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Alternative heating systems for northern remote communities:
Techno-economic analysis of ground-source heat pumps in
Kuujjuaq, Nunavik, Canada
Evelyn Gunawan
Thesis of 60 ECTS credits
Master of Science (M.Sc.) in Sustainable Energy
April 2019
ii
Alternative heating systems for northern remote communities:
Techno-economic analysis of ground-source heat pumps in
Kuujjuaq, Nunavik, Canada
Evelyn Gunawan
Thesis of 60 ECTS credits submitted to the School of Science and Engineering at
Reykjavík University in partial fulfillment of the requirements for the degree of
Master of Science (M.Sc.) in Sustainable Energy
April 2019
Supervisor(s):
Jasmin Raymond, Supervisor
Professor, Institut national de la recherche scientifique, Canada
Nicolò Giordano, Supervisor
Postdoctoral Researcher, Institut national de la recherche scientifique, Canada
Páll Jensson, Advisor
Professor, Department Head, Reykjavik University, Iceland
Juliet Newson, Advisor
Director, Reykjavik University, Iceland
Examiner:
Halldór Pálsson, Examiner
Professor, University of Iceland, Iceland
iv
Copyright
Evelyn Gunawan
April 2019
vi
Alternative heating systems for northern remote communities:
Techno-economic analysis of ground-source heat pumps in
Kuujjuaq, Nunavik, Canada
Evelyn Gunawan
April 2019
Abstract
Geothermal energy, through the utilisation of ground source heat pump (GSHP)
has been proposed as a heating alternative to the low efficiency and
environmentally adverse diesel furnaces currently being used to meet residential
heating demand in Nunavik, a cold and remote region covering the northern third
of Québec, Canada. This study describes the application of the G.POT method,
developed by Casasso and Sethi (2016) to create maps of the shallow geothermal
potential in Kuujjuaq, the largest village in Nunavik. Resulting maps show a
relatively high potential for such cold region, ranging between 5.8 MWh/year and
22.9 MWh/year for borehole heat exchanger lengths of 100 m to 300 m. 50-years
life-cycle cost analyses of such geothermal systems reveal that compression GSHP
with electricity derived from solar photovoltaic panels costs as low as
CAD$0.15/kWh and forms the most economically attractive heating option in
Kuujjuaq as compared to the diesel furnace heating currently used at
CAD$0.21/kWh. Studies focusing on the applications of GSHP in subarctic
conditions are currently limited and hence, this work is expected to fill in this gap.
Keywords: renewable energy, geothermal, ground source heat pump, GIS, life
cycle cost
viii
Möguleigir kostir til húsahitunar í afskekktum nyrðri
byggðum: Tæknileg og fjárhagsleg greining á grunnvirkum
varmadælum í Kuujiuaq, Nunavik, Kanada
Evelyn Gunawan
Apríl 2019
Útdráttur
Fram hafa komið tillögur um að nýta jarðhita með varmadælum (GSHP) til
upphitunar í stað díselofna sem nú eru notaðir til að hita íbúðarhúsnæði í Nunavik,
köldu og afskekktu svæði sem nær yfir norðurhluta Quebec í Kanada. Díselofnar
eru bæði óskilvirkir og ekki umhverfisvænir. Þessi ritgerð lýsir notkun G.POT
aðferðarinnar, sem þróuð var af Casasso og Sethi (2016), til að kortleggja jarðhita
á litlu dýpi í Kuujjuaq, stærsta þorpinu í Nunavik. Kortin sýna tiltölulega mikla
möguleika á þessu kalda svæði, á bilinu frá 5,8 MWh/ári og upp í 22,9 MWh/ári
fyrir borholu á bilinu 100 til 300m. 50 ára kostnaðargreining á lífsferli slíkra
jarðhitakerfa sýnir að þjöppun GSHP með rafmagni sem fæst úr sólarsellum kostar
ekki nema CAD$0,15/kWh og er hagkvæmari kyndingarvalkostur fyrir Kuujjuaq
heldur en díselkynding sem nú er notuð og kostar CAD$0,21/kWh. Rannsóknir
sem beinast að notkun varmadæla í heimskautabyggðum hafa verið takmarkaðar
og því er vonast til að með þessu verkefni sé komið til móts við vöntun á þekkingu
á þessu sviði.
x
Alternative heating systems for northern remote communities:
Techno-economic analysis of ground-source heat pumps in
Kuujjuaq, Nunavik, Canada
Evelyn Gunawan
60 ECTS thesis submitted to the School of Science and Engineering
at Reykjavík University in partial fulfillment
of the requirements for the degree of
Master of Science (M.Sc.) in Sustainable Energy
April 2019
Student:
___________________________________________
Evelyn Gunawan
Supervisor(s):
___________________________________________
Jasmin Raymond
___________________________________________
Nicolò Giordano
___________________________________________
Páll Jensson
___________________________________________
Juliet Newson
Examiner:
___________________________________________
Halldór Pálsson
xii
The undersigned hereby grants permission to the Reykjavík University Library to reproduce
single copies of this Thesis entitled Alternative heating systems for northern remote
communities: Techno-economic analysis of ground-source heat pumps in Kuujjuaq,
Nunavik, Canada and to lend or sell such copies for private, scholarly or scientific research
purposes only.
The author reserves all other publication and other rights in association with the copyright
in the Thesis, and except as herein before provided, neither the Thesis nor any substantial
portion thereof may be printed or otherwise reproduced in any material form whatsoever
without the author’s prior written permission.
date
Evelyn Gunawan
Master of Science
0 2 / 0 5 / 2 0 1 9
xiv
Acknowledgements
I would like to express my sincere gratitude to my supervisor, Dr. Jasmin Raymond,
for providing this memorable opportunity to work on this project at the Institut national de
la recherche scientifique, for his insightful comments and immense knowledge, all the while
supportive of my career goals. I would also like to thank Dr. Nicolò Giordano for his patient
guidance, continuous support and encouragement. Both have shown me, by their examples,
what good scientists and people should be.
Special thank you to Dr. Juliet Newson, who has provided me extensive personal and
professional guidance, and who told me since the very beginning to always “go for it”. My
great appreciation goes to Dr. Páll Jensson for his valuable and constructive suggestions on
the economic aspect of this work. I am indebted to them for their help.
Thank you to the Insitut nordique du Québec for supporting this project financially.
I thank my fellow colleagues at the Iceland School of Energy and Institut national de
la recherche scientifique for being my constant sources of inspiration throughout this
journey.
Finally, I wish to thank my family: my sister, Clarissa Gunawan for her humour and
for enlightening me on the fundamentals of economic analysis, and my parents, Mimi Tjhin
and Hendra Gunawan for their unending support in everything that I pursue. Soli Deo Gloria.
xvi
Preface
This dissertation is original work by the author, Evelyn Gunawan.
xviii
xix
Contents
Acknowledgements ............................................................................................................ xv
Preface ..............................................................................................................................xvii
Contents ................................................................................................................................ 1
List of Figures ................................................................................................................... xxi
List of Tables .................................................................................................................. xxiii
List of Abbreviations and Acronyms ............................................................................ xxv
List of Symbols ..............................................................................................................xxvii
1 Introduction ...................................................................................................................... 1
2 Methods ............................................................................................................................. 4
2.1 Shallow Geothermal Potential Mapping ................................................................. 4
2.2 Residential Building Heating Load......................................................................... 7
2.2.1 Building Heating Scenarios and Effectiveness .......................................... 9
2.2.2 Building Energy Consumption ................................................................. 10
2.2.3 BHE Drilling Lengths .............................................................................. 10
2.2.4 Solar Panels Quantity ............................................................................... 10
2.3 Life-Cycle Cost Analysis ...................................................................................... 10
2.3.1 Costs of Heating System .......................................................................... 10
2.3.2 Cost of CO2 Emissions ............................................................................. 11
2.3.3 Net Present Cost, Levelised Cost of Energy and Sensitivity Analysis .... 12
2.3.4 Revenue from Selling in the Commodity Market .................................... 12
2.3.5 Economic Scenarios ................................................................................. 13
2.3.6 Assumptions ............................................................................................. 13
3 Results .............................................................................................................................. 15
3.1 Shallow Geothermal Potential Maps .................................................................... 15
3.2 Residential Building Heating Load....................................................................... 17
3.2.1 Building Energy Consumption ................................................................. 18
3.2.2 BHE Drilling Lengths .............................................................................. 18
3.2.3 Solar Panels Quantity ............................................................................... 18
3.3 Life-Cycle Cost Analysis ...................................................................................... 18
3.3.1 Economic Scenario 1 ................................................................................ 19
3.3.2 Economic Scenario 2 ................................................................................ 23
3.3.3 Economic Scenario 3 ................................................................................ 24
3.3.4 Economic Scenario 4 ................................................................................ 24
3.3.5 Economic Scenario 5 ................................................................................ 25
xx
4 Discussion ........................................................................................................................ 27
5 Conclusions...................................................................................................................... 29
References………………………………………………………………………….....31
A Detailed Steps for Shallow Geothermal Potential Data Processing and Mapping .. 36
A.1 Depths of Unconsolidated Sediments ..................................................................... 36
A.2 Weighted Thermal Conductivity and Heat Capacity .............................................. 38
A.3 G.POT Calculations and Mapping .......................................................................... 39
B SIMEB Calibration ........................................................................................................ 40
B.1 Calibration ............................................................................................................... 40
B.2 DHW Usage Schedule ............................................................................................ 45
B.3 Occupancy Schedule ............................................................................................... 46
B.4 Results of the Calibration ........................................................................................ 47
C Parameter Inputs to Simulate the Heating Load of Residential Building in
Kuujjuaq............................................................................................................................. 49
D COP Calculations........................................................................................................... 53
D.1 COP of Compression Heat Pump (COMP) ............................................................ 53
D.2 COP of Absorption Heat Pump (ABS) ................................................................... 54
E CO2 Emissions ................................................................................................................ 55
F Monthly Heating Load of a Typical Residential Building in Kuujjuaq .................... 56
G NPCs Based on Financial Scenario 5 ........................................................................... 58
xxi
List of Figures
Figure 1.1 Location of Kuujjuaq, the study area, in Canada. .................................................. 1 Figure 2.1 Kuujjuaq bedrock geology (top) and unconsolidated sediments (bottom) with
"Canada Base Map Service-Transportation" map as a background [19,20]. .......................... 6 Figure 2.2 Building heating scenarios. .................................................................................... 9 Figure 3.1 Geothermal potential maps of Kuujjuaq based on three BHE lengths of 100 m
(top), 200 m (center) and 300 m (bottom). X and Y axes represent map coordinates
(NAD83/UTM Zone 19N). .................................................................................................... 16 Figure 3.2 Average daily temperature and heating load profile of a typical residential
building in Kuujjuaq. ............................................................................................................. 17 Figure 3.3 NPC vs. CO2 emissions of different building heating scenarios. ......................... 19
Figure 3.4 Sensitivity analyses of key parameters in all building heating options based on
Economic Scenario 1. ............................................................................................................ 22
Figure 3.5 Range of accumulated NPCs based on worst to best BHE drilling costs compared
to that of business-as-usual heating scenario. ........................................................................ 23 Figure 3.6 Optimisation to determine the best proportion (%) of electricity coming from
solar panels to run a COMP for building heating in Kuujjuaq. ............................................. 26
Figure A1. Maps of bedrock limits (1), point layer of bedrock depths (2) and point layer of
the combined depths of unconsolidated sediments and the extracted bedrock depths (3) .... 36
Figure A2. Interpolations of the depths of unconsolidated sediments in Kuujjuaq with IDW
(left) and TIN (right) methods with 100 x 100 m grid spacings............................................ 37
Figure A3. Surfer maps with contour lines of unconsolidated sediments depths interpolated
with Kriging method using three different grid spacings ...................................................... 38
Figure A4. QGIS point layer of quaternary deposits depth data interpolated with Kriging
and 300 x 300 m grid spacing in Surfer................................................................................. 38
Figure A5. A sample of the .BLN file used to create the study area limits (left) and the
resulting limits viewed in Surfer used to clip the results to show only the study area (left) . 39
Figure B1. DHW usage schedule for Monday-Friday (top), Saturday (middle) and Sunday
(bottom)……………………………………………………………...………………….…..45
Figure B2. Building occupancy schedule for Monday-Friday (top) and Saturday-Sunday
(bottom)…………………………………..…………………………..……………………..46
Figure B3. Comparison of SIMEB calibration results with building heating load profile
from EERE ............................................................................................................................ 48
Figure D1. Graph of ClimateMaster Model TCH/V120 COP vs. EWT ............................... 54
Figure D2. Graph of Robur Model GAHP-WLB GUE vs. EWT .......................................... 55
Figure F1. Typical residential building space heating and domestic hot water load profiles
in Kuujjuaq………………………………………………………………………………….57
Figure G1. Accumulated NPCs of building heating options for home-owner and government
based on Economic Scenario 5 over 50 years LCC…………………….……………...…...59
xxii
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List of Tables
Table 2.1 Thermal conductivity and heat capacity for unconsolidated sediments and bedrock
[16,17]. ......................................................................................................................................5 Table 2.2 Parameters used for mapping the geothermal potential of Kuujjuaq [6]. .................5
Table 2.3 Main SIMEB parameter inputs to simulate a typical residential building heating
load in Kuujjuaq. .......................................................................................................................8 Table 2.4 Summary of the economic scenarios used to calculate the LCCs. ..........................13 Table 3.1 Energy consumption breakdowns for different heating equipment scenarios. .......18 Table 3.2 Summary of costs, CO2 emissions, NPCs and LCOEs of 50-years LCC for
business-as-usual and alternative heating scenarios. ...............................................................20 Table 3.3 Total 50 years NPCs for home-owner and government based on Economic
Scenario 3. ...............................................................................................................................24
Table 3.4 Total 50 years NPCs for home-owner and government based on Economic
Scenario 4. ...............................................................................................................................24 Table 3.5 Total 50 years NPCs for home-owner and government, and total LCOE based on
Economic Scenario 5. ..............................................................................................................25
Table A1. Comparison of depth interpolation results with Kriging method using three
different grid spacings ............................................................................................................. 38
Table B1. Monthly energy load profile of a typical residential building in Anchorage
obtained from EERE [3] website and modified to assume building heating with electric
equipment ................................................................................................................................ 40
Table B2. SIMEB parameter inputs to simulate a typical residential building heating load in
Anchorage ................................................................................................................................ 41
Table B3. Monthly energy load profile of a typical residential building in Anchorage based
on the calibration results in SIMEB ........................................................................................ 47
Table C1. SIMEB parameter inputs to simulate a typical residential building heating load in
Kuujjuaq .................................................................................................................................. 49
Table D1. Entering water temperatures (EWTs) and their corresponding coefficient of
performances (COPs) [43] ....................................................................................................... 53
Table D2. Entering water temperatures (EWTs) and their corresponding gas utilisation
efficiencies (GUEs) [44] .......................................................................................................... 54
Table E1. CO2 emissions intensity of six heating oil companies in North America ............... 56
xxiv
xxv
List of Abbreviations and Acronyms
ABS Absorption ground-source heat pump
BHE Borehole heat exchanger
CAD Canadian dollars
CO2 Carbon dioxide
COMP Compression heat pump
COP Coefficient of performance
°C Degree Celcius
DHW Domestic hot water
EWT Entering water temperature
GHG Greenhouse gas
GIS Geographic Information System
GSHP Ground-source heat pump
GUE Gas utilisation efficiency
HDD18 Heating degree days below 18°C
h Hour
K Kelvin
kWh Killowatt-hour
LCC Life-cycle cost
LCCA Life-cycle cost analysis
l Litre
LCOE Levelised cost of electricity
MJ Megajoule
MWh Megawatt-hour
m Metre
NPC Net Present Cost
EERE Office of Energy Efficiency and Renewable Energy
PV Photovoltaic
RBOB Reformulated gasoline blendstock for oxygen blending
SH Space heating
t Tonne
USD United States dollars
W Watts
xxvi
xxvii
List of Symbols
Symbol Description Value/Units
�̅�BHE Shallow geothermal potential MWh/year
𝑇𝑙𝑖𝑚 Threshold fluid temperature °C
𝐿 Borehole length m
𝑇0 Undisturbed ground temperature °C
𝑟b Borehole radius m
𝑡s Simulated lifetime years
𝑡c Length of the heating season days
𝑅b Borehole thermal resistance Mk/W
𝜆 Thermal conductivity W/mK
𝐶𝑣 Volumetric heat capacity MJ/m3K
𝑢′s Cycle time parameter -
𝑢′c Simulation time parameter -
𝑡′c Operating time ratio -
xxviii
𝐸g available Thermal energy available per metre drilled MWh/year-m
Eg Electricity demand to be met by solar PV
panels per year MWh/year
𝐿drill Total BHE drilling length m
𝑁s Number of solar PV panels -
Es available Electricity generated by each solar PV
panels kWh/year
𝐸s Electricity demand to be met by solar PV
panels kWh/year
r Discount rate %
𝐶t Total cost $
𝐶c Capital cost $
𝐶a Annual cost $
𝐶p Periodic cost $
n Time point Year 0, 1, 2, …
Et Annual energy output kWh/year
1
Chapter 1
1Introduction
Nunavik, home to 14 Inuit villages with a total of 12,300 inhabitants, is a remote
region covering the northern third of Québec province, Canada. These communities are not
connected to the electrical grid and hence, are reliant on diesel power plants and furnaces to
meet their electricity and building heating (space heating (SH) and domestic hot water
(DHW)) demands. However, due to the distance between the location and the closest
transmission lines there is no plan to connect these communities to the grid. In 2018, the
price of fuel oil was $2.03/l, which is heavily subsidised by the local government to $1.63/l
[1]. Such high cost of fuel is partly associated to the additional cost of fuel transportation
from the south to Nunavik. Additionally, diesel is only shipped once a year to these
communities. As a result, they are forced to purchase annual supplies of diesel fuel on the
spot market, making diesel price volatile in this region [2]. Kuujjuaq, the regional capital of
Nunavik, experiences a low annual average temperature of -5.4°C and an annual average of
8,520 heating degree days below 18°C (HDD18), which translates to high building heating
requirements. Furthermore, between 2006 and 2011, the Inuit population in Nunavik
increased by 12% [3]. The combination of high fuel cost, high building heating
requirements, increasing demand and adverse environmental impact of fossil fuel
combustion calls for the development of new approaches, specifically via renewable energy
sources to supply clean and reliable energy in these off-grid communities.
Kuujjuaq
Figure 1.1 Location of Kuujjuaq, the study area, in Canada.
2 CHAPTER 1: INTRODUCTION
In 2011, the government of Québec launched the Plan Nord, a sustainable
development strategy that targets various sectors and aims to provide a platform for
development in Québec north of 49th degree of latitude by 2035. As part of the strategy, one
of the action plans identified in the Priority Actions for 2015-2020 in the Energy Sector is to
support projects in the northern communities that replace fossil fuels with renewable energy
sources [4]. Several options, such as hydro-power and wind generation have been studied to
date. Hydro-Québec [5], Québec’s electric utility company, published a report in 2011 on the
current state and future potential of energy transport and distribution in Québec’s First
Nations territories, which proposed a hybrid of wind and diesel generation in various
communities as a measure to reduce fossil fuel consumption. However, this notion was
rejected by the communities due to various reasons listed in the report. Weis and Llinca [2]
assessed the potential for wind power generation in 89 remote communities in Canada, while
Yan et al. [6] ranked the suitability of waste gasification and combustions of fuel oil, pellets
and natural gas for building heating in Nunavik. However, the potential of geothermal energy
as a possible solution has not been fully assessed.
In this study, geothermal energy, specifically through the adoption of ground-source
heat pump (GSHP) technology is proposed as a viable alternative to the low efficiency and
high greenhouse gas- (GHG-) emitting diesel furnaces currently used for heating buildings.
A GSHP is a highly efficient technology that can provide both cooling and heating to
buildings by taking advantage of Earth’s subsurface maintaining a relatively constant
temperature year-round. Although it is powered by either electricity or a heat source, the main
advantage of this technology lies in its ability to supply more energy than that used to operate
it. During the heating season, the GSHP system extracts heat from the ground via borehole
heat exchanger (BHE) and distributes it to warm the building. During the cooling season, the
system reverses, transferring heat from the building to the ground.
Geng et al. [7] presented a case study on Shenyang, one of the coldest regions in China
with 3,905 HDD18. Since 2006, the municipality has installed 780 GSHPs, representing
36.3% of the country’s total, which resulted in a GHG emission reduction of 2.1 t from 2006
to 2010. Ozyurt and Ekinci [8] conducted a one-year experimental study in 2007 to analyse
the performance of an electric compression GSHP (COMP) with vertical BHE used for space
heating in Erzurum, the coldest city in Turkey with 4,634 HDD18. They found the coefficient
of performance1(COP), which is the measure for GSHP effectiveness, for this entire year to
be favourable, ranging between 2.43 and 3.55. Pike and Whitney [9] reviewed the economic
performances of seven GSHPs with vertical BHEs in Alaska. The authors noted that the
economics of GSHPs depends heavily on the costs of electricity and alternate fuel source,
such as natural gas or heating oil in the location. The Cold Climate Housing Research Centre
installed a GSHP at its Research and Testing Facility in Fairbanks, Alaska with a horizontal
BHE in 2013 and published a report to assess its performance within the first four years of
operation [10]. They found that the GSHP system operated with better-than-expected
performance, ranging between 2.82 to 3.69. Their models suggest that the decline in COP
will plateau in year 5. The cost effectiveness of GSHP however, depends on the cost of oil
and electricity in the area. The lower the cost of oil, the less cost effective the GSHP system
would be compared to the conventional oil furnace heating system [10]. Le Dû et al. [11]
conducted economic analyses of GSHP to meet the cooling and heating demand of a typical
130 m2 residential building in Halifax, Montreal, Toronto and Vancouver in Canada, with
HDD18 of 3,941, 4,363, 3,498 and 2,818, respectively [12]. In Montreal and Halifax, which
1 The effectiveness of GSHP is measured in terms of its COP, which is typically well above 1. For instance, a
COP of 3 indicates that for every 1 unit of electrical or thermal energy input, 3 units of thermal energy would be
delivered.
2.1 SHALLOW GEOTHERMAL POTENTIAL MAPPING
3
use electricity and heating oil as their heating energy sources, paybacks for GSHP installation
are expected to be 18.5 years and 11.3 years, respectively. In Toronto and Vancouver, which
use natural gas as their heating source, no payback for GSHP installation are expected due to
the low price of natural gas. Healy and Ugursal [13] conducted a techno-economic analysis
of GSHP with horizontal BHE in Halifax, Canada and concluded that the technology is
economically viable compared to the oil heating system used in the region. Kegel et al. [14]
analysed the application of GSHP for building heating in Whitehorse and Yellowknife,
Canada and showed that in both regions, significant energy, utility cost and GHG emissions
reductions can be achieved with GSHP. The main challenges of operating GSHPs in such
cold climate relate to the low ground temperature near freezing point, lower GSHP COPs,
high building heating needs and the fact that the usage of electricity to run the GSHP is not
advised by Hydro-Québec as electricity in Nunavik is generated by diesel. These studies
established that GSHP has been successfully installed and tested in cold regions around the
world, even though its economic viability may vary according to factors such as the energy
source used to run the GSHP and the cost of that energy. However, none have studied the
application of GSHP in remote and cold region, specifically Kuujjuaq, Nunavik, Canada.
The objective of the present thesis is to quantify the shallow geothermal potential of
Kuujjuaq, by estimating the maximum amount of energy that can be extracted with a GSHP
coupled to vertical BHE installed in shallow subsurface with a relatively cold temperature of
slightly above 0°C, where this system has never been used in such extreme and cold
environment. Additionally, its economical viability will be evaluated.
To achieve this goal, this study is divided into three main parts:
1. Mapping of the shallow geothermal potential of Kuujjuaq using a geographic
information system- (GIS-) based workflow.
2. Simulating the heating load of a typical residential building in Kuujjuaq using
the local weather data.
3. Calculating the 50-years life-cycle costs of business-as-usual heating scenario
of using diesel furnace and four alternative heating scenarios using GSHP.
This work is expected to serve as a basis for future studies focusing on the applications
of GSHP in subarctic conditions, where low ground temperature near the freezing point,
unbalanced heating/cooling loads and remoteness of the communities can significantly
affect its techno-economic feasibility.
4 : METHODS
Chapter 2
2Methods
2.1 Shallow Geothermal Potential Mapping
The G.POT method (Eq. 2.1) is used to estimate the shallow geothermal potential or
the maximum thermal energy that can be sustainably extracted annually by a closed-loop
BHE in a homogeneous subsurface [15]. This method can be used for both cooling and
heating mode. However, geothermal potential of Kuujjuaq is calculated only for heating
mode as there are very low cooling requirements in the study area.
�̅�BHE =0.0701∙(𝑇0−𝑇lim)∙𝜆∙𝐿∙𝑡′
c
−0.629∙𝑡′c∙log(𝑢′
s)+(0.532𝑡′c−0.962)∙log(𝑢′
c)−0.455𝑡′c−1.619+4𝜋𝜆∙𝑅b
(2.1)
The geothermal potential �̅�BHE (MWh/year) is dependent on the maximum possible
temperature difference between the ground and the fluid 𝑇0 − 𝑇lim (°C), the ground thermal
conductivity 𝜆 (W/mK), the borehole length 𝐿 (m), the thermal resistance of the borehole 𝑅b
(mK/W) and the three non-dimensional parameters 𝑢′s, 𝑢′c and 𝑡′c defined by the following
equations:
𝑢′s =𝐶𝑣∙𝑟𝑏
2
4𝜆𝑡s (2.2)
which depends on the ground heat capacity (𝐶𝑣), borehole radius (𝑟𝑏) and simulated
lifetime (𝑡s):
𝑢′c =
𝐶𝑣∙𝑟2b
4𝜆𝑡c (2.3)
which depends on the heating season length (𝑡c), and
𝑡′c =𝑡c
𝑡y (2.4)
which depends on the length of the load cycle (𝑡y).
The threshold fluid temperature (𝑇lim) is the minimum average fluid temperature in
the BHE and is a design parameter that depends on the BHE length and the temperature
difference between the ground and the fluid flowing through the BHE. In this paper, 𝑇lim is
assumed to be -5°C. A field campaign was previously conducted over the study area to
collect data related to quaternary sediments depths, as well as thermal conductivity and heat
capacity of unconsolidated sediments and host rock (Table 2.1) [16,17]. The typical BHE
length for residential usage is usually around 100 m. However, due to the constraints of the
study area pertaining to low underground temperature and high building heating
2.1 SHALLOW GEOTHERMAL POTENTIAL MAPPING
5
requirements, deeper BHEs at 200 m and 300 m were also considered. The undisturbed
ground temperature 𝑇0, is estimated to be 1.0°C, 1.75°C and 2.75°C over the first 100 m,
200 m and 300 m, respectively. These values were obtained for the corresponding BHE
lengths by Della Valentina et al. [18]. Data on borehole characteristics were defined based
on the possible diameters that can be installed by drilling firms providing services for mining
exploration companies in Kuujjuaq. The input parameters used to map the geothermal
potential are summarised in Table 2.2.
Table 2.1 Thermal conductivity and heat capacity for unconsolidated sediments and
bedrock [16,17].
Table 2.2 Parameters used for mapping the geothermal potential of Kuujjuaq [6].
Parameter Symbol Values Unit
Threshold fluid temperature 𝑇𝑙𝑖𝑚 -5 °C
Borehole length 𝐿 100/200/300 m
Undisturbed ground temperature 𝑇0 1.0/1.75/2.75 °C
Borehole radius 𝑟b 0.038 m
Simulated lifetime 𝑡s 50 years
Length of the heating season 𝑡c 270 days
Borehole thermal resistance 𝑅b 0.1 mK/W
The “Canada Base Map Service-Transportation” that is available online as a Web Map
S ervice was used as a background map [19]. This map exists as a raster and was displayed
at a scale of 1:150,000 and projected in NAD83/UTM Zone 19N. Shapefiles of
unconsolidated sediments and bedrock geology of the study area were also used [20]
(Fig. 2.1). The QGIS 2.18.21 (QGIS) mapping software [21] was used for this procedure.
Types λ saturated
(W/mK)
𝑪𝒗 saturated
(MJ/m3K)
Bedrock Lithology
Paragneiss 2.7 2.4
Diorites 3.0 2.4
Granites 2.9 2.3
Gabbros 3.0 2.4
Tonalites 3.4 2.3
Unconsolidated
Sediments
Marine 1.5 3.0
Alluvial 1.4 3.2
Glacial Till 1.6 3.0
Outcrops 0 0
6 CHAPTER 2: METHODS
Using both QGIS and Surfer® 9 (Surfer) software [22], a depth layer consisting of
existing data of depths of unconsolidated sediments obtained from the field study was
created and interpolated with the Kriging method using a 300 x 300 m grid spacing to cover
the entire study area. The ground thermal conductivity and heat capacity values for both
unconsolidated sediments and bedrock geology were also incorporated to the layer. The
weighted thermal conductivity and heat capacity were calculated for 100 m, 200 m and
300 m BHE lengths scenarios. A sample formula used to calculate the weighted thermal
conductivity at 100 m BHE length is given as follow:
𝜆𝑤𝑒𝑖𝑔ℎ𝑡𝑒𝑑 = (𝐷𝑒𝑝𝑡ℎ𝑢𝑛𝑐𝑜𝑛𝑠𝑜𝑙𝑖𝑑𝑎𝑡𝑒𝑑
100∙ 𝜆𝑢𝑛𝑐𝑜𝑛𝑠𝑜𝑙𝑖𝑑𝑎𝑡𝑒𝑑) + (
100−𝐷𝑒𝑝𝑡ℎ𝑢𝑛𝑐𝑜𝑛𝑠𝑜𝑙𝑖𝑑𝑎𝑡𝑒𝑑
100∙ 𝜆𝑏𝑒𝑑𝑟𝑜𝑐𝑘) (2.5)
The shallow geothermal potential of Kuujjuaq was calculated for each BHE length
scenario by applying Equation 2.1 in Microsoft Excel and then visualised in Surfer. An in-
depth description of the mapping procedure is provided in Appendix A.
Kuujjuaq Unconsolidated Sediments
Kuujjuaq Bedrock Geology
Figure 2.1 Kuujjuaq bedrock geology (top) and unconsolidated sediments (bottom) with
"Canada Base Map Service-Transportation" map as a background [19,20].
2.2 RESIDENTIAL BUILDING HEATING LOAD
7
2.2 Residential Building Heating Load
The heating load of a 252 m2, one-floor residential house with 5 occupants was
modeled with SIMEB using weather data for Kuujjuaq and known parameters on residential
buildings [23,24]. SIMEB is a software program that simulates building energy
consumption, which allows the estimation of hour-by-hour building energy usage given
certain inputs, such as architectural data, thermal envelope, occupancy and mechanical
systems, such as lighting, ventilation and heating [25]. This tool provides a simplified
interface for the DOE-2 and EnergyPlus calculation engines that were developed to perform
building energy simulation. DOE-2 was developed by the Lawrence Berkeley National
Laboratory and funded by the US Department of Energy in late 1970s. EnergyPlus was
developed in 1996 based on the systems algorithms of DOE-2 [25]. In this paper, the DOE-2
algorithm was chosen to model the heating load of the house as it remains one of the most
widely-used building energy modeling programs.
Since current data on building energy usage in Kuujjuaq is limited, hourly load profile
data for a typical residential building in Anchorage, Alaska, US was initially used to
calibrate the inputs specified in SIMEB (Appendix B) [26]. Anchorage was chosen as both
Anchorage and Kuujjuaq have a subarctic climate, with the Alaskan capital showing 7,500
HDD18. The building occupancy and usage schedule were adjusted until similar heating load
profiles were achieved (Appendix B) [27].
Table 2.3 lists down some of the important parameter inputs that were used in SIMEB
to model the building heating load in Kuujjuaq. The full list of inputs, their sources and
calculations can be found in Appendix C. Due to its cold weather, buildings in Kuujjuaq are
regulated by the Société d’habitation du Québec to meet the minimum insulation in order to
minimise heat loss [28]. The RSI-value (m2K/W) is a way to measure insulation and depends
on the thermal resistance of the material. U-value (W/m2K) measures heat loss through a
structure, while SHGC (unitless) represents the amount of solar radiation through a window.
8 CHAPTER 2: METHODS
Table 2.3 Main SIMEB parameter inputs to simulate a typical residential building
heating load in Kuujjuaq.
Parameter Values
Thermal Envelope
Roof insulation 9 RSI
Wall insulation 5.11 RSI
Fenestration U: 2.16 W/m2 K
SHGC: 0.5
DHW
Water heater Electrical
Efficiency 100%
Maximum load 20.7 W/m2
Central HVAC System
Type Single zone: single
supply duct system
Heating Electrical
Heating equipment
efficiency 100%
Cooling None
Regulation
Minimum temperature 21.1 °C
Maximum temperature 24.4 °C
Perimeter heating Hydronic baseboard
Occupation
Sensible heat 64.5 W/occupant
Latent heat 48.1 W/occupant
2.2 RESIDENTIAL BUILDING HEATING LOAD
9
2.2.1 Building Heating Scenarios and Effectiveness
The building heating systems considered in this study are summarised in Figure 2.2.
Both COMP and ABS can provide heating and cooling in building applications.
However, there are fundamental differences between the two. COMP runs on electricity to
extract geothermal energy. ABS runs on thermal input, most commonly natural gas.
However, since diesel is readily available in Kuujjuaq, it is assumed the ABS described in
Case 3 will be customised to run on diesel. The effectiveness of COMP and ABS are
measured in coefficient of performance (COP) and gas utilisation efficiency (GUE),
respectively, and depend on the entering water temperature (EWT), which is defined as the
temperature of fluid entering the heat pump. In turn, the EWT depends on both the BHE
configuration and 𝑇0. In this paper, the EWT was assumed to be equal to 𝑇lim at -5°C. Both
COP and GUE measure the ratio of the heating supplied to the building, to the electrical
energy or in the case of ABS, gas consumed by the thermal compressor (Eq. 2.6). For
instance, a COP of 3 indicates that for every 1 unit of electrical or thermal energy input, 3
units of thermal energy would be delivered. For simplicity, the term COP will be used in
this paper to refer to the effectiveness of both COMP and ABS. The COP ratings of COMP
are typically higher than ABS [29]. The COMP selected for this paper has a COP of 3.1,
while the ABS has a COP of 1.2 at the selected EWT. Refer to Appendix D for detailed
calculations. These values were calculated based on the product specifications provided by
the manufacturers. The COP of a heat pump is measured by:
𝐶𝑂𝑃 =𝑈𝑠𝑒𝑓𝑢𝑙 ℎ𝑒𝑎𝑡
𝑊𝑜𝑟𝑘 𝑒𝑥𝑝𝑒𝑛𝑑𝑒𝑑 (2.6)
Electricity, which is produced by the local diesel power plant is not advised to be used
for building heating in Kuujjuaq since it is generated from a diesel power plant at an
efficiency of roughly 33.2% [30]. Therefore, Cases 2A and 2B consider the generation of
electricity from solar photovoltaic (PV) panels.
Sizing a GSHP to provide all the heating required by a house is not normally
Building Heating Scenario
Case 1: Business-as-usual with diesel
furnace
Case 2: Compression heat pump (COMP)
A. 70% of electricity by solar PV panels,
30% from diesel power plant
B. 100% of electricity by solar PV panels
C. 100% of electricity by diesel power plant
Case 3: Absorption heat pump (ABS)
Figure 2.2 Building heating scenarios.
10 CHAPTER 2: METHODS
recommended. The occasional peak heating load during severe weather conditions are
usually met by a secondary heating system. Hence, for both Cases 2 and 3, the GSHP is
sized to meet 50% of the peak load. The remaining load will be covered with diesel furnace,
which has an efficiency of 78%.
2.2.2 Building Energy Consumption
Based on the simulated total annual building heating load in Kuujjuaq (Table 3.1), the
energy consumptions for each heating scenario and for different heating equipment were
calculated according to the efficiency for diesel furnace and COPs for heat pump, as well
ass energy densities or calorific values [31] as follow:
1. 1 kWh electricity = 0.0036 GJ
2. 1 l diesel oil = 0.0387 GJ
2.2.3 BHE Drilling Lengths
Based on the average geothermal potential in Kuujjuaq (�̅�BHE), the thermal energy
available per meter drilled (Eg available) were calculated for Cases 2 and 3 based on the three
BHE lengths (L) considered in the G.POT calculation.
𝐸g available =�̅�BHE
𝐿 (2.7)
Based on the total ground load (Eg), which is the ground thermal energy required to
meet the building load with the GSHP system, the total drilling length necessary (𝐿drill) were
calculated as follows:
𝐿drill =𝐸g ∙ 𝐿
�̅�BHE (2.8)
2.2.4 Solar Panels Quantity
The number of solar PV panels required (Ns) for Cases 2A and 2B were calculated by
dividing the electricity demand to be met by the solar PV panels (Es) by the energy generated
from each panel (Es available). Es available was calculated by multiplying the solar PV panel
rating, which was assumed at 0.3 kW with 1,033 kWh/kW/year, the average annual solar
PV potential in Kuujjuaq [32].
𝑁s =𝐸s
𝐸s available (2.9)
2.3 Life-Cycle Cost Analysis
2.3.1 Costs of Heating System
All costs in this study are in Canadian dollars (CAD), unless otherwise specified. For
2.3 LIFE-CYCLE COST ANALYSIS 11
prices involving the United States dollars (USD), the conversion rate 1 USD = 1.272 CAD
on November 6, 2018 was considered [33]. A 14.98% Québec sales tax was applied to all
costs. The total cost (Ct) was divided into capital costs (Cc), annual costs (Ca), and periodic
costs (Cp) (Eq. 2.10). Capital costs include the cost of equipment, installation or labour and
shipping. Annual costs were divided to the costs of energy (diesel and/or electricity),
maintenance and GHG or carbon dioxide (CO2) emissions. Periodic costs include the cost
of equipment to be replaced at the end of its lifetime, installation and shipping.
𝐶t = 𝐶c + 𝐶a + 𝐶p (2.10)
Price of fuel: Diesel price in Kuujjuaq is $2.03/l before and $1.63/l after the subsidy
[1]. The cost of electricity production by diesel power plant in Kuujjuaq is $0.86/kWh [34].
With subsidies, the base rate for electricity if 40.64c/day, and $5.40/month in summer and
$6.21/month in winter, while the variable rate is 5.91c/kWh for the first 10,950 kWh per
annum and 41.05c/kWh thereafter [35].
Price and lifetime of equipment: The price of oil tank is $666.92, which has an
expected lifetime of 25 years [36]. The price of boiler is $3,248.30 and a lifetime of 15 years
[37]. The price of both COMP and ABS were assumed to be the same at USD$7,000 for
35 kW, which can cover the heating needs of three houses. The lifetime of heat pump is
expected to be 20 years. The cost of drilling sums to $344.94/m, which includes labour and
u-pipe heat exchanger [38]. The lifetime of the heat exchanger is assumed to be 50 years.
The cost of solar PV panel installation, which includes both labour and equipment is
assumed to be at a higher end at $5.0/W in Kuujjuaq, which was inferred from the average
installation cost in Québec at $2-3.5/W [39]. The lifetime of solar PV panel is assumed to
be 20 years.
Labour wage and installation time: The average wage for 13 maintenance and
technician jobs in Kuujjuaq was $26.32/hour [40]. It takes two working days for boiler
installation and one working day for tank installation. Due to the difference in expertise
required, the average wage for heat pump installation is assumed to be $35.00/hour. Heat
pump installation takes two working days.
Maintenance: Maintenance for all heating scenario is assumed to be conducted
annually at $3.87/m2 for diesel furnace system and $1.81/m2 for both heat pump systems
[41]. Since in Cases 2 and 3 diesel furnaces is only used to meet 50% of the peak heating
demand, the maintenance cost for oil furnace in these cases were halved and added to the
heat pump maintenance cost.
Shipping: Shipping of oil tank, oil furnace and heat pumps from Québec City is
provided by NEAS cargo shipping company at approximately $1.15/kg, which includes tax
and fuel surcharge [42].
Equipment weight: A 275-gallon oil tank weighs 127 kg. The average weight of
seven oil furnaces is 255 kg. The weight of COMP is 316.6 kg [43]. The weight of ABS is
300 kg [44]. The weight of wooden pallet packaging for each equipment was assumed at
15 kg. The weight of solar PV panel was assumed at 15 kg/m2, while a typical size of a solar
PV panel is 1.64 m2.
2.3.2 Cost of CO2 Emissions
The CO2 emissions per MJ of product of six heating oil companies in North America
were averaged and multiplied by the annual diesel consumption to determine the annual
carbon dioxide emissions for each heating scenario (Appendix E) [45].
12 CHAPTER 2: METHODS
The CO2 emissions for each scenario was multiplied with $19.40/t, the estimated price
of carbon in Québec’s carbon market in 2020, to obtain the cost of CO2 emissions associated
with each heating option [46].
2.3.3 Net Present Cost, Levelised Cost of Energy and Sensitivity Analysis
A net present cost (NPC) and levelised cost of energy (LCOE) approaches were
chosen to compare the 50-years life-cycle costs (LCCs) of the heating alternatives. It is
important to note that life-cycle cost analysis (LCCA) cannot be used for budget allocation.
However, LCCA is especially useful to compare project alternatives that fulfill similar
function, which in this study is for building heating in Kuujjuaq, and to select the most cost-
efficient option. The NPC formula converts or discounts costs incurred at different time
point (n) during the project life-cycle, at the discount rate (r) to a common point in time,
which in this study is 2020. NPC calculations were applied to obtain the LCC for both home-
owner and government.
𝑁𝑃𝐶 = ∑𝐶t,n
(1+𝑟)n𝑁𝑛=0 (2.11)
The LCOE is an additional way to rank project alternatives. Compared to the NPC
method, LCOE considers both the total LCC, as well as the total amount of energy
consumed, both of which are discounted over the project’s lifetime. It indicates the minimum
cost per unit of energy that will recover the lifetime costs of the system and is measured by
dividing the NPC of the heating system by its total lifetime energy output. The annual energy
output (Et) is the total energy consumption for each heating scenario (Table 3.2).
𝐿𝐶𝑂𝐸 =𝑁𝑃𝐶
∑𝐸t,n
(1+𝑟)n𝑁𝑛=1
(2.12)
To address the uncertainty in predicting these costs and to identify critical parameters,
sensitivity analyses were conducted to measure the effect on the NPC of variations in the
key input variables. The key inputs that were subject to sensitivity analysis were capital cost,
energy cost, maintenance cost, and periodic costs for heat pump, oil boiler, oil tank and solar
PV panels. Each of the key inputs was changed by 30% in 10% increments above and below
their original values. Sensitivity graphs were plotted for each heating scenario to visualise
the results of the sensitivity analyses (Fig. 3.4). The gradients of the lines indicate how
sensitive the NPC is to changes in each of the inputs. A steeper slope indicates a more crucial
variable that has more effect on the NPC.
2.3.4 Revenue from Selling in the Commodity Market
Switching from business-as-usual heating scenario in Case 1 to GSHP heating systems
in Case 2 and 3 cuts the consumption of diesel. This opportunity benefit is defined as the
revenue gained from selling surplus diesel in the commodity market and the avoided cost
for not shipping and selling to Kuujjuaq. These costs were considered when calculating the
NPCs of Cases 2 and 3. The cost of diesel was assumed to be USD$1.41/gal or $0.47/l based
on the price of RBOB gasoline in the commodity market on January 5, 2019 [47]. The cost
of shipping diesel was assumed to be the cost of diesel production before subsidy minus the
cost after subsidy at $0.40/l.
2.3 LIFE-CYCLE COST ANALYSIS 13
2.3.5 Economic Scenarios
To be able to propose recommendation and/or identify areas to be considered for
future improvement, the LCCAs were applied for various economic scenarios, where one to
several variables were varied, while the others were held constant (Table 2.4). First, an
LCCA based on the current condition and the values assumed above was created. Second,
LCCAs to show the uncertainties resulting from best ($50/m), moderate ($175/m) and worst
($300/m) BHE drilling costs were created. The best drilling cost was assumed based on the
typical BHE drilling cost in the south. Third, a scenario was analysed in which the
government covers 50% of worst BHE drilling cost ($300/m) and GSHP and/or solar PV
panels costs, while all subsidies on electricity and diesel remain. Fourth, the government still
covers 50% of BHE drilling cost and GSHP and/or solar PV panels costs, but there would
be no more subsidies on electricity and diesel for the home-owner. Fifth, the government
covers 50% of GSHP and/or solar PV panels costs, but there would be no more subsidies on
electricity and diesel for the home-owner. In this last scenario, the home-owner are fully
responsible for the cost of drilling at $50/m. From the third economic scenario onwards, the
effect of government incentive to the NPC as well as the effect of such incentive to the
distribution of cost between home-owner and government can be observed, whereas the first
and second economic scenarios are expected to provide an overview of the total costs of the
project.
Table 2.4 Summary of the economic scenarios used to calculate the LCCs.
2.3.6 Assumptions
In addition to the costs and economic scenarios stated above, the following technical
assumptions were made:
1. Solar PV panels were installed south facing at an angle equal to the latitude, with no
shade, such as from buildings, trees and snow.
2. Cost of solar energy storage was not considered.
3. To limit the scope of the economic analysis, the cost of heating distribution was not
considered.
4. Tools and parts, such as bolts and screws were considered negligible and not
included.
5. Roof replacement costs incurred when solar PV panels are replaced were not
considered as roof has an expected lifetime of 20 years and hence, need to be
replaced regardless in all cases.
The following economic assumptions were made:
Economic
Scenario
Drilling Energy (diesel
and electricity)
Subsidy
GSHP and Solar
PV Panel Costs
Covered by the
Government
Cost ($/m) Cost Covered
by the
Government
1 300 no yes no
2 300, 175 and 50 no yes no
3 300 50% yes 50%
4 300 50% no 50%
5 50 no no 50%
14 CHAPTER 2: METHODS
1. Discount rate = 6% [48].
2. Annual energy and maintenance costs escalation rates = 0%.
3. Project lifetime = 50 years. Project starts in 2020 and ends in 2069.
4. No sudden fluctuation in the costs of electricity and diesel throughout the project life-
cycle.
5. Depreciation rates of heating equipment not considered.
1. In the third, fourth and fifth economic scenarios, the government is assumed to bear
the cost of CO2 emissions.
3.1 SHALLOW GEOTHERMAL POTENTIAL MAPS
15
Chapter 3
3Results
3.1 Shallow Geothermal Potential Maps
With the input parameters described in Tables 2.1 and 2.2, the shallow geothermal
potential, �̅�𝐵𝐻𝐸 was calculated using the G.POT equation (Eq. 2.1). Figure 3.1 presents the
resulting geothermal potential maps based on three BHE lengths in Kuujjuaq.
16 CHAPTER 3: RESULTS
Figure 3.1 Geothermal potential maps of Kuujjuaq based on three BHE lengths of
100 m (top), 200 m (center) and 300 m (bottom). X and Y axes represent map
coordinates (NAD83/UTM Zone 19N).
3.2 RESIDENTIAL BUILDING HEATING LOAD
17
The geothermal potential at 100 m BHE length ranged 5.2-6.6 MWh/year and
averaged 5.8 MWh/year. At 200 m, the geothermal potential ranged 12.2-14.9 MWh/year
and averaged 13.3 MWh/year. At 300 m, the geothermal potential ranged
21.3-25.6 MWh/year and averaged 22.9 MWh/year. Thus, the geothermal potential
increases supralinearly with borehole lengths due to higher temperature at greater depths
and lower thermal conductivity of shallow quaternary deposits.
Geologically-accurate geothermal potential maps were successfully produced by
applying the steps outlined in the methodology. In areas where the dominating bedrock
lithology has lower thermal conductivity, there is generally lower geothermal potential in
the area, and vice versa. For instance, in the area overlying paragneiss bedrock, which has
an average thermal conductivity of 2.7 W/mK, there is lower geothermal potential. While in
area that overlies the tonalites, which has an average thermal conductivity of 3.4 W/mK,
there is higher geothermal potential (Table 2.1).
3.2 Residential Building Heating Load
Based on Kuujjuaq’s weather data and the building parameters described previously,
the annual heating load of a 252 m2 residential building in Kuujjuaq is approximately
71,300 kWh (Appendix F). Figure 3.2 shows the daily heating load profile modelled using
SIMEB. Apart from the main input parameters (Table 2.3), the building heating load is
heavily influenced by the outdoor air temperature data. During warmer summer months,
from June-August, the average outside daily temperature reaches an hourly average of
18.5°C and the total heating load is 39.4 kWh. During winter months, it gets as cold as -
36.3°C and the total heating load is predicted to be as high as 272.1 kWh.
Figure 3.2 Average daily temperature and heating load profile of a typical residential
building in Kuujjuaq.
18 CHAPTER 3: RESULTS
3.2.1 Building Energy Consumption
The energy consumptions for each heating equipment scenario (Fig. 2.2) were
calculated based on the building heating load, the effectiveness or COP of the heating
equipment and the energy densities (Table 3.1). The efficiency of the diesel furnace was
assumed to be 78%, while the COPs for COMP and ABS were 3.1 and 1.2, respectively. For
Cases 2 and 3, 50% of the heating load was allocated to the secondary system, which is
diesel furnace. For the business-as-usual heating scenario (Case 1), this translates to an
annual energy consumption of 8,174.7 l or 32.4 l/m2 (Table 3.1). This value is comparable
with the reported annual average energy consumption of 3,100 l diesel for a 110.9 m2 house
in Kuujjuaq, which translates to an energy consumption of 28.0 l/m2 [6].
Table 3.1 Energy consumption breakdowns for different heating equipment scenarios.
Heating
Scenario
For diesel
furnace For GSHP
Diesel (l)
Electricity from
solar PV panels,
Es (kWh)
Diesel for
GSHP (l)
Ground
thermal energy,
Eg (kWh)
Electricity from
diesel power
plant (kWh)
1 8,174.7
4,253.1
4,253.1
4,253.1
4,253.1
0 0 0 0
2A 8,054.9 0 24,164.6 3,452.1
2B 11,506.9 0 24,164.6 0
2C 0 0 24,164.6 11,506.9
3 0 2,764.5 5,945.3 0
3.2.2 BHE Drilling Lengths
Based on the average geothermal potential in Kuujjuaq at different BHE lengths, the
annual thermal energy that can be extracted (Eg available) were 58.4 kWh/m for 100 m BHE,
66.3 kWh/m for 200 m BHE and 76.3 kWh/m for 300 m BHE. The drilling lengths (Ldrill)
for each type of heat pump were then calculated according to the required thermal energy
from the ground (Eg). For Case 2, the Eg available from a 300 m BHE was considered due to
the high Eg, while the Eg available from a 100 m BHE was used in Case 3. Based on this, the
drilling lengths required in Cases 2 and 3 were 316.5 m and 101.8 m, respectively.
3.2.3 Solar Panels Quantity
The energy generated by each solar PV panel (Es available) was calculated to be
309.9 kWh/year. The number of solar PV panels required (Ns) for Case 2A is 26 panels and
for Case 2B is 37 panels.
3.3 Life-Cycle Cost Analysis
The NPCs and LCOEs for all heating scenario were calculated to determine the most
viable alternative, if any, to building heating in Kuujjuaq that reduces both costs and CO2
emissions. Other factors that affect the NPC, such as cost of CO2 emission, payback period
and sensitivity analysis are also presented.
3.3 LIFE-CYCLE COST ANALYSIS 19
The average CO2 emission considered and determined from six heating oil companies
is 0.0902 tCO2/GJ (Appendix E). The cost of emission was then obtained by multiplying
this value with the price of carbon and included in the NPC calculations.
3.3.1 Economic Scenario 1
The results of the 50-years LCCA based on the current condition and values outlined
in the methodology are shown in Table 3.2. In this economic scenario, it is interesting to
note that the two options that emits the least CO2 have the lowest NPCs and LCOEs
(Fig. 3.3). A linear trend between CO2 emissions and NPC could also be observed; the
heating option emitting higher CO2 has higher 50-years total NPC (Fig. 3.3). Despite the
high capital costs incurred in Cases 2A and 2B, the low annual costs combined with the high
annual opportunity benefit make COMP with solar PV panels an economically attractive
building heating solution that also reduces CO2 emissions. Cases 2A and 2B are expected to
have a payback period comparable to the business-as-usual scenario within 11 and 12 years,
respectively, which can be considered fast for such major investment.
1
2A
2B
2C3
0.0
5.0
10.0
15.0
20.0
25.0
30.0
150K 170K 190K 210K 230K 250K 270K 290K
CO
2E
mis
sions
(t)
NPC ($)
Figure 3.3 NPC vs. CO2 emissions of different building heating scenarios.
20 CHAPTER 3: RESULTS
Table 3.2 Summary of costs, CO2 emissions, NPCs and LCOEs of 50-years LCC for business-as-usual and alternative heating scenarios.
Heating
Scenario
Capital
Cost ($)
Annual Costs ($) Periodic
Cost ($)
Parts
Replaced
Annual
Opportunity
Benefit ($)
CO2
Emissions
(t)
Annual Cost
of Emission
($)
Total
NPC ($)
LCOE
($/kWh) Energy Maintenance
1 5,063 16,595 1,059 1,041 Diesel tank
0 28.5 554 276,875 0.21 4,022 Diesel furnace
2A 158,324 8,634 849
4,354 Heat pump
9,819 18.0 350 203,153 0.13 1,041 Diesel tank
4,022 Diesel furnace
39,723 Solar PV panel
2B 175,348 8,634 849
4,354 Heat pump
9,819 14.8 288 179,433 0.15 1,041 Diesel tank
4,022 Diesel furnace
56,747 Solar PV panel
2C 118,601 18,530 849
4,354 Heat pump
9,819 25.5 495 258,500 0.21 1,041 Diesel tank
4,022 Diesel furnace
3 44,484 14,246 849
4,335 Heat pump
2,897 24.5 475 231,459 0.19 1,041 Diesel tank
4,022 Diesel furnace
3.3 LIFE-CYCLE COST ANALYSIS 21
Sensitivity analyses of key inputs revealed that the most sensitive cost item for all
heating equipment were either the energy cost or capital cost (Fig. 3.4). Variations on the
periodic costs and maintenance cost appear to have little effect on the NPC of the LCC of
the heating options. The energy cost is more sensitive than the capital cost for heating
options that rely heavily on diesel fuel (Cases 2C and 3). For these heating options, the high
energy cost, which is heavily influenced by the transportation cost to the north, affects the
NPC more than the capital cost, which includes the cost of the heating equipment and BHE
drilling in the case of GSHP heating.
K
100K
200K
300K
400K
-30% -20% -10% 0% 10% 20% 30%
NP
C (
$)
Variation in Parameter
Case 1: Sensitivity Analysis
K
50K
100K
150K
200K
250K
-30% -20% -10% 0% 10% 20% 30%
NP
C (
$)
Variation in Parameter
Case 2A: Sensitivity Analysis
22 CHAPTER 3: RESULTS
Figure 3.4 Sensitivity analyses of key parameters in all building heating options
based on Economic Scenario 1.
K
50K
100K
150K
200K
250K
-30% -20% -10% 0% 10% 20% 30%
NP
C (
$)
Variation in Parameter
Case 2B: Sensitivity Analysis
K
100K
200K
300K
400K
-30% -20% -10% 0% 10% 20% 30%
NP
C (
$)
Variation in Parameter
Case 2C: Sensitivity Analysis
K
100K
200K
300K
400K
-30% -20% -10% 0% 10% 20% 30%
NP
C (
$)
Variation in Parameter
Case 3: Sensitivity Analysis
3.3 LIFE-CYCLE COST ANALYSIS 23
Figure 3.5 Range of accumulated NPCs based on worst to best BHE drilling costs
compared to that of business-as-usual heating scenario.
3.3.2 Economic Scenario 2
As for many development projects, there is typically an initial need to develop
industrial policies that promote supporting businesses in the area. The purpose of this
economic scenario is to reveal whether there is a need to support the northern drilling
industry to make the cost of drilling more economical. LCCs for the heating scenarios were
calculated based on best ($50/m), moderate ($175/m) and worst ($300/m) drilling costs
(Fig. 3.5). Figure 3 shows that regardless of the drilling costs, switching to any type of GSHP
is always more economically attractive and will payback within 50 years in respect to the
business-as-usual scenario. Cases 2A and 2B present the largest savings from the business-
as-usual scenario. However, with the best drilling cost at $50/m, the paybacks for these two
cases are expected to significantly decrease to within 3 and 4 years, respectively. Thus, a
policy to support the growth of drilling industry to lower drilling cost in the north could be
beneficial, especially when considering a COMP as an alternative heating system in
Kuujjuaq.
Compression heat pump: 70% electricity from solar panels
Compression heat pump: 100% electricity from solar panels
Absorption heat pump: runs of diesel
Compression heat pump: 100% from diesel power plant
24 CHAPTER 3: RESULTS
3.3.3 Economic Scenario 3
This economic scenario analyses an incentive scheme in which the government covers
half of the current drilling cost ($300/m), as well as the GSHP and/or solar PV panels costs,
while subsidy on electricity and diesel remain. The purpose of this analysis is to calculate a
scenario in which the home-owner still has the option to use a diesel furnace, although a
GSHP heating system has been introduced. Additionally, while the total NPCs remain the
same for all cases as in ‘Economic Scenario 1’, this scenario helps in analysing the
breakdown of burden on home-owner and government.
In this scenario, Case 3 presents savings for both home-owner and government
compared to business-as-usual heating (Table 3.3). However, when analysing the total NPC,
Cases 2A and 2B present optimum options that cut costs from the business-as-usual Case 1
and distribute these costs most evenly between home-owner and government.
Table 3.3 Total 50 years NPCs for home-owner and government based on Economic
Scenario 3.
Heating
Scenario
Total NPC for
Home-Owner ($)
Total NPC
Government ($)
1 220,022 56,854
2A 110,123 93,029
2B 114,499 64,934
2C 95,205 163,294
3 179,924 51,534
3.3.4 Economic Scenario 4
Economic scenario 4 was modified from ‘Economic Scenario 3’, the only difference
being that the subsidy on electricity and diesel were eliminated, such that home-owners will
pay the unsubsidised cost of diesel fuel and/or electricity. The purpose of this analysis is to
analyse the role of subsidy in the distribution of the costs of building heating between home-
owner and government.
When a heating option consumes more fossil fuel, the distribution of costs between
home-owner and government becomes more uneven, with a higher proportion of the burden
falling on the hands of the home-owner (Table 3.4). Therefore, as long as the costs of energy
remain high in Kuujjuaq, any heating option that consume more fossil fuel and emit more
CO2 will result in higher annual costs and hence, become less economically attractive.
Table 3.4 Total 50 years NPCs for home-owner and government based on Economic
Scenario 4.
Heating Scenario Total NPC for
Home-Owner ($)
Total NPC for
Government ($)
1 268,646 8,232
3.3 LIFE-CYCLE COST ANALYSIS 25
2A 149,941 53,211
2B 116,471 62,962
2C 228,039 30,460
3 214,783 16,676
3.3.5 Economic Scenario 5
This economic scenario analyses a government incentive scheme after the northern
drilling industry has been developed such that the cost of drilling is the same as that in the
south at $50/m. In this scenario, the government still covers 50% of GSHP and/or solar PV
panels costs, although the home-owner is fully responsible for the cost of drilling. Subsidies
on electricity and diesel are also eliminated to encourage the switch to a cleaner heating
alternative. Previous sensitivity analyses (Fig. 3.4) have shown energy and capital to be the
most sensitive cost items in Cases 2A and 2B. Thus, the purpose of this economic scenario
is to analyse the effect of eliminating subsidy on diesel and electricity and lower BHE
drilling cost in the north and shed light on the potential of GSHP as an optimum building
heating solution in northern remote communities that can reduce both costs and CO2
emissions.
Although Case 2C brings profit to the government, the cost to the home-owner is
relatively high (Table 3.5). Business-as-usual and Case 3 are not the most viable due to the
high costs incurred to the home-owners and the high LCOEs. Again, Cases 2A and 2B have
the lowest LCOEs and total NPCs and hence, are more economically attractive compared to
the business-as-usual and other heating options (Appendix G). Additionally, this economic
scenario results in lower total NPCs for Cases 2 and 3 as compared to Economic Scenario 1,
which analyses NPCs based on the current conditions. This means that the development of
northern drilling industry and such government incentive are predicted to be efficient in
reducing total LCCs for any GSHP systems listed in this paper.
Table 3.5 Total 50 years NPCs for home-owner and government, and total LCOE
based on Economic Scenario 5.
Heating Scenario Total NPC for
Home-Owner ($)
Total NPC for
Government ($)
LCOE
($/kWh)
1 268,646 8,232 0.21
2A 117,550 4,625 0.10
2B 84,080 14,375 0.08
2C 195,648 -18,126 0.15
3 204,369 1,055 0.17
Both Cases 2A and 2B utilises the COMP as the main heating equipment, the only
difference being the proportion of electricity that comes from solar PV panels. The optimal
26 CHAPTER 3: RESULTS
proportion of electricity coming from solar PV panels is illustrated in Figure 3.6. Increasing
the proportion of electricity coming from solar PV panels reduces the cost of heating for the
home-owner more than it increases for the government. Additionally, when all electricity
required for the COMP comes from solar PV panels, the total NPC and CO2 emissions
become lower than other combinations. Below 56%, the government would have a negative
total NPC in 50 years of its lifetime, which means positive cashflow or revenue through
selling surplus diesel in the commodity market, but higher total NPC for the home-owner.
At 56% the government breaks even. However, for COMP to be an economically more
attractive option for the government than the business-as-usual heating scenario, the
proportion of electricity coming from solar PV panels needs to be below 80% (Fig. 3.6).
Figure 3.6 Optimisation to determine the best proportion (%) of electricity coming
from solar panels to run a COMP for building heating in Kuujjuaq.
0
5
10
15
20
25
30
-50K
K
50K
100K
150K
200K
250K
300K
0 10 20 30 40 50 60 70 80 90 100
CO
2 E
mis
sions
(t)
Tota
l N
PC
($)
% Electricity from Solar PV Panels
COMP, Home-Owner COMP, Government
Diesel Furnace, Home-Owner Diesel Furnace, Government
CO2 Emissions
3.3 LIFE-CYCLE COST ANALYSIS 27
Chapter 4
4Discussion
One of the limitations of this study arose from the assumption that the COPs of the
GSHP systems considered remain constant throughout all seasons and years. This COP
assumption is conservative since it is based on the minimum water temperature leaving the
BHE for the 50-years period considered in the G.POT calculation. It was also assumed that
the GSHPs operate only in heating mode and there is no cooling requirement in the region
[15]. Thus, further study on the actual performances of COMP and ABS operating in the
area would be required to more accurately predict the project’s viability. Additionally, the
average annual solar PV potential in Kuujjuaq was used in calculating the number of solar
panels required in the COMP heating scenario as a simplification, as a detailed solar analysis
was not within the scope of this study. Future study could therefore focus on the economics
of using battery storage versus sizing the solar panels according to the monthly solar PV
potential in Kuujjuaq. Moreover, although the LCCA is not a useful tool for budget
allocation, it is a straightforward way to compare the profitability or for capital budgeting.
Social acceptability and level of implementation effort, such as those measured in Yan et
al.’s study was not considered and could be a subject of future research [6].
In 2012, Majorowicz and Grasby [49] conducted an initial assessment of the potential
of geothermal energy development in northern Canadian communities, showing that there
is enough energy to heat northern communities at competitive cost in Mackenzie Corridor
areas and Yukon for 3-5 km and 6 km wells depths. Specifically, their study concerns high-
temperature or deep geothermal resources, which is defined as heat obtained from
geothermal fluid with temperatures above 150°C. Deep geothermal resources are commonly
utilized to drive turbines in geothermal power plants to generate electricity. Low-
temperature or shallow geothermal resources on the other hand, deals with geothermal fluid
temperatures of 150°C and less. Shallow geothermal resources are typically used in direct-
use applications, such as for heating, greenhouses and fish-drying facilities. Thus, this study
attempted to further Majorowicz and Grasby’s work [49] by investigating the shallow
geothermal potential of Kuujjuaq, another northern Canadian community in Nunavik.
As far as the author’s knowledge and apart from this study, only Yan et al. [6] has
investigated alternative heating systems for Kuujjuaq. Their study disqualified geothermal
technology due to climate limitations, electricity production and economical issues. Instead,
they analysed waste gasification and combustions of fuel oil, wood pellets and natural gas,
with wood pellets ranking first in their analysis. However, since there is no local supply for
wood pellets, they need to be imported to the area [6]. In addition to this present study
showing a relatively high shallow geothermal potential in the area, as well as the economic
viability of the GSHP system, the Cold Climate Housing Research Centre [10] installed a
pilot GSHP system with horizontal BHE in 2013 in Fairbanks, Alaska, which also has a
similar, subarctic climate as Kuujjuaq and demonstrated that GSHP operation is feasible in
such climate. Therefore, GSHP as a heating alternative should not be quickly dismissed.
Consistent with the results from Pike and Whitney’s [9] study on the costs and
performance of seven GSHPs currently installed in Alaska, heat pumps are viable heating
28 CHAPTER 4: DISCUSSION
technology for colder climates. The economic benefit of GSHP system, however, depends
heavily on the costs of energy (fuel and electricity) in the area. Similar conclusion was
achieved in this study; sensitivity analyses for various GSHP heating options in Kuujjuaq
demonstrated that the costs of energy form one of the most critical factor that influences the
system’s economic viability. In Alaska, although the costs of fuel oil and natural gas are
relatively high, the cost of electricity is low [9]. For Kuujjuaq, a combination of solutions
was considered and COMP with electricity from solar PV panels was found to be the most
economically attractive option, as the costs of both fuel and electricity are high in this region.
One of the challenges of operating GSHPs in cold regions pertain to the soil thermal
imbalances. You et al.’s study [50] proposed solutions addressing each of these challenges
through modifications on BHE, system design and operation design. Additionally, although
previous studies have proven successful utilisation of GSHP technology in various cold
regions worldwide, none have studied its application and economic feasibility in remote
subarctic region [7-14]. This study attempted to address this gap. Furthermore, the G.POT
method [15], which considered a sustainable resource extraction was successfully applied to
estimate the shallow geothermal potential in Kuujjuaq, enabling a long-term prediction of
GSHP economic performance in such climate and community. Finally, this study proposed
a viable alternative to building heating in Kuujjuaq of using COMP with electricity derived
from solar PV panels, thereby providing a solution to help this community achieve energy
security and independence using a locally-generated and sustainable resource.
3.3 LIFE-CYCLE COST ANALYSIS 29
Chapter 5
Conclusion
Presently, Nunavik‘s remote northern communities are heavily dependent on fossil
fuel to meet their heating demands, which incurs high costs, energy dependence and net CO2
emissions. This study focused on the economic attractiveness and emissions reduction
potential of ground-source heat pump (GSHP) as an alternative heating source. The heating
options analysed in this study were:
1. Case 1: Business-as-usual using diesel furnace
2. Case 2A: Compression GSHP with 70% of electricity derived from solar photovoltaic
(PV) panels and 30% from diesel power plant
3. Case 2B: Compression GSHP with 100% of electricity derived from solar PV panels
4. Case 2C: Compression GSHP with 100% of electricity derived from diesel power
plant
5. Case 3: Absorption GSHP customised to run on diesel
Maps of the shallow geothermal potential of Kuujjuaq were created based on
laboratory measurements of the subsurface thermal conductivity samples, field measurement
of the subsurface temperature and using a GIS-based workflow to estimate the maximum
amount of energy that can be extracted with a GSHP system operating in cold temperatures.
The resulting maps show that the average geothermal potential in Kuujjuaq is relatively high
for such cold region, ranging between 5.8 MWh/year and 22.9 MWh/year, and that it
increases more than linearly with borehole depths. These maps provide a useful tool for
planners to identify the most suitable location for future GSHP installations and serve as a
crucial first-step towards calculating the total drilling costs for the borehole heat exchanger
(BHE). The annual heating load of a typical residential building in Kuujjuaq was then
modeled using local weather data to determine the energy consumptions for each heating
options considered.
50-years life-cycle cost analysis (LCCA) based on current costs and conditions
(Economic Scenario 1) revealed that all GSHP heating options are economically more
attractive compared to the diesel furnace heating currently being used. However,
compression GSHP with electricity derived from solar PV panels (Cases 2A and 2B)
presents the most environmentally friendly and economically attractive heating option. Such
outcome was partially driven by the fact that surplus diesel obtained from switching to
GSHP system can now be sold to the commodity market, serving as a government revenue.
Cases 2A and 2B save up to $97,442 in total net present cost (NPC) and have a maximum
payback within 12 years –depending on the proportion of electricity derived from solar PV
panels– when compared to the business-as-usual heating scenario. A positive linear trend
between CO2 emissions and NPCs of the heating options further indicates the long-term
viability of GSHP technology in reducing emissions.
However, consistent with the results of previous studies, energy and capital costs form
the most sensitive cost items for all heating options, implying that in addition to the high
30 CHAPTER 5: CONCLUSION
capital costs incurred from BHE drilling in the case of GSHP heating and the cost of
equipment itself, the economic feasibility of any heating system in Kuujjuaq depends
heavily on the source and cost of energy used in the area [9,10,11]. Varying the drilling cost
from the current price in Kuujjuaq at $300/m to the current price in the south at $50/m
revealed a significant reduction in total NPC and payback periods for Cases 2A and 2B
heating options. This shows that without the appropriate government policy to supports the
drilling industry in the north or the government incentive to alleviate the cost burden from
the hands of the home-owner, it would be challenging to initiate such project.
The best economic outcome was thus obtained in Economic Scenario 5 when the cost
of BHE drilling was reduced to $50/m and government provides incentive by covering 50%
of GSHP and/or solar PV panels costs, but subsidies on energy are eliminated and the home-
owner is fully responsible for the drilling cost. In this scenario, Cases 2A and 2B present the
lowest levelised cost of energy (LCOE) and total NPC for both government and home-owner
alike, compared to all other economic scenarios. This scenario results in lower LCOEs at
$0.10/kWh and $0.08/kWh for Cases 2A and 2B, as compared to those of economic
scenario 1 at $0.13/kWh and $0.15/kWh. In comparison, the LCOE for business-as-usual
diesel furnace heating for all economic scenario is $0.21/kWh. In terms of total NPCs for
both government and home-owner, Cases 2A and 2B save up to $178,423 compared to diesel
furnace heating.
Finally, higher proportion of electricity derived from solar PV panels will result in
lower total NPCs and LCOEs for compression GSHP heating option. However, 80% was
determined to be the maximum cut-off for this technology as an economically more
attractive heating solution for the government compared to the diesel furnace. The optimum
proportion depends on factors such as governmental budget, availability of grants and
capital. In any case, compression GSHP with a proportion of electricity derived from solar
PV panels remains the most economically attractive option that offsets CO2 emissions
compared to a diesel furnace heating based on the conditions listed in this study.
Chapter 5
31
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https://markets.businessinsider.com/commodities/rbob-gasoline
[48] Freyman, T., & Tran, T. (2018, January). Renewable Energy Discount Rate Survey Results
2017 (Rep.). Retrieved https://www.grantthornton.ie/globalassets/1.-member-
firms/ireland/insights/publications/grant-thornton---renewable-energy-discount-rate-survey-
2017.pdf
[49] Majorowicz, J., & Grasby, S. E. (2014). Geothermal energy for northern Canada: Is it
economical? Natural Resources Research, 23(1), 159-173. doi:10.1007/s11053-013-9199-3
[50] You, T., Wu, W., Shi, W., Wang, B., & Li, X. (2016). An overview of the problems and
solutions of soil thermal imbalance of ground-coupled heat pumps in cold regions. Applied
Energy, 177, 515-536. doi:10.1016/j.apenergy.2016.05.115
[51] OpenEI. (2017). Building Characteristics for Residential Hourly Load Data (Rep.).
Retrieved September 26, 2018, from National Renewable Energy Laboratory website:
https://openei.org/doe-opendata/dataset/eadfbd10-67a2-4f64-a394-
3176c7b686c1/resource/cd6704ba-3f53-4632-8d08-
c9597842fde3/download/buildingcharacteristicsforresidentialhourlyloaddata.pdf
[52] BC Hydro. (n.d.). Reference Guide for Lighting Calculator Version 2.7 (Rep.). Retrieved
September 27, 2018, from BC Hydro website:
https://www.bchydro.com/content/dam/hydro/medialib/internet/documents/psbusiness/pdf/ps
_business_-_hpb-eeld.pdf
[53] Goldner, F. S., & Price, D. C. (1994). Domestic Hot Water Loads, System Sizing and
Selection for Multifamily Buildings. American Council for an Energy Efficient Economy
35
Summer Study Proceedings,2. Retrieved September 27, 2018, from
https://aceee.org/files/proceedings/1994/data/papers/SS94_Panel2_Paper12.pdf
[54] ASHRAE. (2013). ASHRAE Standard: Ventilation for Acceptable Indoor Air Quality
(Rep.). Retrieved September 27, 2018, from American Society of Heating, Refrigerating and
Air-Conditioning Engineers, Inc website: http://arco-hvac.ir/wp-
content/uploads/2016/04/ASHRAE-62_1-2010.pdf
[55] RDH Building Engineering Ltd. (2013). Air Leakage Control in Multi-Unit Residential
Buildings: Development of Testing and Measurement Strategies to Quantify Air Leakage in
MURBS (Rep. No. 5314). Retrieved September 27, 2018, from RDH Building Engineering
Ltd website: https://rdh.com/wp-content/uploads/2014/04/Air-Leakage-Control-in-Multi-
Unit-Residential-Buildings.pdf
[56] Déry, S., & Zoungrana, H. (2009, December). The Housing Situation in Nunavik: A
public health priority (Rep.). Retrieved September 27, 2018, from Nunavik Regional Board of
Health and Social Services website:
http://www.krg.ca/images/stories/docs/Parnasimautik/Annexes/ENG/Annex 4 The housing
situation in Nunavik a public health priority eng.pdf
36
APPENDIX A
Detailed Steps for Shallow Geothermal
Potential Data Processing and Mapping
A.1 Depths of Unconsolidated Sediments
The outcrops of bedrock from the unconsolidated sediments map was first extracted
to create a new polygon layer that showed only the outcrops. Using the unconsolidated
sediments shapefile, the “extract nodes” vector geometry tool was used to draw points along
the outline of the outcrops. These points were assigned depth values of zero, referring to the
absence of unconsolidated sediments in areas where there are outcrops. The resulting point
vector layer was then combined with the data of depths of unconsolidated sediments
obtained from the field study to produce a new layer (Fig. A1).
Figure A1. Bedrock limits (1), point layer of bedrock depths (2) and point layer of the
combined depths of unconsolidated sediments and the extracted bedrock depths (3).
The combined depths data, along with their respective coordinates were then extracted
from the attribute table, saved in Microsoft Excel (2016) .CSV format and imported to create
a grid file using the Surfer® 9 (Surfer) software [22]. Surfer contains an internal algorithm
that takes the irregularly spaced XYZ data and uses it to create an interpolated, regularly
37
spaced grid file. Each point will have its respective XY location and has a Z value or in this
case, depth value associated with it.
The Inverse Distance Weighting (IDW) interpolation method with 100 x 100 m grid
spacing was first tested. This interpolation method assumes that nodes that are close by are
more similar than those further apart. Therefore, the nodes closest to the unknown point have
more weight on the point than those further away. As a result, shadows of the data points
can be seen on the contour map and the resulting map does not best represent the real
environment due to the presence of the shadows (Fig. A2). Hence, the IDW interpolation
method was not chosen.
Next, the Triangulation with Linear Interpolation (TIN) method with 100 x 100 m grid
spacing was tested. This method draws lines between data points to create triangles, with no
triangles intersecting each other. Although the resulting map appeared smoother than the
IDW interpolated map, this method was also not chosen as the resulting maps contain jagged
lines that again, do no best represent the real environment. Additionally, this algorithm
produced a maximum outlier value of 1.70 x 1023 m, even after the values were limited to
the study area.
Figure A2. Interpolated depths of unconsolidated sediments in Kuujjuaq with IDW (left)
and TIN (right) methods at 100 x 100 m grid spacing.
The Kriging method was finally chosen to interpolate the depths of unconsolidated
sediments. This method can compensate for clustered data as it gives less weight to the
cluster during interpolation. Additionally, each grid point is calculated based on the known
data points of neighbouring node and is weighted by its distance away from the node.
Therefore, points that are further from the node will also have less weight in the node
estimation. Three grid spacing options, 100 x 100 m, 300 x 300 m and 400 x 400 m were
tested, and the results compared with each other. Visually, the 100 x 100 m spacing contour
map produced the smoothest contour lines, while the 400 x 400 m spacing map resulted in
more jagged lines (Fig. A3). The interpolated results were then filtered to show only values
that fall within the study area and compared to each other (Table A1).
38
Figure A3. Surfer maps with contour lines of unconsolidated sediments depths
interpolated with Kriging method using three grid spacing options.
Table A1. Comparison of depth interpolation results with Kriging method using three
different grid spacings.
Comparison 100 x 100 m 300 x 300 m 400 x 400 m
Lowest interpolated value -4.00 -1.80 -3.22
# Negative data points 930 86 40
# Total data points 4,995 536 309
Negative values (%) 18.6 16.0 12.9
The 300 x 300 m grid spacing interpolation method produced the least negative outlier
(Table A1). Although it still has a larger percentage of negative values than the 400 x 400
m grid spacing interpolation, the resulting contour map using the 300 x 300 m grid spacing
has smoother contour lines. Therefore, the Kriging method with 300 x 300 m grid spacing
was selected. The Kriging results were then imported back as a point layer in QGIS 2.18.21
(QGIS) (Fig. A4) [21].
Figure A4. QGIS point layer of quaternary deposits depth data interpolated with Kriging
and 300 x 300 m grid spacing in Surfer.
A.2 Weighted Thermal Conductivity and Heat Capacity
The geological and unconsolidated sediments map layers were modified to include the
thermal conductivity and heat capacity data from Table 2.1. The point layer as shown in
39
Figure A4 was then duplicated. The “Point Sampling Tool” plugin in QGIS was used to
apply the thermal conductivity and heat capacity values from the bedrock geology and
unconsolidated sediments maps to the corresponding points in the duplicated layer. Thus,
four new point layers, such as in Figure A4 were generated for: 1) Unconsolidated sediments
thermal conductivity, 2) unconsolidated sediments heat capacity, 3) bedrock geology
thermal conductivity, 4) and bedrock geology heat capacity.
The ground thermal properties, along with their respective coordinates value were
imported from the attribute table and viewed in an Excel document. The weighted thermal
conductivity and heat capacity values were calculated for 100 m, 200 m and 300 m BHE
lengths scenarios based on Equation 2.5.
A.3 G.POT Calculations and Mapping
The shallow geothermal potential of Kuujjuaq is calculated for each BHE length
scenario by applying Equation 2.1 in Excel. The calculated G.POT values for each scenario,
along with their respective coordinates where then opened in Surfer as contour maps. The
Kriging interpolation option with 100 x 100 m grid spacing was selected to image the
geothermal potential of the area.
With Kriging interpolation in Surfer, the resulting maps are always extrapolated
beyond the study area. To limit the results to the study area, a .BLN file, which records the
boundary coordinates of the study area was created (Fig. A5). The “Blank” function in Surfer
is then used to crop the maps according to the boundary recorded in the .BLN file. The
contours property and colours were then adjusted for visualisation purposes.
Figure A5. A sample of the .BLN file used to create the study area limits (left) and the
resulting limits viewed in Surfer used to clip the results to show only the study area (left).
Kuujjuaq
Koksoak River
40
APPENDIX B
5SIMEB Calibration
B.1 Calibration
To calibrate the parameter input for SIMEB, an Excel dataset containing hourly energy
load profile for a typical residential building in Anchorage, Alaska, US was downloaded
from the Office of Energy Efficiency and Renewable Energy (EERE) website [51]. This data
represents the current, annual energy usage for a typical house in Anchorage, in which SH
and DHW requirements are met with natural gas [51]. According to the “2014 Building
America House Simulation Protocol”, the efficiency of natural gas heating equipment is
78%. To obtain the heating load for the building and for future comparison purposes, the
data was modified to assume building heating with electric equipment, which has an
efficiency of 100% (Table B1).
Table B1. Monthly energy load profile of a typical residential building in Anchorage
obtained from EERE [3] website and modified to assume building heating with electric
equipment.
Month Interior
Lights
Outdoor
Lights Heating Equipment
HVAC
Fans DHW Total
(in kWh)
January 210 46 9,607 525 206 822 11,415
February 165 36 8,566 476 184 757 10,185
March 155 34 7,857 488 169 827 9,530
April 122 27 5,236 473 112 773 6,743
May 110 24 3,168 477 68 691 4,538
June 99 21 1,487 433 32 662 2,734
July 105 23 892 448 19 641 2,128
August 117 26 0 424 0 535 1,101
September 136 30 1,859 434 40 613 3,112
October 170 37 4,984 476 107 669 6,442
November 195 42 7,358 459 158 697 8,909
December 216 47 8,855 512 190 705 10,525
Total 1,799 392 59,868 5,625 1,286 8,392 77,361
Two documents, 1) “2014 Building America House Simulation Protocols”, which
describes simulation protocols for various building types and 2) List of key parameters used
by the authors to create the Anchorage residential building energy profile were used to obtain
the parameters inputs required to replicate similar energy profile in SIMEB [26,27]. Table
B2 records the parameters inputs to simulate residential building energy load in Anchorage
41
using SIMEB. The building is a 252 m2, one-floor residential house with an approximate
dimension of 21 m x 12 m and wall height of 2.5 m. An unfinished basement with wall
height of 2.4 m, with the same area as the main dwelling. The building occupancy and usage
schedule were then adjusted until similar energy load profiles were achieved.
Table B2. SIMEB parameter inputs to simulate a typical residential building heating
load in Anchorage.
Parameter Values Source Remarks/Calculation
Building azimuth North, 0°
Type of construction Medium
Thermal envelope
Uniform roof insulation 8.63 RSI [27]
Uniform wall insulation 3.87 RSI [27]
Uniform basement wall
insulation
2.4 m (8 ft) RSI
2.64 (R-15) ext.,
Concrete
[27]
Fenestration
Other (U: 1.99
W/m2K; SHGC:
0.44)
[27]
Outdoor lighting capacity 0.1 kW [52]
From [52], canopies and overhangs
= 1.3 W/ft2 = 13.99 W/m2
Assuming 0.3 m overhangs on all
sides and only 2 sides have lights,
surface area of overhangs = (21 ×
0.3) + (12 × 0.3) = 9.9 m2
Hence, lighting on overhang =
13.99 W/m2 × 9.9 m2 = 138.501 W
= 0.1 kW
DHW
Type of water heater Electrical
Typical residential buildings in
Anchorage uses natural gas.
Electricity input chosen to obtain
maximum energy demand
Efficiency 100%
Maximum load 6.21 W/m2 [52,27]
From [52], medium DHW usage in
peak hour = 5 gal/person
From [27], number of occupants =
0.59 × Nbedroom + 0.87 = 0.59 × 3 +
0.87 = 3 occupants
Hence, maximum load = 15
gal/hour = 1.58 x 10-5 m3/s
42
From [27], water heater set off =
125°F = 51.7°C
Specific heat capacity, 𝑄 =𝑚𝐶∆𝑇 = 𝜌𝑉𝐶∆𝑇. Hence, Q = 997
kg/m3 x 1.58 ×10-5 m3/s × 4185.5
J/kg°C × (51.7 – 4) °C = 3145 J/s =
3145 W
Dividing by the total floor area,
maximum DHW load = 3145 W ÷
504 m2 = 6.21 W/m2
Central HVAC system
Type Single zone: single
supply duct system
Preheating None
Heating Electricity
Typical residential buildings in
Anchorage uses natural gas.
Electricity input chosen to obtain
maximum energy demand
Heating coil capacity Autosized Default
SIMEB
Heating equipment
efficiency 100%
Cooling None
Humidification None
Ventilation
Supply flow 154 l/s [54]
From [54], minimum ventilation
rate in residential dwelling unit =
0.06 CFM/ft2. Hence, flow = 0.06
CFM/ft2 x 5425 ft2 = 326 CFM =
154 l/s
Static pressure 0.32 kPa Default
SIMEB
Regulation
Minimum supply
temperature 21.1°C [27]
Maximum supply
temperature 24.4°C [27]
Envelope (Basement)
Exterior walls infiltration 0.25 l/s/m2 Default
SIMEB
Default is chosen to reflect the low
basement occupancy.
Type of contact with ground Slab on ground Houses in Kuujjuaq have crawl
space foundation
Envelope (Dwelling unit)
43
Exterior walls infiltration 2.92 l/s/m2 [55]
Anchorage is in climate zone 7.
From source, residential buildings in
climate zone 7 ACH50 = 2.75
Volume of house = 12 m x 21 m x
2.5 m = 630 m3 = 22248.2 ft3
ACH = 60 CFM ÷ Volume. Hence,
CFM = 1019.71 = 481.25 l/s
Surface area of exterior walls = (2 x
12 m x 2.5 m) + (2 x 21 m x 2.5 m)
= 165 m2. Hence, specific
infiltration = 481.25 l/s ÷ 165 m2 =
2.92 l/s/m2
Type of contact with ground Basement
Lighting and plug loads (Basement)
Lighting density 2.15 W/m2 [52]
Plug loads 0.00 W/m2 Unfinished basement
Lighting and plug loads (Dwelling unit)
Lighting density 3.23 W/m2 [52]
Plug loads 4.95 W/m2 Default
SIMEB
Processes (Basement)
Power 0.0 kW Unfinished basement
Energy source -
Sensible heat -
Latent heat -
Processes (Dwelling unit)
Power 0.4 kW [27]
Assuming the house is equipped
with refrigerator, clothes washer
with 3.2 ft3 drum, electric cooking
range and miscellaneous equipment,
and there are no dryer and
dishwasher
From [27], electricity usage for:
Refrigerator = 434 kWh/year
Cooking range = 499 kWh/year
Clothes washer = 77.5 kWh/year
Miscellaneous = 2590.65 kWh/year
Total = 3601.245 kwh/year = 0.4
kW
44
Energy source Electrical
Sensible heat 86.20% [27]
From [27], sensible load fraction
for:
Refrigerator = 1.00
Cooking range = 0.40
Clothes washer = 0.80
Miscellaneous = 0.93
Total sensible load = (434 x 1.00) +
(499 x 0.4) + (77.5 x 0.80) +
(2590.65 x 0.93) + 3104.90
kWh/year
% sensible heat = (3104.90
kWh/year ÷ 3601.245 kwh/year) x
100% = 86.2%
Latent heat 5.60% [27]
From [27], latent load fraction for:
Refrigerator = 0.00
Cooking range = 0.30
Clothes washer = 0.00
Miscellaneous = 0.02
Total latent load = 201.51 kWh/year
% latent load = (201.51 kWh/year ÷
3601.245 kwh/year) x 100% = 5.6%
HVAC (Basement)
Central HVAC None
Perimeter Heating Electric baseboard
HVAC (Dwelling unit)
Central HVAC Yes
Perimeter heating Electric baseboard
Occupation
Occupation density 84.01 m2/occupant
As determined in previous equation,
number of occupants = 3 people.
Hence, occupation density = 252 m2
÷ 3 occupants = 84 m2/occupant
Sensible heat 64.5 W/occupant [27]
Latent heat 48.1 W/occupant [27]
Outside air (basement) 0.300 l/s/m2 Default
SIMEB
Per area unit default is chosen to
reflect the low basement occupancy
Outside air (dwelling unit) 2.360 l/s/occupant [54]
45
B.2 DHW Usage Schedule
46
Figure B1. DHW usage schedule for Monday-Friday (top), Saturday (middle) and
Sunday (bottom).
B.3 Occupancy Schedule
47
Figure B2. Building occupancy schedule for Monday-Friday (top) and Saturday-
Sunday (bottom).
B.4 Results of the Calibration
Using these parameters inputs, a total annual energy load of 77,734 kWh was obtained
(compared to the total annual energy load of 77,361 kWh from the original simulation done
by EERE). Table B3 shows the calibration results in SIMEB. Figure B3 shows the
comparison between the calibration results and the data obtained from EERE.
Table B3. Monthly energy load profile of a typical residential building in Anchorage
based on the calibration results in SIMEB.
Month Interior
Lights
Outdoor
Lights Heating
Plug loads
and Process Fans Pumps DHW Total
(in kWh)
January 190 46 8,553 545 87 37 719 10,177
February 172 36 7,887 492 78 34 648 9,348
March 192 37 8,623 545 87 37 722 10,242
April 185 30 5,113 528 84 36 690 6,664
May 101 25 2,483 545 87 23 719 3,983
June 99 24 1,113 528 84 5 698 2,550
July 102 25 562 545 87 1 713 2,035
August 101 31 724 545 87 3 719 2,210
September 100 33 1,567 528 84 13 692 3,016
October 190 40 6,231 545 87 37 719 7,850
November 184 42 7,659 528 84 36 696 9,228
December 192 50 8,805 545 87 37 716 10,431
Total 1,808 419 59,320 6,419 1,023 299 8,451 77,734
48
Figure B3. Comparison of SIMEB calibration results with building heating load profile
from EERE.
0
100
200
300
400
500
600
700
800
900
Load
(kW
h)
Month
Domestic Hot Water
SIMEB Simulation EERE Simulation
0
2000
4000
6000
8000
10000
12000
Load
(kW
h)
Month
Space Heating
0
2000
4000
6000
8000
10000
12000
Load
(kW
h)
Month
Total Heating Load
49
APPENDIX C
6Parameter Inputs to Simulate the Heating
Load of Residential Building in Kuujjuaq
Table C1. SIMEB parameter inputs to simulate a typical residential building heating
load in Kuujjuaq.
Parameter Values Source Remarks/Calculation
Building azimuth North, 0°
Type of construction Medium
Thermal Envelope
Uniform roof insulation 9 RSI [28]
Uniform wall insulation 5.11 RSI [28]
Fenestration
Double clear efficient
with argon - low-E (U:
2.16 W/m2K; SHGC:
0.5)
[28]
Outdoor lighting
capacity 0.1 kW [52] Same as calibration
DHW
Type of water heater Electrical [28]
Efficiency 100% [27]
Maximum load 20.69 W/m2 [53,56]
From [27], medium DHW
usage in peak hour = 5
gal/person
From [56], average occupants
of houses in Kuujjuaq = 5
people
Hence, maximum load = 25
gal/hour = 2.63 x 10-5 m3/s
From [53], water heater set
off = 125°F = 51.7°C
50
Specific heat capacity, 𝑄 =𝑚𝐶∆𝑇 = 𝜌𝑉𝐶∆𝑇. Hence, Q =
997 kg/m3 x 2.63 ×10-5 m3/s ×
4185.5 J/kg°C × (51.7 – 4) °C
= 5235 J/s = 5235 W
Dividing by the total floor
area, maximum DHW load =
5235 W ÷ 252 m2 = 20.69
W/m2
Central HVAC system
Type Single zone: single
supply duct system
Preheating None
Heating Electricity SIMEB has no option for oil
heating equipment
Heating coil capacity Autosized Default
SIMEB
Heating equipment
efficiency 100%
Cooling None
Humidification None
Ventilation
Supply flow 77 l/s [53]
From [53], minimum
ventilation rate in residential
dwelling unit = 0.06 CFM/ft2.
Hence, flow = 0.06 CFM/ft2 x
2712.5 ft2 = 163 CFM = 77 l/s
Static pressure 0.32 kPa Default
SIMEB
Regulation
Minimum supply
temperature 21.1°C [27]
Maximum supply
temperature 24.4°C [27]
Envelope
Exterior walls
infiltration 2.12 l/s/m2 [55]
Kuujjuaq is in climate zone 7.
From source, residential
buildings in climate zone 8
ACH50 = 2
Volume of house = 12 m x 21
m x 2.5 m = 630 m3 =
22248.2 ft3
51
ACH = 60 CFM ÷ Volume
Hence, CFM = 741.61 = 350
l/s
Surface area of exterior walls
= (2 x 12 m x 2.5 m) + (2 x 21
m x 2.5 m) = 165 m2. Hence,
specific infiltration = 350 l/s ÷
165 m2 = 2.12 l/s/m2
Type of contact with
ground No contact Houses in Kuujjuaq have
crawl space foundation
Lighting and plug loads
Lighting density 3.23 W/m2 [52]
Plug loads 4.95 W/m2 Default
SIMEB
Processes
Power 0.4 kW [27] Same as calibration
Energy source Electrical
Sensible heat 86.20% [27] Same as calibration
Latent heat 5.60% [27] Same as calibration
HVAC
Central HVAC Yes
Perimeter heating Hydronic
baseboard/radiator
Occupation
Occupation density 50.4 m2/occupant
As determined previously,
number of occupants = 5
people. Hence, occupation
density = 252 m2 ÷ 5
occupants = 50.4 m2/occupant
Sensible heat 64.5 W/occupant [27]
Latent heat 48.1 W/occupant [27]
Outside air 2.360 l/s/occupant [27]
Plant: Hot water loop
Type Boiler
Energy source Oil, with burner
modulation
Capacity Autosized Default
SIMEB
Efficiency 78% [27]
Temperature control Fixed temperature [27]
52
(setpoint: 51.7°C)
Pump flow control None
53
APPENDIX D
7COP Calculations
D.1 COP of Compression Heat Pump (COMP)
The ClimateMaster Model TCH/V120 was selected for the analysis [43]. An EWT vs.
COP table was provided in the product specification (Table D1).
Table D1. Entering water temperatures (EWTs) and their corresponding coefficient of
performances (COPs) [43].
EWT (°F) EWT (°C) COP
20 -6.7 3
30 -1.1 3.3
40 4.4 3.6
50 10.0 4
60 15.6 4.3
70 21.1 4.6
80 26.7 4.9
85 29.4 5
90 32.2 5.1
The values in Table D1 were graphed in Figure D1. Based on the graph, the COP of
this COMP operating in Kuujjuaq is 3.1.
Figure D1. Graph of ClimateMaster Model TCH/V120 COP vs. EWT.
y = 0.0554x + 3.3889
0
1
2
3
4
5
6
-10.0 0.0 10.0 20.0 30.0 40.0
CO
P
EWT (°C)
54
D.2 COP of Absorption Heat Pump (ABS)
The Robur Model GAHP-WLB was selected for the analysis [44]. The effectiveness
of an ABS is measured by its gas utilisation efficiency (GUE), which is the ratio of the
heating supplied to the building to the energy consumed by the compressor. Although an
EWT vs. GUE table was not provided in the product specification, the heating mode
capacity, gas input and chilled water temperature, which is the same as EWT are provided
(Table D2). The GUEs were calculated by dividing the heating mode capacity by the gas
input.
Table D2. Entering water temperatures (EWTs) and their corresponding gas
utilisation efficiencies (GUEs) [44].
Gas input: 95,500 BTU/h (28.0 Kw)
Chilled water inlet
temperature (°F)
Chilled water inlet
temperature (°C)
Heating Mode
Capacity
(BTU/h)
Heating Mode
Capacity (kW) GUE
32 0 119,400 35.0 1.3
41 5 124,600 36.5 1.3
50 10 128,400 37.6 1.3
59 15 131,000 38.4 1.4
68 20 132,400 38.8 1.4
77 25 132,900 38.9 1.4
The values in Table D2 were graphed in Figure D2. Based on the graph, the GUE of
this COMP operating in Kuujjuaq is 1.2.
Figure D2. Graph of Robur Model GAHP-WLB GUE vs. EWT.
y = -0.0002x2 + 0.011x + 1.2549
1.15
1.2
1.25
1.3
1.35
1.4
1.45
-10 -5 0 5 10 15 20 25 30
GU
E
Chilled water temperature (°C)
55
APPENDIX E
8CO2 Emissions
Table E1. CO2 emissions intensity of six heating oil companies in North America.
Company Emissions (in gCO2/MJ) Emissions (in tCO2/GJ)
US Wyoming WC 86 0.086
US Bakken No Flare 87 0.087
Canada Hibernia 88 0.088
US Texas Spraberry 90 0.09
US Texas Eagle Ford
Black Oil Zone 91 0.091
US Bakken Flare 99 0.099
Average 90.2 0.0902
56
APPENDIX F
9Monthly Heating Load of a Typical
Residential Building in Kuujjuaq
0100020003000400050006000700080009000
Lo
ad (
kW
h)
Month
Space Heating
0100020003000400050006000700080009000
10000
Load
(kW
h)
Month
Total Heating Load
57
Figure F1. Typical residential building space heating and domestic hot water load
profiles in Kuujjuaq.
100010201040106010801100112011401160118012001220
Lo
ad (
kW
h)
Month
Domestic Hot Water
58
APPENDIX G
10NPCs Based on Financial Scenario 5
Figure G1. Accumulated NPCs of building heating options for home-owner and
government based on Economic Scenario 5 over 50 years LCC.
K
50K
100K
150K
200K
250K
300K
2018
2020
2022
2024
2026
2028
2030
2032
2034
2036
2038
2040
2042
2044
2046
2048
2050
2052
2054
2056
2058
2060
2062
2064
2066
2068
Acc
um
ula
ted
NP
C (
$)
Year
Home-Owners
-25K
-20K
-15K
-10K
-5K
K
5K
10K
15K
20K
25K
30K
20
18
20
20
20
22
20
24
20
26
20
28
20
30
2032
2034
20
36
20
38
20
40
20
42
20
44
20
46
20
48
20
50
20
52
20
54
20
56
20
58
20
60
20
62
20
64
20
66
20
68
Acc
um
ula
ted N
PC
($)
Year
Government
Case 1 Case 2A Case 2B Case 2C Case 3
59
Eau Terre Environnement Research Centre
Institut national de la recherche scientifique
490 Rue de la Couronne
Québec City, Québec G1K 9A9, Canada
www.inrs.ca
School of Science and Engineering
Reykjavik University
Menntavegur 1
101 Reykjavik, Iceland
Tel. +354 599 6200
www.ru.is