demand-Side Management (DSM) is common this functionality may be abused in a similar way. In DSM the
smart metering system directly controls power to certain devices such as heaters. The utility can remotely control the
turn-on and turn-off of these devices to smoothen out the load curve. In exchange the customer is billed a lower price
for the energy consumed by these loads. DSM was traditionally done in a federated fashion usually through low-frequency
PLC over the distribution grid\cite{dzung01}. Smart metering systems no longer require large, resource-intensive
transmitters in substations and bear the potential for a rollout of such technology on a much wider scale than before.
This leads to a potentially significant role of DSM systems in the impact calculation of an attack on a smart metering
system. DSM does not control as much load capacity as remote disconnect switches do but the attacks cited in the above
paragraph still fundamentally apply.

\subsection{Practical threats}

As a highly integrated system the electrical grid is vulnerable to attacks from several angles. One way to classify
attacks is by their motivation. Along this axis we found the following motives:

\begin{description}
    \item[Service disruption.] An attack aimed at disrupting service could e.g.\ aim at causing a blackout. It could
        also take aim in a more subtle way targeting a degradation of parameters such as power quality (voltage,
        frequency and waveform). It could target a particular customer, geographic area or all parts of the grid.
        Possible motivations range from a tennage hacker's boredom to actual cyberwar\cite{cleveland01,lee01}.
    \item[Commercial disruption.] Simple commercial motives already motivate a wide variety of attacks on grid
        infrastructure\cite{czechowski01}. Though generally mostly harmless from a cypersecurity point of view there are
        instances where these attacks put the lives of both the attacker and bystanders at grave risk\cite{anderson01}.
        Such attacks generally aim at the meter itself but a more sophisticated attacker might also target the
        utility's backend computer bureaucracy.
    \item[Data extraction.] The smart grid collects large amounts of data on both individual consumers and on an
        aggregate level. The privacy risk in individual consumer's data is obvious. On the web
        data collection practices ranging from questionable to flat-out illegal have widely proliferated for various
        purposes including election manipulation\cite{heise03}. Assuming criminals in this field would eschew
        fertile ground such as this due to legal or ethical concerns is optimistic. Taking the risk to individual
        customer's data out of the equation even aggregate data is still highly attractive to some. Aggregate real-time
        electricity usage data is a potential source on timely information on matters such as national social events
        (through TV set energy consumption\cite{greveler01}) or the state of the economy.
\end{description}

A factor to consider in all these cases is that one actor's attacks have the potential to weaken system security
overall. An attacker might add new backdoors to gain persistence or they might disable existing mitigations to enable
further steps of their attack.

In this paper we will largely concentrate on attacks of the first type because they both have the most serious
consequences and the most motivated attackers. Attackers that may want to disrupt service include nation state's
cyberwar operations. This type of attacker is both highly skilled and highly funded.

\subsection{Conclusion or, why we are doomed}

We can conclude that a compromise of a large number of smart electricity meters cannot be ruled out. The complexity of
network-connected smart meter firmware makes it exceedingly unlikely that it is in fact flawless. Large-scale
deployments of these devices sometimes with disconnect relays make them an attractive target for attackers interested in
causing grid instability. The attacker model for these devices includes nation states, who have considerable resources
at their disposal.

For a reasonable guarantee that no large-scale compromises of hard- and software built today will happen over a span of
some decades, we would have to radically simplify its design and limit attack surface. Unfortunately, the complexity of
smart electricity meter implementations mostly stems from the large list of requirements these devices have to conform
with. Alas, the standards have already been written, political will has been cast into law and changes that reduce scope
or functionality have become exceedingly unlikely at this point.

A general observation with smart grid systems of any kind is that they comprise a departure from the federated
control structure of yesterday's ``dumb'' grid and the advent of centralization to an enormous scale. This modern,
centralized infrastructure has been carefully designed to defend against malicious actors and all involved parties have
an interest in keeping it secure but in centralized systems scaling attacks is inherently easier than in decentralized
systems\cite{anderson02}. An attacker can employ centralized control to their advantage.  From this perspective the
centralization of smart metering control systems--sometimes up to a national level\cite{anderson01,anderson02}--poses a
security risk.

\chapter{Restoring endpoint safety in an age of smart devices}

As laid out in the previous section we cannot fully rule out a large-scale compromise of smart energy meters at some
point in the long-term future. Instead we have to rephrase our claim to security. We cannot rule out exploitation: We
have to limit its impact. Assuming that we cannot strip any functionality from smart meters all we can do is to flush
out an attacker once they are in. Mitigation replaces prevention.

In a worst-case scenario an attacker would gain unconstrained code execution e.g.\ by exploiting a flaw in a network
protocol implentation. Smart meters use standard microcontrollers that do not have advanced memory protection functions
(cf.\ Section \ref{sm-cpu}). We can assume the attacker has full control over the main microcontroller given any such
flaw. With this control they can actuate the disconnect switch if present. They can transmit data through the device's
communication interfaces or use the user interface components such as LEDs and the LCD. Using the self-programming
capabilities of flash microcontrollers an attacker could even gain persistency. Note that in systems separating
cryptographic functions into some form of cryptographic module\footnote{such as systems used in
Germany\cite{bsi-tr-03109}.} we can be optimistic and assume the attacker has not yet compromised this cryptographic
co-processor.

With the meter's core microcontroller under attacker control we cannot use this microcontroller to restore control over
the system. We have no way of ensuring the attacker does not simply delete a security mechanism we include in the core
microcontroller's firmware. Theoretically a secure boot implementation could be used to ensure meters boot into a safe
state after temporary power loss but we cannot rely on secure boot being present on every smart meter application
controller. Nowadays secure boot is a standard feature in many SoC aimed at smartphones or smart TVs but it is still
very uncommon in microcontrollers.

Our solution to this problem is to add another smaller microcontroller to the smart meter design. This microcontroller
will contain a small piece of software that receives cryptographically authenticated commands from utility companies. On
demand it can reset the meter's core microcontroller to a known-good state. To reliably flush out an attacker from a
compromised core microcontroller we re-program the core microcontroller in its entirety. We propose using JTAG to
re-program the core microcontroller with a known-good firmware image read from a sufficiently large SPI flash connected
to the reset controller. JTAG is supported by most microcontrollers complex enough to be used in a smart meter design.
JTAG programming functionality can be ported to a new microcontroller with relatively little work.

Our solution requires the core mircocontroller's JTAG interface to be activated (i.e. not fused-shut). For our solution
to work the core microcontroller firmware must not be able to permanently disable the JTAG interface by itself.  In
microcontrollers that do not yet provide this functionality this is a minor change that could be added to a custom
microcontroller variant at low cost. On most microcontrollers keeping JTAG open should not interfere with code readout
protection\footnote{Readout protection usually forces a device to erase its program and data memories before allowing
JTAG access.}. Code secrecy should be of no concern\cite{schneier01} here but some manufacturers have strong preferences
due to a fear of copyright infringement.

\section{The theory of endpoint safety}
\label{sec_criteria}

In order to gain anything by adding our reset controller to the smart meter's already complex design we must satisfy two
interrelated conditions.
\begin{enumerate}
\item \emph{security} means our reset controller itself does not have any remotely exploitable flaws
\item \emph{safety} menas our reset controller will perform its job as intended
\end{enumerate}

Note that our \emph{security} property includes only remote exploitation, and excludes any form of hardware attack.
Even though most smart meters provide some level of physical security, we do not wish to make any assumptions on this.
In the following section we will elaborate our attacker model and it will become apparent that sufficient physical
security to defend against all attackers in our model would be infeasible, and thus we will design our overall system
to remain secure even if we assume some number of physically compromised devices.

\subsection{Attack characteristics}
The attacker model the two above conditions must hold under is as follows. We assume three angles of attack: Attacks by the
customer themselves, attacks by an insider within the metering systems controlling utility company and lastly attacks
from third parties. Examples for these third parties are hobbyist hackers or outside cybercriminals on the one hand,
but also other companies participating in the smart grid infrastructure besides the utility company such as intermediary
providers of meter-reading services.

Due to the critical nature of the electrical grid, we have to include hostile state actors in our attacker model. When
acting directly, these would be classified as third-party attackers by the above schema, but they can reasonably be
expected to be able to assume either of the other two roles as well e.g. through infiltration or bribery.  In the
generalized attacker model in \cite{fraunholz01} the authors give a classification of attacker types and provide a nice
taxonomy of attacker properties. In their threat/capability rating, criminals are still considered to have higher threat
rating than state-sponsored attackers. The New York Times reported in 2016 that some states recruit their hacking
personnel in part from cybercriminals. If this report is true, in a worst-case scenario we have to assume a
state-sponsored attacker to be the worst of both types. Comparing this against the other attacker types in
\cite{fraunholz01}, this state-sponsored attacker is strictly worse than any other type in both variables. We are left
with a highly-skilled, very well-funded, highly intentional and motivated attacker.

Based on the above classification of attack angles and our observations on state-sponsored attacks, we can adapt
\cite{fraunholz01} to our problem, yielding the following new attacker types:

\begin{enumerate}
    \item \textbf{Utility company insiders controlled by a state actor.}
        We can ignore the other internal threats described in \cite{fraunholz01} since an insider coöperating with a
        state actor is strictly worse in every respect.
    \item \textbf{State-sponsored external attackers.}
        A state actor can directly attack the system through the internet and with proper operations security they do
        not risk exposure or capture.
    \item \textbf{Customers controlled by a state actor.}
        A state actor can very well compromise some customers for their purposes. They might either physically
        infiltrate the system posing as legitimate customers, or they might simply deceive or bribe existing customers
        into coöperation.
    \item \textbf{Regular customers.}
        A hostile state actor might gain control of some number of customers through means such as voluntary
        coöperation, bribery or infiltration but this limits the scale of an attack since an attacker has to avoid
        arousing premature attention. Though regular customers may not have the motivation, skill or resources of a
        state-sponsored attacker, potentially large numbers of them may try to attack a system out of financial
        incentives\cite{anderson01,czechowski01}. To allow for this possibility, we consider regular customers separate
        from state actors posing as customers.
\end{enumerate}

\subsection{Overall structural system security}

Considering overall security, we first introduce the reset authority, a trusted party acting as the single authority for
issuing reset commands in our system. In practice this trusted party may be part of the utility company, part of an
external regulatory body or a hybrid setup requiring both to coöperate. We assume this party will be designed to be
secure against all of the above attacker types. The precise design of this trusted party is out of scope for this work
but we will provide some practical suggestions on how to achieve security below in Section \ref{sec-regulation}.

Using an asymmetric cryptographic design centered around the reset authority, we rule out all attacks except for
denial-of-service attacks on our system by any of the four attacker types. All reset commands in our system originate
from the reset authority and are cryptographically secured to provide authentication and tamper detection.  Under this
model attacks on the electrical grid components between the reset authority and the customer device degrade into denial
of service attacks. To ensure the \emph{safety} criterion from Section \ref{sec_criteria} holds we must make sure our
cryptography is secure against man-in-the-middle attacks and we must try to harden the system against denial-of-service
attacks by the attacker types listed above. Given our attacker model we cannot fully guard against this sort of attack
but we can at least choose a communication channel that is resilient under the above model.

Finally, we have to consider the issue of hardware security. We will solve the problem of physical attacks by simply not
programming any secret information into devices. This also simplifies hardware production. We consider supply-chain
attacks out-of-scope for this work.

\subsection{Complex microcontroller firmware}

The \emph{security} property from \ref{sec_criteria} is in a large part reliant on the security of our reset
controller firmware. The best method to increase firmware security is to reduce attack surface by limiting external
interfaces as much as possible and by reducing code complexity as much as possible.  If we avoid the complexity of most
modern microcontroller firmware we gain another benefit beyond implicitly reduced attack surface: If the resulting
design is small enough we may even succeed in formal verification of our security properties.  Though formal
verification tools are not yet suitable for highly complex tasks they are already adequate for small amounts of code and
simple interfaces.

\subsection{Modern microcontroller hardware}

Microcontrollers have gained enormously in both performance and efficiency as well as in peripheral support. Alas, these
gains have largely been driven by insatiable customer demand for faster, more powerful chips and for the longest time
security has not been considered important outside of some specific niches such as smartcards. A few years ago a
microcontroller would spend its entire lifetime without ever being exposed to any networks\cite{anderson02}. Though this
trend has been reversing with the increasing adoption of internet-of-things things and more advanced security features
have started appearing in general-purpose microcontrollers, most still lack even basic functionality found in processors
for computers or smartphones.

One of the components lacking from most microcontrollers is strong memory protection or even a memory mapping unit as it
is found in all modern computer processors and SoCs for applications such as smartphones. Without an MPU (Memory
Protection Unit) or MMU (Memory Management Unit) many memory safety mitigations cannot be implemented.  This and the
absence of virtualization tools such as ARM's TrustZone make hardening microcontroller firmware a big task.  It is very
important to ensure memory safety in microcontroller firmware through tools such as defensive coding, extensive testing
and formal verification.

In our design we achieve simplicity on two levels: One, we isolate the very complex metering firmware from our reset
controller by having both run on separate microcontrollers. Two, we keep the reset controller firmware itself extremely
simple to reduce attack surface there. Our protocol only has one message type and no state machine.

\subsection{Safety vs. security: Opting for restoration instead of prevention}

By implementing our reset system as a physically separate microcontroller we sidestep most security issues around the
main application microcontroller.  There are some simple measures that can be taken to harden its firmware.
Implementing industry best practices such as memory protection or stack canaries will harden the system and increase the
cost of an attack but it will not yield a system that we can be confident enough in to say it is fully secure. The
complexity of the main application controller firmware makes fully securing the system a formidable effort--and one that
would have to be repeated by every meter vendor for every one of their code bases.

In contrast to this our reset system does not provide any additional security. Any attack that could occur without it
can still occur with it in place. What it provides is a fail-safe mechanism that can quickly immobilize a malicious
actor mid-attack. It does this in a way that can be adapted to any meter architecture and any microcontroller platform
with low effort since it relies on established standard interfaces such as JTAG and SWD. Concentrating research and
development resources on a single platform like this allows for a system that is more economical to implement across
device series and across vendors.

Attack resilience in the power grid can benefit from a safety-focused approach. The greater threat such an attack poses
is not the temporary denial of service of utility metering functions. Even in a highly integrated smart grid as
envisioned by utility companies these measurement functions are used by utility companies to increase efficiency and
reduce cost but are not necessary for the grid to function at all.  Thus if we can provide mere \emph{safety} with a
fail-safe semantic instead of unattainable perfect \emph{security} we have gained resilience against a large class of
realistic attack scenarios.

\subsection{Technical outline of a safety reset system}

There are several ways our system could be practically implemented. The most basic way is to add a separate
microcontroller connected to the meter's main application MCU and optionally other embedded microcontrollers such as
modems. This discrete chip could either be placed on the metering board itself or it could be placed on a separate PCB
connected to the programming interface(s) of the metering board. In certain cases the latter might allow its use in
otherwise unmodified legacy designs.

The safety reset controller would be a much simpler MCU than the meter's main application controller. Its software can
be kept simple leading to low program flash and RAM requirements. Since it does not need to address rich periphery such
as external parallel memory, LCDs etc.\ it can be a physically small, low-pin count device. If the main application
controller is supposed to be reset to a full factory image with little or no reduced functionality its firmware image
size is certainly too large for the reset controller's embedded flash. Thus a realistic setup would likely use an
external SPI flash chip to store this image.

The most likely interfaces to reset the main application controller and possibly other microcontrollers such as modem
chips would be the controller's integrated programming port such as JTAG.  Parallel high-voltage flash programming has
come to be uncommon in modern microcontrollers and most nowadays use some form of a serial interface.  There exist a
variety of serial programming and debug interfaces but JTAG has grown to be by far the most broadly supported one and
has largely displaced vendor-specific debug interfaces except for very small devices.

The kind of microcontroller that would likely be used as the main application controller in a smart meter application
will almost certainly support JTAG. These microcontrollers are high pin-count devices since they need to connect to a
large set of peripherals such as the LCD and the large program flash makes it likely for a proper debugging interface to
be present.  The one remaining issue in this coarse technical outline is what communication interface should be used to
transmit the trigger command to the reset controller. In the following section we will give an overview on communication
interfaces established in energy metering applications and evaluate each of them for our purpose.

\section{Communication channels on the grid}

There is a number of well-established technologies for communication on or along power lines. We can distinguish three
basic system categories: Systems using separate wires (such as DSL over landline telephone wiring), wireless radio
systems (such as LTE) and \emph{power line communication} (PLC) systems that reüse the existing mains wiring and
superimpose data transmissions onto the 50 Hz mains sine\cite{gungor01,kabalci01}.

For our scenario, we will ignore short-range communication systems. There exists a large number of \emph{wideband}
power line communication systems that are popular with consumers for bridging Ethernet segments between parts of an
apartment or house.  These systems transmit up to several hundred megabits per second over distances up to several tens
of meters\cite{kabalci01}.  Technologically, these wideband PLC systems are very different from \emph{narrowband}
systems used by utilities for load management among other applications and they are not relevant to our analysis.

\subsection{Power line communication (PLC) systems and their use}

In long-distance communications for applications such as load management, PLC systems are attractive since they allow
re-using the existing wiring infrastructure and have been used as early as in the 1930s\cite{hovi01}. Narrowband PLC
systems are a potentially low-cost solution to the problem of transmitting data at small bandwidth over distances of
several hundred meters up to tens of kilometers.

Narrowband PLC systems transmit on the order of Kilobits per second or slower.  A common use of this sort of system are
\emph{ripple control} systems. These systems superimpose a low-frequency signal at some few hundred Hertz carrier
frequency on top of the 50Hz mains sine. This low-frequency signal is used to encode switching commands for
non-essential residential or industrial loads. Ripple control systems provide utilities with the ability to actively
control demand while promising savings in electricity cost to consumers\cite{dzung01}.

In any PLC system there is a strict trade-off between bandwidth, power and distance. Higher bandwidth requires higher
power and reduces maximum transmission distance. Where ripple control systems usually use few transmitters to cover
the entire grid of a regional distribution utility, higher bandwidth bidirectional systems used for automatic meter
reading (AMR) in places such as Italy or France require repeaters within a few hundred meters of a transmitter.

\subsection{Landline and wireless IP-based systems}

Especially in automated meter reading (AMR) infrastructure the cost-benefit trade-off of power line systems does not
always work out for utilities. A common alternative in these systems is to use the public internet for communication.
Using the public internet has the advantage of low initial investment on the part of the utility company as well as
quick commissioning. Disadvantages compared to a PLC system are potentially higher operational costs due to recurring
fees to network providers as well as lower reliability. Being integrated into power grid infrastructure, a PLC system's
failure modes are highly correlated with the overall grid. Put briefly, if the PLC interface is down, there is a good
chance that power is out, too. In contrast general internet services exhibit a multitude of failures that are entirely
uncorrelated to power grid stability.  For purposes such as meter reading for billing purposes, this stability is
sufficient. However for systems that need to hold up in crisis situations such as the recovery system we are
contemplating in this thesis, the public internet may not provide sufficient reliability.

\subsection{Short-range wireless systems}

Smart meters contain copious amounts of firmware but still pale in comparison to the complexity of full-scale computers
such as smartphones. For short-range communication between a meter and a cellular radio gateway mounted nearby or
between a meter and a meter reading operator in a vehicle on the street a protocol such as Wifi (IEEE 802.11) is too
complex. Absent widely-used standards in this space proprietary radio protocols grew attractive. These are often based
on some standardized lower-level protocol such as ZigBee (IEEE 802.15) but entirely home-grown ones also exist. To the
meter manufacturer a proprietary radio protocol has several advantages. It is easy to implement and requires no external
certification. It can be customized to its specific application. In addition it provides vendor lock-in to customers
sharing infrastructure such as a cellular radio gateway between multiple devices.  In other fields a lack of
standardization has led to a proliferation of proprietary protocols and a fragmented protocol landscape. This is a large
problem since the consumer cannot easily integrate products made by different manufacturers into one system. In advanced
metering infrastructure this is unlikely to be a disadvantage since usually there is only one distribution grid
operator for an area.  Shared resources such as a cellular radio gateway would most likely only be shared within a
single building and usually they are all operated by the same provider.

Systems in Europe commonly support Wireless M-Bus, an European standardized protocol\cite{silabs01} that operates on
several ISM bands\footnote{
    Frequency bands that can be used for \emph{Industrial, Scientific and Medical} applications by anyone and that do
    not require obtaining a license for transmitter operation. Manufacturers can use whatever protocol they like on
    these bands as long as they obtain certification that their transmitters obey certain spectral and power
    limitations.
}. ZigBee is another popular standard and some vendors additionally support their own proprietary protcols\footnote{
    For an example see \cite{honeywell01}.
}.

\subsection{Frequency modulation as a communication channel}

For our system, we chose grid frequency modulation (henceforth GFM) as a low-bandwidth unidirectional broadcast
communication channel.  Compared to traditional PLC, GFM requires only a small amount of additional equipment, works
reliably throughout the grid and is harder to manipulate by a malicious actor. 

Grid frequency in Europe's synchronous areas is nominally 50 Hertz, but there are small load-dependent variations from
this nominal value. Any device connected to the power grid (or even just within physical proximity of power wiring) can
reliably and accurately measure grid frequency at low hardware overhead. By intentionally modifying grid frequency, we
can create a very low-bandwidth broadcast communication channel. Grid frequency modulation has only ever been proposed
as a communication channel at very small scales in microgrids before\cite{urtasun01} and to our knowledge has not yet
been considered for large-scale application.

Advantages of using grid frequency for communication are low receiver hardware complexity as well as the fact that a
single transmitter can cover an entire synchronous area. Though the transmitter has to be very large and powerful the
setup of a single large transmitter faces lower bureaucratic hurdles than integration of hundreds of smaller ones into
hundreds of local systems that each have autonomous governance.

\subsubsection{The frequency dependency of grid frequency}

Despite the awesome complexity of large power grids the physics underlying their response to changes in load and
generation is surprisingly simple. Individual machines (loads and generators) can be approximated by a small number of
differential equations and the entire grid can be modelled by aggregating these approximations into a large system of
nonlinear differential equations. Evaluating these systems it has been found that in large power grids small signal
steady state changes in generation/consumption power balance cause an approximately linear change in
frequency\cite{kundur01,crastan03,entsoe02,entsoe04}. \emph{Small signal} here describes changes in power balance that
are small compared to overall grid power.  \emph{Steady state} describes changes over a time frame of multiple waveform
cycles as opposed to transient events that only last a few milliseconds.

This approximately linear relationship allows the specification of a coefficient with unit \si{\watt\per\hertz} linking
power differential $\Delta P$ and frequency differential $\Delta f$.  In this thesis we are using the European power
grid as our model system. We are using data provided by ENTSO-E (formerly UCTE), the governing association of European
transmission system operators. In our calculations we use data for the continental European synchronous area, the
largest synchronous area. $\frac{\Delta P}{\Delta f}$, called \emph{Overall Network Power Frequency Characteristic} by
ENTSO-E is around \SI{25}{\giga\watt\per\hertz}.

We can derive general design parameter for any system utilizing grid frequency as a communication channel from the
policies of ENTSO-E\cite{entsoe02,entsoe03}.  Any such system should stay below a modulation amplitude of
\SI{100}{\milli\hertz} which is the threshold defined in the ENTSO-E incidents classification scale for a Scale 0-1
(from ``Anomaly'' to ``Noteworthy Incident'' scale) frequency degradation incident\cite{entsoe02} in the continental
Europe synchronous area.

\subsubsection{Control systems coupled to grid frequency}

The ENTSO-E Operations Handbook Policy 1 chapter\cite{entsoe02} defines the activation threshold of primary control to
be \SI{20}{\milli\hertz}. Ideally, a modulation system would stay well below this threshold to avoid fighting the
primary control reserve. Modulation line rate should likely be on the order of a few hundred Millibaud.  Modulation at
these rates would outpace primary control action which is specified by ENTSO-E as acting within between ``a few
seconds'' and \SI{15}{\second}.

Keeping modulation amplitude below this threshold would help to avoid spuriously triggering these control functions.
The effective \emph{Network Power Frequency Characteristic} of primary control in the European grid is reported by
ENTSO-E at around \SI{20}{\giga\watt\per\hertz}.   This works out to an upper bound on modulation power of
\SI{20}{\mega\watt\per\milli\hertz}.

\subsubsection{An outline of practical transmitter implementation}

In its most basic form a transmitter for grid frequency modulation would be a very large controllable load connected to
the power grid at a suitable vantage point. A spool of wire submerged in a body of cooling liquid such as a small lake
along with a thyristor rectifier bank would likely suffice to perform this function during occasional cybersecurity
incidents.  We can however decrease hardware and maintenance investment even further compared to this rather
uncultivated solution by repurposing regular large industrial loads as transmitters in an emergency situation.  For some
preliminary exploration we went through a list of energy-intensive industries in Europe\cite{ec01}.  The most
electricity-intensive industries in this list are primary aluminum and steel production.  In primary production raw ore
is converted into raw metal for further refinement such as casting, rolling or extrusion.  In steelmaking iron is
smolten in an electric arc furnace. In aluminum smelting aluminum is electrolytically extracted from alumina. Both
processes involve large amounts of electricity with electricity making up \SI{40}{\percent} of production costs. Given
these circumstances a steel mill or aluminum smelter would be good candidates as transmitters in a grid frequency
modulation system.

In aluminum smelting high-voltage mains is transformed, rectified and fed into about 100 series-connected electrolytic
cells forming a \emph{potline}. Inside these pots alumina is dissolved in molten cryolite electrolyte at about
\SI{1000}{\degreeCelsius} and electrolysis is performed using a current of tens or hundreds of Kiloampère. The resulting
pure aluminum settles at the bottom of the cell and is tapped off for further processing.

Like steelworks, aluminum smelters are operated night and day without interruption. Aside from metallurgical issues the
large thermal mass and enormous heating power requirements do not permit power cycling. Due to the high costs of
production inefficiencies or interruptions the behavior of aluminum smelters under power outages is a
well-characterized phenomenon in the industry. The recent move away from nuclear power and towards renewable energy has
lead to an increase in fluctuations of electricity price throughout the day. These electricity price fluctuations have
provided enough economic incentive to aluminum smelters to develop techniques to modulate smelter power consumption
without affecting cell lifetime or product quality\cite{duessel01,eisma01}. Power outages of tens of minutes up to two
hours reportedly do not cause problems in aluminum potlines and are in fact part of routine operation for purposes such
as electrode changes\cite{eisma01,oye01}.

The power supply system of an aluminum plant is managed through a highly-integrated control system as keeping all cells
of a potline under optimal operating conditions is challenging. Modern power supply systems employ large banks of diodes
or SCRs\footnote{SCRs, also called thyristors, are electronic devices that are often used in high-power switching
applications. They are normally-off devices that act like diodes when a current is fed into their control terminal.} to
rectify low-voltage AC to DC to be fed into the potline\cite{ayoub01}. The potline voltage can be controlled almost
continuously through a combination of a tap changer and a transductor. The individual cell voltages can be controlled by
changing the anode to cathode distance (ACD) by physically lowering or raising the anode.  The potline power supply is
connected to the high voltage input and to the potline through isolators and breakers.

In an aluminum smelter most of the power is sunk into resistive losses and the electrolysis process. As such an
aluminum smelter does not have any significant electromechanical inertia compared to the large rotating machines used
in other industries. Depending on the capabilities of the rectifier controls high slew rates are possible, permitting
modulation at high\footnote{Aluminum smelter rectifiers are \emph{pulse rectifiers}. This means instead of simply
rectifying the incoming three-phase voltage they use a special configuration of transformer secondaries and in some
cases additional coils to produce a large number of equally spaced phases (e.g.\ six) from a standard three-phase input.
Where a direct-connected three-phase rectifier would draw current in six pulses per mains voltage cycle a pulse
rectifier draws current in more, smaller pulses to increase power factor. For example a 12-pulse rectifier will draw
current in 12 pulses per cycle. In the best case an SCR pulse rectifier switched at zero crossing should allow
\SIrange{0}{100}{\percent} load changes from one rectifier pulse to the next, i.e. within a fraction of a single cycle.}
data rates.

\subsubsection{Avoiding dangerous modes}

Modern power systems are complex electromechanical systems. Each component is controlled by several carefully tuned
feedback loops to ensure voltage, load and frequency regulation. Multiple components are coupled through transmission
lines that themselves exhibit complex dynamic behavior. The overall system is generally stable, but may exhbit
instabilities to particular small-signal stimuli\cite{kundur01,crastan03}. These instabilities, called \emph{modes},
occur when due to mis-tuning of parameters or physical constraints the overall system exhibits oscillation at a
particular frequency.  \cite{kundur01} separates these modes into four categories:

\begin{description}
    \item[Local modes] where a single power station oscillates in some parameter,
    \item[Interarea modes] where subsections of the overall grid oscillate with respect to each other due to weak
        coupling between them,
    \item[Control modes] caused by imperfectly tuned control systems and
    \item[Torsional modes] that originate from electromechanical oscillations in the generator itself.
\end{description}

The oscillation frequencies associated with each of these modes are usually between a few tens of Millihertz and a few
Hertz\cite{grebe01,entsoe01,crastan03}. It is hard to predict the particular modes of a power system at the scale of the
central European interconnected system. Theoretical analysis and simulation may give rough indications but cannot yield
conclusive results. Due to the obvious danger as well as high economical impact due to inefficiencies experimental
measurements are infeasible. Modes are highly dependent on the power grid's structure and will change with changes in
the power grid over time. For all of these reasons, a grid frequency modulation system must be designed very
conservatively without relying on the absence (or presence) of modes at particular frequencies. A concrete design
guideline that we can derive from this situation is that the frequency spectrum of any grid frequency modulation system
should not exhibit large peaks and should avoid a concentration of spectral energy in small frequency bands.

\subsubsection{Overall system parameters}

In conclusion we end up with the following tunable parameters for a grid frequency modulation based on a large
controllable load:

\begin{description}
    \item[Modulation amplitude.] Amplitude is proportionally related to modulation power. In a practical setup we might
        realize a modulation power up to a few hundred \si{\mega\watt} which would yield a few tens of \si{\milli\hertz}
        of frequency amplitude.
    \item[Modulation preemphasis and slew-rate control.] Preemphasis might be necessary to ensure an adequate
        Signal-to-Noise ratio (SNR) at the receiver. Slew-rate control and other shaping measures might be necessary to
        reduce the impact of these sudden load changes on the transmitter's primary function (say, aluminum smelting)
        and to prevent disturbances to other grid components.
    \item[Modulation frequency.] For a practical implementation a careful study would be necessary to determine the
        optimal frequency band for operation. On one hand we need to prevent disturbances to the grid such as the
        excitation of local or inter-area modes. On the other hand we need to optimize Signal-to-Noise ratio (SNR)
        and data rate to achieve optimal latency between transmission start and reset completion and to reduce the
        overall burden on both transmitter and grid.
    \item[Further modulation parameters.] The modulation itself has numerous parameters that are discussed in Section
        \ref{mod_params} below.
\end{description}

\section{From grid frequency to a reliable communication channel}
Based on the physical properties oulined above we will provide the theoretical groundwork for a practical communication
system based on grid frequency modulation.

\subsection{Channel properties}
In this section we will explore how we can construct a reliable communication channel from the analog primitive we
have outlined in the previous section. Our load control approach to grid frequency modulation leads to a channel with the
following properties.

\begin{description}
    \item[Slow-changing.] Accurate grid frequency measurements take several periods of the mains sine wave. Faster
        sampling rates can be achieved with more complex specialized synchrophasor estimation algorithms but this will
        result in a trade-off between sampling rate and accuracy\cite{belega01}.
    \item[Analog.] Grid frequency is an analog signal.
    \item[Noisy.] While stable over long periods of time thanks to power stations' Load-Frequency Control
        systems\cite{entsoe04} there are considerable random short-term variations. Our modulation amplitude is limited
        by technical and economic constraints so we have to find a system that will work at poor SNRs.
    \item[Polarized.] Grid frequency measurements have an inherent sense of polarity that we can use in our modulation
        scheme.
\end{description}

\subsection{Modulation and its parameters}
\label{mod_params}

In this section we will analyze what makes for a good set of parameters for a modulation scheme fitting grid frequency
modulation.

As described before the grid's oscillatory modes mean that we should avoid any modulation technique that would
concentrate energy in a small bandwidth. Taking this principle to its extreme provides us with a useful pointer towards
techniques that might work well: Spread-spectrum techniques. By employing spread-spectrum modulation we can produce
close to ideal frequency-domain behavior. Modulation energy is spread almost flatly across the modulation
bandwidth\cite{goiser01}. At the same time we achieve modulation gain which increases system sensitivity.  This
modulation gain potentially allows us to use a weaker stimulus allowing for a further reduction of the probability of
disturbance to the overall system. Spread-spectrum techniques also inherently allow us to trade-off receiver sensitivity
for data rate. This tunability is a useful parameter in the overall system design.

Spread spectrum covers a whole family of techniques that are comprehensively explained in \cite{goiser01}.
\cite{goiser01} divides spread spectrum techniques into the coarse categories of \emph{Direct Sequence Spread Spectrum},
\emph{Frequency Hopping Spread Spectrum} and \emph{Time Hopping Spread Spectrum}.

In \cite{goiser01} a BPSK or similar modulation is assumed underlying the spread-spectrum technique. Our grid frequency
modulation channel effectively behaves more like a DC-coupled wire than a traditional radio channel: Any change in
excitation will cause a proportional change in the receiver's measurement. Using our FFT-based measurement methodology
we get a real-valued signed quantity. In this way grid frequency modulation is similar to a channel using coherent
modulation. We can utilize both signal strength and polarity in our modulation.

For our purposes we can discount both Time and Frequency Hopping Spread Spectrum techniques. Time hopping helps to
reduce interference between multiple transmitters but does not help with SNR any more than Direct Sequence does since
all it does is allowing other transmitters to transmit.  Our system is strictly limited to a single transmitter so we do
not gain anything through Time Hopping.

Frequency Hopping Spread Spectrum techniques require a carrier. Grid frequency modulation itself is very limited in
peak frequency deviation $\Delta f$. Frequency hopping could only be implemented as a second modulation on top of GFM,
but this would not yield any benefits while increasing system complexity and decreasing data bandwidth.

Direct Sequence Spread Spectrum is the only remaining approach for our application. Direct Sequence Spread Spectrum
works by directly modulating a long pseudo-random bit sequence onto the channel. The receiver must know the same
pseudo-random bit sequence and continuously calculates the correlation between the received signal and the pseudo-random
template sequence mapped from binary $[0, 1]$ to bipolar $[1, -1]$. The pseudo-random sequence has an approximately equal
number of $0$ and $1$ bits. The positive contribution of the $+1$ terms of the correlation template approximately cancel
out with the $-1$ terms when multiplied with an uncorrelated signal such as white Gaussian noise.

By using a family of pseudo-random sequences with low cross-correlation channel capacity can be increased. Either the
transmitter can encode data in the choice of sequence or multiple transmitters can use the same channel at once.  The
longer the pseudo-random sequence, the lower its cross-correlation with noise or other pseudo-random sequences of the
same length. Choosing a long sequence we increase modulation gain while decreasing bandwidth. For any given application
the sweet spot will be the shortest sequence that is long enough to yield sufficient SNR for subsequent processing
layers such as channel coding.

A popular code used in many DSSS systems are Gold codes. A set of Gold codes has small cross-correlations. For some
value $n$ a set of Gold codes contains $2^n + 1$ sequences of length $2^n - 1$. Gold codes are generated from two
different maximum length sequences generated by linear feedback shift registers (LFSRs). For any bit count $n$ there are
certain empirically determined preferred pairs of LFSRs that produce Gold codes with especially good cross-correlation.
The $2^n + 1$ gold codes are defined as the XOR sum of both LFSR sequences shifted from $0$ to $2^n-1$ bit as well as
the two individual LFSR sequences. Given LFSR sequences \texttt{a} and \texttt{b} in numpy notation this is
\mintinline{python}{[a, b] + [ a ^ np.roll(b, shift) for shift in len(b) ]}.

In DSSS modulation the individual bits of the DSSS sequence are called \emph{chips}. Chip duration determines modulation
bandwidth\cite{goiser01}. In our system we are directly modulating DSSS chips on mains frequency without an underlying
modulation such as BPSK as it is commonly used in DSSS systems.

\subsection{Error-correcting codes}

To reduce reception error rate we have to layer channel coding on top of the DSSS modulation. The messages we expect to
transmit are at least a few tens of bits long. We are highly constrained in SNR due to limited transmission power and
with lower SNR comes higher BER (Bit Error Rate). At a fixed BER, packet error rate grows exponentially with
transmission length so for our relatively long transmissions we would realistically get unacceptable error rates.

Error correcting codes are a very broad field with many options for specialization. Since we are implementing only an
advanced prototype in this thesis we chose to spend only limited resources on optimization and settled on a basic
Reed-Solomon code. We have no doubt that applying a more state-of-the-art code we could gain further improvements in
code overhead and decoding speed among others\cite{mackay01}. Since message length in our system limits system response
time but we do not have a fixed target we can tolerate some degree of overhead.  Decoding speed is of very low concern
to us because our data rate is extremely low.  We derived our implementation by adapting and optimizing an existing open
source decoder that we validated on an open source encoder implementation. We generate test signals using a Python tool
on the host.

\subsection{Cryptographic security}
\label{sec-crypto}
Above the communication base layer elaborated in the previous section we have to layer a cryptographic protocol to
ensure system security. We want to avoid a case where a third party could interfere with our system or even subvert this
safety system itself for an attack.  From a protocol security perspective the system we are looking for can informally
be modelled as consisting of three parties: the trusted \emph{transmitter}, one of a large number of untrusted
\emph{receivers}, and an \emph{attacker}.  These three play according to the following rules:

\begin{description}
    \item[Access.] Both transmitter and attacker can transmit any bit sequence.
    \item[Indistinguishability.] The receiver receives any transmission by either but cannot distinguish between them.
    \item[Kerckhoff's principle.] Since the protocol design is public and anyone can get access to an electricity meter
        the attacker knows anything any receiver might know\cite{kerckhoff01,kerckhoff02}.
    \item[Priority.] The transmitter is stronger than an attacker and will ``win'' during simultaneous transmission.
    \item[Seeding.] Both transmitter and receiver can be seeded out-of-band with some information on each other such as
        public key fingerprints.
\end{description}

We are not considering situations where an attacker attempts to jam an ongoing transmission. In practice there are
several avenues to prevent such attempts. Compromised large loads that are being abused by the attacker can be manually
disconnected by the utility. Error-correcting codes can be used to provide resiliency against small-scale disturbances.
Finally, the transmitter can be designed to have high enough power to be able to override any likely attacker.

With the above properties in mind our goal is to find a cryptographic primitive that has the following properties:
\begin{description}
    \item[Authentication.] The transmitter can produce a message bit sequence that a certain subset of receivers can
        identify as being generated by the transmitter. On reception of this sequence, all addressed receivers perform a
        safety reset.
    \item[Unforgeability.] The attacker cannot forge a message, i.e.\ find a bit sequence other than one of the
        transmitter's previous messages that a receiver would accept. This implies that the attacker also cannot create
        a new distinct message from a previously transmitted message.
    \item[Brevity.] The message should be short. Our communication channel is outrageously slow compared to anything
        else used in modern telecommunications and every bit counts.
\end{description}

On a protocol level we also have to ensure \emph{idempotence}. Our system should have an at-most-once semantic. This
means for a given message each receiver either performs exactly one safety reset or none at all, even if the message is
re-transmitted by either the transmitter or an attacker.  We cannot achieve the ideal exactly-once semantic wit pure
protocol gymnastics since we are using an unidirectional lossy communication primitive. A receiver might be offline
(e.g.\ due to a local power outage) and then would not hear the transmission even if our broadcast primitive was
reliable. Since there is no back channel, the transmitter has no way of telling when that happens.  The practical impact
of this can be mitigated by the transmitter repeating the message a number of times.

It follows from the unforgeability requirement that we can trivially reach idempotence at the protocol level by keeping
a database of all previous messages and only accepting new messages. By considering this in our cryptographic design we
can reduce the storage overhead of this ``database''.

Along with the indistinguishability property the access requirement implies that we need a cryptographic
signature\cite{lamport01}.  However, we have relaxed constraints on this signature compared to standard cryptographic
practice\cite{anderson04}.  While cryptographic signatures need to work over arbitrary inputs, all we want to ``sign''
here is the instruction to perform a safety reset. This is the only message we might ever want to transmit so our
message space has only one element. The information content of our message thus is 0 bit! All the information we want to
transmit is already encoded \emph{in the fact that we are transmitting} and we do not require a further payload to be
transmitted: We can omit the entirety of the message and just transmit whatever ``signature'' we
produce\cite{haller01,rfc1760}. This is useful to conserve transmission bits so our transmission does not take an
exceedingly long time over our extremely slow communication channel.

We can modify this construction to allow for a small number of bits of information content in our message (say two or
three instead of zero) at no transmission overhead by transmitting the cryptographic signature as usual but simply
omitting the message. The message contains only a few bits of information and we are dealing with minutes of
transmission time so the receiver can reconstruct the message through brute-force. Though this trade-off between
computation and data transmission might seem inelegant it does work for our extremely slow link for up to a few bits of
information.

There is an important limitation in the rules of our setup above: The attacker can always record the reset bit sequence
the transmitter transmits and replay that same sequence later. Even without cryptography we can trivially prevent an
attacker from violating the at-most-once criterion. If every receiver memorizes all bit sequences that have been
transmitted so far it can detect replays. With this mitigation by replaying an older authentic transmission an attacker
can cause receivers that were offline during the original transmission to reset at a later point. Considering our goal
is to reset them in the first place this should not pose a threat to the system's safety or security.

A possible scenario would be that an attacker first causes enough havoc for authorities to trigger a safety reset. The
attacker would record the trigger transmission. We can assume most meters were reset during the attack. Due to this the
attacker cannot cause a significant number of additional resets immediately afterwards.  However, the attacker could
wait several years for a number of new meters to be installed that might not yet have updated firmware that includes the
last transmission. This means the attacker could cause them to reset by replaying the original sequence.

A possible mitigation for this risk would be to introduce one bit of information into the trigger message that is
ignored by the replay protection mechanism.  This \emph{enable} bit would be $1$ for the actual reset trigger message.
After the attack the transmitter would then perform scheduled transmissions of a ``disarm'' message that has this bit
set to $0$. This message informs all new meters and meters that were offline during the original transmission of the
original transmission for replay protection without actually performing any further resets.

We could use any of several traditional asymmetric cryptographic primitives to produce these signatures. The
comparatively high computational effort required for signature verification would not be an issue. Transmissions take
several minutes anyway and we can afford to spend some tens of seconds even in signature verification. Transmission
length and by proxy system latency would be determined by the length of the signature. For RSA signature length is the
modulus length (i.e. larger than \SI{1000}{bit} for very basic contemporary security). For elliptic curve-based systems
curve length is approximately twice the security level and signature size is twice the curve length because two curve
points need to be encoded\cite{anderson02}.  For contemporary security this results in more than 300 bit transmission
length. We can exploit our unique setting's low message entropy to improve on this by basing our scheme on a
cryptographic hash function used as a one-way pseudo-random function (PRF). Hash-based signature schemes date back to
the very beginnings of cryptographic signatures\cite{anderson04,diffie01,lamport02}. Today, in general applications
schemes based on asymmetric cryptography are preferred but hash-based signature systems have their applications in
certain use cases. One example of such a scheme is the TESLA scheme\cite{perrig01} that is the basis for navigation
message authentication in the European Galileo global navigation satellite system. Here, a system based purely on
asymmetric primitives would result in too much computation and communication overhead\cite{ec05}.  In the following
sections we will introduce the foundations of hash-based signatures before deriving our authentication scheme.

\subsubsection{Lamport signatures}

1979, Lamport in \cite{lamport02} introduced a signature scheme that is based only on a one-way function such as a
cryptographic hash function. The basic observation is that by choosing a random secret input to a one-way function and
publishing the output, one can later prove knowledge of the input simply by publishing it. In the following paragraphs
we will describe a construction of a one-time signature scheme based on this observation. The scheme we describe is the
one usually called a ``Lamport Signature'' in modern literature but is slightly different from the variant described in
the 1979 paper. For our purposes we can consider both to be equivalent.

\paragraph{Setup.} In a Lamport signature, for an n-bit hash function $H$ the signer generates a private key $s =
\left(s_{b, i} | b\in\left\{0, 1\right\}, 0\le i<n\right)$ of $2n$ random strings of length $n$. The signer publishes a
public key $p = \left(p_{b, i} = H\left(s_{b, i}\right), b\in\left\{0, 1\right\}, 0\le i<n\right)$ that is simply the
list of hashes of each of the random strings that make up the private key.

\paragraph{Signing.} To sign a message $m$, the signer publishes the signature $\sigma = \left(\sigma_i = k_{H(m)_i,
i}\right)$ where $H(m)_i$ is the $i$-th bit of $H$ applied to $m$. That is, for the $i$-th bit of the message's hash
$H(m)$ the signer publishes either of $p_{0, i}$ or $p_{1, i}$ depending on the hash bit's value, keeping the other
entry of $P$ secret.

\paragraph{Verification.} The verifier can compute $H(m)$ themselves and check the corresponding entries $\sigma_i =
k_{H(m)_i}$ of $S$ correctly evaluate to $p_{b, i} = H\left(s_{b, i}\right)$ from $P$ under $H$.

The above scheme is a one-time signature scheme only. After one signature has been published for a given key, the
corresponding key must not be reüsed for other signatures. This is intuitively clear as we are effectively publishing
part of the private key as the signature, and if we were to publish a signature for another message an attacker could
derive additional signatures by ``mixing'' the two published signatures.

\subsubsection{Winternitz signatures}

An improvement to basic Lamport signatures as described above are Winternitz signatures as detailed in
\cite{merkle01,dods01}. Winternitz signatures reduce public key length as well as signature length for hash length $n$
from $2n$ to $\mathcal O \left(n/t\right)$ for some choice of parameter $t$ (usually a small number such as 4).

\paragraph{Setup.} The signer generates a private key $s = \left(s_i\right)$ consisting of $\ceil{\frac{n}{t}}$ random
bit strings. The signer publishes a public key $p = \left(H^{2^t}\left(s_i\right)\right)$ where each element
$H^{2^t}\left(s_i\right)$ is the $2^t$-fold recursive application of $H$ to $s_i$.

\paragraph{Signing.} The signer splits $m$ padded to a multiple of $t$ bits into $\ceil{\frac{n}{t}}$ chunks $m_i$ of
$t$ bit each. The signer publishes the signature $\sigma = \left( \sigma_i = H^{m_i}\left(s_i\right) \right)$.

\paragraph{Verification.} The verifier can calculate for each $\sigma_i = H^{m_i}\left(s_i\right)$ that $H^{2^t -
m_i}\left(\sigma_i\right) = H^{2^t - m_i}\left(H^{m_i}\left(s_i\right)\right) = H^{2^t - m_i + m_i} \left(s_i\right) =
p_i$.

To prevent an attacker from forging additional signatures from one signature by calculating $\sigma_i' =
H\left(\sigma_i\right)$ matching $m_i' = m_i + 1$, this scheme is usually paired with a simple checksum as described in
\cite{merkle01}.

\subsubsection{Using hash-based signatures for trigger authentication}

Applying these concepts the most basic trigger authentication scheme possible would be to simply generate a random
secret key bit string $s$ and publish $p = H(s)$ for some hash function $H$. To activate the trigger, $\sigma = s$ is
published and receivers verify that $H(\sigma) = p = H(s)$. This simplistic scheme has one main disadvantage: It is a
fundamentally one-time construction. To prevent an attacker from re-triggering a receiver a second time by replaying a
valid trigger $\sigma$ all receivers have to blacklist any ``used'' $\sigma$. Alas, this means we can only ever trigger
a receiver \emph{once}.  The good part is that any receiver that missed this trigger can still be triggered later, but
the bad part is that once $s$ is burned we are out of options. The trivial solution to this would be to simply provision
each receiver with a whole list of public keys in advance. This however takes $n$ times the amount of space for $n$-fold
retriggerability and for each one we have to memorize separately whether it has been used up. Luckily we can easily
derive a scheme that yields $n$-fold retriggerability and naturally memorizes replay state while using no more space
than the original scheme by taking some inspiration from Winternitz signatures.

In this improved scheme the secret key $s$ is still a random bit string. The public key is $p = H^n(s)$ for $n$-times
retriggerability.  The $i$-th time the trigger is activated, $\sigma_i = H^{n-i}(s)$ is published, and every receiver
can verify that $\sigma_{i-1} = H\left(\sigma_i\right)$ with $\sigma_0 = p$. In case a receiver missed one or more
previous triggers it continues computing $H\left(H\left(\sigma_i\right)\right)$ and
$H\left(H\left(H\left(\sigma_i\right)\right)\right)$ and so on until either reaching the $n$-th recursion
level--indicating an invalid signature--or finding $H^n\left(\sigma_i\right) = \sigma_j$ with $\sigma_j$ being the last
signature this receiver recorded or $p$ in case there is none.

This scheme provides replay protection since the receiver memorizes the last signature they acted on. Public key length
is equal to the length of the hash function $H$ used. Even for our embedded systems use case $n$ can realistically be up
to $\mathcal O\left(10^3\right)$, which is enough for our purposes. This use of a hash chain for event authentication is
identical to the one in the S/KEY one-time password system\cite{anderson04,haller01,rfc1760}.
% 1990ies crypto yeah!

The ``disarm'' message we discussed above for replay protection can be integrated into this scheme by encoding the
``enable'' bit into the least significant bit of $n$ in our $H^n$ construction. In the chain of valid signatures every
second one would be a disarm signature: Reset and disarm signatures would alternate in this scheme. By skipping a disarm
signature two resets can still be triggered directly after one another.

In practice it may be useful to have some control over which meters reset. An attack exploiting a particular network
protocol implementation flaw might only affect one series of meters made by one manufacturer. Resetting \emph{all}
meters may be too much in this case. A simple solution for this is to define addressable subsets of meters.  ``All
meters'' along with ``meters made by manufacturer $x$'' and ``meters of model $y$'' are good choices for such scopes. On
the cryptographic level the protocol state is simply duplicated for each scope. This incurs memory and computation
overhead linear in the number of scopes but device memory requirements are small at a few bytes only and computation is
of no concern due to the very slow channel so this simple solution is adequate. The transmitter has to either store
copies of all scope's keys or derive these keys from a root key using the scope's identifier. Keys are small and the
transmitter would be using a regular server or hardware security module for key management so either easily feasible.

A diagram of the key structure in this key management scheme is shown in Figure \ref{fig:sig_key_chain}. The
transmitter key management is shown in Figure \ref{fig:tx_scope_key_illu}. This scheme is simplistic but suffices for
our prototype in Section \ref{sec-prototype} and may even be useful in a practical implementation. During
standardization of a safety reset system the key management system would most likely have to be customized to the
particular application's requirements. Developing an universal solution is outside the scope of this work.

\begin{figure}
    \centering
    \begin{minipage}[c]{0.5\textwidth}
        \includegraphics{resources/signature_key_chain}
    \end{minipage}
    \begin{minipage}[c]{0.45\textwidth}
        \caption{
            The hash chain between secret transmitter key and public device key. Each step represents one invocation of the
            hash function. To generate a new chain a random transmitter key is generated, then hashed $n$ times to
            generate the corresponding device key. A new trigger message can be generated by generating the key at depth
            $m-1$ where $m$ is the height of the last used trigger, or $n$ initially. Every second trigger message is a
            disarm message and every second one a reset message. Depending on which is needed either one may be skipped.
        }
        \label{fig:sig_key_chain}
    \end{minipage}
\end{figure}

\begin{figure}
    \centering
    \includegraphics[width=\textwidth]{resources/transmitter_scope_key_illustration}
    \caption{
        An illustration of a key management system using a common master key. First, the transmitter derives one secret
        key for each addressable group from the master key. Then public device keys are generated like in Figure
        \ref{fig:sig_key_chain}. Finally for each device the manufacturer picks the group public keys matching the
        device. In this example one device is a series A meter made by manufacturer B so it gets provisioned with the
        keys for the ``all devices'', ``manufacturer B'' and ``series A'' groups. The other device is also made by
        manufacturer B but is a series C device so it gets provisioned with the ``all devices'', ``manufacturer B'' and
        ``series C'' device keys. In this example the transmitter stores (or is able to derive) all six shown
        group keys, but each device only needs to store the three applying to it--one for each of the three scopes ``all
        devices'', ``manufacturer'' and ``series''.
    }
    \label{fig:tx_scope_key_illu}
\end{figure}

\chapter{Practical implementation}

To validate the practical feasibility of the theoretical concepts we laid out in the previous chapter we decided to
build a prototype of a safety reset controller.  In this section we describe the reasoning behind the components of this
prototype and the engineering that went into its firmware. The prototype consists of a smart meter whose application
microcontroller is reset by a microcontroller on an external circuit board. We lay out how we extensively
tested all parts of our firmware implementation. We conclude with results of a practical end-to-end experiment
exercising every part of our prototype.

\section{Data collection for channel validation}

To design a solid system we needed to parametrize mains frequency variations under normal conditions. To set modulation
amplitude as well as parameters of our modulation scheme we need a frequency spectrum of mains frequency variations
(that is $\mathcal F\left(f(V(t))\right)$: Taking mains frequency $f(x)$ as a variable, the frequency spectrum of that
variable, as opposed to the frequency spectrum of mains voltage $V(t)$ itself).

\subsection{Grid frequency estimation}
\label{frequency_estimation}

In commercial power systems Phasor Measurement Units (PMUs, also called \emph{synchrophasors}) are used to precisely
measure parameters of the mains voltage waveform, one of which is grid frequency. PMUs are used as part of SCADA systems
controlling transmission networks to characterize the operational state of the network.

From a superficial viewpoint measuring grid frequency might seem like a simple problem. Take the mains voltage waveform,
measure time between two rising-edge (or falling-edge) zero-crossings and take the inverse $f = t^{-1}$. In practice,
phasor measurement units are significantly more complex than this. This discrepancy is due to the combination of both
high precision and quick response that is demanded from these units. High precision is necessary since variations of
mains frequency under normal operating conditions are quite small--in the range of \SIrange{5}{10}{\milli\hertz} over
short intervals of time. Relative to the nominal \SI{50}{\hertz} this is a derivation of less than \SI{100}{ppm}.
Relative to the corresponding period of \SI{20}{\milli\second} this means a time derivation of about $2 \mu\text{s}$
from cycle to cycle. From this it is already obvious why a simplistic measurement cannot yield the required precision
for manageable averaging times: We would need either an ADC sampling rate in the order of megabits per second or for a
reconstruction through interpolated readings an impractically high ADC resolution.

Detail on the inner workings of commercial phasor measurement units is scarce but given their essential role to SCADA
systems there is a large amount of academic research on such algorithms\cite{narduzzi01,derviskadic01,belega01}. A
popular approach to these systems is to perform a Short-Time Fourier Transform (STFT) on ADC data sampled at high
sampling rate (e.g. \SI{10}{\kilo\hertz}) and then perform analysis on the frequency-domain data to precisely locate the
peak at \SI{50}{\hertz}. A key observation here is that FFT bin size is going to be much larger than required frequency
resolution. This fundamental limitation follows from the Nyquist criterion\cite{shannon01}
and if we had to process an \emph{arbitrary} signal this would severely limit our practical measurement accuracy
\footnote{
    Some software packages providing FFT or STFT primitives such as scipy\cite{virtanen01} allow the user to
    super-sample FFT output by specifying an FFT width larger than input data length, padding the input data with zeros
    on both sides. Note that in line with the Nyquist theorem this \emph{does not} actually provide finer output
    resolution but instead just amounts to an interpolation between output bins. Depending on the downstream analysis
    algorithm it may still be sensible to use this property of the DFT for interpolation, but in general it will be
    computationally expensive compared to other interpolation methods and in any case it will not yield any better
    frequency resolution aside from a potential numerical advantage\cite{gasior02}.
}.
For this reason all approaches to grid frequency estimation are based on a model of the voltage waveform.  Nominally
this waveform is a perfect sine at $f=\SI{50}{\hertz}$. In practice it is a sine at $f\approx\SI{50}{\hertz}$
superimposed with some aperiodic noise (e.g. irregular spikes from inductive loads being energized) as well as harmonic
distortion that is caused by topologically nearby devices with power factor $\cos \theta \neq 1.0$. Under a continuous
fourier transform over a long period the frequency spectrum of a signal distorted like this will be a low noise floor
depending mainly on aperiodic noise on which a comb of harmonics as well as some sub-harmonics of $f \approx
f_\text{nom} = \SI{50}{\hertz}$ is riding. The main peak at $f \approx f_\text{nom}$ will be very strong with the
harmonics being approximately an order of magnitude weaker in energy and the noise floor being at least another order of
magnitude weaker. See Figure \ref{mains_voltage_spectrum} for a measured spectrum.  This domain knowledge about the
expected frequency spectrum of the signal can be employed in a number of interpolation techniques to reconstruct the
precise frequency of the spectrum's main component despite distortions and the comparatively coarse STFT resolution.

Published grid frequency estimation algorithms such as \cite{narduzzi01,derviskadic01} are rather sophisticated and use
a combination of techniques to reduce numerical errors in FFT calculation and peak fitting. Given that we do not need
reference standard-grade accuracy for our application we chose to start with a very basic algorithm instead. We chose to
use a general approach to estimate the precise fundamental frequency of an arbitrary signal that was published by
experimental physicists Gasior and Gonzalez at CERN\cite{gasior01}. This approach assumes a general sinusoidal signal
superimposed with harmonics and broadband noise.  Applicable to a wide spectrum of practical signal analysis tasks it is
a reasonable first-degree approximation of the much more sophisticated estimation algorithms developed specifically for
power systems.  Some algorithms use components such as kalman filters\cite{narduzzi01} that require a physical model.
As a general algorithm \cite{gasior01} does not require this kind of application-specific tuning, eliminating one source
of error.

The Gasior and Gonzalez algorithm\cite{gasior01} passes the windowed input signal through a DFT, then interpolates the
signal's fundamental frequency by fitting a wavelet such as a Gaussian to the largest peak in the DFT results. The bias
parameter of this curve fit is an accurate estimation of the signal's fundamental frequency. This algorithm is similar
to the simpler interpolated DFT algorithm used as a reference in much of the synchrophasor estimation
literature\cite{borkowski01}. The three-term variant of the maximum side lobe decay window often used there is a
Blackman window with parameter $\alpha = \frac{1}{4}$. Analysis has shown\cite{belega01} that the interpolated DFT
algorithm is worse than algorithms involving more complex models under some conditions but that there is \emph{no free
lunch} meaning that more complex perform worse when the input signal deviates from their models.

\subsection{Frequency sensor hardware design}

\label{sec-fsensor}
Our safety reset controller will have to measure mains frequency to later demodulate a reset signal transmitted through
it. Since we have decided to do our own frequency measurement system here we can reüse this frequency measurement setup
as a prototype for the frequency measurement component of the demodulation system we will develop later. Since we do
not plan to do a large-scale field deployment of our measurement setup we can keep the hardware implementation simple by
moving most of the signal processing to a regular computer and concentrating our hardware efforts on raw signal capture.

\begin{figure}
    \begin{center}
        \begin{tikzpicture}[start chain = going below, node distance = 12mm and 50mm, every join/.style = {norm}]
            \tikzset{
                base/.style = {draw, on chain, on grid, align=center, minimum height = 4ex, font=\footnotesize},
                text/.style = {base},
                component/.style = {base, rectangle, text width=40mm},
                coord/.style = {coordinate, on chain, on grid, node distance=6mm and 25mm}
            }
            \node[text centered] (input)                                {Single phase mains input};
            \node[component] (safety)       [below = of input]          {Input protection};
            \node[coord]     (safety-anchor) [below = of safety]        {};
            \node[component] (analog)       [below = of safety-anchor]  {Analog signal processing};
            \node[component] (powersupply)  [left = of analog]          {Power supply};
            \node[component] (adc)          [below = of analog]         {ADC};
            \node[component] (micro)        [below = of adc]            {Microcontroller};
            \node[component] (isol)         [below = of micro]          {Galvanic digital isolation};
            \node[coord]     (isol-left)    [left = 6cm of isol.west]   {};
            \node[coord]     (isol-right)   [right = 1cm of isol.east]  {};
            \node[component] (usb)          [below = of isol]           {USB interface};

            \draw[->] (input.south) -- (safety.north);
            \draw[-]  (safety.south) -- (safety-anchor);
            \draw[->] (safety-anchor) -| (powersupply.north);
            \draw[->] (safety-anchor) -| (analog.north);
            \draw[->] (powersupply.south) |- (adc.west);
            \draw[->] (powersupply.south) |- (micro.west);
            \draw[->] (analog.south) -- (adc.north);
            \draw[->] (adc.south) -- (micro.north);
            \draw[->] (micro.south) -- (isol.north);
            \draw[->] (isol.south) -- (usb.north);

            \draw[dashed] (isol.west) -- (isol-left.east);
            \draw[dashed] (isol.east) -- (isol-right.west);
        \end{tikzpicture}
    \end{center}
    \caption{Frequency sensor hardware block diagram.}
    \label{fmeas-sens-diag}
\end{figure}

An overall block diagram of our system is shown in Figure \ref{fmeas-sens-diag}. The microcontroller we chose is an
\texttt{STM32F030F4P6} ARM Cortex M0 microcontroller made by ST Microelectronics. The ADC in Figure
\ref{fmeas-sens-diag} in our implementation is the integrated 12-bit ADC of this microcontroller, which is sufficient
for our purposes. The USB interface is a simple USB to serial converter IC (\texttt{CH340G}) and the galvanic digital
isolation is accomplished with a pair of high speed optocouplers on its \texttt{RX} and \texttt{TX} lines. The analog
signal processing is a simple voltage divider using high power resistors to get the required creepage along with some
high frequency filter capacitors and an op-amp buffer. The power supply is an off-the-shelf mains-input power module.
The system is implemented on a single two-layer PCB that is housed in an off-the-shelf industrial plastic case fitted
with a printed label and a few status lights on its front. The schematics of our system can be found in Appendix
\ref{sec-app-freq-sens-schematics}.

\subsection{Clock accuracy considerations}

Our measurement hardware will sample line voltage at some sampling rate $f_S$, e.g.\ \SI{1}{\kilo\hertz}. All downstream
processing is limited in accuracy by the accuracy of $f_S$\footnote{
We are not considering the effect of clock jitter. We are highly oversampling the signal and the FFT done in our
downstream processing will average out small jitter effects leaving only frequency stability to worry about.  }. We
generate our sampling clock in hardware by clocking the ADC from one of the microcontroller's timer blocks clocked from
the microcontroller's system clock. This means our ADC's sampling window will be synchronized cycle-accurate to the
microcontroller's system clock.

Our downstream estimation of mains frequency by nature is relative to our sampling frequency $f_S$. In the setup
described above this means we have to make sure our system clock is stable. A frequency deviation of \SI{1}{ppm} in our
system clock causes a proportional grid frequency measurement error of $\Delta f = f_\text{nom} \cdot 10^{-6} =
\SI{50}{\micro\hertz}$. In a worst-case scenario where our system is clocked from a particularly bad crystal that
exhibits \SI{100}{ppm} of instabilities over our measurement period we end up with an error of \SI{5}{\milli\hertz}.
This is well within our target measurement range, so we need a more stable clock source. Ideally we want to avoid
writing our own clock conditioning code where we try to change an oscillators operating frequency to match some
reference. Clock conditioning algorithms are complex\cite{ti01} and in our case post processing of measurement data and
simply adding an offset is simpler and less error-prone.

Our solution to these problems is to use a crystal oven\footnote{
    A crystal oven is a crystal oscillator closely thermally coupled to a heater and temperature sensor and enclosed in
    a thermally isolated case. The heater is controlled to hold the crystal oscillator at a near constant temperature
    some tens of degrees Celsius above ambient temperature. Ambient temperature variations will be absorbed by the
    temperature control.  This yields a crystal frequency that is almost completely unaffected by ambient temperature
    variations below the oven temperature and whose main remaining instability is aging.
}as our main system clock source. Crystal ovens are expensive compared to ordinary crystal oscillators. Since any
crystal oven will be much more accurate than a standard room-temperature crystal we chose to reduce cost by using one
recycled from old telecommunications equipment.

To verify clock accuracy we routed an externally accessible SMA connector to a microcontroller pin that is routed to one
of the microcontroller's timer inputs. By connecting a GPS 1pps signal to this pin and measuring its period we can
calculate our system's Allan variance\footnote{
    Allan variance is a measure of frequency stability between two clocks.
}, thereby measuring both clock stability and clock accuracy.
We ran a 4 hour test of our frequency sensor that generated the histogram shown in Figure \ref{ocxo_freq_stability}.
These results show that while we get a systematic error of about \SI{10}{ppm} due to manufacturing tolerances the
random error at less than \SI{10}{ppb} is smaller than that of a room-temperature crystal oscillator by 3-4 orders of
magnitude. Since we are interested in grid frequency variations over time but not in the absolute value of grid
frequency the systematic error is of no consequence to us.  The random error at \SI{3.66}{ppb} corresponds to a
frequency measurement error of about \SI{0.2}{\micro\hertz}, well below what we can achieve at reasonable sampling rates
and ADC resolution.

\begin{figure}
    \centering
    \includegraphics{../lab-windows/fig_out/ocxo_freq_stability}
    \caption{OCXO Frequency derivation from its nominal \SI{19.440}{\mega\hertz} frequency measured against a GPS
    receiver's 1pps reference output.}
    \label{ocxo_freq_stability}
\end{figure}

\subsection{Firmware implementation}

The firmware uses one of the microcontroller's timers clocked from an external crystal oscillator to produce an
\SI{1}{\milli\second} tick that the internal ADC is triggered from for a sample rate of \SI{1}{\kilo sps}. Higher sample
rates would be possible but reliable data transmission over the opto-isolated serial interface might prove challenging
and \SI{1}{\kilo sps} already corresponds to $20$ samples per cycle at $f_\text{nominal}$. This figure exceeds the
Nyquist criterion by a factor of ten and is plenty for accurate measurements.

The ADC measurements are read using DMA and written into a circular buffer. Using DMA controller features this
circular buffer is split in back and front halves with one being written to and the other being read at the same time.
Buffer contents are moved from the ADC DMA buffer into a packet-based reliable UART interface as they come in. The UART
packet interface keeps two ring buffers: One byte-based ring buffer for transmission data and one ring buffer pointer
structure that keeps track of ADC data packet boundaries in the byte-based ring buffer. Every time a chunk of data is
available from the ADC the data is framed into the byte-based ring buffer and the packet boundaries are logged in the
packet pointer ring buffer. If the UART transmitter is idle at this time a DMA-backed transmission of the oldest packet
in the packet ring buffer is triggered at this point. Data is framed using Consistent Overhead Byte Stuffing
(COBS)\footnote{
COBS is a framing technique that allows encoding $n$ bytes of arbitrary data into exactly $n+1$ bytes with no embedded
$0$ bytes that can then be delimited using $0$ bytes. COBS is simple to implement and allows both one pass decoding and
encoding. The encoder either needs to be able to read up to \SI{256}{\byte} ahead or needs a buffer of \SI{256}{\byte}.
COBS is very robust in that it allows self-synchronization. At any point a receiver can reliably synchronize itself
against a COBS data stream by waiting for the next $0$ byte. The constant overhead allows precise bandwidth and buffer
planning and provides constant, good efficiency close to the theoretical maximum.}\cite{cheshire01} along with a
CRC-32 checksum for error checking. When the host receives a new packet with a valid checksum it returns an
acknowledgement packet to the sensor. When the sensor receives the acknowledgement, the acknowledged packet is dropped
from the transmission packet ring buffer. When the host detects an incorrect checksum it simply stays quiet and waits for
the sensor to resume with retransmission when the next ADC buffer has been received.

The serial interface logic presents most of the complexity of the sensor firmware. This complexity is necessary since
we need reliable, error-checked transmission to the host. Though rare, bit errors on a serial interface do happen and
data corruption is unacceptable. The packet layer queueing on the sensor is necessary since the host is not a realtime
system and unpredictable latency spikes of several hundred milliseconds are possible.

The host in our recording setup is a Raspberry Pi 3 model B running a Python script. The Python script handles serial
communication and logs data and errors into an SQLite database file. SQLite has been chosen for its simple yet flexible
interface and its good tolerance of system resets due to unexpected power loss. Overall our setup performed adequately
with IO contention on the Raspberry PI/Linux side causing only 16 skipped sample packets over a 68 hour recording span.

\subsection{Frequency sensor measurement results}

\begin{figure}
    \centering
    \begin{minipage}[c]{0.48\textwidth}
        \includegraphics{resources/grid_meas_device_front.jpg}
    \end{minipage}
    \begin{minipage}[c]{0.48\textwidth}
        \includegraphics{resources/grid_meas_device_open.jpg}
    \end{minipage}
    \vspace*{3mm}
    \caption{
        The finished grid frequency sensor device. The large yellow part on the bottom left is the crystal oven. The
        large black part is the power supply module. The microcontroller is on the bottom right of the device and the
        measurement circuit is in its middle. The device connects to the data recording computer via galvanically
        isolated USB on the bottom and to a regular wall socket through the IEC connector on the top of the device.
    }
    \label{pic_freq_sensor}
\end{figure}

Our completed frequency sensor can be seen in Figure \ref{pic_freq_sensor}.  The raw voltage waveform data we captured
with it has been processed in the Jupyter Lab environment\cite{kluyver01} and grid frequency estimates are extracted as
described in Section \ref{frequency_estimation} using the Gasior and Gonzalez\cite{gasior01} technique.  The Jupyter
notebook we used for frequency measurement is included with the supplementary materials to this thesis. In Figure
\ref{freq_meas_feedback} we fed back to the frequency estimator its own output giving us an indication of its numerical
performance. The result was \SI{1.3}{\milli\hertz} of RMS noise over a \SI{3600}{\second} simulation time. This
indicates performance is good enough for our purposes. In addition to this we validated our algorithm's performance by
applying it to the test waveforms from \cite{wright01}. In this test we got errors of \SI{4.4}{\milli\hertz} for the
\emph{noise} test waveform, \SI{0.027}{\milli\hertz} for the \emph{interharmonics} test waveform and
\SI{46}{\milli\hertz} for the \emph{amplitude and phase step} test waveform. Full results can be found in Figure
\ref{freq_meas_rocof_reference}.

Figures \ref{freq_meas_trace} and \ref{freq_meas_trace_mag} show our measurement results over a 24-hour and a 2-hour
window respectively.

\begin{figure}
    \centering
    \includegraphics[width=\textwidth]{../lab-windows/fig_out/freq_meas_feedback}
    \caption{
        The frequency estimation algorithm applied to a synthetic noise-less mains waveform generated from its own
        output. This feedback simulation gives an indication of numerical errors in our estimation algorithm. The top
        four graphs show a comparison of the original trace (blue) and the re-calculated trace (orange). The bottom
        trace shows the difference between the two. As we can tell both traces agree very well with an overall RMS
        deviation of about \SI{1.3}{\milli\hertz}. The bottom trace shows deviation growing over time. This is an effect
        of numerical errors in our ad hoc waveform generator.
    }
    \label{freq_meas_feedback}
\end{figure}

\begin{figure}
    \centering
    \includegraphics[width=\textwidth]{../lab-windows/fig_out/freq_meas_rocof_reference}
    \caption{
        Performance of our frequency estimation algorithm under the test suite specified in \cite{wright01}. Shown are
        standard deviation and variance measurements as well as time-domain traces of absolute differences.
    }
    \label{freq_meas_rocof_reference}
\end{figure}

\begin{figure}
    \centering
    \includegraphics[width=\textwidth]{../lab-windows/fig_out/freq_meas_trace_24h}
    \caption{Trace of grid frequency over a 24 hour time span. One clearly visible feature are large positive and negative
    transients at full hours. Times shown are UTC. Note that the European continental synchronous area that this
    sensor is placed in covers several time zones which may result in images of daily load peaks appearing in 1 hour
    intervals. Figure \ref{freq_meas_trace_mag} contains two magnified intervals from this plot.}
    \label{freq_meas_trace}
\end{figure}

\begin{figure}
    \begin{subfigure}{\textwidth}
        \centering
        \includegraphics[width=\textwidth]{../lab-windows/fig_out/freq_meas_trace_2h_1}
        \caption{A 2 hour window centered on 00:00 UTC.}
    \end{subfigure}
    \begin{subfigure}{\textwidth}
        \centering
        \includegraphics[width=\textwidth]{../lab-windows/fig_out/freq_meas_trace_2h_2}
        \caption{A 2 hour window centered on 18:30 UTC.}
    \end{subfigure}
    \caption{Two magnified 2 hour windows of the trace from Figure \ref{freq_meas_trace}.}
    \label{freq_meas_trace_mag}
\end{figure}

\begin{figure}
    \centering
    \includegraphics[width=\textwidth]{../lab-windows/fig_out/mains_voltage_spectrum}
    \caption{Power spectral density of the mains voltage trace in Figure \ref{freq_meas_trace}.  Data was captured using
    our frequency measurement sensor (\ref{sec-fsensor}) and FFT-processed after applying a Blackman window. The
    vertical lines indicate \SI{50}{\hertz} and odd harmonics.  We can see the expected peak at \SI{50}{\hertz} along
    with smaller peaks at odd harmonics. We can also see a number of spurious tones both between harmonics and at low
    frequencies. We can also see bands containing high noise energy around \SI{0.1}{\hertz}. This graph shows a high
    signal-to-noise ratio that is not very demanding on our frequency estimation algorithm.
    }
    \label{mains_voltage_spectrum}
\end{figure}

\section{Channel simulation and parameter validation}
\label{sec-ch-sim}

To validate all layers of our communication stack from modulation scheme to cryptography we built a prototype
implementation in Python. Implementing all components in a high level language builds up familiarity with the concepts
while taking away much of the implementation complexity. For our demonstrator we will not be able to use Python since
our target platform is an inexpensive low-end microcontroller. Our demonstrator firmware will have to be written in a
low-level language such as C or Rust. For prototyping these languages lack flexibility compared to Python.

To validate our modulation scheme we first performed a series of simulations on our Python demodulator prototype
implementation. To simulate a modulated grid frequency signal we added noise to a synthetic modulation signal. For most
simulations we used measured frequency data gathered with our frequency sensor. We only have a limited amount of capture
data. Re-using segments of this data as background noise in multiple simulation runs could lead to our simulation
results depending on individual features of this particular capture that would be common between all runs. To estimate
the impact of this problem we re-ran some of our simulations with artificial random noise synthesized with a power
spectral density matching that of our capture. To do this, we first measured our capture's PSD, then fitted a
low-resolution spline to the PSD curve in log-log coördinates. We then generated white noise, multiplied the resampled
spline with the DFT of the synthetic noise and performed an iDFT on the result. The resulting time-domain signal is our
synthetic grid frequency data. Figure \ref{freq_meas_spectrum} shows the PSD of our measured grid frequency signal. The
red line indicates the low-resolution log-log spline interpolation used for shaping our artificial noise. Figure
\ref{simulated_noise_spectrum} shows the PSD of our simulated signal overlaid with the same spline as a red line and
shows time-domain traces of both simulated (blue) and reference signals (orange) at various time scales. Visually both
signals look very similar, suggesting that we have found a good synthetic approximation of our measurements.

\begin{figure}
    \centering
    \hspace*{-1.2cm}\includegraphics[width=1.2\textwidth]{../lab-windows/fig_out/freq_meas_spectrum}
    \caption{Power spectral density of the 24 hour grid frequency trace in Figure \ref{freq_meas_trace} with some notable
    peaks annotated with the corresponding period in seconds. The $\frac{1}{f}$ line indicates a pink noise spectrum.
    Around a period of \SI{20}{\second} the PSD starts to fall off at about $\frac{1}{f^3}$ until we can make out some
    bumps at periods around $2$ and \SI{3}{\second}.  Starting at at around \SI{1}{Hz} we can see a white noise floor in
    the order of \si{\micro\hertz^2\per\hertz}.
    % TODO: where does this noise floor come from? Is it a fundamental property of the grid? Is it due to limitations of
    % our measurement setup (such as ocxo stability/phase noise) ???
    }
    \label{freq_meas_spectrum}
\end{figure}

\begin{figure}
    \centering
    \hspace*{-1.2cm}
    \includegraphics[width=1.2\textwidth]{../lab-windows/fig_out/simulated_noise_spectrum}
    \caption{Synthetic grid frequency in comparison with measured data. The topmost graph shows the synthetic spectrum
    compared to the spline approximation of the measured spectrum (red line). The other graphs show time-domain
    synthetic data (blue) in comparison with measured data (orange).
    }
    \label{simulated_noise_spectrum}
\end{figure}

In our simulations, we manipulated four main variables of our modulation scheme and demodulation algorithm and observed
their impact on symbol error rate (SER):

\begin{description}
    \item[Modulation amplitude.] Higher amplitude corresponds to a lower SER.
    \item[Modulation bit count.] Higher bit count $n$ means longer transmissions but yields higher theoretical decoding
        gain, and should increase demodulator sensitivity. Ultimately, we want to find a sweet spot of manageable
        transmission length at good demodulator sensitivity.
    \item[Decimation or DSSS chip duration.] The chip time determines where in the grid frequency spectrum (Figure
        \ref{freq_meas_spectrum}) our modulated signal is located. Given our noise spectrum (Figure
        \ref{freq_meas_spectrum}) lower chip durations (shifting our signal upwards in the spectrum) should yield lower
        in-band background noise which should correspond to lower symbol error rates.
    \item[Demodulation correlator peak threshold factor.] The first step of our prototype demodulation algorithm is to
        calculate the correlation between all $2^n+1$ Gold sequences and our signal and to identify peaks corresponding
        to the input data containing a correctly aligned Gold sequence. The threshold factor determines peaks of which
        magnitude compared to baseline noise levels are considered in the following maximum likelihood estimation (MLE)
        decoding (cf.\ Figure \ref{fig_demo_sig_schema}).
\end{description}

Our results indicate that symbol error rate is a good proxy of demodulation performance. With decreasing signal-to-noise
ratio, margins in various parts of the demodulator decrease which statistically leads to an increased symbol error rate.
Our simulations yield smooth, reproducible SER curves with adequately low error bounds. This shows SER is related
monotonically to the signal-to-noise margins inside our demodulator prototype.

\subsection{Sensitivity as a function of sequence length}

A basic parameter of our DSSS modulation is the length of the Gold codes used. The length of a Gold code is exponential
in the code's bit count.  Figure \ref{dsss_gold_nbits_overview} shows a plot of the symbol error rate of our demodulator
prototype depending on amplitude for each of five, six, seven and eight bit Gold sequences. In regions where symbol
error rate is neither clipping at $0$ nor at $1$ we can see the expected dependency that a $n+1$ bit Gold sequence at
roughly twice the length yields roughly one half the SER. We can also observe a saturation effect: At low amplitudes,
increasing the correlation length does not yield much benefit in SER anymore. In particular at a signal amplitude of
\SI{2.5}{\milli\hertz} even with asymptotically infinite sequence length our demodulator would still not be able to
produce a good demodulation. This is likely due to numerical errors in our demodulator. Since Gold codes of more than 7
bit would yield unacceptably long transmission times this does not pose a problem in practice.

Figure \ref{dsss_gold_nbits_sensitivity} for each bit count shows the minimum signal amplitude at which our demodulator
crossed below $\text{SER}=0.5$. If we have sufficient transmitter power to allocate selecting either a 5 bit or a 6 bit
Gold code yields sufficient performance at manageable data rates.

\begin{figure}
    \centering
    \includegraphics[width=0.6\textwidth]{../lab-windows/fig_out/dsss_gold_nbits_overview}
    \caption{
        Symbol Error Rate (SER) as a function of transmission amplitude. The line represents the mean of several
        measurements for each parameter set. The shaded areas indicate one standard deviation from the mean. Background
        noise for each trial is a random segment of measured grid frequency. Background noise amplitude is the same for
        all trials. Shown are four traces for four different DSSS sequence lengths. Using a 5-bit gold code, one DSSS
        symbol measures 31 chips. 6 bit per symbol are 63 chips, 7 bit are 127 chips and 8 bit 255 chips. This
        simulation uses a decimation of 10, which corresponds to an $1 \text{s}$ chip length at our $10 \text{Hz}$ grid
        frequency sampling rate. At 5 bit per symbol, one symbol takes $31 \text{s}$ and one bit takes $6.2 \text{s}$
        amortized. At 8 bit one symbol takes $255 \text{s} = 4 \text{min} 15 \text{s}$ and one bit takes $31.9 \text{s}$
        amortized. Here, slower transmission speed buys coding gain. All else being equal this allows for a decrease
        in transmission power.
    }
    \label{dsss_gold_nbits_overview}
\end{figure}

\begin{figure}
    \centering
    \begin{minipage}[c]{0.5\textwidth}
        \hspace*{-1cm}\includegraphics[width=1.1\textwidth]{../lab-windows/fig_out/dsss_gold_nbits_sensitivity}
    \end{minipage}\begin{minipage}[c]{0.45\textwidth}
        \caption{
            Amplitude at an SER of 0.5\ in mHz depending on symbol length. Here we can observe an increase of sensitivity
            with increasing symbol length, but we can clearly see diminishing returns above 6 bit (63 chips). Considering
            that each bit roughly doubles overall transmission time for a given data length it seems lower bit counts are
            preferrable if the required transmitter power can be realized.
        }
        \label{dsss_gold_nbits_sensitivity}
    \end{minipage}
\end{figure}

\subsection{Sensitivity versus peak detection threshold factor}

One of the high level parameters of our demodulation algorithm is the \emph{threshold factor}. This parameter is
an implementation detail specific to our algorithm and not general to all possible DSSS demodulation algorithms. After
correlating the input signal against the template Gold sequences our algorithm runs a single channel discrete wavelet
transform (DWT) on the correlator output to better discriminate peaks from background noise. The output of this DWT is
then normalized against a running average and then fed into a simple threshold detector. The threshold of this detector
is our threshold factor. This threshold is the ratio that a correlation peak after DWT has to stand out from long-term
average background noise to be considered a peak.

The threshold factor is an empirically determined unitless parameter. Low threshold factors yield many false positives
that in the extreme ultimately overload our MLE estimator's capacity to discard them. Moderate numbers of false
positives do not pose much of a challenge to our MLE since these spurious peaks have a random time distribution and are
easily discarded by our MLE's detection of sequences of equally-spaced symbols.  High threshold factors lead the
algorithm to completely ignore some valid peaks. To some degree this can be compensated by our later interpolation step
for missing peaks but in the extreme will also break demodulation. In our simulations good values lie in the range from
$4.0$ to $5.5$.

Figure \ref{dsss_thf_amplitude_5678} contains plots of demodulator sensitivity like the one in Figure
\ref{dsss_gold_nbits_overview}. This time there is one color-coded trace for each threshold factor between $1.5$ and
$10.0$ in steps of $0.5$. We can see a clear dependency of demodulation performance from threshold factor with both very
low and very high values breaking the demodulator. The runaway traces that we can see at low threshold factors are
artifacts of an implementation issue with our prototype code. We later fixed this issue in the demonstrator firmware
in Section \ref{sec-demo-fw-impl}. For comparison purposes this issue do not matter.

\begin{figure}
    \centering
    \hspace*{-1cm}\includegraphics[width=1.2\textwidth]{../lab-windows/fig_out/dsss_thf_amplitude_5678}
    \caption{
        SER vs.\ amplitude graph similar to Figure \ref{dsss_gold_nbits_overview} with one color-coded traces for
        threshold factors between $1.5$ and $10.0$.  Each graph shows traces for a single DSSS symbol length.
    }
    \label{dsss_thf_amplitude_5678}
\end{figure}

If we again look at the intercept points where the amplitude traces cross $\text{SER}=0.5$ in these graphs we get the
plots in Figure \ref{dsss_thf_sensitivity_all_bits}. From this we can conclude that the range between $4.0$ and $5.0$ will
yield adequate threshold factors for our use case.

\begin{figure}
    \centering
    \hspace*{-1cm}\includegraphics[width=1.1\textwidth]{../lab-windows/fig_out/dsss_thf_sensitivity_5678}
    \caption{
        Graphs of amplitude at $SER=0.5$ for each symbol length as well as asymptotic SER for large amplitudes.  Areas
        shaded red indicate that $SER=0.5$ was not reached for any amplitude in the simulated range. The bumps in the 7
        bit and 8 bit graphs are due to the convergence problem we identified above and do not exist in our demonstrator
        implementation. We see that smaller symbol lengths favor lower threshold factors, and that optimal threshold
        factors for all symbol lengths are between $4.0$ and $5.0$.
    }
    \label{dsss_thf_sensitivity_all_bits}
\end{figure}

\subsection{Chip duration and bandwidth}

A parameter of any DSSS system is the frequency band used for transmission. Instead of specifying absolute frequencies
in our simulations we expressed DSSS bandwidth through chip duration and Gold sequence length. In our prototype, chip
duration is specified in grid frequency sampling periods to ease implementation without loss of generalization.

Figure \ref{chip_duration_sensitivity} shows the dependence of symbol error rate at a fixed good threshold factor from
chip duration. The color bars indicate both chip duration translated to seconds real-time and the resulting symbol
duration at the given Gold code length. In the lower graphs we show the trace of amplitude at $\text{SER}=0.5$ over chip
duration like we did in Figure \ref{dsss_thf_sensitivity_all_bits} for threshold factor. In both graphs we can see a
faint optimum for very short chips with a decrease of sensitivity for long chips. This effect is due to longer chips
moving the signal band into noisier spectral regions (cf.\ Figure \ref{freq_meas_spectrum}).

\begin{FPfigure}
    \begin{subfigure}{\textwidth}
        \centering
        \hspace*{-1cm}\includegraphics[width=1.2\textwidth]{../lab-windows/fig_out/chip_duration_sensitivity_5}
        \vspace*{-1cm}
        \label{chip_duration_sensitivity_5}
        \caption{
        5 bit Gold code.
        }
    \end{subfigure}
%\end{figure}
%\begin{figure}
%    \ContinuedFloat
    \begin{subfigure}{\textwidth}
        \centering
        \hspace*{-1cm}\includegraphics[width=1.2\textwidth]{../lab-windows/fig_out/chip_duration_sensitivity_6}
        \vspace*{-1cm}
        \label{chip_duration_sensitivity_6}
        \caption{
        6 bit Gold code.
        }
    \end{subfigure}
    \caption{
        Dependence of demodulator sensitivity on DSSS chip duration. Due to computational constraints this simulation is
        limited to 5 bit and 6 bit DSSS sequences. There is a clearly visible sensitivity maximum at short chip
        lengths around $0.2 \text{s}$. Short chip durations shift the entire transmission band up in frequency. In
        Figure \ref{freq_meas_spectrum} we can see that noise energy is mostly concentrated at lower frequencies, so
        shifting our signal up in frequency will reduce the amount of noise the decoder sees behind the correlator by
        shifting the band of interest into a lower-noise spectral region. For a practical implementation chip duration
        is limited by physical factors such as the maximum modulation slew rate ($\frac{\text{d}P}{\text{d}t}$) that can
        be technically realized and the maximum Rate-Of-Change-Of-Frequency (ROCOF, $\frac{\text{d}f}{\text{d}t}$) that
        the grid can tolerate.
    }
    \label{chip_duration_sensitivity}
\end{FPfigure}

In the previous graphs we have used random clips of measured grid frequency noise as noise in our simulations. Comparing
between a simulation using measured noise and synthetic noise generated as we outlined in the beginning of Section
\ref{sec-ch-sim} we get the plots in Figure \ref{chip_duration_sensitivity_cmp}. We can see that while not perfect our
simulated noise is an adequate approximation of reality: Our prototype demodulator shows no significant difference in
behavior between measured and simulated noise. Simulated noise causes slightly worse performance for long chips. Overall
the results for both are very close in absolute value.

\begin{FPfigure}
    \begin{subfigure}{\textwidth}
        \centering
        \hspace*{-1cm}\includegraphics[width=1.2\textwidth]{../lab-windows/fig_out/chip_duration_sensitivity_cmp_meas_6}
        \vspace*{-1cm}
        \label{chip_duration_sensitivity_cmp_meas_6}
        \caption{
            Simulation using baseline frequency data from actual measurements.
        }
    \end{subfigure}
%\end{figure}
%\begin{figure}
%    \ContinuedFloat
    \begin{subfigure}{\textwidth}
        \centering
        \hspace*{-1cm}\includegraphics[width=1.2\textwidth]{../lab-windows/fig_out/chip_duration_sensitivity_cmp_synth_6}
        \vspace*{-1cm}
        \label{chip_duration_sensitivity_cmp_synth_6}
        \caption{
            Simulation using synthetic frequency data.
        }
    \end{subfigure}
    \caption{
        Chip duration/sensitivity simulation results like in Figure \ref{chip_duration_sensitivity} compared between a
        simulation using measured frequency data like in the previous graphs and one using artificially generated noise.
        There is little visible difference indicating that we have found a good model of reality in our noise
        synthesizer, but also that real grid frequency behaves like a frequency-shaped Gaussian noise process.
    }
    \label{chip_duration_sensitivity_cmp}
\end{FPfigure}

\section{Implementation of a demonstrator unit} 
\label{sec-prototype}

To demonstrate the viability of our reset architecture we decided to implement a demonstrator system. In this
demonstrator we use JTAG to reset part of a commodity smart meter from an externally-connected reset controller. The
reset controller receives its commands over the grid frequency modulation system we outlined in this thesis. To keep
implementation cost low the reset controller is fed a simulation of a modulated grid frequency signal through a standard
\SI{3.5}{\milli\meter} audio jack\footnote{
    By generously cutting two PCB traces the meter we chose to use can be easily modified to provide galvanic separation
    between grid and main application microcontroller. With this modification we have to supply power to its main
    application MCU externally along with the JTAG interface but now the modified meter is electrically safe.
}. Measurement of actual grid frequency instead would simply require a voltage divider and depending on the setup an
analog optoisolator.

\subsection{Selecting a smart meter for demonstration purposes}
\label{sec-easymeter}

\begin{figure}[h!]
    \centering
    \begin{subfigure}{\textwidth}
        \centering
        \includegraphics[width=0.6\textwidth]{resources/easymeter_board_composite.jpg}
        \label{easymeter_display_board_composite}
        \caption{
            \footnotesize
            Optical composite image of the display and data logging board in the top of the case. The six pins at the
            top are the SPI chip-on-glass segment LCD. Of the eight pads on the left six are unused and two carry the
            auxiliary power supply from the measurement board below. The bottom right section contains the
            \si{\kilo\watt\hour} impulse LED and the angled IR communication LED. The flying wires
            connect to the 14-pin JTAG and serial debug header.
        }
    \end{subfigure}
    \begin{subfigure}{\textwidth}
        \vspace{1cm}
        \centering
        \includegraphics[width=0.8\textwidth]{resources/easymeter_baseboard_composite.jpg}
        \label{easymeter_measurement_board_composite}
        \caption{
            \footnotesize
            Composite microfocus x-ray image of the potted measurement module in the bottom of the case. The ovals on
            the top left and right are power supply and data jumper connections for external modules such as SMGW
            interfaces. The bright parts at the bottom are the massive screw terminals with integrated current shunts.
            The circuitry right of the three independent measurement channels is the power supply circuit for the
            display board.
        }
    \end{subfigure}

    \caption{
        Composite images of the circuit boards inside the EasyMeter Q3DA1002 smart electricity meter used in our
        demonstration.
    }
    \label{easymeter_composites}
\end{figure}

\begin{figure}[h!]
    \centering
    \begin{subfigure}{0.45\textwidth}
        \centering
        \includegraphics[width=\textwidth]{resources/easymeter_baseboard_channel.jpg}
        \label{easymeter_channel_xray}
        \caption{Microfocus x-ray of one channel's data acquisition circuit.}
    \end{subfigure}\hspace*{5mm}
    \begin{subfigure}{0.45\textwidth}
        \centering
        \includegraphics[width=\textwidth]{resources/easymeter_baseboard_powersupply.jpg}
        \label{easymeter_powersupply_xray}
        \caption{Microfocus x-ray of the auxiliary power supply.}
    \end{subfigure}

    \caption{
        Microfocus x-rays of major sections of the EasyMeter Q3DA1002 measurement board.
    }
    \label{easymeter_detail_xrays}
\end{figure}

For our demonstrator to make sense we wanted to select a realistic reset target. In Germany where this thesis was
written a standards-compliant setup would consist of a comparatively feature-limited smart meter and a smart meter
gateway (SMGW) containing all of the complex bidirectional protocol logic such as wireless or landline IP connectivity.
The realistic target for a setup in this architecture would be the components of an SMGW such as its communication modem
or main application processor. In the German architecture the smart meter does not even have to have a bi-directional
data link to the SMGW effectively mitigating any attack vector for remote compromise.

Despite these considerations we still chose to reset the application MCU inside smart meter for two reasons. One is that
SMGWs are much rarer on the second-hand market. The other is that SMGWs are a particular feature of the German
standardization landscape and in many other countries functions of an SMGW such as wireless protocol handling are
integrated into the meter itself (see e.g.\ \cite{honeywell01}).

In the end we settled on a Q3DA1002 three phase 60A meter made by German manufacturer EasyMeter. This meter is typical
of what would be found in an average German household and can be acquired very inexpensively as new old stock on online
marketplaces.

The meter consists of a plastic enclosure with a transparent polycarbonate top part and a gray ABS bottom part that are
ultrasonically welded together. In the bottom part of the case a PCB we call the \emph{measurement} board is potted in
epoxide resin (see Figure \ref{easymeter_composites}). This PCB contains three separate energy measurement ASICs for the
three phases (see Figure \ref{easymeter_detail_xrays}). It also contains a capacitive dropper power supply for the meter
circuitry and external modules such as a SMGW.  The measurement board through three infrared links (one per phase)
communicates with a smaller unpotted PCB we call the \emph{display} board in the top of the case. This PCB handles
measurement logging and aggregation, controls a small segment LCD displaying totals and handles the externally
accessible \si{\kilo\watt\hour} impulse LED and serial IR links.

The measurement board does not contain any logging or outside communication interfaces. All of that is handled on the
display board by a Texas Instruments \texttt{MSP430F2350} application MCU. This is a 16-bit RISC MCU with
\SI{16}{\kilo\byte} flash and \SI{2}{\kilo\byte} SRAM\footnote{
    At first glance the microcontroller might seem overkill for such a simple application, but most of its
    \SI{16}{\kilo\byte} program flash is in fact used. A casual glance with Ghidra shows that a large part of program
    flash is expended on keeping multiple redundant copies of energy consumption aggregates including error recovery in
    case of data corruption and some effort has even been made to guard against data corruption using simple
    non-cryptographic checksums. Another large part of the MCU's firmware handles data transmission over the meter's
    externally accessible IR link through Smart Message Language\cite{bsi-tr-03109-1-IVb}.
}. There is an I2C EEPROM that is used in conjunction with the microcontroller's internal \SI{256}{\byte} data flash to
keep redundant copies of energy consumption aggregates. On the side of the display board there is a 14-pin header
containing both a standard TI MSP430 JTAG pinout and a UART serial interface for debugging. Conveniently, the JTAG port
was left enabled by fuse in our particular production unit.

We chose to use this \texttt{MSP430} series application MCU as our reset target. Though in this particular unit remote
compromise is impossible due to a lack of bidirectional communication links some of its sister models do contain
bidirectional communication links\cite{easymeter01} making compromise through communication interfaces an at least
theoretical possibility. In other countries, meters with a similar architecture to the Q3DA1002 include complex protocol
logic as part of the meter itself or have bidirectional links to it\cite{honeywell01,ifixit01,bigclive01,eevblog01}. As
an example, the Honeywell REX2 uses a Maxim Integrated \texttt{71M6541} main application microcontroller along with a
Texas Instruments \texttt{CC1000} series radio transceiver and is advertised to support both over-the-air firmware
upgrade and a remotely accessible disconnect switch.

\subsection{Firmware implementation}
\label{sec-demo-fw-impl}

We based our safety reset demonstrator firmware on the grid frequency sensor firmware we developed in Section
\ref{sec-fsensor}. We implemented DSSS demodulation by translating the Python prototype code we developed in Section
\ref{sec-ch-sim} to embedded C code. After validating the C translation in extensive simulations we integrated our code
with a Reed-Solomon implementation and a libsodium-based implementation of the cryptographic protocol we designed in
Section \ref{sec-crypto}.  To reprogram the target \texttt{MSP430} microcontroller we ported the low-level bitbang JTAG
driver of \texttt{mspdebug}\footnote{\url{https://github.com/dlbeer/mspdebug}}. See Figure \ref{fig_demo_sig_schema} for
a schematic overview of signal processing in our demonstrator.

For all computation-heavy high level modules of our firmware such as the DSSS demodulator or the grid frequency
estimator we wrote test fixtures that allow the same code that runs on the microcontroller to be executed on the host
for testing. These test fixtures are very simple C programs that load input data from a file or the command line, run
the algorithm and print results on standard output. To enable automatic testing of a large parameter set we run these
test fixtures repeatedly from a set of Python scripts sweeping parameters.

\begin{figure}
    \centering
    \includegraphics[width=\textwidth]{resources/prototype_schema}
    \caption{The signal processing chain of our demonstrator.}
    \label{fig_demo_sig_schema}
\end{figure}

\section{Grid frequency modulation emulation}

To emulate a modulated grid frequency signal we superimposed a DSSS-modulated signal at the proper amplitude with
synthetic grid frequency noise generated according to the measurements we took in Section \ref{sec-fsensor}. In this
primitive simulation we do not simulate the precise impulse response of the grid to a DSSS-modulated stimulus signal.
Our results still serve to illustrate the possibility of data transmission in this manner this impulse response can be
compensated for at the transmitter by selecting appropriate modulation parameters (e.g. chip rate and amplitude) and at
the receiver by equalization with a matched filter.

\section{Experimental results}

\begin{figure}
    \centering
    \includegraphics[width=0.6\textwidth]{resources/prototype.jpg}
    \caption{The completed prototype setup. The board on the left is the safety reset microcontroller. It is connected
    to the smart meter in the middle through an adapter board. The top left contains a USB hub with debug interfaces to
    the reset microcontroller. The cables on the bottom left are the debug USB cable and the \SI{3.5}{\milli\meter}
    audio cable for the simulated mains voltage input.}
    \label{fig_proto_pic}
\end{figure}

After extensive simulations and testing of the individual modules of our solution we proceeded to conduct a real-world
experiment. We tried the demonstrator setup in Figure \ref{fig_proto_pic} using an emulated noisy DSSS signal in
real-time. Our experiment went without any issues and the firmware implementation correctly reset the demonstrator's
meter. We were happy to see that our extensive testing paid off: The demonstrator setup worked on its first try.

\section{Lessons learned}

Before settling on the commercial smart meter we first tried to use an \texttt{EVM430-F6779} smart meter evaluation kit
made by Texas Instruments. This evaluation kit did not turn out well for two main reasons. One, it shipped with half the
case missing and no cover for the terminal blocks. Because of this some work was required to get it electrically safe.
Even after mounting it in an electrically safe manner the safety reset controller prototype would also have to be
galvanically isolated to not pose an electrical safety risk since the main MCU is not isolated from the grid and the
JTAG port is also galvanically coupled. The second issue we ran into was that the \texttt{EVM430-F6779} is based around
an \texttt{MSP430F6779} microcontroller. This microcontroller is a rather large part within the \texttt{MSP430} series
and uses a new revision of the CPU core and associated JTAG peripheral that are incompatible with all \texttt{MSP430}
programmers we tried to use on it. \texttt{mspdebug} does not have support for it and porting TI's own JTAG programmer
reference sources did not yield any results either. Finally we tried an USB-based programmer made by TI themselves that
turned out to either have broken firmware or a hardware defect, leading to it frequently reënumerating on the USB.

Overall our initial assumption that a development kit would certainly be easier to program than a commercial meter did
not prove to be true. Contrary to our expectations the commercial meter had JTAG enabled allowing us to easily read out
its stock firmware without needing to reverse-engineer vendor firmware update files or circumventing code protection
measures. The fact that its firmware was only available in its compiled binary form was not much of a hindrance as it
proved not to be too complex and all we wanted to know could be found out with just a few hours of digging in Ghidra.

In the firmware development phase our approach of testing every module individually (e.g. DSSS demodulator, Reed-Solomon
decoder, grid frequency estimation) proved to be very useful. In particular debugging benefited greatly from being able
to run several thousand tests within seconds. In case of our DSSS demodulator this modular testing and simulation
architecture allowed us to simulate thousands of runs of our implementation on test data and directly compare it to our
Jupyter/Python prototype (see Figure \ref{fw_proto_comparison}). Since we spent more time polishing our embedded C
implementation it turned out to perform better than our Python prototype. At the same time it shows fundamentally
similar response to its parameters.  One significant bug we fixed in the embedded C version was the Python version's
tendency towards incorrect decodings at even very large amplitudes.

\begin{figure}
    \centering
    \begin{subfigure}{\textwidth}
        \centering
        \hspace*{-1cm}
        \includegraphics[trim={0 4cm 0 0},clip,width=1.2\textwidth]{../lab-windows/fig_out/dsss_thf_amplitude_56_jupyter_impl}
        \caption{Python prototype.}
    \end{subfigure}
    \begin{subfigure}{\textwidth}
        \centering
        \hspace*{-1cm}
        \includegraphics[trim={0 4cm 0 0},clip,width=1.2\textwidth]{../lab-windows/fig_out/dsss_thf_amplitude_56_fw_impl}
        \caption{Embedded C implementation.}
    \end{subfigure}

    \caption{
        Symbol error rate plots versus threshold factor for both our Python prototype (above) and our firmware
        implementation of our demodulation algorithm. Note the slightly different threshold factor color scales. Cf.\
        Figure \ref{dsss_thf_amplitude_5678}.
    }
    \label{fw_proto_comparison}
\end{figure}

In accordance with our initial estimations we did not run into any code space nor computation bottlenecks for chosing
floating point emulation instead of porting over our algorithms to fixed point calculations. The extremely slow sampling
rate of our systems makes even heavyweight processing such as FFT or our brute-force dynamic programming approach to
DSSS demodulation possible well within our performance constraints.

Since we are only building a prototype we did not optimize firmware code size at all.  The compiled code size of our
firmware implementation is slightly larger than we would like at around \SI{64}{\kilo\byte} for our firmware image
including everything except the target microcontroller firmware image. See appendix \ref{symbol_size_chart} for a graph
illustrating the contribution of various parts of the signal processing toolchain to this total. Overall the most
heavy-weight operations by far are the SHA512 implementation from libsodium and the FFT from ARM's CMSIS signal
processing library. Especially the SHA512 implementation has large potential for size optimization because it is highly
optimized for speed using extensive manual loop unrolling.

\chapter{Future work}

\section{Precise grid characterization}

We based our simulations on a linear relationship between the generation/consumption power imbalance and grid frequency.
Our literature study suggests that this is an appropriate first order approximation\cite{crastan03}.  We kept the
modulation bandwidth in our simulations inside a \SIrange{1000}{100}{\milli\hertz} frequency band that we reason is most
likely to exhibit this linear behavior in practice. At lower frequencies primary control kicks in. With the frequency
delta thresholds specified for primary control systems\cite{entsoe04} this would lead to significant non-linear
effects.  At higher frequencies grid frequency estimation at the receiver becomes more complex.  Higher frequencies also
come close to modes of mechanical oscillation in generators (usually at \SI{5}{\hertz} and above\cite{crastan03}).

An analysis of the above concerns can be performed using dynamic grid simulation models\cite{semerow01,entsoe05}.
Presumably out of security concerns these models are only available under non-disclosure agreements. Integrating
NDA-encumbered results stemming from such a model in an open-source publication such as this one poses a logistical
challenge which is why we decided to leave this topic for a separate future work.

After detailed model simulation we ultimately aim to validate our results experimentally. Assuming linear grid behavior
even under very small disturbances a small-scale experiment is an option. Such a small-scale experiment would require
very long integration times.  Given a frequency characteristic of \SI{30}{\giga\watt\per\hertz} a stimulus of
\SI{10}{\kilo\watt} yields $\Delta f = \SI{0.33}{\micro\hertz}$. At an estimated \SI{20}{\milli\hertz} of RMS noise over
a bandwidth of interest this results in an SNR slightly better than \SI{-50}{\decibel}. The correlation time necessary
to offset this with DSSS processing gain at a chip rate of \SI{1}{\baud} would be in the order of days. With such long
correlation times clock stability starts to become a problem as during correlation transmitter and receiver must
maintain close phase alignment with respect to one chip period. A phase difference requirement of less than
\SI{10}{\degree}over this period of time would translate into clock stability better than \SI{10}{ppm}. Though certainly
not impossible to achieve this does pose an engineering challenge.

A way to reduce clock alignment might be to use grid frequency itself as a reference. Instead of keying the DSSS
modulator/demodulator on a local crystal oscillator, chip timings would be described in fractions of a mains voltage
cycle. This would track grid frequency variations synchronously at both ends and would maintain phase alignment even
over long periods of time at cost of a slight increase in system complexity. The receiver would then measure differences
between consecutive chips instead of their absolute values.

\section{Technical standardization}

The description of a safety reset system provided in this work could be translated into a formalized technical standard.
Our system is simple compared to e.g.\ a full smart meter communication standard and thus can conceivably be
described in a single, concise document. The complicated side of standardization would be the standardization of the
backend operation including key management, coördination and command authorization.

\section{Regulatory adoption}
\label{sec-regulation}

Since the proposed system adds significant cost and development overhead at no immediate benefit to either consumer or
utility company it is unlikely that it would be adopted voluntarily. Market forces limit what long-term planning utility
companies can do. An advanced mitigation such as this one might be out of their reach on their own and might require
regulatory intervention to be implemented. To regulatory authorities a system such as this one provides a primitive to
guard against attacks. Due to the low-level approach our system might allow a regulatory authority to restore meters to
a safe state without the need of fine-grained control of implementation details such as application network protocols.

A regulatory authority might specify that all smart meters must use a standardized reset controller that on command
resets to a minimal firmware image that disables external communication, continues basic billing functions and enables
any disconnect switches. This system would enable the regulatory authority to directly preempt a large-scale attack
irrespective of implementation details of the various smart meter implementations.

Cryptographic key management for the smart reset system is not much different to the management of highly privileged
signing keys as they are used in many other systems such as TLS already.  If the safety reset system is implemented by a
regulatory authority they would likely be able to find a public entity that is already managing root keys for other
government systems to also manage safety reset keys. Availability and security requirements of safety reset keys do not
differ significantly from those for other types of root keys.

\section{Zones of trust}

In our design, we opted for a safety reset controller in form of a separate micocontroller entirely separate from
whatever application microcontroller the smart meter design is already using.  This design nicely separates the meter
into an untrusted application on the core microcontroller and the trusted reset controller. Since the interface between
the two is simple and one-way, it can be validated to a high standard of security.

Despite these security benefits, the cost of such a separate hardware device might prove high in a mass-market rollout.
In this case, one might attempt to integrate the reset controller into the core microcontroller in some way. Primarily,
there would be two ways to accomplish this. One is a solution that physically integrates an additional microcontroller
core into the main application microcontroller package either as a module on the same die or as a separate die in a
multi-chip module (MCM) with the main application microcontroller. A custom solution integrating both on a single die
might be a viable path for very large-scale deployments but will most likely be too expensive in tooling costs alone to
justify its use. More likely for a medium- to large-scale deployment of millions of meters would be a MCM integrating an
off-the-shelf smart metering microcontroller die with the reset controller running on another, much smaller
off-the-shelf microcontroller die. This solution might potentially save some cost compared to a solution using a
discrete microcontroller for the reset controller.

The more likely approach to reducing cost overhead of the reset controller would be to employ virtualization
technologies such as ARM's TrustZone in order to incorporate the reset controller firmware into the application firmware
on the same processor core without compromising the reset controller's security or disturbing the application firmware's
operation.

TrustZone is a virtualization technology that provides a hardware-assisted privileged execution domain. In traditional
virtualization setups a privileged hypervisor is managing several unprivileged applications that share resources between
them. Separation between applications in this setup is longitudinal between adjacent virtual machines. Two applications
would both be running in unprivileged mode sharing the same CPU and the hypervisor would merely schedule them, configure
hardware resource access and coördinate communication. This longitudinal virtualization simplifies application
development since from the application's perspective the virtual machine looks very similar to a physical one. In
addition, in general this setup can be used to reciprocally isolate two applications with neither one being able to gain
control over the other.

In contrast to this, a TrustZone-like system in general does not provide several application virtual machines and
longitudinal separation. Instead, it provides lateral separation between two domains: The unprivileged application
firmware and a privileged hypervisor. Application firmware may communicate with the hypervisor through defined
interfaces but due to TrustZone's design it need not even be aware of the hypervisor's existence. This makes a perfect
fit for our reset controller. The reset controller firmware would be running in privileged mode and without exposing any
communication interfaces to application firmware. The application firmware would be running in unprivileged mode 
without any modification. The main hurdles to the implementation to a system like this are the requirement for a
microcontroller providing this type of virtualization on the one hand and the complexity of correctly employing this
virtualization on the other hand. Virtualization systems such as TrustZone are still orders of magnitude more complex to
correctly configure than it is to simply use separate hardware and secure the interfaces in between.

\chapter{Conclusion}

In this thesis we have developed an end-to-end design of a reset system to restore smart meters to a safe operating
state during an ongoing large-scale cyberattack. We have laid out the fundamentals of smart metering infrastructure and
elaborated the need for an out of band method to reset a meter's firmware due to the large attack surface of this
complex firmware.  To allow our system to be triggered even in the middle of a cyberattack we have developed a broadcast
data transmission system based on intentional modulation of the global grid frequency. We have developed the theoretical
foundations of the process based on an established model of inertial grid frequency response to load variations and
shown the viability of our end-to-end design through extensive simulations. To properly base these simulations we have
developed a grid frequency measurement methodology comprising of a custom-designed hardware device for electrically safe
data capture and a set of software tools to archive and process captured data. Our simulations show good behavior of our
broadcast communication system and give an indication that coöperating with a large consumer such as an aluminum
smelter would be a feasible way to set up a transmitter with very low hardware overhead.  Based on our broadcast
primitive we have developed a cryptographic protocol ready for embedded implementation in resource-constrained systems
that allows triggering all or a selected subset of devices within a quick response time of less than 30 minutes.
Finally, we have experimentally validated our system using simulated grid frequency data in a demonstrator setup based
on a commercial microcontroller as our safety reset controller and an off-the-shelf smart meter. We have laid out a path
for further research and standardization related to our system. Our code and electronics designs are available at the
public repository listed on the second page of this document.

\newpage

%\nocite{*} TODO: check unused references
\printbibliography[heading=bibintoc]
\newpage

\appendix
%\chapter{Transcripts of Jupyter notebooks used in this thesis}

%\includenotebook{Grid frequency estimation}{grid_freq_estimation}
%\includenotebook{Grid frequency estimation validation against ROCOF test suite}{freq_meas_validation_rocof_testsuite}
%\includenotebook{Frequency sensor clock stability analysis}{gps_clock_jitter_analysis}
%\includenotebook{DSSS modulation experiments}{dsss_experiments-ber}

\chapter{Frequency sensor schematics}
\label{sec-app-freq-sens-schematics}
\fancyhead[C]{Frequency sensor schematics (1/3)}
\fancyfoot[C]{}
\fancyhead[R]{\thepage}
\includepdf[fitpaper,landscape,pagecommand={\thispagestyle{fancy}}]{resources/platform-export-pg1.pdf}
\fancyhead[C]{Frequency sensor schematics (2/3)}
\includepdf[fitpaper,pagecommand={\thispagestyle{fancy}}]{resources/platform-export-pg2.pdf}
\fancyhead[C]{Frequency sensor schematics (3/3)}
\includepdf[fitpaper,landscape,pagecommand={\thispagestyle{fancy}}]{resources/platform-export-pg3.pdf}
\fancyfoot[C]{\thepage}

%\chapter{Firmware source code excerpts}
%\section{DMA-backed ADC capture (adc.c)}
%\inputminted[fontsize=\footnotesize,linenos,firstline=18,lastline=115,breaklines]{C}{../gm_platform/fw/adc.c}
%
%\section{Frequency sensor packetized serial interface}
%\subsection{serial.c}
%\inputminted[fontsize=\footnotesize,linenos,breaklines]{C}{../gm_platform/fw/serial.c}
%\subsection{packet\_interface.c}
%\inputminted[fontsize=\footnotesize,linenos,breaklines]{C}{../gm_platform/fw/packet_interface.c}
%\subsection{cobs.c}
%\inputminted[fontsize=\footnotesize,linenos,breaklines]{C}{../gm_platform/fw/cobs.c}
%\subsection{Host data logging utility (tw\_test.py)}
%\inputminted[fontsize=\footnotesize,linenos,breaklines]{python}{../gm_platform/fw/tw_test.py}
%
%\section{Frequency estimation (freq\_meas.c)}
%\inputminted[fontsize=\footnotesize,linenos,breaklines]{C}{../controller/fw/src/freq_meas.c}
%\section{DSSS demodulation (dsss\_demod.c)}
%\inputminted[fontsize=\footnotesize,linenos,breaklines]{C}{../controller/fw/src/dsss_demod.c}
%\section{Cryptographic protocol handling}
%\subsection{protocol.c}
%\inputminted[fontsize=\footnotesize,linenos,breaklines]{C}{../controller/fw/src/protocol.c}
%\subsection{crypto.c}
%\inputminted[fontsize=\footnotesize,linenos,breaklines]{C}{../controller/fw/src/crypto.c}


\chapter{Demonstrator firmware symbol size map}
\emph{Please find this appendix enclosed in the pouch on the inside of the back cover.}
\label{symbol_size_chart}
\includepdf[fitpaper]{resources/safetyreset-symbol-sizes.pdf}

% TODO
%\chapter{Economic viability of countermeasures}
%\section{Attack cost}
%\section{Countermeasure cost}
%\section{Conclusion}

\end{document}
