Incorporating Landscape Dynamics in Small-Scale Hydropower Site Location Using a GIS and Spatial Analysis Tool: The Case of Bohol, Central Philippines

: Hydropower depends on the elevation head and water ﬂow of a river. However, other factors must be considered, such as the risk associated with surface processes and environmental factors. The study aims to analyze a landscape’s dynamics and locate potential sites for small-scale hydropower systems (<10 MW) using a geographic information system, the curve number method, and the TopoToolbox with a digital elevation model and available spatial datasets. Across Bohol Island in the central Philippines, the study found 94 potential sites with hydraulic heads ranging from 20–62.4 m, river discharges between 0.02 to 9.71 m 3 /s, and a total hydropower capacity of 13.595 MW. The river proﬁle analysis classiﬁed the sites to ﬁve levels of risk to geo-hazards, with three-fourths of the sites being at ‘high’ to ‘very high’ risk levels while more than 50% of the total power can be generated in ‘low’ risk areas. Land-use and population constraints reduced the sites to 25 and the hydropower capacity by 60%. Although limited to the table assessment phase of hydropower development, the study showed the potential of small-scale hydropower systems in the study area, their spatial distribution, and the risk associated with each site. The study results provided data-limited resource managers’ and energy planners’ insights in targeting potential locations and minimizing ﬁeld investigation costs and time.


Introduction
The increasing environmental issues associated with fossil-based energy production, depleting sources, and increasing energy demand have led to intensifying use, development, and exploration of alternative renewable energy resources [1][2][3]. For tropical islands with rich natural resources that suffer from nature's vicissitudes adversely affecting energy supply, searching for more energy sources becomes urgent [4].
Hydropower is one of the world's renewable energy resources. A high-resolution assessment of global hydropower potential by Hoes et al. [2] revealed that about a third of the annual energy requirement can be provided by hydropower but existing hydropower plants produced only 3% of the yearly energy needs. One of the notable features of hydropower sources, especially the small-scale systems (SHP), is the lesser greenhouse gas emission [1,5,6]. The run-of-river small hydropower has become more cost-effective than mini-grids powered by diesel gen-sets due to falling energy costs [7]. IRENA [7] commended the micro-hydro power systems as a better option for household lighting than the commonly used solar PV in areas where the resource is available for a cluster of households. The SHPs supported rural development in many developing countries in Asia and Africa [8]. Such systems helped improve remote areas' productivity and contributed directly to the development of women by powering small agro-industries usually performed by hand and almost entirely by women [8].
Recent studies compare the impacts of SHP and large-scale hydropower (LHP) systems. Different indicators were evaluated and the demarcations between scales also differ which led to contrasting results. For example, in Duero Basin, Spain, Mayor et al. [9] found that the cumulative impacts of the deployment of many SHPs outweighed the impacts of a few LHP upon evaluating indicators under three categories of energy, water, and environment. An installed capacity of 10 MW demarcates the SHP from the LHP was used in the study [9]. In contrast, Zhang et al. [6] analysis in Tibet, China, found that SHPs have reduced externalities compared to LHPs, considering greenhouse gas emission translated into CO 2 equivalent: SHPs and LHPs produced an average of 5.1 and 29.2 g CO 2 -e per kWh, respectively. Reservoir impoundment and occupation were the critical components of the total externality of LHP, the study emphasized. One implication of their study was that a higher power density can decrease externality, which favor the SHP systems. In this study of Zhang et al. [6], an installed capacity of 50 MW was used to differentiate the two hydropower scales. A unified system of evaluation particularly on the indicators to be assessed and the scale to delineate between SHP and LSP may be put forward to resolve opposing results.
The hydropower potential in the Philippines is high [7,10], with untapped resources amounting to 13,097 MW. In 2018, the hydropower share was only 9.4% of the total generation mix of 99,765 GWh [11]. The ADB [10] associated the low hydropower utilization in the country to 'global isolation and the lack of financial and technical capacity'.
Hydropower produces electrical energy from moving water converted through mechanical turbines. The amount of power generated is directly proportional to the head and the flow. In particular, the small-scale hydropower systems depend on the available head and sufficient water flow in the river [12]. Along river channels, locating suitable sites for hydropower plants is a bit challenging [13,14]. A range of factors including hydraulic head, catchment area, flow characteristics, and sensitive environmental issues such as biodiversity and land use pattern must be critically considered in finding potential sites. In response, several studies have developed methods and approaches for identifying potential hydropower sites.
In the last few decades, geographic information systems coupled with hydrologic models were the primary tools employed to identify potential sites for hydropower development. In Pakistan's data-scarce Kunhar River Basin, Moiz et al. [13] developed a geographic information system-based decision-support system for decision-makers evaluating potential hydropower schemes. The system optimized the site selection process for run-of-river small hydropower plants using topographic and hydrologic factors. Bayazit et al. [15] applied GIS-based hydrological modeling with a topographical and meteorological dataset to analyze the hydropower potential of the Bilecik Regional Sakarya Basin, Turkey. Thin et al. [11] integrated GIS and the Soil and Water Assessment Tool (SWAT) and developed a GIS-based tool using Python to locate potential hydropower in Myanmar's Myitnge River Basin. Similarly, Sekac et al. [15] adopted GIS and remote sensing technology to identify potential hydropower sites in the Busu River Catchment in Papua New Guinea. Sammartano et al. [16] also employed GIS and SWAT model to determine the optimal potential run-of-river sites in Taw at Umberleigh Catchment of South West England. Their study assessed the small hydropower projects' environmental and economic feasibility and conducted a multi-objective analysis to highlight profitable schemes. In the Philippines, a geographic information system and a hydrologic model were employed to identify potential hydropower sites in two separate river basins in Mindanao, Philippines [17,18]. Both studies explored possible renewable energy resources to address the perennial energy crisis through hydropower development. A comprehensive method was developed in Energies 2022, 15,1130 3 of 31 the study of [19] to ensure cost-effectiveness and high-performance hydropower projects in the Fomanat Plain of Gilan, Iran. In Estonia, Tamm and Tamm [20], proposed a virtual hydropower assessment method in identifying other potential locations in all large rivers where hydropower plants already existed and found several suitable sites for miniand micro-hydro types.
The initial assessment for potential hydropower sites centered on topographic and hydrologic factors. Initial investigations commonly assessed larger rivers or major watersheds in an area, neglecting the potential of smaller catchments. The conventional approach may have overlooked the potential of small systems in these areas, which may be beneficial to small clusters of users.
Another observation is that existing studies gave less attention to geomorphic features in a landscape related to surface processes and, thereby, to geomorphic hazards. Geomorphic hazards [21] 'are natural processes until they intersect with human activities and settlements'. These hazards are either natural or anthropogenic to some degree and usually happen along or adjacent to river channels. Hydropower facilities are sited along or adjacent to river channels, and the stability of hillslopes and channels is critical to the sustainability of the engineering structures [22,23]. Although these factors are critically evaluated in the subsequent phase of system development, it is valuable to have such information earlier to have a priority list of potential sites.
Geomorphologists analyzed river profiles to extract information on landscape evolution and the processes that shape the topography of landscapes [24], linking climate, tectonic and surface processes across a landscape [25]. The geomorphic index such as the river steepness index [22,24] and the presence of knickpoints [26] are proxies of natural surface processes. As Boulton [26] noted, steeper channels and regions undergoing higher erosion and uplift rates, can be recognized with river profile analysis as indicated by the high river steepness index. Similarly, the study of Castillo et al. [27] in western Mexico rivers found high river steepness index values that suggests high rock uplift and erosion rates that control the topography of river basins. The river steepness index is a commonly used index to analyze river profiles to infer erosion rates, bedrock erodibility and highlight areas of tectonic activity [24]. Knickpoints, on the other hand, are sharp changes in the channel slope [28] that reflects conditions and processes associated with erosion, lithological changes, and uplift rates. Boulton [26] noticed that knickpoints formed in response to changes in uplift rates are found in areas where river steepness index is high. Chen et al. [29] found steep rivers with many tectonic knickpoints in the eastern flank of the central range of the Taiwanese island where the mountains are under rapid collisional processes. Low river steepness index values indicate low uplift rates [29].
The study presents a rapid method of assessing the dynamics of a landscape for identifying potential sites for small-scale hydropower projects (<10 MW). Specifically, the study aims to (a) examine the topography from a digital elevation model to locate potential sites along river channels, (b) estimate surface runoff using the CN method, (c) compute the hydropower capacity of each site, (d) investigate the geometric indices associated with geo-hazards and (e) analyze the existing land-use and population data. The study is limited to the initial stage of hydropower development. It is applied to an island landscape where natural disasters like typhoons and earthquakes challenge energy supply and accessibility. Results are presented as maps showing the landscape's hydropower potential, the spatial distribution of potential sites, and the risk levels associated with each site. The study results are expected to benefit local resource managers, decision-makers, and energy planners faced with limited data for analysis, in identifying potential sites, targeting directly potential areas and minimizing field investigation costs and time. Figure 1 shows the workflow of the analysis, and a detailed discussion follows. Data processing started with a topographic analysis that defined the streamlines and determined the required elevation head. Next, the hydrologic analysis provided an estimate of the flow rate passing through each identified potential site. The two primary factors, elevation head, and flow are inputs to compute the potential hydropower at each site. Then, the river profile analysis determined the geomorphic indices of surface processes associated with channel stability. Lastly, we considered population and land use in the constraint analysis. Figure 1 shows the workflow of the analysis, and a detailed discussion follows. Data processing started with a topographic analysis that defined the streamlines and determined the required elevation head. Next, the hydrologic analysis provided an estimate of the flow rate passing through each identified potential site. The two primary factors, elevation head, and flow are inputs to compute the potential hydropower at each site. Then, the river profile analysis determined the geomorphic indices of surface processes associated with channel stability. Lastly, we considered population and land use in the constraint analysis.

Datasets
The study gathered the required input datasets from several sources as given in Table  1 and processed them following Figure 1 (a detailed process flow is given in Appendix A Figure A1). Table 1 presents a list of all the datasets used, their sources, and data format.

Datasets
The study gathered the required input datasets from several sources as given in Table 1 and processed them following Figure 1 (a detailed process flow is given in Appendix A Figure A1). Table 1 presents a list of all the datasets used, their sources, and data format. Digital elevation model (DEM). The digital elevation data is critical in the study since this is the primary data where the rest of the analysis depends. In a GIS platform, we preprocessed a DEM and used it to delineate watersheds, determine drainage lines, and compute elevation differences. The DEM is also the primary input to a terrain analysis tool for river profile analysis.
Global datasets. Due to the limited availability of local soil and landcover data, we used freely available global datasets on monthly precipitation, hydrologic soil group, and landcover. The global hydrologic soil group (HYSOGs250m) for curve number-based runoff modeling [30] represents a globally consistent, gridded dataset of hydrologic soil group with a geographical resolution of 1/480 decimal degrees, equivalent to a projected resolution of approximately 250-m. The soil texture classes and depth to bedrock information provided by the Food and Agriculture Organization soilGrids250m system are the bases for classifying the HSG. The Copernicus Global Land Service [31] global landcover dataset provides spatial information on different types (classes) of the Earth's surface physical coverage, e.g., forests, grasslands, croplands, lakes, and wetlands. We used the annual dataset, a moderate resolution landcover map targeting landcover detection and its changes.
Climate data. The WorldClimv2.1 climate data for 1970-2000 [32] provide monthly total precipitation. This dataset was downloaded and used in the runoff determination using the CN method.
Local flow and rainfall data. Flow and rainfall data are available from the monitoring activity of a hydropower plant. The study used the flow and the rainfall data from local rain gauges to describe the area's hydrology but not estimate the surface runoff.
Population data. The study used the 2015 census of the Philippine Statistics Authority (PSA) population data at the barangay (village) level. The data were linked to a barangay shapefile to create a raster surface describing the spatial variability of population density across the study area.

Topographic Analysis
The topographic analysis examined a DEM (see Appendix A Figure A2) to locate potential sites in the study area. The process is outlined in a model builder created in ArcGIS, as shown in Figure 2. The model builder used a DEM to create the flow direction and flow accumulation rasters. The flow direction raster shows the flow direction from each cell to its steepest downslope neighbor, while the flow accumulation raster shows the accumulated flow into each cell. From the flow accumulation raster, the cells with values of at least 10,000 (equivalent to 100 ha upslope area) were selected using the SetNull tool, creating a new flow accumulation raster. The new flow accumulation raster was used as an input to create the stream raster. Then, the elevation values following the stream raster were extracted and analyzed. The Focal Analysis Tool with a rectangular neighborhood of the same height and width at 100 m was used to determine the maximum elevation in a 100-m channel segment. The channel length was adopted from the study by Sammartano et al. [16]. The elevation head is the difference between the maximum elevation and the local elevation rasters, stored as the elevation head raster. From the elevation head raster, raster values equal to or greater than 20 m (≥20 m) were selected using the Set Null tool. The 20 m minimum head which was adopted from previous studies in the study area [33] and in Uganda [34]. The minimum head value anticipated the low flows from the small catchment and from the upper part of the watersheds which can still produce power at 20 m head or higher. These selected raster values were converted into point vector.
The conversion resulted in clusters of points, as shown in Figure 3, where points were found to assemble around channel segments. For each cluster, a point was selected based on the elevation head value and the location of the point. For instance, in a cluster found at the convergence of two different stream orders, high consideration is given to a point along the higher-order stream because the flow is expected to be higher in high-order stream than in low-order stream. The study manually picked a point to represent each cluster. A distance of at least 500 m between selected points from each cluster was maintained by using the distance tool. The 500-m minimum site spacing is commonly adopted (ex. [13,33,35]) to allow river ecosystem rejuvenation. These selected points were the potential sites for small-scale hydropower.
Energies 2022, 15, x FOR PEER REVIEW 6 of 34 tion in a 100-m channel segment. The channel length was adopted from the study by Sammartano et al. [16]. The elevation head is the difference between the maximum elevation and the local elevation rasters, stored as the elevation head raster. From the elevation head raster, raster values equal to or greater than 20 m (>=20 m) were selected using the Set Null tool. The 20 m minimum head which was adopted from previous studies in the study area [33] and in Uganda [34]. The minimum head value anticipated the low flows from the small catchment and from the upper part of the watersheds which can still produce power at 20 m head or higher. These selected raster values were converted into point vector. The conversion resulted in clusters of points, as shown in Figure 3, where points were found to assemble around channel segments. For each cluster, a point was selected based on the elevation head value and the location of the point. For instance, in a cluster found at the convergence of two different stream orders, high consideration is given to a point along the higher-order stream because the flow is expected to be higher in high-order stream than in low-order stream. The study manually picked a point to represent each cluster. A distance of at least 500 m between selected points from each cluster was maintained by using the distance tool. The 500-m minimum site spacing is commonly adopted (ex. [13,33,35]) to allow river ecosystem rejuvenation. These selected points were the potential sites for small-scale hydropower.

Runoff Estimation Using CN Method
Several studies used the USDA-CRS curve number (CN) method for estimating surface runoff [36][37][38]. Due to its simplicity, the study adopted the CN method to estimate direct surface runoff at each identified potential site. The CN method requires only precipitation values and a single parameter called CN to estimate the direct surface runoff using the equation:

Runoff Estimation Using CN Method
Several studies used the USDA-CRS curve number (CN) method for estimating surface runoff [36][37][38]. Due to its simplicity, the study adopted the CN method to estimate direct surface runoff at each identified potential site. The CN method requires only precipitation values and a single parameter called CN to estimate the direct surface runoff using the equation: where q is the accumulated runoff or rainfall excess (mm), R is the rainfall depth (mm), I a is the initial abstraction (mm), and S is the potential maximum retention (mm). USDA-CRS [39] estimated I a as 20% of S based on its extensive database. Meanwhile, S is expressed in terms of CN as: With this, (1) is written as: Equation (2) derived the S raster and then (3) computed the monthly surface runoff q with the corresponding R monthly precipitation data.
The CN factor was estimated based on landcover information and hydrologic soil group described in Tables 2 and 3, respectively. The study used the HYSOGs250m [30], a gridded dataset of hydrologic soil groups (HSGs) with approximately 250-m projected resolution. Ross et al. [30] derived the HSG classification from the soil textural classes and depth to bedrock of the FAO soilGrids250m system to support USDA-based CN runoff modeling. Based on the dataset, the study area has two standard soils, HSG C and HSG D, corresponding to moderately high and high runoff potential, respectively. Water/wetlands 0 0 0 0 0 Notes: (1) Hydraulic condition is based on combination factors that affect infiltration and runoff, including (a) density and canopy of vegetative areas, (b) amount of year-round cover, (c) amount of grass or close-seeded legumes, (d) percent of residue on the land surface (good ≥ 20%), and © degree of surface roughness. (2) Good: Woods are protected from grazing, and litter and brush adequately cover the soil.  Table 3. The Global hydrologic soil group and its description.

Pixel Values Description
1 HSG-A: low runoff potential (>90% sand and <10% clay) 2 HSG-B: moderately low runoff potential (50-90% sand and 10-20% clay) 3 HSG-C: moderately high runoff potential (<50% sand and 20-40% clay) 4 HSG-D: high runoff potential (<50% sand and >40% clay) 11 HSG-A/D: high runoff potential unless drained (>90% sand and <10% clay) 12 HSG-B/D: high runoff potential unless drained (50-90% sand and 10-20% clay) 13 HSG-C/D: high runoff potential unless drained (<50% sand and 20-40% clay) 14 HSG-D/D: high runoff potential unless drained (<50% sand and >40% clay) We used the annual global landcover map data from the Copernicus Land Monitoring Service [31]. The global annual landcover maps follow the UN-FAO Land Cover Classification System (LCCS) and contain 23 discrete classes. The updated 2015 classification has slightly higher accuracy in characterizing forest, cropland, and permanent water classes according to Buchhorn et al. [31]. We then clipped and reclassified the 2015 landcover map according to the description provided by the USDA-SCS as shown in Table 2 and assigned the corresponding curve number. Figure 4 shows the raster analysis process towards the creation of CN values.  The information on the catchment area is needed to compute the discharge or flow rate at each site. The individual catchments were delineated using the identified sites as outlets within the SWATwatershed delineator. The catchment boundary and area, in square meters, were computed. The catchment boundary was input to the Zonal Statistics of ArcGIS Spatial Analyst, which extracted the mean ̅ raster values (in meters) within each catchment. We get twelve values (one for each month) of ̅ for each site. The discharge at each site, in m 3 /s, is computed using (4) where is the number of seconds in a month.
We used the 80% dependable flow value, the value used by NWRB-DENR [40] in its technical evaluation for hydropower projects. To get the 80% dependable flow, we constructed the flow duration curves (FDC) using the CN-estimated monthly runoff values for each potential site. With FDC, the monthly flow values were arranged in descending The information on the catchment area is needed to compute the discharge or flow rate at each site. The individual catchments were delineated using the identified sites as outlets within the SWATwatershed delineator. The catchment boundary and area, A i in square meters, were computed. The catchment boundary was input to the Zonal Statistics of ArcGIS Spatial Analyst, which extracted the mean q i raster values (in meters) within each catchment. We get twelve values (one for each month) of q i for each site. The discharge at each site, Q i in m 3 /s, is computed using (4) where t m is the number of seconds in a month. We used the 80% dependable flow value, the value used by NWRB-DENR [40] in its technical evaluation for hydropower projects. To get the 80% dependable flow, we constructed the flow duration curves (FDC) using the CN-estimated monthly runoff values for each potential site. With FDC, the monthly flow values were arranged in descending order, assigned the corresponding rank of 1 to 12 (1 for the highest monthly flow, 12 for the lowest flow), and computed the probability of flow exceedance using the equation, where p, M, and n refer to the probability of exceedance (in percentage), discharge rank, and the number of events in a period, respectively. An example of a flow duration curve is shown in Figure 5. We examined the actual flow record from an existing hydropower plant, the Loboc Hydroelectric Plant (LHEP), and the CN-estimated runoff. With the available data, we found no common years between the actual flow and the CN-estimated runoff. The flow data at LHEP spanned between 2005 to 2019. On the other hand, the CN-estimated runoff used a gridded precipitation dataset from the work of [32] based on precipitation records between 1970-2000. The different record years constrained us from comparing the actual and estimated runoff. In this case, the average patterns of the CN-estimated runoff and the local inflow data were presented instead.

Hydropower Capacity and Annual Energy Generation
The hydropower capacity, (kW), is computed using the equation, where is the efficiency at 0.85 [41], (kN/m 3 ) is the specific weight of water equal to 9.810, , (m) is the net hydraulic head equivalent to 90% of the elevation head where 10% is allotted for frictional losses along the penstock, and 80 , (m 3 /s) is the net flow equivalent to 90% of the flow at 80% probability of exceedance where 10% returned to the waterway as environmental flow following the Philippines-National Water Resources Board Resolution No. 030613 [40] on the granting of water rights over surface water for hydropower projects. The sites' computed hydropower values were then classified according to Table 4. Table 4. Classification of small-scale hydropower systems based on power capacity and the potential applications to a range of beneficiaries.

Type
Power Output 1,2 Applicability 1 Small 1-10 MW Small communities with a possibility to supply electricity to a regional grid We examined the actual flow record from an existing hydropower plant, the Loboc Hydroelectric Plant (LHEP), and the CN-estimated runoff. With the available data, we found no common years between the actual flow and the CN-estimated runoff. The flow data at LHEP spanned between 2005 to 2019. On the other hand, the CN-estimated runoff used a gridded precipitation dataset from the work of [32] based on precipitation records between 1970-2000. The different record years constrained us from comparing the actual and estimated runoff. In this case, the average patterns of the CN-estimated runoff and the local inflow data were presented instead.

Hydropower Capacity and Annual Energy Generation
The hydropower capacity, P i (kW), is computed using the equation, where η is the efficiency at 0.85 [41], γ (kN/m 3 ) is the specific weight of water equal to 9.810, H net,i (m) is the net hydraulic head equivalent to 90% of the elevation head where 10% is allotted for frictional losses along the penstock, and Q 80net,i (m 3 /s) is the net flow equivalent to 90% of the flow at 80% probability of exceedance where 10% returned to the waterway as environmental flow following the Philippines-National Water Resources Board Resolution No. 030613 [40] on the granting of water rights over surface water for hydropower projects. The sites' computed hydropower values were then classified according to Table 4.  [20,42].
The annual energy generation E i at each potential site is computed using (7) where CF is the minimum capacity factor set at 33.73%, as considered by the Bohol Island Power Development Plan (BIPDP) [4], and T is 8760 h.

River Profile Analysis
The topographic profile of a river system holds useful information of climatic and tectonic forcing across a landscape [43]. A river profile analysis demarcates locations of tectonic activity in tectonically active landscapes [44]. The study examined two geomorphometric indices: the knickpoints and the river steepness index.
The stream power model is widely used to describe the evolution of a river profile, e.g., [45,46], expressed as: where ∂z/∂t is the change in elevation z {L} of a point in the channel that varies with time t {T} and distance x {L}, U {LT −1 } is the rock uplift rate, and E {LT −1 } is the river incision rate. At steady state, ∂z/∂t = 0, indicating a balance between rock uplift and erosion. Rearranging Equation (8) and solving for S gives: where Equation (9) defines the channel incision rate E [45] as proportional to the erodibility K {T −1 L (1−2m) }, local slope S{L/L} and catchment area A{L 2 }, and m and n are constants. Equation (10) describes a positive correlation between channel gradient and rock uplift rates [43] and assumes that river profiles developed over areas with similar climate, lithology and uplift rates uplift [47]. The terms k s and θ in Equation (11) refer to river steepness and concavity index, respectively, and where k s = (U/K) 1/n and θ = m/n. Equation (11) expresses a power relation between S and drainage area A. A regression analysis of log (S) versus log (A) gives the concavity index value, which usually ranged between 0.35-0.6 for tectonically active mountains and 0.3-0.6 under normal conditions. A reference concavity index, θ re f , is introduced to remove the effect of different catchment areas [43,47] and to determine the normalized river steepness index, k sn , as: where θ re f varies between 0.35 to 0.65. k sn and K are dimensional coefficients whose dimensions depend on the value of θ and the value of m [47]. The factor k s is equivalent to M χ [47], also called the river steepness index, which is the slope of the integral solution to the stream power model, when the reference area, A 0 , in Equation (13), is equal to one: M χ is also used to demarcate regions with rapid rock uplift in tectonic geomorphology [22]. A study by Schwanghart et al. [22] evaluated M χ with peak ground acceleration in the Himalayan regions after the 2015 Gorka earthquake and established that earthquaketriggered landslide damages to hydropower plants clustered in areas where M χ is high. The current study used Topotoolbox to analyze k sn of stream profiles to illustrate quantitatively the channel morphology and provide insights into the spatial dynamics of deformation along river channels [48] and adopted a commonly used θ value of 0.45.
Knickpoints are manifestations of perturbations along river channels [44]. In addition, knickpoints are indicators of landscape disequilibrium significant in engineering structures [23]. In TopoToolbox, [28] located knickpoints using the 'knickpointfinder' function that extracts sharp convex sections in the river profile.
In our study, we used both the k sn and the knickpoints to determine the level of risk associated with potential slope failures that may affect the structural stability of hydropower systems. We used TopoToolbox [28] to extract k sn and the knickpoints from a digital elevation model and did further analysis and visualization in a GIS platform. The study classified the k sn (in m 0 . 9 ) values into five levels of risk using the natural breaks method as follows: 5-very low (<19 m 0.9 ), 4-low (19-59 m 0.9 ), 3-medium (59-131 m 0.9 ), 2-high (131-298 m 0.9 ), and 1-very high (>298 m 0.9 ). Then, we overlaid the identified knickpoints on k sn , and rendered to each knickpoint the corresponding risk level class of the matching k sn .
To identify the risk level associated with each potential site, we drew a 200-m radius buffer region around each site and determined the presence of a knickpoint within the buffer. When two or more knickpoints were present within the buffer, we attributed the highest level of risk for the site.

Land Use and Population Analysis
National parks and equivalent reserves are 'valuable for economic and scientific reasons and as areas for the future preservation of fauna and flora' [49,50]. In the Philippines, renewable energy projects may be allowed within the protected area and located outside the strict protection zones [50] (Sec. 13). The protected areas were obtained from the World Database on Protected Areas (WDPA), downloaded from www.protectedplanet.net (accessed on 13 October 2021), and the Protected Areas Database of the Regional Office 7 of the Department of Environment and Natural Resources. The protected areas within the study area were clipped and overlaid on the identified potential sites. The available protected area dataset has no information on different zones, specifically on strict protection zones. In this case, all protected areas were considered as strict protection zones, and all the potential sites found within were excluded from the list.
In evaluating the population that the potential hydropower systems can serve, the 2015 Philippine Census of Population data was used. The population data at the barangay (village) level can be downloaded from the Philippine Statistics Authority (http://psa.gov.ph) (accessed on 5 August 2021). The administrative map at the barangay level was obtained from a GIS data repository PhilGIS (http://philgis.org) (accessed on 8 August 2021), and the maps' area attribute was used to compute the population density. Next, the number of households per unit area was calculated, wherein the average household size of 4.4 in 2015 [51] was utilized. A point vector datum, located at the center of each barangay polygon, represents households per area. Finally, the point vector data were used to interpolate and create a raster of household per area.
The next step was to determine the number of households present in the vicinity of each potential site. In the potential sites layer, we created a 200-m buffer around each site. Then, the layer was overlaid on the household per area raster. The Zonal Analysis of ArcGIS extracted the mean household density within the buffer. The number of households within the 200-m radius was calculated as the product of the mean household density and 12.566 hectares. In this paper, this parameter is called HH 200m .
The number of households (required for pico-and micro-hydropower systems only following Table 4) that each potential site could support was estimated using the country's electricity consumption per capita of 696 kWh in 2014 WorldBank data (https://data.worldbank.org) (accessed on 22 August 2021). Using a capacity factor of 33.73% and the annual number of hours of 8760, a micro-hydropower type with a 5-100 kW capacity can support a community of 5-96 households. In contrast, a pico system (<5 kW) can provide enough electricity to a cluster of fewer than five households. This parameter is referred to as HH site in this paper. The difference between HH 200m and HH site is then obtained. A zero or a positive value indicates electricity-consuming households that can make hydropower financially viable. In contrast, a negative value indicates that the number of households within the 200-m radius of each site is not enough to make the hydropower system economically feasible.

Case Study Application in Bohol Island, Central Philippines
Bohol Island is in the Philippines' archipelago's Central Visayas region, as shown in Figure 6. The island province covers roughly 4117 km 2 and its highest elevation is at around 833 m (see Figure A2). A 2015 global landcover data has identified more trees with a top density of 30%, dominating the island's landcover of about 70%, as shown in Appendix A Figure A3. Agriculture and tourism are the primary drivers of the island's economy.
The island's climate falls under the 4th type of Corona's climatic classification having rainfall distributed evenly throughout the year, with distinct dry and wet seasons. The annual precipitation between 2000-2012 observed at Tagbilaran Station ranged from 1210 to 2273 mm. Meanwhile, Appendix A Figure A4 shows the spatial variation of precipitation on the island based on a global climate dataset [32].

Case Study Application in Bohol Island, Central Philippines
Bohol Island is in the Philippines' archipelago's Central Visayas region, as shown in Figure 6. The island province covers roughly 4117 km 2 and its highest elevation is at around 833 m (see Figure A2). A 2015 global landcover data has identified more trees with a top density of 30%, dominating the island's landcover of about 70%, as shown in Appendix A Figure A3. Agriculture and tourism are the primary drivers of the island's economy.
The island's climate falls under the 4th type of Corona's climatic classification having rainfall distributed evenly throughout the year, with distinct dry and wet seasons. The annual precipitation between 2000-2012 observed at Tagbilaran Station ranged from 1210 to 2273 mm. Meanwhile, Appendix A Figure A4 shows the spatial variation of precipitation on the island based on a global climate dataset [32].
Based on the FAO-DSMW (Food and Agriculture Organization-Digitized Soil Map of the World) (WRB-IUSS, 2014), the soils in the island is dominated by three soil types consisting of orthic luvisols, dystric nitosols, and pellic vertisols. The luvisols are soils with clay-enriched subsoil. The nitosols are soil types with significant accumulation of clay (30 percent or more by mass and extending as much as 150 cm below the surface) and a blocky aggregate structure. On the other hand, the vertisols are heavy clay soils with a high proportion of swelling clays. Regarding the hydrologic properties estimated from the global hydrologic soil groupings [52], the soils in the area are described as having moderately high to high runoff potential (See Appendix A Figure A5).  blocky aggregate structure. On the other hand, the vertisols are heavy clay soils with a high proportion of swelling clays. Regarding the hydrologic properties estimated from the global hydrologic soil groupings [52], the soils in the area are described as having moderately high to high runoff potential (See Appendix A Figure A5).
The island has two major watersheds: the Loboc and the Wahig-Inabanga Watersheds. All three existing run-of-river hydroelectric power plants are found in the Loboc Watershed along the main trunk: Sevilla mini HEPP, Loboc mini HEPP (LHEP), and Janopol HEPP (small HEPP) with a combined dependable capacity of 8.7 MW [52]. In 2015, these hydropower plants supplied around 11% of the island's peak energy demand of 77-MW while the Visayas Grid (Leyte-Bohol Transmission Interconnection) provided most of the island's energy needs [4].
Natural disasters such as typhoons and earthquakes regularly affect the island. In October 2013, a 7.2 magnitude earthquake destroyed physical infrastructure and cut off the island's energy supply for a few days to months. In the following month, the super typhoon Yolanda (with international code name Haiyan), although this time spared the island from further destruction, had wrecked the power transmission lines of nearby provinces from where Bohol receives most of its energy supply. Thus, power outages from the earthquake and typhoon interrupted energy-dependent activities and related activities, resulting in significant economic loss.
The unfortunate experience sent an urgent call for the Boholano people to plan and ensure sufficient power supply for the island if a natural catastrophe disengaged the province from the Visayas Grid [4]. To be more resilient to the effects of natural disasters, the government planned to put its energy generation plants in place. Hence, a resource assessment is timely to support the local government exploring potential renewable energy sources for energy self-sufficiency.
The province of Bohol has rich natural resources. While addressing the sustainable development goal of providing clean energy, renewable energy sources could ensure accessibility and availability of the needed energy, especially in rural areas. Rapid resource assessments and feasibility studies on potential hydropower generation sites were critical actions recommended by the Technical Working Group [4] to augment the power supply in the province. The assessment made by Pojadas et al. [42] found that the island's technical potential for domestic renewable energy resources, from any combination of solar PV, wind, biopower, and hydropower projects, can meet the 35% share of the renewable energy portfolio. On account of these resources and the natural disasters experienced by the island, the study assesses its hydropower potential incorporating landform dynamics following methods discussed previously. Figure 7 shows the spatial distribution of small-scale hydropower sites identified for an island-wide topographic analysis along with the stream order. The topographic analysis identified 94 potential sites along river channels with a minimum elevation head of 20 m and higher. More than half of the identified sites are found outside of the two major watersheds. There are nine sites located along the main trunk of the Loboc Watershed, which already hosts the three existing hydropower plants. The potential sites are located at distances of more than 500 m from the existing hydropower plants. Other features of each site are given in Appendix B Table A1.  The potential sites fall under different stream orders that vary with elevation heads and catchment areas, as shown in Figure 8. Using Strahler's stream ordering system, five stream orders are identified in the study area. The longest river, a fifth-order stream, has a total length of 83.3 km but no potential site is found. More than half of the sites (or 52%) are found in the first-order streams, while only four are in the fifth-order streams. The number of potential sites decreases with increasing stream order. A similar trend was found in the study of [16] in the Taw at Umberleigh catchment of South West England where more than half of the detected locations are found in the first-order channels, and the number decreases as the channel order increases. Twelve sites with third-order streams have the highest average elevation head of 36.4 m, while five with fourth-order streams have the lowest average elevation head of 22.8 m. Results indicated no correlation between stream order and elevation head. Four sites found in fifth-order streams have the highest average catchment area of 473 km 2 , while more than half of the identified sites have first-order streams with an average catchment area of only 2 km 2 . The sites' catchment areas increase with stream order. The potential sites fall under different stream orders that vary with elevation heads and catchment areas, as shown in Figure 8. Using Strahler's stream ordering system, five stream orders are identified in the study area. The longest river, a fifth-order stream, has a total length of 83.3 km but no potential site is found. More than half of the sites (or 52%) are found in the first-order streams, while only four are in the fifth-order streams. The number of potential sites decreases with increasing stream order. A similar trend was found in the study of [16] in the Taw at Umberleigh catchment of South West England where more than half of the detected locations are found in the first-order channels, and the number decreases as the channel order increases. Twelve sites with third-order streams have the highest average elevation head of 36.4 m, while five with fourth-order streams have the lowest average elevation head of 22.8 m. Results indicated no correlation between stream order and elevation head. Four sites found in fifth-order streams have the highest average catchment area of 473 km 2 , while more than half of the identified sites have first-order streams with an average catchment area of only 2 km 2 . The sites' catchment areas increase with stream order. Figure 9 shows the spatial variation of the annual and monthly runoff in the study area, including the annual precipitation. Based on a global dataset [32], the mean annual precipitation varies from 1537 mm to 2263 mm, with the westernmost coast as the driest part and the high-altitude southern portion as the wettest part of the island. The average annual runoff depth varies across the landscape from 657 mm to 1941 mm, or 43% to 87% of the annual precipitation becomes runoff, increasing from the east towards the interior part of the island. The monthly variation of runoff indicates April as the driest month, while November is the wettest month.  Figure 9 shows the spatial variation of the annual and monthly runoff in the study area, including the annual precipitation. Based on a global dataset [32], the mean annual precipitation varies from 1537 mm to 2263 mm, with the westernmost coast as the driest part and the high-altitude southern portion as the wettest part of the island. The average annual runoff depth varies across the landscape from 657 mm to 1941 mm, or 43% to 87% of the annual precipitation becomes runoff, increasing from the east towards the interior part of the island. The monthly variation of runoff indicates April as the driest month, while November is the wettest month.    Figure 9 shows the spatial variation of the annual and monthly runoff in the study area, including the annual precipitation. Based on a global dataset [32], the mean annual precipitation varies from 1537 mm to 2263 mm, with the westernmost coast as the driest part and the high-altitude southern portion as the wettest part of the island. The average annual runoff depth varies across the landscape from 657 mm to 1941 mm, or 43% to 87% of the annual precipitation becomes runoff, increasing from the east towards the interior part of the island. The monthly variation of runoff indicates April as the driest month, while November is the wettest month. Figure 9. Spatial variation of (a) mean annual precipitation, (b) mean annual runoff depth, and (c) mean monthly runoff estimated using CN method. Figure 9. Spatial variation of (a) mean annual precipitation, (b) mean annual runoff depth, and (c) mean monthly runoff estimated using CN method. Figure 10 shows the relationship among flow estimates, catchment area, and stream order. The average catchment area and the average flow estimates increase with increasing stream order (Figure 10a). Earlier, Figure 8 shows fewer potential sites are identified in higher order streams, and more than half are in the first-order stream. Zooming in on the flows under the first-order stream, we found flow increasing linearly with the catchment area ( Figure 10b). However, in Figure 10c, several potential sites concentrated at the bottom left side of the graph and depicts a reduced linear relationship between the catchment area and flows compared to the general relationship using all the potential sites in this stream order.

Runoff Estimates
in higher order streams, and more than half are in the first-order stream. Zooming in on the flows under the first-order stream, we found flow increasing linearly with the catchment area (Figure 10b). However, in Figure 10c, several potential sites concentrated at the bottom left side of the graph and depicts a reduced linear relationship between the catchment area and flows compared to the general relationship using all the potential sites in this stream order.  in higher order streams, and more than half are in the first-order stream. Zooming in on the flows under the first-order stream, we found flow increasing linearly with the catchment area (Figure 10b). However, in Figure 10c, several potential sites concentrated at the bottom left side of the graph and depicts a reduced linear relationship between the catchment area and flows compared to the general relationship using all the potential sites in this stream order.   Table 5 summarizes the potential sites' count, power, and energy generation for each watershed. Section 3.1 presents the distribution of sites per watershed. The power capacity and energy generation are highest in Loboc Watershed, with 75% of the total. It is followed by 21% from other watersheds and 4% from the Wahig-Inabanga Watershed. All the four small types are found in the Loboc Watershed, which has a total power capacity of 6.5 MW accounting for 48% of the total power. Most of the sites are found in smaller watersheds, with 5 mini and 39 micro types having a total power capacity of 2831 MW accounting for 21% of the total power capacity. Although the Wahig-Inabanga Watershed is the second-largest catchment, only a few potential sites are found in the watershed with smaller power capacities. The number of potential sites in the study area is dominated by micro types followed by pico, mini, and small types, having 69%, 14%, 13%, and 4% of the total count. Although the micro types lead in terms of number, they only contribute 10% to the total annual energy generation since each site can generate around 62 MWh on average. In terms of total power capacity per type, the major contribution comes from four small types contributing 48%, while 12 mini types share 42% of the total power capacity. Table 6 shows the classification of the potential sites according to geo-hazard risk level, while Figure 12 depicts the spatial distribution and the associated risk. Potential sites with 'high to very high' risk levels comprise 74% (70 out of 94 sites), supplying 18% of the total potential power. Most of the micro types are found under this risk level, with 55 out of 65 micro sites. Meanwhile, the sites with 'low to very low' risk levels are 16% of the total sites and contribute 52% of the total potential power. There are nine sites with 'medium' risk levels which provide about a third of the total potential power. On the other hand, a quarter of the total potential power comes from two small types in low-risk areas.

Geo-Hazard Risks Associated with Each Potential Sites
The map in Figure 12 shows the spatial distribution of the 94 potential sites, the type indicated by the size of each bubble, and the associated risk level indicated by the color. In the Loboc Watershed, there are 17 sites exposed to 'high to very high' risk levels that contribute 12% to the total power capacity, including a small type with a capacity of 1.341 MW. The other three small types found inside the watershed are under 'low to medium' risk levels with an aggregate capacity of 5.143 MW. Inside the Wahig-Inabanga Watershed, 14 of the 15 sites are under 'high to very high' risk levels. One mini type, located downstream of the watershed, is classified under 'very low' risk level. The remaining 50 sites located outside of these 2 watersheds are under different risk levels. There are 21 and 18 sites with 'high' and 'very high' risk levels, respectively, where 32 sites are micro types. Table 6. Geo-hazard risk levels associated with the small-scale hydropower type and the power potential.  1  32  676  907  Micro  31  231  High  Small  1  38  1341  1591  Micro  24  197  Pico  13  53  Medium  Small  1  9  1790  4078  Mini  4  2209  Micro  4  80  Low  Small  2  5  3353  3895  Mini  1  411  Micro  2  131  Very low  Mini  6  10  2837  3122  Micro  4  285  Total  94 13,595

Geo-Hazard Risk Level
The map in Figure 12 shows the spatial distribution of the 94 potential sites, the type indicated by the size of each bubble, and the associated risk level indicated by the color. In the Loboc Watershed, there are 17 sites exposed to 'high to very high' risk levels that contribute 12% to the total power capacity, including a small type with a capacity of 1.341 MW. The other three small types found inside the watershed are under 'low to medium' risk levels with an aggregate capacity of 5.143 MW. Inside the Wahig-Inabanga Watershed, 14 of the 15 sites are under 'high to very high' risk levels. One mini type, located downstream of the watershed, is classified under 'very low' risk level. The remaining 50 sites located outside of these 2 watersheds are under different risk levels. There are 21 and 18 sites with 'high' and 'very high' risk levels, respectively, where 32 sites are micro types.

Land-Use and Population Constraints
The protected areas in the study area's mainland, depicted in Figure 12, cover 35,016 hectares as promulgated by the Philippine Law [50]. The same legal instrument indicated that hydropower projects within protected areas are allowed but preferably outside of the strict protection zones and upon the approval of authorized agencies. However, the available dataset does not specify the specific zones within the protected areas, especially the strict protection zones. With this limitation, the study assumed that the protected areas are the strict protection zones and, hence, excluded all potential sites found inside the protected areas.
There are 35 potential sites inside the protected areas, accounting for 37% of the total sites and 53% of the total potential power capacity. Of the 35 sites, 22 are micro types with an aggregate power capacity of only 402 kW. Inside the protected areas are found two small and seven mini types, which account for 50% of the total power capacity, and one of the existing hydropower plants.
The population analysis targets the pico and micro types. Due to the limited capacities of these hydropower types, certain household number should be present in the vicinity of the site to minimize the cost of putting up transmission lines [53]. The household analysis found 27 sites fail to show the required household number within a 200-m radius. Hence, there are 25 potential sites left after land-use and population constraint analysis. The remaining power capacity is now reduced to 40% of the total. Six sites inside the Loboc Watershed provide 58% of the remaining power capacity. A total of 64% of the remaining sites are found outside the two major watersheds with 36% power capacity. In contrast, the three sites inside Wahig-Inabanga Watershed contribute only 7% of the power capacity.

Discussion
The hydropower potential of a landscape is driven by the dynamics of its topography and hydrology: topography provides the hydraulic head while the hydrology provides the discharge rate information. Characterizing these features of the landscape will help us to understand the potential of the available resource [54] particularly for hydropower generation. Such landscape characterization also enables the identification of geo-hazard risks associated with each site enabling the development of location-specific engineering designs or the prioritization of sites for further development [23]. The dynamics of a landscape is also, in one way or another, impacted by anthropogenic influences which can further restrict potential resource use in favor of environmental concerns as well as economic considerations.

Loboc Watershed Hydropower Potential and Environmental Concerns
Most of the hydropower potential in the island landscape of Bohol, Philippines, can be harnessed within the Loboc Watershed. About three-fourths of the estimated hydropower (or 10.2 MW) can be generated from the sites identified inside the watershed, mainly along the main trunk where the three existing hydropower systems are found. The nine potential sites found in the Loboc River can possibly augment the three existing hydropower plants currently having a total installed capacity of 8.7 MW [4]. Tamm and Tamm [20] also found new suitable sites along Estonian rivers where hydropower has been or is currently harvested. However, the identified potential sites suggest a series of small-scale hydropower projects. In this kind of arrangement, Mayor et al. [9] cautioned that such systems would result in a "cumulative environmental impact cascading along the river system". Their study suggested reducing the number of low-capacity systems with less significance to the final energy generation and optimizing the use of existing hydropower infrastructure by integrating pumping and storage technologies.
The Loboc Watershed is also an area of high biodiversity value where 40% of its land area is declared protected (see Appendix A Figure A5). About 77% of the protected areas in the mainland of Bohol are inside the watershed covering the Loboc Watershed Forest Reserve and the Chocolate Hills Natural Monument [49,50]. Section 13 of Ref. [50] restricted renewable energy projects within strict protection zones of the protected areas. However, as of the conduct of the study, data defining the strict zones inside the protected areas were not available. Given the situation, we applied the restrictions inside the whole protected areas, similar to a study of [16], and found only two of the nine sites on the main Loboc River to be developable. In the study of Sammartano et al. [16] in the Taw at Umberleigh catchment (South West England) all sites within protected areas were excluded due to environmental and economic issues. The UK Environment Agency required potential sites located within protected areas to secure permits and only the sites with well-designed measures preventing negative impacts may be allowed [16]. Integrating the best measures to ensure environmental integrity will entail higher investment cost to realize a hydropower plant [16].

Potential Sites Outside of Major Watersheds
The topographic analysis using a DEM, which covers the whole landscape, has identified more than half of the total potential sites outside the two major watersheds in the study area. These potential sites dispersed across the study area present an opportunity for remote areas to harvest hydropower, take advantage of the available resource, and provide power to small communities and small-agro industries, as documented in several studies [53,55]. The study results provide a new perspective on assessing a landscape for potential small-scale hydropower sites to encompass all watersheds irrespective of scale. In the initial assessment of an area for potential hydropower site exploration, such an approach is critical, giving insights into the overall hydropower potential of an island landscape. Further work to improve on this new approach, including the validation of the identified sites (ex. [16,20]), is suggested in future studies.

Small-Scale Hydropower Potential in the Island Landscape
The results of power capacity analysis showed that harnessing the hydro-based renewable energy sources in the study area will comprise several small-scale units distributed throughout the main island. However, there are contrasting feedbacks on the deployment of many small-scale hydropower systems due to environmental impacts and other issues (e.g., [9,53]). But for the Italian case where large-scale systems were already developed and suitable sites were already utilized, it was emphasized that increasing hydropower contribution could come from small-scale systems [56]. Moreover, many of the small-scale hydropower systems benefit rural development [8,53,55]. The advantages of these systems to rural areas in developing countries include improvement in productivity, women empowerment through energizing small agro-industries, and the notable little environmental impact. On a side note, small-scale hydropower systems are also challenged with high initial costs [55], but such can be counteracted by little operation and maintenance costs.
Notably, the study limits the potential sites to a minimum elevation head of 20 m. Future studies may consider a lower elevation head (<20 m) to identify potential hydropower sites. The global hydropower assessment of Hoes et al. [2] sets a minimum elevation head of 1 m but limits the river discharge to 0.1 m 3 /s to deliver the smallest hydropower plant capacity of 1 kW, while the study of Arthur et al. [35] considers 10 m as the minimum head in its final selection of hydropower sites.

Dataset Limitations
One of the challenges in resource assessment for many developing countries is the limited historical climate datasets, flow data, updated landcover, and soil hydrologic properties of a target landscape [13,57]). The study demonstrated the use of global datasets to estimate runoff from hydrologic soil group data, gridded precipitation data, and landcover datasets in the initial assessment phase. Several similar studies used global datasets such as the FAO digital soil map of the world to carry their analysis (ex. [35]). However, the study results still call for localized data to validate the estimated runoff and establish the efficiency of the CN method in estimating runoff for the target landscape. Furthermore, it would also be interesting to use physically based hydrologic models such as the studies of [16,18,35,58] to improve understanding of the hydrology of the study area. Further fieldwork such as those conducted by [16] is necessary to validate the results.

Geometric Index of Geo-Hazard Risk
The river profile analysis from a digital elevation model was employed to quantify the geo-hazard risk level associated with each potential site, using the geometric index k sn and knickpoints. The analysis gave insights on tectonically active areas in the landscape as manifested by the river channels' high river steepness index and presence of knickpoints, thus indicating the landscape's vulnerability to tectonic activity. A positive correlation of k sn with uplift rates, and the arrangement of knickpoints are indications that a landscape is temporarily reacting to regional uplift along the subduction zone as what Boulton et al. [26] found in the Makira, Solomon Islands. Further, the study [26] suggested that the formation and propagation of knickpoints was generated by an increase in uplift rates and the associated base-level fall. A study by [22] found severe damages to hydropower projects as primarily caused by earthquake-triggered landslides in the Himalayan region during the 2015 Nepal's Gorkha earthquake, and also revealed the landslides clustered in areas with high values for river steepness index and ground peak acceleration. Upon evaluation using seismic hazard and river steepness, the study [22] predicted most of the Himalayan rivers were unsuitable for hydropower projects. In their study, it was emphasized that hazard assessment for hydropower projects must consider both seismic and geomorphic settings of potential sites. Landform dynamics indicated by geomorphic indices, proxies of tectonic and climatic processes, are crucial for engineering structures that sit on transient landscapes as emphasized in the study of Geach et al. [23] Channel stability, according Schwanghart et al. [22], is a primary concern where hydropower structures are usually situated along or adjacent to 'steep river channels and towering sidewalls' that are disposed to become unstable during strong seismic activity.
The integration of geomorphic indices in the initial assessment of land resources for small-scale hydropower sites allow for classifying potential sites according to geologyrelated hazards. The classification maybe a useful tool to assist decision-makers and project developers to prioritize potential sites for further development. The study by Geach et al. [23] produced a geohazard constraint map showing ground related hazard. The maps are expected to provide guidance to the project crew in conducting field investigations, designing location-specific construction methodologies and in addressing ground limitations [23].
The current study, however, is limited to two geometric indices only. Future work may consider other metrics of surface and geology-related processes relevant to hydro-related structures such as those in the studies of [22,23]. The availability of landslide records in the study area may reinforce the usefulness of the river profile analysis in the initial assessment phase of hydropower development.

Land-Use Policy and Population Density as Constraints
Land-use classifications posed limitations to hydropower projects as promulgated by legal instruments. Existing land-use policy limits hydropower projects within 'strict zones' of protected areas [59]. Due to limited information on the zoning within declared protected areas, the study has considered the whole protected areas as strict zones, removing several potential sites. Meanwhile, the presence of end-users near potential sites is an indicator of project economic feasibility, specifically for micro and pico hydropower types. For these types, a minimum number of households that clusters near a potential site is a requirement to keep the cost of transmission low [3,53].
The constraint analysis, examining land use and population, has significantly reduced the number of potential sites by 73% and consequently the potential hydropower capacity by 60%. However, these two issues can be viewed as temporary constraints and are expected to change in the future. With the country's increasing population, there is a tendency that areas devoid of communities may later be encroached with clusters of households that need hydro-based energy sources to support their economic activities, turning the identified potential sites to be more economically viable. On the other hand, planning authorities may soon refine and precisely define zones under strict use within the protected areas. Once this happens, potential sites located in the protected areas but not in strict zones can be developed, thus, optimizing the hydropower potential found in the landscape.
As the economy develops, the demand for more energy to drive economic activities increases. It has been shown that energy generation significantly contributes to global warming and environmental impacts [6,7]. One way forward is to explore for lesser impacts and shift towards renewable energy sources, integral for a sustainable future. In many developing countries where land and water resources are available, the exploitation of hydropower sources is an attractive prospect [3,7]. Such systems offer less impact on the environment than fossil-fueled energy production, but initial investment cost seems high [3,7,35,54]. Knowledge of the possible adverse effects of hydropower and the underlying cost effectiveness are a challenge to future decisions on the scale of new developments. However, small-scale hydropower systems are still an alternative where the large-scale hydropower systems are no longer feasible or are already explored [60]. Other renewable sources such as geothermal, biomass, wind, and solar are other options to explore.

Conclusions
The resource assessment for hydropower site identification is usually limited to major watersheds identified in each landscape. A landscape's topography and hydrology are examined using GIS, terrain analysis tools, and hydrologic models to understand watershed parameters necessary to identify suitable locations and estimate hydropower capacity. Moreover, local datasets needed to carry out the analysis are usually not available or are limited. Advanced tools and the freely available global datasets enable the characterization of landscape dynamics for potential hydropower sites. An equally important factor to consider in the site exploration is the risk to geo-hazard and other surface processes in tectonically active landscape. Further, existing land-use policy in relation to environmental concerns and a population analysis posed as constraints to limit the identified potential sites. We applied the foregoing method in the island landscape of Bohol, the Philippines, and drew the following conclusions: (a) The approach employed in the study reveals potential small-scale hydropower sites inside major and small watersheds. More than half of the identified sites are located outside the major watersheds, with a share of about 21% of the total potential power capacity; (b) Freely available global datasets are successfully used to estimate runoff using the CN method and found runoff varying spatially and temporally across the landscape and at each potential site; (c) The hydropower potential in the study area consists of a range of small-scale hydropower systems with different power and energy generation capacities. In terms of number, the micro types dominate in the study area, but four small types provide almost half of the potential hydropower; (d) Each potential site is found under varying levels of geo-hazard risk innate to the geography and geology of the area. Seventy-four percent (74%) of the sites are under 'high-very high levels' of geo-hazard risk, while 52% of the total potential power capacity can be produced from low-risk sites; (e) The land-use and population analysis found several potential sites inside protected areas and in areas where the number of beneficiaries is still limited. The analysis result reduces the number of sites by 73%, and consequently, power capacity by 60%. Future changes in land-use planning and an increase in population in remote areas are seen to optimize the development of the identified potential sites; (f) The study produced decision-support maps showing the potential sites' spatial distribution, the hydropower types and power capacities, and the risk levels associated with each site. The maps are expected to provide crucial information for resource managers and decision-makers.

Acknowledgments:
The main author is grateful to the Graduate Scholarship Grant from DOST-ERDT at the School of Engineering-University of San Carlos and the Bohol Island State University-Bilar Campus for the support. The different sources of the local and global datasets used in the study are gratefully acknowledged.

Conflicts of Interest:
The authors declare no conflict of interest.
Appendix A Figure A1. A detailed flow of analysis for the study. Figure A1. A detailed flow of analysis for the study.    Figure A3. Details of the landcover in the study area. Figure A3. Details of the landcover in the study area.  Figure A4. Temporal and spatial variation of precipitation in the study area. Figure A4. Temporal and spatial variation of precipitation in the study area.  Figure A5. Spatial variation of the hydrologic soil group in the study area. Figure A5. Spatial variation of the hydrologic soil group in the study area.