fix 2 documentation typos

Author: softwareengineerprogrammer

docs/Fervo_Project_Cape-4.md

@@ -158,7 +158,7 @@ Fervo Energy. (2024, September 10). Fervo Energy’s Record-Breaking Production
 Enhanced
 Geothermal. https://www.businesswire.com/news/home/20240910997008/en/Fervo-Energys-Record-Breaking-Production-Results-Showcase-Rapid-Scale-Up-of-Enhanced-Geothermal
 
-Gradl, C. (2018). SReview of Recent Unconventional Completion Innovations and their Applicability to EGS Wells. Stanford
+Gradl, C. (2018). Review of Recent Unconventional Completion Innovations and their Applicability to EGS Wells. Stanford
 Geothermal Workshop.
 https://pangea.stanford.edu/ERE/pdf/IGAstandard/SGW/2018/Gradl.pdf
 

docs/Theoretical-Basis-for-GEOPHIRES.md

@@ -158,7 +158,7 @@ The method in GEOPHIRES to estimate capital cost is based on the following: (1)
 
 with _C_<sub>wells</sub>, _C_<sub>stim</sub>, _C_<sub>gath</sub>, _C_<sub>plant</sub>, and _C_<sub>expl</sub> as the total well cost, reservoir stimulation cost, field gathering system cost, surface plant cost, and exploration cost, respectively. GEOPHIRES has built-in correlations for each of these capital cost terms. Users can use these correlations directly, multiply them by a factor, or provide their own cost figures. The built-in capital cost correlations are as follows:
 
-* The total well cost (_C_<sub>wells</sub>) is calculated as the cost per well multiplied by the userprovided number of production and injection wells. GEOPHIRES considers all wells to have the same depth; however, this assumption can easily be modified to account for various well depths. Four correlations are implemented to estimate the drilling and completion cost per well based on the work by Lowry et al. (2017[^13]). These correlations include 15% contingency and 5% for indirect costs (project management and engineering costs) (DOE 2016<a href="#fn-8">[8]</a>). These correlations are for small well diameter (0.16 m casing inner diameter) vs. large well diameter (0.22 m casing inner diameter), and vertical and open-hole vs. horizontal and with liner. They are plotted in Fig. 3. Correlation 4 falls within 10% of both the large diameter well cost correlation implemented in GETEM (DOE 2016<a href="#fn-8">[8]</a>) and the geothermal well cost correlation developed by Lukawski et al. (2014[^14]). Correlation 2 follows closely (within 10%) the small diameter well cost correlation in GETEM. GEOPHIRES assumes as default a 100% well drilling success rate, which may overstate actual field drilling success rates. Sanyal and Morrow (2012[^15]) found an average success rate of 71%, based on drilling and production data in 52 geothermal fields. GETEM assumes as default a 75% drilling success rate for hydrothermal development wells and 90% drilling success rate for EGS development wells. To account for failed wells in GEOPHIRES, the user can assign a drilling cost multiplier (e.g., a multiplier of 2 for a 50% drilling success rate).
+* The total well cost (_C_<sub>wells</sub>) is calculated as the cost per well multiplied by the user-provided number of production and injection wells. GEOPHIRES considers all wells to have the same depth; however, this assumption can easily be modified to account for various well depths. Four correlations are implemented to estimate the drilling and completion cost per well based on the work by Lowry et al. (2017[^13]). These correlations include 15% contingency and 5% for indirect costs (project management and engineering costs) (DOE 2016<a href="#fn-8">[8]</a>). These correlations are for small well diameter (0.16 m casing inner diameter) vs. large well diameter (0.22 m casing inner diameter), and vertical and open-hole vs. horizontal and with liner. They are plotted in Fig. 3. Correlation 4 falls within 10% of both the large diameter well cost correlation implemented in GETEM (DOE 2016<a href="#fn-8">[8]</a>) and the geothermal well cost correlation developed by Lukawski et al. (2014[^14]). Correlation 2 follows closely (within 10%) the small diameter well cost correlation in GETEM. GEOPHIRES assumes as default a 100% well drilling success rate, which may overstate actual field drilling success rates. Sanyal and Morrow (2012[^15]) found an average success rate of 71%, based on drilling and production data in 52 geothermal fields. GETEM assumes as default a 75% drilling success rate for hydrothermal development wells and 90% drilling success rate for EGS development wells. To account for failed wells in GEOPHIRES, the user can assign a drilling cost multiplier (e.g., a multiplier of 2 for a 50% drilling success rate).
 
 ![Figure 3](_images/theoretical-basis-fig-3.png)
 
@@ -181,7 +181,7 @@ with _C_<sub>O&M,plant</sub>, _C_<sub>O&M,wells</sub>, _C_<sub>O&M,water</sub>,
 * GEOPHIRES estimates the annual surface plant O&M costs (_C_<sub>O&M,plant</sub>) as the sum of 1.5% of the total plant capital cost (for annual non-labor costs), and 75% of the annual labor costs, which is an approach similar to GETEM and GEOPHIRES v1.0 (Beckers 2016<a href="#fn-4">[4]</a>). The other 25% of the labor costs are assigned to the wellfield O&M cost. The labor costs are calculated internally in GEOPHIRES using the 2014 labor costs provided by Beckers (2016<a href="#fn-4">[4]</a>), indexed to 2017 using the Bureau of Labor Statistics (BLS) Employment Cost Index for utilities (BLS 2018[^21]). The original 2014 labor cost correlation expresses the labor costs as M$ year<sup>−1</sup> as a function of the plant size (MW) using an approximate logarithmic curve fit to the built-in labor cost data in GETEM (Beckers 2016<a href="#fn-4">[4]</a>).
 * The built-in correlation for the wellfield O&M costs (_C_<sub>O&M,wells</sub>) is similar as the surface plant O&M costs: it assumes that _C_<sub>O&M,wells</sub> consists of 1% of the total well plus field gathering system costs (for annual non-labor costs) and 25% of the labor costs (the other 75% of the labor cost were assigned to the surface plant O&M cost).
 * To account for loss of water in the reservoir (especially in the case of EGS-type reservoirs), the user can provide a water loss rate. GEOPHIRES estimates the annual costs to buy make-up water (_C_<sub>O&M,water</sub>) using a water price of $3.5/1000 gallons.
-* If the end-use option is direct-use heat only, then electricity is purchased at a userprovided electricity rate to power the geothermal fluid circulation pumps (_C_<sub>O&M,pump</sub>). In the case of electricity-only or cogeneration mode, the pumping power is considered auxiliary power and subtracted from the gross electricity generation.
+* If the end-use option is direct-use heat only, then electricity is purchased at a user-provided electricity rate to power the geothermal fluid circulation pumps (_C_<sub>O&M,pump</sub>). In the case of electricity-only or cogeneration mode, the pumping power is considered auxiliary power and subtracted from the gross electricity generation.
 
 ### Levelized cost models