April 1, 2014

IMPERIAL COUNTY AIR POLLUTION CONTROL DISTRICT

Authority to Construct and Permit to Operate Review

Minor Permit Modification

Permit: 2002I-3

Source Name: Ormesa, LLC

Source Type: Geothermal Power Plant 

Application for: Removal of Emergency Generators and 

Modification of Emergency Fire Pump

Mailing Address: Ormesa, LLC

P.O. Box 86

Holtville, CA 92250

Location: GEM 2&3 Electrical Generation Facility

3300 East Evan Hewes Highway

Holtville, CA 92250

Responsible Agent/

Facility Contact: Michael Moore,

Plant Manager

Phone: (760) 356-3020

Cell: (760) 457-8531

Permit Reviewer: Thomas Brinkerhoff,

APC Engineer 

Introduction

Ormesa, LLC submitted a permit application on March 19, 2014 to the Air District for the 

modification of Air District Permit No. 2002I-2. This permit, held by Ormesa, LLC, is for 

the emission sources within the GEM 2&3 electrical generation/geothermal plant, 

located at 3300 East Evan Hewes Highway in Holtville, CA. The permittee is seeking to 

remove two (2) existing diesel emergency generators from the permit, since the facility 

will no longer have the need for backup power from these units. Also, Ormesa is 

requesting to increase the annual limit for the maintenance and testing hours of the 

onsite emergency fire pump. This review will result in the issuance of a new Authority to 

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Construct (ATC) and Permit to Operate (PTO) for Ormesa, which will be numbered 

Permit 2002I-3. 

Project Description

The proposed project involves the removal of two existing diesel-fueled emergency 

generator sets, as well as the request to increase the hours of maintenance and testing 

for the fire pump. The two listed generators which were previously utilized at GEM 2&3 

are identical units, each driven by a Cummins Model NTTA85562 diesel engine with a 

rating of 535 bhp at 1,800 rpm. The generators will be completely disconnected from 

switchgear, as well as removing their batteries and fuel tanks which will render the units 

inoperable. As stated in the application, Ormesa will notify the Air District once the 

permanent disconnection is made and in the event that the generators are completed 

removed from GEM 2&3. 

As previously mentioned, Ormesa is also requesting to increase the emergency fire 

pump’s allotted hours per year for maintenance and testing (M&T) purposes to thirty 

(30) hours. The fire pump, which is driven by a Caterpillar Model 3306BDI diesel 

engine. The engine has a rating of 237 bhp at 1,800 rpm. The current annual limit for 

the unit stands at 20 hours per year, which was originally required per the California Air 

Resources Board’s (ARB) regulation for diesel engines known as the Airborne Toxic 

Control Measure for Stationary Compression-Ignition (CI) Engines (ATCM). In-use 

diesel engines, with a diesel PM standard greater than 0.40 g/bhp-hr, are required to 

limit M&T operations to 20 hours per year. However, in later versions of the ATCM, the 

allowance was made for emergency fire pumps to operate more than 20 hours per year 

for M&T in order to satisfy the testing requirements of the National Fire Protection 

Association (NFPA) 25 "Standard for the Inspection, Testing, and Maintenance of 

Water-Based Fire Protection Systems," 2002 edition. Therefore, the Air District will 

accept the new proposed M&T limit of 30 hours per year for the emergency fire pump 

and ensure that all applicable permit conditions are modified accordingly. 

Air Emissions

Emergency Combustion Equipment 

Emissions will continue to be produced by the existing Caterpillar emergency fire pump, 

however the potential to emit (PTE) from this source category will decrease, due to the 

removal of the two diesel-fueled emergency generators. Although the permittee has 

requested to increase the hours allotted for maintenance and testing of the fire pump 

from 20 to 30 hours in order to comply with NFPA 25 standard, the unit’s PTE will 

continue to be based on a total operation of 500 hours per year. The 500 hours per 

year operation rate is a standardized schedule which EPA has for emergency 

combustion equipment at major and synthetic minor sources. Air emissions were 

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calculated for the fire pump using emission factors from U.S. EPA AP-42, Ch. 3.3 and 

the engine specification sheet provided by the permittee:

Caterpillar Fire Pump

Unit NOx CO SOx PM10 VOC Benzene

lb/hr 5.05 2.69 0.59 0.26 0.41 0.0019

lb/yr 2526 1347 297 130 205 0.95

ton/yr 1.26 0.67 0.15 0.07 0.10 0.0004

New Facility PTE 

With the proposed removal of the two diesel emergency generators, the PTE for the 

GEM 2&3 geothermal facility will decrease. Below is the new PTE, post-modification, 

for GEM 2&3. The table includes both the daily and annual PTE for the facility, with the 

daily PTE based on normal operations (with the RTO/Scrubber system online) and one 

hour of testing of the emergency fire pump. For a detailed analysis of the other 

emission source categories of GEM 2&3, please refer to the Synthetic Minor Source 

review that was carried out in permit review 2002I-3 (Note: 2002I-3 incorrectly listed 

VOC emissions as 38.48 tons/yr, actually was 28.48 tons/yr). 

HAP and Regulated Air Pollutant Yearly Emissions

Pollutant *Daily 

(lbs/day)

Yearly 

(Tons/Yr)

Benzene 49.3 9.94

VOC(non-benzene)* 148.08 28.29

Hydrogen Sulfide 117.1 22.0

PM10** 173.41 31.68

Sulfur Dioxide 3.65 0.71

Nitrogen Oxides 18.8 3.77

*Includes Isopentane Emissions from OEC Units (142.9 lbs/day; 26.08 tons/yr)

**Includes PM10 Emissions from Cooling Towers (116.5 lbs/day; 29.42 tons/yr)

Benzene and hydrogen sulfide emissions are based on 8,400 hours per year of RTO 

operation and 360 hours of maintenance per year. PM10, sulfur dioxide, nitrogen 

oxides emissions are based on 8,760 hours of RTO operation.

Applicable Rules Compliance Status

108 Inspections In Compliance

109 Source Sampling In Compliance

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111 Equipment Breakdown In Compliance

201a Authority to Construct In Compliance

201b Permit to Operate In Compliance

204 Applications In Compliance

206 Processing of Applications In Compliance

207 New and Modified Stationary In Compliance

Sources

400.3 Internal Combustion Engines In Compliance 

401 Opacity of Emissions In Compliance

403 General Limitations on the In Compliance

Discharge of Air Contaminants

405 Sulfur Compounds Emission Standards In Compliance

Standards, Limitations and Prohibitions

407 Nuisance Rule In Compliance

900 Procedures for Issuing Permits In Compliance

for Sources Subject to Title V 

of the Federal Clean Air Act 

Amendments of 1990

1002 California Airborne Toxic Control In Compliance

CONDITIONS FOR AUTHORITY TO CONSTRUCT

AND PERMIT TO OPERATE No. 2002I-4

Synthetic Minor Source

A. General Conditions

1. The facility shall be constructed and operated in compliance with the project 

description and operating parameters of the following applications, except as 

may be modified by more stringent requirements of law or these conditions: (FR# 

31750), dated March 23rd, 1988; (FR#240364), dated January 12th, 1997; 

(FR#522563-522565), dated January 23rd, 2006; (FR#527237), dated October 

10th, 2006; (FR# 549046) dated August 22, 2007; (FR# 2011635910) dated 

February 9th, 2011; (FR#2011636) dated April 21st 2011; (FR#2012639920) 

dated March 19, 2014.

2. Operation of all equipment shall be in compliance with applicable APCD Rules 

and Regulations.

3. This permit does not authorize the emissions of air contaminants in excess of 

those allowed by the U.S. EPA (title 40 of the Code of Federal Regulation), the 

State of California Division 26, Part 4, Chapter 3 of the Health and Safety Code, 

or the APCD (Rules and Regulations).

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4. This permit cannot be considered permission to violate applicable existing laws, 

regulations, rules or statues of other governmental agencies.

5. No air contaminant shall be released into the atmosphere which causes a public 

nuisance. (Rule 407). 

6. The Permittee shall not release or discharge into the atmosphere from any single 

source of emission, any air contaminant as dark or darker as designated as No. 1 

on the Ringlemann Chart (20% opacity) for a period or periods aggregating more 

than three (3) minutes in any hour.

7. The Permittee shall comply with the general requirements for control of fine 

particulate matter (PM10); construction and earthmoving activities; bulk 

materials; carry-out and track-out; open areas; paved and unpaved roads; and 

conservation management practices.

8. The emissions of any regulated pollutant, as defined pursuant to 40CFR70.2, 

shall be less than the major source threshold values of Rule 900.B.20, of the 

Imperial County APCD, for the facility.

9. The emission of any single hazardous air pollutant, as defined pursuant to 

Section 112(b) of the 1990 Clean Air Act and Rule 900.B.20, shall be less than 

10 tons per year, for the facility. Total combined emissions of all hazardous air 

pollutants, as defined pursuant to Section 112(b) of the 1990 Clean Air Act and 

Rule 900.B.20, shall be less than 25 tons per year, for the facility. 

10. Total facility wide benzene emissions shall not exceed 9.93 tons per year.

11. Any unpaved roads, paved roads, and open areas subject to be disturbed by 

vehicles traffic shall comply with the requirements for fugitive dust control (Rule 

805).

12. The Permittee shall prevent or cleanup any carry-out or track-out (Rule 803).

13. All equipment shall be maintained in good operating conditions and shall be 

operated in a manner to minimize emissions of air contaminants into the 

atmosphere. 

B. Isopentane Emissions 

1. Under normal operating conditions: maintenance, Vapor Recovery Unit (VRU) 

purging and fugitive daily emissions, the total isopentane emissions shall not 

exceed a quarterly average of 142.9 lbs/day from the entire facility, as 

determined by inventory and mass balance procedures. 

a. All noncondensable gas (NCG) purging of any OEC Unit shall be 

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conducted through the facility’s Vapor Recovery Unit (VRU). The purging 

of gases through the VRU to the atmosphere shall be conducted only after 

the separation cycle of NCG and isopentane gases is completed. Purging 

of NCG to the atmosphere shall be conducted in a manner to minimize 

entrainment of isopentane gases with the NCG.

b. Isopentane emissions occurring during normal purging events shall be 

considered part of the daily average isopentane emissions for the total 

isopentane loss for the reporting quarter.

2. Isopentane emissions occurring during normal repair and maintenance shall not 

be considered a breakdown and shall be considered part of the daily average 

isopentane emissions for the total isopentane loss for the reporting quarter.

3. Prior to conducting maintenance, repairs or modifications on the portions of the 

OEC isopentane system that cannot be independently isolated, and the OEC 

isopentane system has to be open and exposed to air, the Permittee shall control 

the isopentane emissions by doing all the following:

a. Empty the OEC unit of Isopentane by pumping it to the Maintenance 

tanks.

b. Purge Isopentane Vapors from the OEC unit using nitrogen gas and 

condensing the Vapors through the portable VRU system equipped with a 

chiller. The liquefied Isopentane collected in the portable VRU tank shall 

be pumped to the storage tank.

c. The Portable VRU shall achieve a minimum 95% Isopentane vapor 

recovery efficiency during the purging of the emptied OEC before 

maintenance.

4. The Permittee shall install and maintain, in good working order, an in-line flow 

meter (cfm) at the inlet of the VRU. The flow meter shall be equipped with a 

totalizer.

5. Venting isopentane from an OEC Unit to the atmosphere for the sole purpose of 

evacuation is prohibited.

6. Any breakdown, malfunction, or upset occurrence which constitutes a breakdown 

condition resulting in the emission of any air pollutant to the atmosphere, shall be 

reported to the APCD as soon as reasonably possible but no later than two (2) 

hours after its detection, and should identify the time, specific location, equipment 

involved, and to the extent known the cause of the occurrence, and immediate 

remedial measures shall be undertaken to correct the problem and prevent 

further emissions into the atmosphere. The completion of corrective measures or 

the shutdown of emitting equipment is required within twenty four (24) hours of 

occurrence of a breakdown condition.

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7. If the breakdown condition will require more than twenty four (24) hours to 

correct, the Permittee, in lieu of shutdown, shall submit a variance application to 

the Air Pollution Control Officer (APCO) requesting to commence the variance 

procedure set forth in the APCD Hearing Board Procedures.

8. Within ten (10) days after a breakdown occurrence has been corrected; the 

owner or operator shall submit a written report to the APCO which includes:

a. A statement that the occurrence has been corrected, along with the date 

of correction and proof of compliance.

b. A specific statement of the reason(s) or cause(s) of the occurrence so that 

the APCO can determine whether the occurrence was a breakdown 

condition.

c. A description of the corrective measures undertaken and/or to be 

undertaken to avoid such an occurrence in the future.

d. An estimate of the emissions caused by the occurrence.

e. Pictures of the equipment or controls which failed, if available.

9. Failure to comply, or comply in a timely manner, with the reporting requirements 

shall constitute cause for enforcement action.

10. Isopentane breakdown emissions and losses shall be deducted from the total 

isopentane loss for the reporting quarter before calculating the daily average 

emissions. 

C. Regenerative Thermal Oxidizer/Scrubber Unit 

1. The Permittee shall install, operate, and maintain the RTO/Scrubber system

during all times the production wells are in use, except as provided below: 

a. Maintenance activities (operation of wells without the RTO/Scrubber 

system) shall be restricted to a maximum of 360 hours per year. 

b. The ICAPCD shall be notified at least 24 hours in advanced via fax or 

telephone before any scheduled maintenance is performed on the 

RTO/Scrubber system. 

2. For normal RTO/Scrubber operations, the following emission limits from the 

controlled NCG scrubber stack shall not be exceeded:

a. Benzene emissions 5.2 pounds per day.

b. Hydrogen sulfide emissions 1.66 pounds per day.

c. Sulfur dioxide emissions 3.06 pounds per day.

d. Nitrogen oxide emissions 13.75 pounds per day.

e. PM10 emissions 12.0 pounds per day.

f. VOC (not including Benzene) emissions 4.77 pounds per day

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3. The following emission limits from the condensate line (condenser hotwell/cooling tower) shall not be exceeded:

a. Benzene emissions 44.10 pounds per day.

b. Hydrogen sulfide emissions 115.44 lb/day.

4. During periods of operation without the abatement system (RTO/Scrubber) being 

online due to repairs and regular maintenance, including rock muffler venting 

events, which shall not exceed 15 days per year, emissions from the uncontrolled 

NCG stack and condensate line shall not exceed the following:

a. Benzene emissions 174.00 pounds per day.

b. Hydrogen sulfide emissions 198.48 lb/day.

c. VOC (not including Benzene) emissions 170.52 pounds per day.

5. Except during maintenance activities, the RTO combustion chamber 

temperatures shall maintain an operating temperature of at least 1,500° 

Fahrenheit. Propane shall be used during cold start-ups to pre-heat the RTO 

until the target temperature is reached.

6. The operating temperature of the RTO Combustion Chamber shall be monitored 

continuously; the data shall be logged and shall be available to the APCD 

inspectors to demonstrate compliance.

7. The Permittee shall continuously monitor noncondensable gas flow into the RTO, 

RTO combustion bed and chamber temperature, and RTO exhaust temperature. 

8. A log shall be maintained on the premises showing weekly hours of operation 

and routine repairs of the RTO/Scrubber system. This log shall be made 

available to the APCD for inspection upon request.

9. The operating scrubber water re-circulation rate and scrub water pH shall be 

continuously monitored and maintained in a daily log. The records shall be made 

available to the APCD for inspection upon request. .

10. The RTO/Scrubber system shall count with an electronic log in its PLC 

(Programmable Logic Controller) or DCS (Direct Control System) and shall be 

available for the APCD Inspectors showing hours of operation, shutdown hours 

for routine repairs and combustion chamber operating temperature.

D. Monitoring and Testing

1. The APCD may at any time monitor emissions from any source within the facility 

2. The APCD may at any time, but no more than twice per year, authorize thirdparty air emissions testing and/or an inventory of the air emissions of the facility. 

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The cost of the air emissions testing shall be borne by the Permittee. The APCD 

shall give advance notification to the Permittee prior to any air emissions testing 

or air emissions inventory required.

3. The Permittee shall conduct a source test of the facility every six months 

performing the following analyses:

a. Of turbine condenser condensate for: hydrogen sulfide, benzene, 

ammonia arsenic, beryllium, cadmium, chromium, copper, lead, 

manganese, mercury, nickel, radon, selenium, and zinc.

b. Of cooling tower blow-down for: hydrogen sulfide, benzene, ammonia, 

arsenic, beryllium, cadmium, chromium, copper, lead, manganese, 

mercury, nickel, radon, selenium, and zinc.

c. Of the non-condensable gas line for before the RTO/Scrubber system 

(uncontrolled) for hydrogen sulfide, ammonia, benzene, arsenic, mercury, 

radon, toluene, and xylene. 

d. Of the RTO/Scrubber Stack gas exhaust for: hydrogen sulfide, benzene, 

ammonia, SOx, NOx, and PM10.

e. Testing protocol shall be submitted to the District for approval prior to 

source test being conducted.

f. All source test analysis shall use U.S. EPA/ARB approved methods and/or 

ICAPCD approved equivalent.

g. During the source test the steam and the non-condensable gases mass 

flow rate shall be determined and the results submitted into the report in 

pounds per hour, per day and tons per semester for every pollutant. All 

analysis results shall be available at the facility for inspection.

h. The source test report shall include the results in pounds per hour, per day 

and tons per Semester of hydrogen sulfide, benzene and ammonia before 

and after BACT (RTO/Scrubber). SOx, NOx and PM10 emissions after 

BACT shall be included as well.

i. All official source tests shall be witnessed by an ICAPCD official. This 

condition may be waived upon ICAPCD written authorization.

4. The Permittee shall monitor through the sight glass the volume of the Isopentane 

in the working tank and storage tank on a weekly basis and every time in which 

the following occurs: 

a. maintenance is conducted and the OEC system has to be emptied and 

vapors recuperated through the VRU portable system.

b. a new load of Isopentane is added to the system.

5. The Permittee shall calculate all isopentane and reactive organic compounds 

daily emissions of pounds per day based on a quarterly average.

6. Each performance test protocol shall be submitted to the APCO for approval 30 

days prior to testing and should include the following:

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a. Emission unit identification and description

b. Sampling and analysis procedures

c. Test schedule

7. Performance tests for criteria pollutants, H2S and benzene shall be conducted in 

accordance with approved CARB or US EPA stationary source test methods (or 

alternate methods with prior written approval by the ICAPCD):

a. US EPA Methods 1-4 Sampling, Volumetric flow, Mw and %moisture

b. CARB Method 100 NOx, VOC, CO, CO2 and O2

c. SCAQMD Method 307 H2S

d. US EPA Method 6 SO2

e. CARB Method 410A Benzene

8. The Permittee shall conduct a Source Test of the portable VRU. The Source 

Test shall be conducted three months after the commissioning of the VRU; and 

every year thereafter, or sooner if requested by the APCO. The source testing 

shall use EPA methods or APCD approved equivalent. The source testing shall 

be witnessed by APCD staff. All analytical results shall be available at the facility 

for inspection. Source test shall be conducted for the following:

a. Of the non-condensable gases vented for: VOC’s, N2, O2, CO2.

9. The Permittee shall inspect, on a yearly basis, during the turnaround or plant 

shut down the Cooling Tower Drift Eliminators to ensure that every Cooling 

Tower Cell have the complete set of panels of Drift Eliminators and replace those 

that are damaged. 

10. The Permittee shall monitor, on a monthly basis, the cooling tower water 

chemistry including Total Dissolved Solids.

11. The Permittee shall provide records, collect samples or gather other required 

information to demonstrate compliance with APCD Rules and Regulations as 

requested by the APCO.

10. All required source testing, sampling, analysis and reporting costs shall be borne 

by the Permittee.

11. Upon proper notification, the APCD or its designee shall have the right to enter, 

inspect and take samples within the permitted facility. 

E. Reporting

1. The Permittee shall submit to the ICAPCD a report containing source test results 

conducted pursuant to the requirements of Condition D.3 (NCG, condensate, 

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cooling tower water and RTO/Scrubber) above, expressed in pounds per hour. 

The partial report shall be submitted to the APCD within 60 days of the preceding 

month and the annual report by the end of February of each operating year.

2. The Permittee shall submit to the ICAPCD a report containing the portable VRU 

source testing results pursuant to Condition D.8. The report shall be submitted 

within 60 days of the test.

a. Analysis conducted pursuant to the requirements of Condition D.8 above.

b. Based on the analyses conducted in Condition D.8, the emissions derived 

from the analyses, an emission inventory for the facility showing 

compliance with permit limits.

3. Permittee shall submit to the ICAPCD a quarterly report 30 days after the end of 

the quarter which consists of the following:

a. The Permittee shall submit an Isopentane inventory and mass balance,

including the changes in volume, for the working Isopentane tank and the 

used Isopentane tank. The Permittee shall calculate the Isopentane 

expended per day, week, month and year pursuant to the requirements of 

Conditions D.4 and D.5.

b. The total amount of isopentane renewals brought to the facility during the 

reporting quarter and the previous quarters of that calendar year. The 

facility shall include the isopentane supplier’s name and address.

c. The total amount of isopentane present at the facility before renewals.

d. The number of isopentane withdrawals from OEC units for maintenance.

e. The number of rotating seals replaced or installed, or any other OEC seal 

or gasket failure, that occurred during the reporting quarter.

f. The number of pressure relief rupture discs removed and replaced during 

the reporting quarter.

g. The total flow, in cubic feet, through the VRU during the reporting quarter.

h. The Permittee shall report to the APCD by telephone all non-normal 

(upset) releases of isopentane or geothermal gases to the atmosphere 

within 24 hours of the release occurrence. 

4. The Permittee shall submit to the ICAPCD an annual report by the end of 

February of each operating year. This report shall include the following:

a. Total tons of H2S, Benzene, SOx, NOx and PM10 emissions for the 

reporting year.

b. Types and quantities of cooling water additives.

c. The status of all active wells associated with this facility used for 

production or injection during the reporting year. For each well include the 

total days of rig activity (work over, clean out or drilling) and the total 

hours of venting to the atmosphere (from test units).

d. Gross and Net electrical megawatt-hours produced for the reporting year.

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e. The total volume and pounds of Isopentane expended (purchased) during 

the year.

f. The number of times that the OEC system was opened for repairs, 

maintenance or modifications.

g. The isopentane emissions report by month, by quarter and by year. 

5. Within 10 days after a breakdown occurrence has been corrected, the Permittee 

shall submit a written report to the APCO which includes the following: 

a. A statement that the occurrence has been corrected.

b. The reason(s) or cause(s) of the occurrence. 

c. A description of the corrective measures undertaken.

d. The type of emission and estimated quantity of the emissions caused by 

the occurrence.

F. Emergency Fire Pump

1. The listed diesel emergency fire pump shall be restricted to operate a total of 

thirty (30) hours per year for maintenance and testing purposes.

2. The listed emergency fire pump shall not discharge into the atmosphere any 

visible air contaminant other than uncombined water vapor, for a period or 

periods aggregating more than three minutes in any one hour, which is 20% 

opacity or greater.

3. The listed emergency fire pump shall be equipped with a non-resettable hour 

meter which must be kept in proper working condition at all times.

4. The diesel engine of the listed emergency fire pump shall be fueled only with one 

or a combination of the following:

a. CARB diesel fuel; or

b. an alternative diesel fuel, such as biodiesel or a biodiesel blend that 

does meet the definition of CARB diesel fuel; or

c. any alternative diesel fuel that meets the requirements of the 

Verification Procedure; or

d. CARB diesel fuel used with fuel additives that meets the 

requirements of the Verification Procedure.

5. The permittee shall maintain an engine operating daily log onsite for every month 

or any part of a month that the listed emergency fire pump operated. The 

Permittee shall maintain all required records required for a minimum of two (2) 

calendar years and make them available to the District upon request. The log

shall include the following for each emergency unit:

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a. Engine manufacturer name, model number, brake horsepower output 

rating, and type of fuel combusted;

b. A manual of recommended maintenance as provided by the engine 

manufacturer or other maintenance procedure as approved in writing by 

the APCO;

c. Record of routine engine maintenance, including date(s) and type of 

maintenance performed;

d. A specific emission inspection procedure, with an inspection schedule, to 

ensure that the engine is operated in continual compliance with Air District 

Rule 400.3. Inspections shall be conducted every quarter or after every 

2,000 hours of engine operation. In no event shall the frequency of 

inspections be less than once per year.

e. Total daily recorded hours of operation for maintenance and testing 

purposes.

f. Total daily recorded hours of operation for emergency events.

6. The Permittee shall submit to the APCD an annual report by the end of February 

of each operating year which contains the following information for the listed 

emergency fire pump:

a. Monthly fuel consumption 

b. Monthly hours of operation for maintenance and testing purposes.

c. Monthly hours of operation for emergency events.

Equipment List

1. Geothermal Production and Injection Wells 

Following is the list of production and injection wells associated with GEM 

Resources, LLC, GEM 2&3 Geothermal Power Plant facility:

No. of Wells PRODUCTION 

WELLS

INJECTION WELLS

1 P/W 88-7 I/W 83-7

2 P/W 24-8 I/W 63-7

3 P/W 54-7 I/W 27-7

4 P/W 41-7 I/W 33-7

5 P/W 71-7 I/W 53-17

6 P/W 82RD-7 I/W 61-7

7 P/W 61-12 I/W 81-7

8 P/W 54-12 I/W 8-1

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9 P/W 81-12 I/W 27-8

10 P/W 21-7 I/W 84-7

11 P/W 25-7 I/W 32-17

12 P/W 74-12 I/W 56RD-7

13 P/W 65-7 I/W 53-12

14 P/W 61-18 I/W 13-7

15 P/W 26-7 I/W 44-7

16 P/W 72-13 I/W 44A-7

17 I/W 44B-7

18 I/W 42-18

19 I/W 85-12

20 I/W 28-7

21 I/W 16-7

22 I/W 78-12

23 I/W 25A-7

24 I/W 49-7

2. Emergency Fire Pump 

One (1) Emergency Fire Pump, Caterpillar Diesel Engine, Model 3306BDI, with a 

rating of 231 hp at 1,800 rpm. 

3. Gems 2&3 Dual Flash Geothermal Power Generating Units (47MW).

4. Two Thermodynamic Cycle - ORMAT ENERGY CONVERTER (OEC) (10 MW).

a. Turbo generator skid

b. Lubricating and seal oil system skid

c. Heat exchangers Water-cooled condenser

d. Organic motive fluid and geothermal brine piping system.

e. Control and power system

f. Two Turbines: two stages, rated power at 1,800 rpm of 5,000 kW.

g. Synchronous type Generator, output rating 10,000 kV.

h. OEC Motive Fluid: Isopentane, charge 369,446.3 lbs

i. Isopentane storage tank

j. Isopentane working tank

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5. One (1) Vapor Recovery Unit (VRU), designated as VRU#2:

The VRU#2 is truck mounted, equipped with a 300 gallon heat exchanger, a 10-

ton R22 refrigeration units, a 200 gallon chilled water tank, and other ancillary 

equipment (VRU # 2 serves the Ormesa Geothermal II power plant; Ormesa 

Geothermal IH power plant; and the GEM 2&3 power plant).

6. Regenerative Thermal Oxidizer

a. Adwest Technologies RETOX dual-chamber RTO unit.

b Wet scrubber Envitech Packed Bed caustic scrubber.

7. Three (3) Cooling Towers

a For the flash plant two (2) Marley cooling towers counter flow; 

capacity of 41,800 gal/min re-circulation rate each.

b For the Ormat System one (1) Marley cooling tower counter flow; 

capacity of 34, 700 gal/min re-circulation rate.

Recommendations

Staff has carried out a full review of the permit application and has determined that the 

proposed project is a minor modification to GEM 2&3, resulting in no increase in the 

Potential to Emit for the geothermal power plant facility. Therefore, Staff recommends 

that an Authority to Construct (ATC) and Permit to Operate (PTO) be issued to Ormesa, 

LLC for the equipment and operations described herein. Please prepare and issue to 

the client the permit conditions and equipment list of this permit review along with the 

ATC and PTO.

Permit Fees

Rule 302, Schedule 6 – Geothermal Schedule:

Geothermal Resource Production/Utilization Facility 

Capacity: 37.0 MW – GEM 2&3 Power Plant.

$296.00 per MW (for each subsequent year) x 37.0 MW = $10,952.00

Ormat Energy Converters (OECs)

Capacity: 10.0 MW

$296.00 per MW (for each subsequent year) x 10.0 MW = $2,960.00

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Rule 302, Schedule 9 – Miscellaneous Schedule:

RTO and Scrubber System

2014 Fee: ($177.50 x 1 RTO/scrubber system) = $177.50

Standby Combustion Equipment 

2014 Fee: ($177.50 x 1 emergency unit) = $177.50

Evacuation Skid System-Vapor Recovery Unit (VRU) 

2014 Fee: ($177.50 x 1 VRU) = $177.50

Total Operating Fee: 

($10,952.00 + $2,960.00 + $177.50 + $177.50 + $177.50) = $14,444.50

2014 Operating Fee = $14,444.50 (Previously Paid) 

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