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Home My WebLink About20110734.tiff STATE OF COLORADO John W.Hickenlooper,Governor Christopher E. Urbina, MD,MPH /OP•coin\ Executive Director and Chief Medical Officer F� Z, Dedicated to protecting and improving the health and environment of the people of Colorado 4300 Cherry Creek Dr. S. Laboratory Services Division wave" Denver,Colorado 80246-1530 8100 Lowry Blvd. Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department Located in Glendale,Colorado (303)692-3090 of Public Health http://www.cdphe.state.co.us and Environment March 9, 2011 Mr. Steve Moreno Weld County Clerk 1402 N. 17th Ave. Greeley, CO 80631 Dear Mr. Moreno: The Air Pollution Control Division will publish a public notice for the Timberline Energy, LLC. This public notice will be published in the Greeley Tribune on March 15, 2011. Thank you for assisting the Division by making the enclosed package(includes public notice, preliminary analysis, Air Pollutant Emission Notice(s) and draft permit(s)) available for public review and comment. It must be available for public inspection for a period of thirty (30) days from the date the public notice is published. Please forward any comment regarding this public notice to the address below. Colorado Department of Public Health and Environment APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Attention: Ellen Evans Regards, Ellen Evans Public Notice Coordinator Stationary Sources Program Air Pollution Control Division -pi)30.0 ('e : /IL-C , PL 3 - � I -II 3 - Itx _I / 2011-0734 NOTICE OF REQUEST FOR CONSTRUCTION PERMIT FOR LANDFILL GAS TO ENERGY PLANT BY Timberline Energy, LLC CONTENTS 1 . PUBLIC NOTICE 2. PRELIMINARY ANALYSIS 3. AIR POLLUTANT EMISSION NOTICES 4. DRAFT PERMIT PREPARED BY: Matthew S. Burgett, P.E. COLORADO DEPARTMENT OF PUBLIC HEALTH & ENVIRONMENT 4300 CHERRY CREEK DRIVE SOUTH, APCD-SS-B1 DENVER, CO 80246-1530 STATE OF COLORADO John W.Hickenlooper,Governor " Christopher E.Urbina, MD, MPH F.0 op Executive Director and Chief Medical Officer 1' 90 Dedicated to protecting and improving the health and environment of the people of Colorado *n ''f ,;o • """"' 4300 Cherry Creek Dr.S. Laboratory Services Division . . 1676 Denver,Colorado 80246-1530 8100 Lowry Blvd. Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department Located in Glendale,Colorado (303)692-3090 of Public Health http://www.cdphe.state.co.us and Environment Released to: The Greeley Tribune on March 9, 2011, and Published on March 15, 2011 PUBLIC NOTICE OF A PROPOSED PROJECT OR ACTIVITY WARRANTING PUBLIC COMMENT The Colorado Air Pollution Control Division declares the following proposed construction activity warrants public comment. Therefore, the Air Pollution Control Division of the Colorado Department of Public Health and Environment hereby gives NOTICE, pursuant to Section 25-7-114.5(5), C.R.S. of the Colorado Air Quality Control Act that the Division received an application for an air pollution emission permit on the following proposed project and activity: Timberline Energy, LLC proposes to construct and operate three 2,233 horsepower landfill gas fueled engines near Denver Regional Landfill at 2200 Weld County Road 6, Erie, in Weld County. Each engine will combust up to 372.7 million standard cubic feet of landfill gas per year. The proposed engines are considered a single-source with Denver Regional Landfill (North & South) and Front Range Landfill for purposes of the Prevention of Significant Deterioration (PSD) and Nonattainment New Source Review (NANSR) programs. Upon issuance of the proposed permit, this source would be considered a PSD Major Stationary Source for Carbon Monoxide emissions, a NANSR Major Stationary Source for emissions Volatile Organic Compounds and Nitrogen Oxides, and a Major Source of Hazardous Air Pollutants. This source is also considered a Major Source for Title V Operating Permit requirements. This permit is subject to public comment since controlled emissions will exceed twenty five tons per year for this source located in a nonattainment area, and the engines are subject to Federal National Emission Standards for Hazardous Air Pollutants(Subpart ZZZZ). The Division has determined that the proposed source will comply with all applicable regulations and standards of the Colorado Air Quality Control Commission and has made a preliminary determination of approval of the application. Copies of the draft permit and preliminary analysis are available for review in the public comment package. The Division hereby solicits and requests submission of public comment from any interested person concerning the aforesaid proposed project and activities to comply with the applicable standards and regulations of the Commission for a period of thirty (30) days from the date of this publication. Any such comment must be submitted in writing to the following addressee: Matthew S. Burgett, P.E. Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-BI Denver, Colorado 80246-1530 Within thirty(30)days following the said thirty(30)-day period for public comment, the Division shall consider comments and, pursuant to Section 25-7-1 14.5(7)(a), either grant,deny, or grant with conditions, the emission permits. Said public comment is solicited to enable consideration of approval of and objections to the proposed construction of the subject project and activity by affected persons. A copy of the applications for the emission permits,the preliminary analysis of said applications, and accompanying data concerning the proposed project and activity are available for inspection at the office of the Clerk and Recorder of Weld County during regular business hours and at the office of the Air Pollution Control Division, Colorado Department of Public Health and Environment, 4300 Cherry Creek Drive South, Denver, Colorado. Construction Permit Application Preliminary Analysis Summary CDPHE-Air Pollution Control Division Information Permit Number: 1 O WE 1096 Company Name: Timberline Energy, LLC Source Location: 2200 Weld County Road 6, Erie AIRS ID: 123/0079/010-012 Date: March 9,2011 Review Engineer: Matthew S. Burgett Control Engineer: RK Hancock III Action Completed The Division will issue an Initial Approval permit. Application Administrative Completeness Review Was the correct APEN submitted for this source type? Yes Is the APEN signed with an original signature? Yes Was the APEN filled out completely? Yes Source Description Type of Source: Three landfill gas-fueled engines Is this a portable source? No Is this location in a non-attainment area for any criteria pollutant? Yes: Ozone PRELIMINARY ANALYSIS SUMMARY Permit No. l OWE 1096 Emission Estimate Information Emission Factor Source: AP-42& Manufacturer Did the applicant provide both actual and requested data for emissions? No Note: If no actual data year information was provided,annual fees will be based on permit limits. Permitted throughputs corresponding to permitted emission rates are: 372.7 million scf/yr each engine. Control Type:The engines will control landfill gas emissions from the landfill,but do not include any post combustion add-on control device. Emission Summary(tons per year) TSP PMI0 0 SO2 NOx VOC CO HAP Existing Facility, PTE 6.4 6.4 5.0 39.40 91.20 197.10 4.0 Existing Facility,permitted 6.4 6.4 5.0 39.40 91.20 197.10 Uncontrolled Emission Rate Timberline: Controlled Permitted 13.41 13.41 27.90 76.32 56.91 223.1 43.1 Emission Rate Timberline: Emission Rate at Potential 13.41 13.41 27.90 76.32 56.91 223.1 43.1 (based on design rate) Fugitive Emission Rate Non-Criteria/Hazardous Air Pollutants(pounds per year) Dichloromethane 245.6 Formaldehyde 65,700 HCI 13,364 Acetaldehyde 3,271.5 Stack Testing Requirements Will stack testing be required to show compliance with any emission rate? Yes The Division will require stack testing for NOx&CO due to the lack of data/confidence regarding emissions from landfill gas engines and the fact that these pollutants are at or above 80%of the Major level. In addition,the Division will require emission rate testing for VOC to verify the requested rates. The requested HAP emission rates were conservative and do not require testing. Page 2 PRELIMINARY ANALYSIS SUMMARY Permit No. 1 OWE 1O96 Source Classification Is this a new previously unpermitted source? Yes What is the source classification? Minor for PSD/NSR, Major for OP Does this permit require public comment per CAQCC Regulation 3? Yes - Emissions exceed 25 tpy. Modeling Is modeling required to show compliance with National Ambient Air Quality Standards(NAAQS)? Yes If"Yes", for which pollutants? PM IQ, PM25, CO,NO,, See attached Modeling Review Comments for modeling details. The Division is not requiring a modeling demonstration for the I-hr NO2 and 1-hr SO2 NAAQS since the construction permit application was received prior to the April 12, 2010 effective date of the 1-hr NO2 standard and the August 23, 2010 1-hr SO2 effective date. Regulatory Review Regulation I - Particulate, Smoke, Carbon Monoxide, and Sulfur Dioxide Opacity Regulation 2 -Odor Included in permit. Regulation 3 - APENs, Construction Permits, Operating Permits, PSD RACT requirement. Regulation 6 -New Source Performance Standards NSPS WWW applies. Regulation 7- Volatile Organic Compounds N/A—ICE requirements do not apply to landfill gas engines. Regulation 8 - Hazardous Air Pollutants, MACE Major source MACE ZZZZ. Page 3 PRELIMINARY ANALYSIS SUMMARY Permit No. 10WE1096 • erometric Information Retrieval System Coding Information Point Seg. SCC Code Segment Description Pollutant/ Fugitive Emission Factor& Control CAS /4 (YIN) Source Eft 010 2-02-002-54 2233 HP CAT engine(landfill TSP N 48 lb/MMdscf AP-42 0 gas fueled) CH4 2.4-5 PMIO N 48 Ib/MMdscf 0 CH4 PM2.5 N 48 lb/MMdscf 0 CH4 SO2 N 0.431 g/hp-hr Mfg. 0 NOx N 1.18 g/hp-hr Mfg. 0 CO N 3A5 g/hp-hr Mfg. 0 VOC N 0.88 g/hp-hr Mfg. 0 Methylene N 81.88 lb/yr AP-42 2.4 0 Chloride Formaldehyde N 58.8 Eng. Est. 0 50000 lb/mmscf Acetaldehyde N 2.93 Eng. Est. 0 75070 lb/mmscf HCI N 12.0 Eng. Est. 0 7647010 lb/mmscf 011 2-02-002-54 2233 HP CAT engine(landfill Same as point 010 above. gas fueled) 012 2-02-002-54 2233 HP CAT engine(landfill Same as point 010 above. gas fueled) Miscellaneous Application Processing Notes An application from Timberline Energy, LLC was received to permit three landfill gas fueled engines at Denver Regional Landfill. The"Denver Regional Landfill" single-source includes multiple sources including: Denver Regional Landfill South, Denver Regional Landfill North, Front Range Landfill, and Timberline Energy. These are all considered a single source for Title V and PSD/NSR purposes. Front Range Landfill was recently added as a single source due to its purchase by Waste Connections. The Division sent a letter on August 25,2009 to Waste Connections with the determination that Front Range Landfill is a single source with Denver Regional Landfill. Timberline originally sent the application to add two engines to the construction permit 08WE0517 (which already contained one engine). However, the Division identified some PSD implications with this approach. In addition,the engines are now proposed to be located at a different area than originally contemplated with the 08WE0517 permit. Since construction had not commenced on the engine under permit 08WE0517,Timberline requested cancellation of 08WE0517, and requested the three engines be permitted under a new construction permit. The Division agrees with this approach. The Division received some paperwork from R. Martin Ostholthoff requesting comments on the development proposal by Page 4 PRELIMINARY ANALYSIS SUMMARY Permit No. 1 OWE I096 Timberline Energy. The Division contacted him to discuss the typical permitting process. NSPS WWW The Division included applicable requirements from NSPS WWW which generally relate to the treatment system which must treat the landfill gas prior to combustion in the engines. Proposed revisions to this NSPS have been published, but have not been finalized. These proposed revisions focus on additional requirements of the treatment system. Timberline will need to comply with any future revisions to NSPS WWW as it applies to the treatment system. Timberline submitted information to the US EPA Region 8 regarding the details of the treatment system on September 23, 2010. EPA responded on December 22,2010 agreeing that the proposed landfill gas recovery plant would qualify as a "treatment system" for NSPS WWW purposes. NESHAP Subpart ZZZZ These engines are subject to some requirements of this rule. The rule currently requires new engines>500 HP located at a major source of HAP emissions which combust landfill gas? 10%to meet the following requirements: initial notification, monitor/record fuel use daily,Table 7 annual report, records of daily fuel use monitors. They do not need to meet the emission/operating limitations of this subpart. The applicable ZZZZ requirements have been included in the permit. Reasonably Available Control Technology(RACT) A RACT analysis was previously conducted for the engine covered by permit 08WE0517. The RACT required compliance with New Source Performance Standards (NSPS) Subpart JJJJ for control of spark ignition internal combustion engines. The Division believes this is appropriate for RACT and will include it in this new construction permit. Subpart JJJJ includes emission standards based upon the engine date of manufacture. Hazardous Air Pollutants(HAPs) The original application and APEN did not include any estimate of certain HAP emissions known to be emitted from natural gas fueled internal combustion engines. For example, it is known that formaldehyde emissions result from gas-fueled engines. The Division was going to require stack testing to determine certain HAP emissions(Formaldehyde, Acetaldehyde, HCl). However,Timberline submitted revised APENs(received August 10,2010)and emission calculations to include emission estimates of these HAPs. The Division has accepted these estimates and will remove the HAP testing requirements since they are conservative estimates. The permit was originally drafted as a Synthetic Minor source of HAPs with the required 8/20 ton/yr HAP limits. Timberline commented that it could be difficult to coordinate with the other landfill entities to obtain the appropriate HAP data to monitor compliance with the HAP limits. With the submittal of the revised APENs to report the additional HAP emissions,Timberline and the landfills are now considered a Major source of HAPs. The Synthetic Minor HAP limits have been removed and the appropriate Major HAP requirements have been added (i.e. MACT ZZZZ). Prevention of Significant Deterioration (PSD)and Nonattainment New Source Review (NANSR) This facility(including DRL& FRL)was considered a minor stationary source prior to this permit. After permit issuance, this facility will be considered a Major Stationary Source for NOx, VOC, and CO. Any future modifications will need to conduct PSD/NSR review if the emissions increase is above the significance level(s). DRL may be able to reduce some of the permitted emission limits from the separately permitted flare once the engines are operational to seek minor status. Alternative Operating Scenarios (AOS) The Division updated the engine AOS with the current version 12/10/2008. This AOS was designed for natural gas fueled compressor engines. Some language in the AOS may be confusing due to this. The Division finds that it should also apply to these landfill gas fueled engines and should be interpreted as such. Operating & Maintenance Plan (O&M Plan) Since the engines are used to control landfill gas emissions, an O&M plan is required. The submitted O&M plan should include some parameter monitoring/recordkeeping on the treatment system, including the change in pressure across the Page 5 PRELIMINARY ANALYSIS SUMMARY Permit No. lOWE1096 filters,the change in temperature for the cooler stage, and acceptable operational ranges for those parameters. Page 6 Colorado Department of Public Health and Environment Modeling Review Comments APCD/TSP/MMEIU Project ID: 414-100202 Review Completed: 2/28/2011 Plant/Site Name: Document Reviewed: Timberline Energy at Denver Regional Landfill South modeling submittals prepared by Air Sciences. Jan 2110 and Jun 20)0. Timberline Energy at Denver Regional Landfill South modeling submittals prepared by 1)eren_o and Associates. Inc.Oct 2010,Jan 18.2011.Jan 26.2011.and Feb 2,2011. Reviewed by: Doris Jung Summary The NAAQS and CAAQS currently in effect arc CO(i-hr,8-hr),Pb(rolling 3-month,quarterly),NO2(I-hr, annual), PM 10(24-hr),PM2.5(24-hr,annual).SO2(l-hr,3-hr,24-hr,and annual),and ozone(8-hr).Quantitative impact analyses are warranted to demonstrate compliance with the following pollutants/averaging periods:CO(1- hr,8-hr),NO2 (1-hr,annual), PM 10(24-hr),PM2.5(24-hr,annual),SO2(1-hr). 'I'he applicant's impact analyses have not demonstrated compliance with the NO2(1-hr)NAAQS or the SO2(I- hr)NAAQS.Compliance demonstrations for these NAAQS should be submitted by the applicant to ensure that a requirement of Colorado AQCC Regulation 3, Part B,Section'MD(the proposed source or activity will not cause an exceedance of any National Ambient Air Quality Standards)is satisfied. Compliance with the CO(1-hr,8-hr)NAAQS,PMI0(24-hr)NAAQS, PM2.5(24-hr and annual)NAAQS,NO2 (annual)NAAQS has been demonstrated under the following facility configuration(recommended permit conditions): I)Fencing and Preclusion of Public Access-impacts were estimated at ambient air receptors only(i.c.,an ambient air boundary.`fencing along the leased property boundary was assumed in the modeling-Feb 2,2011 submittal). The permit should contain a condition that,for the duration of permit effectiveness,the source operator shall maintain continuous fencing along the leased property boundary as depicted in the June 11,2010 site plan and preclude public access into this fenced area. 2)Stack I'eight-The engine exhaust stack heights were increased from the heights stated in the APENs received by the Division(Aug 10,2010) to lower modeled impacts and demonstrate compliance with the PM2.5 NAAQS. The permit should contain a condition that,for the duration of permit effectiveness,the engine exhaust shall be discharged at 40 feet above ground level,unobstructed and vertically upward. Ave Maximum Background Total Pollutant Period Modeled Concentration Impact NAAQS PM I O 24-hr 41.3 pg/m3 75 µg/m3 116.3 µg./m3 150 pg/m3 PM2.5 annual 0.9 µg/m3 (5-yr average) 9 µglm3 9.9 µg/m3 15 µg/m3 PM2.5 24-hr 9.8 µgim3 (5-yr average) 19 jig/m3 28.8 pg/m3 35 µg!m3 NO2 annual 3.4 µg/m3 22.6 µ<g/m3 26.0 µg/m3 100 µg/m3 Date Printed: 2/28/2011 Page 1 of 9 Air Pollution Control Division /Technical Services Program Modeling Review Comments APCD/TSP/MMEIU Project Ill: 414-100202 Review Completed: 2/28/2011 Plant/Site Name: Document Reviewed: Timberline Energy al Denver Regional Landfill South modeling submittals prepared by Air Sciences. Jan 2010 and Jun 2010. Timberline Energy at Denver Regional Landfill South modeling submittals prepared by Derenso and Associates. Inc. Oct 2010.Jan 18. 2011.Jan 26,2011, and Feb 2, 2011. Reviewed by: Doris Jung CO I-hr facility's impacts<mudding significance level(2000}tg/m3) 40,000 µg/m3 CO 8-hr facility's impacts<modeling significance level(500 µg/m3) I 0.000 µgim3 Review Checklist I.Topographic Map with Site and Receptor Locations Missing 2. Plant/Site Plot Plan 'Satisfactory 1 Most current site plan dated June II,2010(attached)was submitted with the Feb 2, 2011 submittal. 3. Building Dimension Data Satisfactory Building dimensions discussed in Feb 2,2011 submittal. I3PiPPRM tiles submitted. The building(only one on the site plan)elevation was determined using the June I I, 2010 site plan contours. 4. Determination of Fenceline 'Satisfactory I Fcnceline is assumed at leased property boundary identified on the June I I,2010 site plan.The permit should contain a condition to require fencing along the leased property boundary(see Summary). 5. Identification of Nearby Nonattainment Areas 'Not Addressed I This proposed facility is located within the 8-hr ozone nonattainment area and is.just outside of the I-hr ozone, PM 10,and CO attainmenttmaintenance areas. 6. Identification of Pollutants/Averaging Periods to Model Unsatisfactory Quantitative impact analyses are warranted to demonstrate NAAQS compliance with the following pollutants/averaging periods:CO(1-hr, 8-hr),NO2 (1-hr,annual), PM l0(24- hr),PM2,5(24-hr.annual),SO2(I-hr). The submittals included impact analyses for CO(1-hr and 8-hr), PM 10(24-hr), PM2.5 (24-hr and annual),NO2(annual). A compliance demonstration for the I-hr NO2 NAAQS (effective April 12,2010)should be submitted by the applicant since it is reasonable to believe that the proposed modification may contribute to the violation of the 1-hr NO2 NAAQS (permit will be Date Printed: 2/28/201 I Pale 2 of 9 Air Pollution Control Division /Technical Services Program Modeling Review Comments APCI)/TSP/MMEIU Project ID: 414-100202 Review Completed: 2/28/2011 Pla nt/Site Name: Document Reviewed: Timberline E'nerj,at Denver Region!Landfill South modeling submittals prepared by Air Sciences. Jan 2010 and Jun 2010. Timberline Energy at Denver Regional Landfill South modeling submittals prepared by Deren_a and Associates, Inc. Oct 2010.Jan 18.101 1.Jan 26, 2011.and Feb 2,2011. Reviewed by: Doris Jung issued after the NAAQS effective date)based on preliminary impact estimates. A compliance demonstration for the I-hr SO2 NAAQS(effective August 23,2010) should be submitted by the applicant since it is reasonable to believe that the proposed modification may contribute to the violation of the 1-hr SO2 NAAQS(permit will be issued after the NAAQS effective date)based on preliminary impact estimates. 7.On-Site NAAQS/Non-Criteria Pollutant Emission Inventory Indeterminate Verification of emission rates and exhaust stack parameters of the proposed facility is deferred to the permit review engineer.Modeled emission rates were compared to the requested emissions stated on the APENS received by the Division on August 10,2010. Modeled stack parameters are compared to Table 2 of the Feb 2,2011 submittal. 8.On-Site PSI) Increment Emission Inventory Not Addressed A preliminary determination in June 1998 from the Colorado Attorney General's office suggests that rulemaking would be necessary before compliance with PSD increments is a requirement of permit issuance for minor sources and minor modifications. Therefore, increment consumption from minor source growth is assessed only during the modeling process for new sources and modifications subject to PSD rules and during periodic increment studies. 9. Off-Site NAAQS/Non-Criteria Pollutant Emission Inventory Satisfactory Nearby source inventories were provided by the Division for PM I0iPM2 5 (Jun 2, 2010),NO2/CO(Dec 4,2009). Nearby facilities explicity modeled in MM1:iIJ's PM 10/PM2.5 cumulative impact analyses: Asphalt Specialties-Erie 11MA facility,Sundrops Inc,Van-a Companies Inc, Denver Regional/Front Range Landfill,and Interstate Stone LLC.Arca source representation(size and location)were determined for the latter three(3)facilities by estimating the disturbed area visible on the aerial image(NAIP 2009). Nearby facilities explicity modeled in MMFlU's NO2 cumulative impact analysis:entire NOx inventory provided by the Division. • 10.Off-Site PSD Increment Emission Inventory Not Addressed See lib above. Date Printed: 2/28/201 I Page 3 of 9 Air Pollution Control Division /Technical Services Program Modeling Review Comments APCD/TsP/MMEIU Proje•rt ID: 414-100202 Review Completed: 2/28/2011 Plant/Site Name: Document Reviewed: Timberline Energy at Denver Regional Landfill South modeling submittals prepared by Air Sciences. Jan 21)10 and Jun 2010. Timberline Energy at Denver Regional Landfill South modeling submittals prepared by Derenao and .dssr,ci"ter, Inc.Oct 2010.Jan I .2011.Jan 26.2011,and Feb 2. 2011. Reviewed by: Doris Jung 11, Background Concentration(s) Satisfactory TO: Ejaz Memon FROM: Nancy Chick SUBJECT: Background for Southwestern Weld County DATE: June 2,2010 Per your request,here arc background estimates for the facility at NAD 83,Zone 13, UTM 499,600 meters east and 4,431.880 meters north.This is in Weld County, set theast of Erie. PM[0 Annual Mean 30 ug/m3 Platteville, 1993-1994 24 '.'.iur2nd Maximum 75 ug/m3 PN1l.5 Annual Mean 9 ug/m3 Platteville,2004 - 2006. 24 Hour 98th Percentile 19 ug/m3 Please note that these estimates arc derived from ambient monitored concentrations that are available to the Division to represent background levels(added to the impacts of the project emissions and emissions from other nearby sources)in cumulative ambient air iml•:nets for comparison to the NAAQS. They are not suitable for applications beyond that scope of use.The quantity of data is sometimes limited and may be of uncertain quality. The ambient background concentrations- 1. Do not necessarily substitute for on-site monitoring data. 2. Indicate the ambient levels in general geographic areas,not a specific location. This is particularly true for particulate concentration values. 3. Arc subject to change without notice as new information is acquired. Use of these background estimates should be accompanied by an appropriate citation that indicates their source and their limitations. Referencing this memorandum would be adequate,but an expanded explanation is suggested. Date Printed: 2/28/2011 Page 4 of 9 Air Pollution Control Division /Technical Services Program Modeling Review Comments APCD/TSP/MMEIU Project ID: 414-100202 Review Completed: 2/28/2011 Plant/Site Name: Document Reviewed: Timberline Energy at Denver Regional Landfill South modeling submittals prepared by/fir Sciences. Jan 2010 and Jun 2010. Timberline Energy at Denver Regional Landfill South modeling,submittals prepared by Ueren_a and Associates. Inc, Oct 2010.Jan 18.2011.Jan 26.2011,and Feb 2. 2011. Reviewed by: Doris Jung Recommended by Nancy Chick: NO2(annual)-0.012 ppm CO(1-hr)-4 ppm CO(8-hr)-3 ppm NO2(I-hr)-0.084 ppm SO2(I-hour)-0.050 ppm 12.Selection of Model(s) Satisfactory AERMET(06341;MMEIU-processed tiles).BPIPPRM(04274).AERMAP(09040). AERMOD(09292). 13.Selection of Modeling Parameters 'Satisfactory Nearby source facilities that were modeled as arca sources assumed a release height of 2 meters and an initial vertical dimension of 3 meters. 14. Receptor Network Satisfactory The Jan 2010 and Jun 2010 submittals utilized•a receptor grid network that covered the surrounding area to 10 km.The Oct 2010,Jan 18.2011,Jan 26,2011,and Feb 2.201 1 submittals that address PM 10 and PM2.5 utilized a smaller receptor grid(out to—1.3 km west and—1.9 km for all other cardinal directions). This smaller receptor grid is acceptable and used to execute the MMEIU modeling runs for PM2.5, PM 10,CO.and NO2(annual)since the significant impact arca is less than 1 km from the facility. However,this smaller receptor grid would need to he expanded to fully capture the significant impact area if impact analyses are completed for 1-hr NO2 or I-hr SO2. Fenceline receptors are spaced less than 50 meters apart along the 200'x 312'leased property boundary.Fenceline receptor elevations used in the MMERJ modeling are derived from elevation contours on the site plan. Elevations for all other receptors are derived with AERMAP using NED(1/3 arc-sec). Impacts within the fenccline were not estimated. 15.Treatment of Atmospheric Chemistry(NOx conversion) Not Addressed 16.Standard Temperature Pressure Corrections Not Applicable SIP corrections are currently not required for permit modeling in Colorado. i7. Meteorological Data for Model(s) Date Printed: 2/28/2011 Page 5 of 9 Air Pollution Control Division I Technical Services Program Modeling Review Comments APCD/TSP/MMEIU Project ID: 414-100202 Review Completed: 2/28/2011 Plant/Site Name: Document Reviewed: Timberline Energy at Denver Regional Landfill South modeling submittals prepared by Air Sciences. Jan 2010 and Jun 2010. Timberline Energy at Denver Regional Landfill South modeling submittals prepared by Deren_o and Associates.Inc,Oct 2010.Jan 18,2011.Jan 26.2011.and Feb 2,2011. Reviewed by: Doris Jung Satisfactory Meteorological determination provided by Emmett Malone 11/2/09: The Division has completed the AERMOD meteorology determination for: Source: Denver Regional Landfill Approximate Location:497598m E,4430552 m N,Zone 13,NAD 83 There arc no existing meteorological data,to the Division's knowledge,that are adequately representative of dispersion conditions expected at this site.Consequently, the applicant may either collect a year of site-specific meteorological data(see option I) to support a refined AERMOD modeling analysis,or the applicant may perform a screening impact analysis with AERMOD and the hourly meteorology presented in option 2.1f AERMOD is used in a screening type mode with hourly meteorological data, design value restrictions will apply.The applicant is welcome to provide additional information to assist the meteorological determination.process. OPTION 1: Collect at least one year of site specific meteorological data with a tower setup and location approved by the Division.The monitoring program must be performed in accordance with U.S.EPA accepted procedures as approved by the Division. If this option is pursued,it is strongly recommended that a monitoring plan be prepared and submitted to the Division for review prior to collection of the data.Once data has been collected and approved by the Division,contact the Division for site-specific AERME'f processing guidance. OP'T'ION 2: SURFACE METEOROLOGY: Met Site: Denver Stapleton Tower LAT/LONG: 39.768N, 104.869W Tower type:National Weather Service pre-ASOS Data period: 1990- 1994(5 years) Anemometer he I Om Profile Base Elevation: 5285 ft UPPER MR METEOROLOGY Site: KDEN(Denver,Colorado) WI3AN number:23062 Data type: Radiosonde Site LAT/LONG:39.77N, 104.88W Date Printed: 2/28/2011 Page 6 of 9 Air Pollution Control Division /Technical Services Program Modeling Review Comments APCD/TSP/MMEIl1 Project ID: 414-100202 Review Completed: 2/28/2011 Plant/Site Name: Document Reviewed: Timberline Energy at Denver Regional Landfill South modeling submittals prepared hyAir Sciences, ./an 2010 and Jun 2010. Timberline Energy at Denver Regional Landfill South modeling submittals prepared by DLren_o and Associates, inc.Oct 2010,Jan 18.2011.Jan 26. 2011.and Feb 2,2011. Reviewed by: Doris Jung Collected by: National Weather Service Data format:NOAA Forecast Systems Laboratory(fsl)format Data availability: AERMOD ready files are attached. AERMOD Screening Impact Analysis Design Concentration: Since there are representativeness issues,for short term standards(24 hour average or less),use the "high 1st high"value in the compliance demonstration. in addition, if determining compliance with the annual NO2 standard,use either the Tier 1 (100%conversion of NO to NO2)or Tier 2 method from 40 CFR 51 Appendix W. If the Tier 2 method is used, the recommended empirically derived NO2/NOx value in Colorado is 0.75(i.e.,multiply the Tier 1 cstimate(s)by 0.75 to convert NOx to NO2). This determination is not applicable for an unlimited period and may expire if there is a substantial delay between the date of this determination and the submittal of the permit application. If the location of the source moves or if additional modeling is warranted in the future at this site,contact the Division to find out if this met determination is still valid. This determination is applicable provided that the permit application is not subject to the major source PSD rules.if the permitting action is subject to major source PSD rules,please contact the Division for a PSD pre-construction monitoring determination. 18.Other Modeling Data Satisfactory Elevations for the proposed sources used in the MMEIU modeling are derived from elevation contours on the site plan.Nearby source elevations derived with AERMAP using NED(1/3'arc-sec). The entire facility/property is shifted to the west by approximately 60 ft.Correction of this slight shift is not expected to change the outcome of the compliance demonstrations and was therefore not performed. 19. Modeling Input/Output Files Provided Electronically (Satisfactory 20.Comparison of Impacts with Significance Levels Satisfactory For the pollutants/averaging periods addressed by the submittals(sec 116 above)that have impacts exceeding their respective Slis,cumulative impact analyses were submitted for 24-hr and annual PM2.5, 24-hr PM 10,and annual NO2. Date Printed: 2/28/2011 Page 7 of 9 Air Pollution Control Division ! Technical Services Program Modeling Review Comments APCD/TSP/MMEiU Project ID: 414-100202 Review Completed: 2/28/201 I Plant/Site Name: Document Reviewed: Timberline Energy at Denver Regional Landfill South modeling submittals prepared by Air Sciences, Jan 2010 and Jun 2010. Timberline Energy al Denver Regional Landfill South modeling submittals prepared by Derenso and Associates, Inc,Oct 2010.Jan 18, 2011,Jan 26.2011. and Feb 2, 2011. Reviewed by: Doris Jung 21. Comparison of impacts with Class I 24hr lug/m3 Rule Not Applicable Proposed facility is not a PSD source. 22.Compliance with "75%of Applicable Increment" Rule Not Applicable Proposed facility not subject to PSD requirements. 23.Selection of Geographic Area for Full Impact Analysis Satisfactory 24.Compliance with Class I PSD increments Not Addressed Sec#8 above. 25.Compliance with Class II PSD increments Not Addressed See#8 above. 26. Compliance with NAAQS and State Standards Unsatisfactory AERMOD Screening Impact Analysis Design Concentration for meteorological data Option 2(sec#17 above) : Since there are representativeness issues, for short term standards(24 hour average or less),use the"high 1st high" value in the compliance demonstration. In addition, if determining compliance with the annual NO2 standard, use either the Tier I (100%conversion of'NO to NO2)or Wier 2 method from 40 CFR S I Appendix W. If the Tier 2 method is used,the recommended empirically derived NO2/NOx value in Colorado is 0.75(i.e.,multiply the Tier 1 estimate(s)by 0.75 to convert NOx to NO2). The proposed Timberline facility(Feb 2,201 I configuration)will not cause or contribute to a violation of the annual and 24-hr PM2.5,24-hr PM l0, and annual NO2 NAAQS. See Summary above. Compliance with the 1-hr NO2 NAAQS and 1-hr SO2 NAAQS has not been demonstrated for the proposed Timberline facility. See!6 above. 27. Compliance with Non-Criteria Pollutant Thresholds Not Addressed 28. Determination of Pre-/Post-Monitoring Requirements Not Applicable Proposed facility not subject to PSD requirements. Date Printed: 2/28/201 1 Air Pollution Control Division/Technical Services Program Modeling Review Comments APCI)/TSP/MMEIU Project ID: 414-100202 Review Completed: 2/28/201 I Plant/Site Name: Document Reviewed: Timberline Energy at Denver Regional Landfill South modeling.submittals prepared by Air Sciences. .lam 2(110 and Jun 2010. Timberline Energy at Denver Regional Landfill South modeling submittals prepared by 1)eren:o and .Associates. Inc. Oct 2010../an 18,2011.Jun 26.2011.and Feb 2. 2011 Reviewed by: Doris Jung 29.Visibility Impairment and AQRV Analyses Not Applicable , Proposed facility not subject to l'SD requirements. 30.Anticpated Growth/Soils/Vegetation Analyses Not Applicable Proposed facility not subject to PSD requirements. 31.Compliance with Regulations in Affected Adjacent States Not Applicable 32. Risk Assessment Not Addressed Risk assessments and review of impacts from hazardous air pollutants are not pertbnncd on a routine basis and are only performed when a specific request is made by the Stationary Sources Program(SSP). SSP did not request a risk assessment fbr this modification. Access to data, notes,and files: All information necessary to form the basis of the air quality compliance demonstration is transmitted to the permit reviewer for inclusion in the permit file. In sonic cases, the Technical Services Program retains ambient air monitoring and modeling data,ambient monitoring and modeling plans and reports, electronic modeling input/output files,and other files.These files may contain documents that arc considered to be part of a deliberative process. Date Printed: 2/28'2011 Page 9 of 9 Air Pollution Control Division I Technical Services Progrsm N Ii W 0 an 44 pa, u u y G — ^{ zn -� :� = vii a .c E u c o z ' .. ` L T E U • "/-.1 n ,.. 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ICI '� 0 y p o R C _. y =� y. 7 DLC C t m o .0 G.¢ '^Q� u O .. C L) o to 7 ^ a u c CS 0 a u c N F.y C Y.?0 C = C O y ea w O r 'Z Z O w v - .. ce Lt.. a C :° .� ^ .C ry u a rn Li N N UU OC 61> w tz 37 c 4. S .0 V, E � " E v � - fy _ 4) 0 v °� U y O C C C ^ C C V d _ U R } s:I l� o ^ y u C a 3 t: p E o o c c o = o ' u v = a. r.M ,� '� u `� O k .. 1. p •a:. % % % % L 7 7_ :% (4 'Jr Vi 0 6.1 F C '� u y '� N O CU L) M. .Cl. con o. U n ^ _V C VI / V1 .74 os- V. Gi. I) Cr.4C ca _.• 4J CL W_ d. 0.e I ?w _ ..e• CL C Y C 15 z M cc c O a u c O O U O _c c N a_ 7. _ rU O A w _ y CIO ® a La- ¢ ¢ M y 00 I _ C/� !n 123 /0011 lot 0 HAP Emissions Summary Controlled Emission Rates Pollutant (Ib/MMScf) (lb/hr) (Ib/yr) (ton/yr) Emission Factor Reference 1,1,1-trichloroethane 1.16E-02 4.93E-04 4.32 0.0022 AP-42,Tab.2.4-1, 11/98 1,1,2,2-tetrachloroethane 3.37E-02 1.43E-03 12.56 0.0063 AP-42,Tab. 2.4-1, 11/98 1,1-dichloroethane 4.21E-02 1.79E-03 15.67 0.0078 AP-42,Tab. 2.4-1, 11/98 1,1-dichloroethene 3.51E-03 1.49E-04 1.31 0.0007 AP-42,Tab. 2.4-1, 11/98 1,2-dichloroethane 7.34E-03 3.12E-04 2.74 0.0014 AP-42,Tab. 2.4-1, 11/98 1,2-dichloropropane 3.68E-03 1.56E-04 1.37 0.0007 AP-42,Tab. 2.4-1, 11/98 Acetaldehyde 2.93E+00 1.24E-01 1,090.45 0.5452 AP-42,Tab. 3.2-2, 07/00 Acrylonitrile 1.21E-01 5.13E-03 44.96 0.0225 AP-42,Tab. 2.4-1, 11/98 Benzene 5.36E-02 2.28E-03 19.97 0.0100 AP-42,Tab. 2.4-1, 11/98 Carbon disulfide 1.59E-02 6.75E-04 5.91 0.0030 AP-42,Tab. 2.4-1, 11/98 Carbon tetrachloride 1.11E-04 4.74E-06 0.04 0.0000 AP-42,Tab. 2.4-1, 11/98 Carbonyl sulfide 1.06E-02 • 4.50E-04 3.94 0.0020 AP-42,Tab. 2.4-1, 11/98 Chlorobenzene 5.09E-03 2.17E-04 1.90 0.0009 AP-42,Tab. 2.4-1, 11/98 Chloroethane 1.46E-02 6.21E-04 5.44 0.0027 AP-42,Tab. 2.4-1, 11/98 Chloroform 6.48E-04 2.76E-05 0.24 0.0001 AP-42, Tab. 2.4-1, 11/98 Chloromethane 1.11E-02 4.70E-04 4.12 0.0021 AP-42,Tab. 2.4-1, 11/98 Dichloromethane 2.20E-01 9.35E-03 81.88 0.0409 AP-42, Tab. 2.4-1, 11/98 Ethyl Benzene 1.76E-01 7.48E-03 65.51 0.0328 AP-42, Tab. 2.4-1, 11/98 Ethylene dibromide 6.75E-05 2.87E-06 0.03 0.0000 AP-42, Tab. 2.4-1, 11/98 Hexane 2.03E-01 8.65E-03 75.78 0.0379 AP-42, Tab. 2.4-1, 11/98 Hydrogen chloride 1.20E+01 5.09E-01 4,454.67 2.2273 AP-42, Tab. 2.4-1, 11/98 Mercury(total) 1.51E-04 6.44E-06 0.06 0.0000 AP-42,Tab. 2.4-1, 11/98 Methyl ethyl ketone 1.84E-01 7.81E-03 68.43 0.0342 AP-42, Tab. 2.4-1, 11/98 Methyl isobutyl ketone 6.73E-02 2.86E-03 25.07 0.0125 AP-42, Tab. 2.4-1, 11/98 Perchloroethylene 1.12E-01 4.76E-03 41.70 0.0208 AP-42, Tab. 2.4-1, 11/98 Toluene 1.30E+00 5.53E-02 484.65 0.2423 AP-42, Tab. 2.4-1, 11/98 Trichloroethylene 6.70E-02 2.85E-03 24.98 0.0125 AP-42, Tab. 2.4-1, 11/98 Vinyl chloride 8.30E-02 3.53E-03 30.92 0.0155 AP-42, Tab. 2.4-1, 11/98 Xylene 4.61E-01 1.96E-02 171.94 0.0860 AP-42, Tab. 2.4-1, 11/98 Hydrogen sulfide 2.64E-01 1.12E-02 98.46 0.0492 Timberline estimate,03/10 Formaldehyde 5.88E+01 2.50E+00 21,900.00 10.9500 Stack test, Granger Electric, 01/10 Total HAPs 7.71E+01 3.28E+00 28,738.99 14.3695 See Derenzo and Associates, Inc. HAP Calculation Spreadsheets for Details. N., v o .0 11c ` T• d ti C O _> n- 1 y = 6� C a v = nE .-- .� �veia � s E c c m L T E a c u v Cr)n en en E a 0 - p = 2 O o E < o • l � a a a .° a ct,y a r. W •- > •O 0 00. d' .a 1p --- c .-- y 'o 0 a Ql 3 ❑ c O H CI n 0 6 W U G o' o o ` �t n p .�+ O y aett FO ill o `0 9 0. Mel 3 .6.n �, a It az .0 0 C •� g a o E R• h m m c.c.) Z I a m o `v `v n: u y r = = E R y r > 0 c o, w a a •. a 6 7. O M c c a 3 _ a E SO Nc � iG. M b m o t° nA 0. U r L O a E W 1 •,eL a Q ` OL. L .. C _ - d L 'O 9 �. cc I. .E v ,v` v o '8 0 a a 3 �S { l E N s' o 'o N Yr • L E St W `w d eC o.. C T O 0 .8 it„E B✓ O 9 6 G p SO w .E 3 0 e x h s w • `�" E Q' 9 ; o o m F� VJ 'a v U F v o u E 5 y y L. °� « ,., 0 U Q 3 w r. ry 6 a to �' u 0 u u i.: .! a !c5:-> " a3i 3 .o. v n " c 3 a c L, cevm .t. o w .. — a c c p � 3 o ;g 3 cO• c ° •E ❑ ❑ a 'o R0.' % ca °' Y 3 oy L EE i �▪+ i. m 'Oco le V U • N 6 o i. m .O O E Y b O y \ oO o N1O a m u 0 a o c R u .o E• u o a '- 0 S o. 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U v 0. y = E @� @) 6 a - o Z v Z n W N a v m r W 3 x Z E 'a 1 W c Z Z o „ o sr, m an C7 U < o L Cr o o w r-1 O O U ❑ ❑ c W -o 0 eu c a n n 0 U j q L N O N N .o >, x N N 4 E .. — a U O Ft G OL O h O O O O 0 = E 6 = W Z o° o 0 3 = E _ a y L i G u O i N co n sr a C U .C ^ 3 > O U r H au .0O v OIt n > fi w Z oz o0D y e y E c CE C U 61 > v: d E o �} U 'oo 3 c a ¢ c ''v v ~ r c '0 i U ro ¢ 'C c _ - L. `'- ®❑ to 5 p,W W F ; d U o = U 0.- G 0 .0 0 .. 'a sr [—� c f.. L `° 6 ii s v E 00 1.. U v E rU. = E R 0° _ u O E F R _ c.: Z' ` L .E w Y t Q p N c c x c _ r. E a o o ,c v q v :e 6 -0 0 c o ` '0 r ea m e, O n — c I. E ll .6 a 4 E to. 'v a U ;? H U !n a L L L P r 'OG �.Gi 6 E rt v C L N N E rl E ,c o a v m _ v o o- u o o '-! H E E 0 0 O G F F v v ! -t r 'a.1 `e° i c . 'O a .n a ❑ O .E E 1 ❑® a N v O u 0 E u o .. .. C 0 0 = 0 O ... y m u A zo L E 7 U U c ` 0 y a- y u U 'D 3 3 v L c c E E a U a a E E _ 0 m E o f C7 O o a u u E tr] E C O 0 I z Z V m a o o I ov. 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O c v p -- X u GO—� N n. o u Q CO , CO nO ' C] W Cl) C ® ¢ - Cl) Cr, • 123(00191 O k\ HAP Emissions Summary • Controlled Emission Rates Pollutant (IbIMMScf) (lb/hr) (Ib/yr) (ton/yr) Emission Factor Reference 1,1,1-tichloroethane 1.16E-02 4.93E-04 4.32 0.0022 AP-42,Tab. 2.4-1, 11/98 1,1,2,2-tetrachloroethane 3.37E-02 1.43E-03 12.56 0.0063 AP-42, Tab. 2.4-1, 11/98 1,1-dichloroethane 4.21E-02 1.79E-03 15.67 0.0078 AP-42,Tab.2.4-1, 11/98 1,1-dichloroethene 3.51E-03 1.49E-04 1.31 0.0007 AP-42,Tab. 2.4-1, 11/98 1,2-dichloroethane 7.34E-03 3.12E-04 2.74 0.0014 AP-42, Tab. 2.4-1, 11/98 1,2-dichloropropane 3.68E-03 1.56E-04 1.37 0.0007 AP-42,Tab.2.4-1, 11/98 Acetaldehyde 2.93E+00 1.24E-01 1,090.45 0.5452 AP-42, Tab.3.2-2, 07/00 Acrylonitrile 1.21E-01 5.13E-03 44.96 0.0225 AP-42,Tab. 2.4-1, 11/98 Benzene 5.36E-02 2.28E-03 19.97 0.0100 AP-42, Tab. 2.4-1, 11/98 Carbon disulfide 1.59E-02 6.75E-04 5.91 0.0030 AP-42, Tab. 2.4-1, 11/98 Carbon tetrachloride 1.11E-04 4.74E-06 0.04 0.0000 AP-42, Tab. 2.4-1, 11/98 Carbonyl sulfide 1.06E-02 4.50E-04 3.94 0.0020 AP-42, Tab. 2.4-1, 11/98 Chlorobenzene 5.09E-03 2.17E-04 1.90 0.0009 AP-42, Tab. 2.4-1, 11/98 Chloroethane 1.46E-02 6.21E-04 5.44 0.0027 AP-42, Tab. 2.4-1, 11/98 Chloroform 6.48E-04 2.76E-05 0.24 0.0001 AP-42, Tab. 2.4-1, 11/98 Chloromethane 1.11E-02 4.70E-04 4.12 0.0021 AP-42, Tab. 2.4-1, 11/98 Dichloromethane 2.20E-01 9.35E-03 81.88 0.0409 AP-42, Tab. 2.4-1, 11/98 Ethyl Benzene 1.76E-01 7.48E-03 65.51 0.0328 AP-42, Tab. 2.4-1, 11/98 Ethylene dibromide 6.75E-05 2.87E-06 0.03 0.0000 AP-42, Tab. 2.4-1, 11/98 Hexane 2.03E-01 8.65E-03 75.78 0.0379 AP-42, Tab. 2.4-1, 11/98 Hydrogen chloride 1.20E+01 5.09E-01 4,454.67 2.2273 AP-42, Tab. 2.4-1, 11/98 Mercury(total) 1.51E-04 6.44E-06 0.06 0.0000 AP-42, Tab. 2.4-1, 11/98 Methyl ethyl ketone 1.84E-01 7.81E-03 68.43 0.0342 AP-42, Tab. 2.4-1, 11/98 Methyl isobutyl ketone 6.73E-02 2.86E-03 25.07 0.0125 AP-42, Tab. 2.4-1, 11/98 Perchloroethylene 1.12E-01 4.76E-03 41.70 0.0208 AP-42, Tab. 2.4-1, 11/98 Toluene 1.30E+00 5.53E-02 484.65 0.2423 AP-42, Tab:2.4-1, 11/98 Trichloroethylene 6.70E-02 2.85E-03 24.98 0.0125 AP-42, Tab. 2.4-1, 11/98 Vinyl chloride 8.30E-02 3.53E-03 30.92 0.0155 AP-42, Tab. 2.4-1, 11/98 Xylene 4.61E-01 1.96E-02 171.94 0.0860 AP-42, Tab. 2.4-1, 11/98 Hydrogen sulfide 2.64E-01 1.12E-02 98.46 0.0492 Timberline estimate, 03/10 Formaldehyde 5.88E+01 2.50E+00 21,900.00 10.9500 Stack test, Granger Electric, 01/10 Total HAPs 7.71E+01 3.28E+00 28,738.99 14.3695 See Derenzo and Associates, Inc. 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C C C c C C a U U Y 4 ••• ` U -071 a m ° .-, aJ a c Li G G c C o 0 0 0 0 f ,•;,, f = C a O O L C % r Z Z z '!_ 72 12.‘ ''...4'aC �j N L C. C. 'Vj U n- =•O C a o r? ,n ° c a ea o E cz r i= a�I ;/] N 'C LL .0 23 0 C Ti aJ Fri I _ - 0 u= Q a I a oc ?? I _ 0 I t.w v� p 'o I— a a, N C >. r _❑ u .r co o O 0�c 0 _ p O _ c O E 0. x x U V y _ = O V C 8 z a C 0 c y c to C O O O 'o "0 O 04 . C a c S.rn Q V 8 c O el. :a y o G F- o C U' z > U v v •O O u C . u C. $ Q/ Q X A- aJ a W a = a ® D. Q 5 aai 041 (/) - r.r: - V4 - V) V) 1Z 3700761/01L HAP Emissions Summary Controlled Emission Rates Pollutant (IbIMMScf) (Iblhr) (Ib/yr) (tonlyr) Emission Factor Reference 1,1,1-trichloroethane 1.16E-02 4.93E-04 4.32 0.0022 AP-42,Tab.2.4-1, 11/98 1,1,2,2-tetrachloroethane 3.37E-02 1.43E-03 12.56 0.0063 AP-42,Tab. 2.4-1, 11/98 1,1-dichloroethane 4.21E-02 1.79E-03 15.67 0.0078 AP-42,Tab. 2.4-1, 11/98 1,1-dichloroethene 3.51E-03 1.49E-04 1.31 0.0007 AP-42,Tab. 2.4-1, 11/98 1,2-dichloroethane 7.34E-03 3.12E-04 2.74 0.0014 AP-42, Tab. 2.4-1, 11/98 1,2-dichloropropane 3.68E-03 1.56E-04 1.37 0.0007 AP-42, Tab. 2.4-1, 11/98 Acetaldehyde 2.93E+00 1.24E-01 1,090.45 0.5452 AP-42, Tab. 3.2-2, 07/00 Acrylonitrile 1.21E-01 5.13E-03 44.96 0.0225 AP-42, Tab.2.4-1, 11/98 Benzene 5.36E-02 2.28E-03 19.97 0.0100 AP-42,Tab. 2.4-1, 11/98 Carbon disulfide 1.59E-02 6.75E-04 5.91 0.0030 AP-42,Tab.2.4-1, 11/98 Carbon tetrachloride 1.11E-04 4.74E-06 0.04 0.0000 AP-42,Tab.2.4-1, 11/98 Carbonyl sulfide 1.06E-02 4.50E-04 3.94 0.0020 AP-42,Tab. 2.4-1, 11/98 Chlorobenzene 5.09E-03 2.17E-04 1.90 0.0009 AP-42,Tab. 2.4-1, 11/98 Chloroethane 1.46E-02 6.21E-04 5.44 0.0027 AP-42,Tab. 2.4-1, 11/98 Chloroform 6.48E-04 2.76E-05 0.24 0.0001 AP-42,Tab. 2.4-1, 11/98 Chloromethane 1.11E-02 4.70E-04 4.12 0.0021 AP-42,Tab. 2.4-1, 11/98 Dichloromethane 2.20E-01 9.35E-03 81.88 0.0409 AP-42, Tab.2.4-1, 11/98 Ethyl Benzene 1.76E-01 7.48E-03 65.51 0.0328 AP-42, Tab. 2.4-1, 11/98 Ethylene dibromide 6.75E-05 2.87E-06 0.03 0.0000 AP-42,Tab. 2.4-1, 11/98 Hexane 2.03E-01 8.65E-03 75.78 0.0379 AP-42,Tab. 2.4-1, 11/98 Hydrogen chloride 1.20E+01 5.09E-01 4,454.67 2.2273 AP-42,Tab.2.4-1, 11/98 Mercury(total) 1.51 E-04 6.44E-06 0.06 0.0000 AP-42,Tab. 2.4-1, 11/98 Methyl ethyl ketone 1.84E-01 7.81E-03 68.43 0.0342 AP-42,Tab. 2.4-1, 11/98 Methyl isobutyl ketone 6.73E-02 2.86E-03 25.07 0.0125 AP-42, Tab. 2.4-1, 11/98 Perchloroethylene 1.12E-01 4.76E-03 41.70 0.0208 AP-42, Tab.2.4-1, 11/98 Toluene 1.30E+00 5.53E-02 484.65 0.2423 AP-42, Tab.2.4-1, 11/98 Trichloroethylene 6.70E-02 2.85E-03 24.98 0.0125 AP-42,Tab. 2.4-1, 11/98 Vinyl chloride 8.30E-02 3.53E-03 30.92 0.0155 AP-42, Tab. 2.4-1, 11/98 Xylene 4.61E-01 1.96E-02 171.94 0.0860 AP-42,Tab. 2.4-1, 11/98 Hydrogen sulfide 2.64E-01 1.12E-02 98.46 0.0492 Timberline estimate, 03/10 Formaldehyde 5.88E+01 2.50E+00 21,900.00 10.9500 Stack test, Granger Electric, 01/10 Total HAPs 7.71E+01 3.28E+00 28,738.99 14.3695 See Derenzo and Associates, Inc. HAP Calculation Spreadsheets for Details. DRAFT pL PERMIT PERMIT NO: lOWE1O96 Initial Approval DATE ISSUED: ISSUED TO: Timberline Energy, LLC THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Landfill gas to energy engine facility located near Denver Regional Landfill South, used for the conversion of landfill gas into electricity. Engine facility located at 2200 Weld County Road 6, Erie, Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Three (3)Caterpillar G3520C, Serial No.: TBD, rated 2,233 horsepower, @ 1,200 rpm, turbo-charged four- cycle standard lean-burn landfill-gas fired, internal reciprocating combustion engines. The engines are used for the generation of electricity and primary power. The engines are uncontrolled. This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Caterpillar G3520C engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. The AOS was designed for natural gas fueled compressor engines, but shall also apply to these landfill gas fueled engines. • THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S. (25-7-101 et seq), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: 1. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. EPA Method 9 shall be used to measure opacity. (Reference: Regulation No. I,Section II.A.1. &4.) 2. The permit number shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.)(State only enforceable) 3. Total emissions of air pollutants from all three engines shall not exceed the following limitations (as calculated in the Division's preliminary analysis): (Reference: Regulation No. 3,Part B,II.A.4) Pollutant Annual Limit(tons/year) Monthly limit(tons/month) Particulate Matter 13.41 1.12 PM io(Particulate Matter<I0 pm) 13.41 1.12 PM 2.5(Particulate Matter2.5 µm) 13.41 I.12 Nitrogen Oxides 76.32 6.36 Volatile Organic Compounds 56.91 4.74 Sulfur Dioxide 27.90 2.33 Carbon Monoxide 223.17 18.60 During the first twelve (12) months of operation, compliance with both the monthly and annual emission limitations shall be required. After the first twelve (12) months of operation, compliance with only the annual limitations shall be required. Compliance shall be determined by recording the annual pollutant emissions, from each emission unit, on a rolling (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate monthly emissions and keep a compliance record on site, or at a local field office with site responsibility, for Division review. 4. This source shall be limited to a maximum consumption rate as listed below and all other activities, operational rates and numbers of equipment as stated in the application. Monthly records of the actual consumption rate shall be maintained by the applicant and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B. Il.A.4) AIRS ID: 123/0079/010 - 012 Page 1 of 14 Timberline Energy, LLC Colorado Department of Publi DRAFT ent Permit No.10WE1096 Air ion Initial Approval PERMIT Consumption of landfill gas as fuel shall not exceed 93.175 million standard cubic feet(scf) per month and 1,118.1 million scf per year. During the first twelve (12) months of operation, compliance with both the monthly and yearly consumption limitations shall be required. After the first twelve(12) months of operation, compliance with only the yearly limitation shall be required. Compliance with the yearly consumption limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate monthly consumption of landfill gas and keep a compliance record on site or at a local field office with site responsibility, for Division review. 5. Within one hundred and eighty days(180)after commencement of operation, a source compliance test shall be conducted to measure the emission rate(s)and control efficiency for the pollutants listed below. The test protocol must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual and shall be submitted to the Division for review and approval at least thirty (30)days prior to testing. The protocol shall include manufacturer's analysis of emissions at engine maximum and minimum loads, at site-specific conditions. Engine operating parameters will be included in the analysis with emissions reported in parts per million dry volume and grams per actual horsepower-hour (g/BHP-Hr.) or pounds per million BTU(lb/MMBtu). No test shall be conducted without prior approval from the Division. Any stack test conducted to show compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the allowable number of operating hours for that averaging time, (Reference: Regulation 3, Part B.l1LG3.) Emission Rates: Volatile Organic Compounds, Oxides of Nitrogen, Carbon Monoxide, and Oxygen, using EPA approved methods. 6. Within one hundred and eighty days (180) after commencement of operation, the applicant shall submit to the Division for approval an operating and maintenance plan for all control equipment and control practices, and a proposed record keeping format that will outline how the applicant will maintain compliance on an ongoing basis with the requirements of condition no. 3, 4, 13, 14 & 15 of this permit. The operating and maintenance plan shall commence at startup. (Reference: Regulation No. 3, Part B, Section III.G.7.) 7. Prevention of Significant Deterioration (PSD) requirements shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable PSD threshold will require a full PSD review of the source as though construction had not yet commenced on the source. The source shall not exceed the PSD threshold until a PSD permit is granted. Regulation No. 3 Part D, VI.B.4) 8. Major stationary source requirements for non-attainment areas shall apply at such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable major stationary source threshold will result in this source being subject to Major Stationary Source requirements of Regulation No. 3, Part D, Section V. This source shall not exceed the major stationary source threshold until compliance with Regulation No. 3., Part D, Section V. has been achieved. 9. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, I1.C) a. Annually whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d Whenever a permit limitation must be modified; or AIRS ID: 123/0079•' 9 -012 Paget of 14 Timberline Energy, LLC Colorado Department of Publi ent Permit No.10WE1096 1096 Air DRAFTion Initial Approval PERMIT e. No later than 30 days before the existing APEN expires. f. Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit as Attachment A. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the permittee is exercising an alternative-operating scenario and is installing a permanent replacement engine. 10. The serial number of the subject equipment shall be provided to the Division within one hundred and eighty days (180) after commencement of operation. (Reference: Regulation No. 3,Part B, 111.E.) 11. Within one hundred and eighty days (180) after commencement of operation, compliance with the conditions contained on this permit shall be demonstrated to the Division. It is the permittee's responsibility to self-certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, II.G.2). 12. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this initial approval permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date(See General Condition No. 6., Item 1.). The Division may grant extensions of the deadline per Regulation No. 3, Part B,III.F.4.b. (Reference: Regulation No. 3, Part B,IIl.F.4.) 13. The heat (BTU) content of the landfill gas shall be determined annually (by June 30 of every year) using appropriate EPA or ASTM Methods, or other methods if approved in advance by the Division. The methane content of the landfill gas shall be determined annually (by June 30 of every year). All calculations requiring the use of the landfill gas heat content or methane content shall utilize the most recent analytical results. The heat content and methane content analytical results shall be made available to the Division upon request. 14. This facility is subject to the New Source Performance Standards requirements of Regulation No. 6, Part A, Subpart WWW, Standards of Performance for Municipal Solid Waste Landfills, including, but not limited to, the following: a. Gas sent to Timberline from the landfill(s)shall be routed to a treatment system that processes the collected gas for subsequent use within the engines. All emissions from any atmospheric vent from the gas treatment system shall be subject to the requirements of§60.752(b)(2)(iii)(A) or(B). (Reference: §60.752(b)(2)(iii)(C)). b. Operate the control or treatment system at all times when the collected gas is routed to the system. (Reference: §60.753(1)). Note: US EPA Region 8 has found the proposed energy recovery plant qualifies as a "treatment system" for purposes of NSPS WWW (Reference: December 22, 2010 letter from Cynthia Reynolds). In addition,the following requirements of Regulation No.6, Part A, Subpart A, General Provisions, apply. c. At all times, including periods of start-up, shutdown, and malfunction, the facility and control equipment shall, to the extent practicable, be maintained and operated in a manner consistent with good air pollution control practices for minimizing emissions. Determination of whether or not acceptable operating and maintenance procedures are being used will be based on information available to the Division, which may include, but is not limited to, monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the source. (Reference: Regulation 6, Part A. General Provisions from 40 CFR 60.11) d. No article, machine, equipment or process shall be used to conceal an emission which would otherwise constitute a violation of an applicable standard. Such concealment includes, but is not limited to, the use of gaseous diluents to achieve compliance with an opacity standard or with a standard which is based on the concentration of a pollutant in the gases discharged to the atmosphere. (§ 60.12) e. Written notification of construction and initial startup dates shall be submitted to the Division as required under § 60.7. f. Records of startups, shutdowns, and malfunctions shall be maintained, as required under § 60.7. AIRS ID: 123/0079/010 - 012 Page 3 of 14 Timberline Energy, LI.C Colorado Department of Publi ent Permit No.10 WE 1096 Air DRAFT. ion Initial Approval PERMIT 15. This source is subject to the National Emissions Standards for Hazardous Air Pollutants: Municipal Solid Waste Landfills(40 CFR Part 63, Subpart AAAA) as follows: a. Timberline Energy must develop and implement a written SSM plan according to the provisions in 40 CFR 63.6(e)(3). A copy of the SSM plan must be maintained on site. b. The reports described in 40 CFR 60.757(f)must be submitted every 6 months. c. Timberline Energy must comply with the general provisions of this part specified in table 1 of this subpart. 16. This facility is subject to the odor requirements of Regulation No.2. (State only enforceable) 17. This source is subject to the provisions of Regulation No. 3, Part C, Operating Permits (Title V of the 1990 Federal Clean Air Act Amendments). The application for the Operating Permit is due within one year of commencing operation. 18. A log shall be maintained on site for each engine listing the actual number of hours of operation per day, and total hours per year. The log shall be made available to the Division upon request. 19. This source is located in an ozone non-attainment or attainment-maintenance area and subject to the Reasonably Available Control Technology(RACT)requirements of Regulation number 3, part B, IILD.2.b. The requirements of condition number 21 were determined to be RACT for this source. 20. This source is subject to the requirements of Regulation No. 8, Part E, Subpart III.FFFF National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (40 C.F.R. Part 63, Subpart ZZZZ)including, but not limited to,the following: a. The Initial Notification requirements of§63.6645(d). b. You must monitor and record your fuel usage daily with separate fuel meters to measure the volumetric flow rate of each fuel. In addition, you must operate your stationary RICE in a manner which reasonably minimizes HAP emissions. (§63.6625(c)) c. You must submit an annual report according to Table 7 of this subpart by the date specified, according to the information described in paragraphs(b)(I)through(b)(5)of this section. You must report the data specified in(g)(1)through(g)(3)of this section. (§63.6650(g)) d. You must keep the records of your daily fuel usage monitors. (§63.6655(c)) 21. This source is subject to the New Source Performance Standards requirements of Subpart JJJJ, Standards of Performance for Stationary Spark Ignition Internal Combustion Engines, including, but not limited to, the following: a. Owners and operators of stationary SI ICE with a maximum engine power greater than or equal to 75 KW (100 HP) (except gasoline and rich burn engines that use LPG) must comply with the emission standards in Table I to this subpart for their stationary SI ICE. For owners and operators of stationary SI ICE with a maximum engine power greater than or equal to 100 HP (except gasoline and rich burn engines that use LPG) manufactured prior to January I, 2011 that were certified to the certification emission standards in 40 CFR part 1048 applicable to engines that are not severe duty engines, if such stationary SI ICE was certified to a carbon monoxide (CO) standard above the standard in Table I to this subpart,then the owners and operators may meet the CO certification (not field testing) standard for which the engine was certified. (40 CFR §60.4233(e)) b. Owners and operators of stationary SI ICE must operate and maintain stationary SI ICE that achieve the emission standards as required in §60.4233 over the entire life of the engine. (40 CFR §60.4234) c. After July 1, 2009, owners and operators may not install stationary SI ICE with a maximum engine power of greater than or equal to 500 HP that do not meet the applicable requirements in §60.4233. (40 CFR §60.4236(b)) Compliance Requirements for Owners and Operators AIRS ID: 123/0079/010-012 Page 4 of 14 Timberline Energy, LLC Colorado Department of Publi ent DRAFT• Permit No.10WE1096 Airion Initial Approval PERMIT d. If you are an owner or operator of a stationary SI internal combustion engine and must comply with the emission standards specified in §60.4233(d) or (e), you must demonstrate compliance according to one of the methods specified in paragraphs (6)(1) and (2) of this section. (40 CFR §60.4243(b)) (i) Purchasing an engine certified according to procedures specified in this subpart, for the same model year and demonstrating compliance according to one of the methods specified in paragraph(a)of this section. (ii) Purchasing a non-certified engine and demonstrating compliance with the emission standards specified in §60.4233(d)or(e)and according to the requirements specified in §60.4244,as applicable, and according to paragraphs(b)(2)(i)and(ii)of this section. I. If you are an owner or operator of a stationary SI internal combustion engine greater than 500 HP, you must keep a maintenance plan and records of conducted maintenance and must, to the extent practicable, maintain and operate the engine in a manner consistent with good air pollution control practice for minimizing emissions. In addition, you must conduct an initial performance test and conduct subsequent performance testing every 8,760 hours or 3 years, whichever comes first, thereafter to demonstrate compliance. (40 CFR §60.4243(b)(2)(ii)) Testing Requirements for Owners and Operators e. Owners and operators of stationary SI ICE who conduct performance tests must follow the procedures in paragraphs(a)through (f)of this section. (40 CFR §60.4244) Notification, Reports, and Records for Owners and Operators f. Owners and operators of all stationary SLICE must keep records of the information in paragraphs (a)(1)through (4) of this section. (40 CFR §60.4245(a)) g. Owners and operators of stationary SI ICE greater than or equal to 500 HP that have not been certified by an engine manufacturer to meet the emission standards in §60.4231 must submit an initial notification as required in §60.7(a)(I). The notification must include the information in paragraphs(c)(1)through (5)of this section. (40 CFR §60.4245(c)) h. Owners and operators of stationary SI ICE that are subject to performance testing must submit a copy of each performance test as conducted in §60.4244 within 60 days after the test has been completed. (40 CFR§60.4245(d)) General Provisions "fable 3 to this subpart shows which parts of the General Provisions in §§60.1 through 60.19 apply. (40 CFR §60.4246) Table Ito Subpart JJJJ of Part 60—NO„ CO, and VOC Emission Standards for Stationary Non-Emergency SI Engines≥ 100 HP(Except Gasoline and Rich Burn LPG, Station SI Landfill/Digester Gas Engines,and Stationary Emergency Engines>25 HP Engine type and Maximum Manufacture Emission standards' fuel engine date — power g/HP-hr ppmvd at 15%O2 NO, CO VOCd NO, CO VOCd Landfill/Digester HP>500 7/1/2007 3.0 5.0 1.0 220 610 80 Gas 7/1/2010 2.0 5.0 1.0 150 610 80 'Owners and operators of stationary non-certified SI engines may choose to comply with the emission standards in units of either g/HP-hr or ppmvd at 15 percent O2. AIRS ID: 123/0079/010-012 Page 5 of 14 Timberline Energy,LLC Colorado Department of Publi ent Permit No.10WE1096 Air• DRAFTion Initial Approval PERMIT dFor purposes of this subpart,when calculating emissions of volatile organic compounds, emissions of formaldehyde should not be included. However, emission limits in Condition 3 do include Formaldehyde. 22. The permittee shall maintain continuous fencing along the leased property boundary (200' x 312')as depicted in the June 11,2010 site plan and preclude public access into this fenced area. This site plan is attached as Attachment B. 23. The engine exhaust shall be discharged at 40 feet above ground level,unobstructed and vertically upward. By: By: Matthew S. Burgett, P.E. RK Hancock III, P.E. Permit Engineer Construction Permit Unit Leader Permit History Issuance Date Description Initial Approval This issuance Issued to Timberline Energy, LLC Notes to Permit Holder: 1) The production or raw material processing limits and emission limits contained in this permit are based on the production/processing rates requested in the permit application. These limits may be revised upon request of the permittee providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and application form must be submitted with a request for a permit revision. 2) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The permittee shall notify the Division verbally of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the Division's next working day, and shall submit written notification following the initial occurrence of the excess emissions by the end of the source's next reporting period. The notification shall address the criteria set forth in Section II.E.1. 3) The emission levels contained in this permit are based on the following emission factors: Nitrogen Oxides 1.18 g/hp-hr PM(Particulate Matter): 48 pounds per MMdscf Methane PMio(Particulate Matter<10 pm): 48 pounds per MMdscf Methane PM2 5 (Particulate Matter<I0 µm)• 48 pounds per MMdscf Methane Carbon Monoxide: 3.45 g/hp-hr Volatile Organic Compounds' 0.88 g/hp-hr Sulfur Dioxides: 0.431 g/hp-hr Formaldehyde: 58.8 lb/MMscf landfill gas HCl• 12.0 Ib/MMscf landfill gas Acetaldehyde 2.93 lb/MMscf landfill gas Other HAPs' AP-42 2.4 4) The following emissions of non-criteria reportable air pollutants are estimated based upon the throughput consumption and landfill emissions (as calculated in LandGEM) as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specified compounds. This information is listed on the Division's emission inventory system and can be updated annually if the operator submits the relevant information. C.A.S. H SUBSTANCE EMISSIONS [LR/YR] 75-09-2 Dichloromethane 81.88 each engine AIRS ID: 123/0079/010 -012 Page 6 of 14 • Timberline Energy, LLC Colorado Department of Publi ent • Permit No.10WE1096 Air' DRAFT' ion Initial Approval PERMIT 75070 Acetaldehyde 1,090.5 each engine 50000 Formaldehyde 21,900.0 each engine 7647010 HCI 4,454.7 each engine 5) In accordance with C.R.S. 25-7-114.1, the Air Pollutant Emission Notice (APEN)associated with this permit is valid for a term of five years. The five-year term for the original APEN(s) expires on August 18, 2015. A revised APEN shall be submitted no later than 30 days before the five-year term expires. 6) This source is subject to the provisions of Regulation Number 3, Part C, Operating Permits (Title V of the 1990 Federal Clean Air Act Amendments). The provisions of this construction permit must be incorporated into an operating permit. The application for the Operating Permit is due within one year of commencement of the equipment or modification covered by this permit. 7) This engine is subject to 40 CFR, Part 60, Subpart JJJJ—Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (See January 18, 2008 Federal Register posting—effective March 18, 2008). This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA website at: http://www.epa.govittn/atw/area/frI8ja08.pdf 8) This emission unit is classified as a: Minor Source This facility is currently classified as follows: Applicable Requirement Status Operating Permit Major PSD Major Stationary Source: CO NANSR Major Stationary Source:NOx,VOC MACT ZZZZ Major Source AIRS ID'. 123/0079/010 - 012 Page 7 of 14 Timberline Energy, LLC Colorado Department of Publi ent Permit No.10 WE 1096 Air, DRAFT ion Initial Approval PERMIT GENERAL TERMS AND CONDITIONS: (IMPORTANT! READ ITEMS 5,6,7 AND 8) 1. This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the applicant or applicant's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 2. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-I 14.5(7)(a),C.R.S. 3. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of, a condition hereof shall constitute a rejection of the entire permit and upon such occurrence,this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to final approval by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit,conditions imposed upon a permit are contested by the applicant,or the Division revokes a permit,the applicant or owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 4. This permit and any required attachments must be retained and made available for inspection upon request at the location set forth herein. With respect to a portable source that is moved to a new location, a copy of the Relocation Notice (required by law to be submitted to the APCD whenever a portable source is relocated) should be attached to this permit. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3,Part B, Section 11.13.upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 5. Issuance(initial approval) of an emission permit does not provide "final" authority for this activity or operation of this source. Final approval of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-I14.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section I11.G. Final approval cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. If the APCD so determines, it will provide written documentation of such final approval, which does constitute "final" authority to operate. Compliance with the permit conditions must be demonstrated within 180 days after commencement of operation. 6. THIS PERMIT AUTOMATICALLY EXPIRES IF you (I) do not commence construction or operation within 18 months after either the date of issuance of this permit or the date on which such construction or activity was scheduled to commence as set forth in the permit, whichever is later; (2) discontinue construction for a period of 18 months or more;or(3)do not complete construction within a reasonable time of the estimated completion date. Extensions of the expiration date may be granted by the APCD upon a showing of good cause by the permitter prior to the expiration date. 7. YOU MUST notify the APCD no later than thirty days after commencement of the permitted operation or activity by submitting a Notice of Startup(NOS) form to the APCD. The Notice of Startup (NOS) form may he downloaded online at www.cdphe.state.co.us/ap/downloadforms.html. Failure to do so is a violation of AQCC Regulation No. 3, Part B, Section III.G.I., and can result in the revocation of the permit. You must demonstrate compliance with the permit conditions within 180 days after commencement of operation as stated in condition 5. 8. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (ADEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to he discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 9. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement),-121 (injunctions),-122(civil penalties).-122.1 (criminal penalties), C.R.S. AIRS ID: 123/0079/010 - 012 Page 8 of 14 Timberline Energy, LLC Colorado Department of Publi ent • Permit No.10WE1096 Air DRAFT ion Initial Approval PERMIT ATTACHMENT A: ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERN1L COMBUSTION ENGINES December 10, 2008 The following Alternative Operating Scenario(AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility-Alternative Operating Scenarios, Regulation No. 3, Part B,Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the permittee shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. A.I Engine Replacement The following AOS is incorporated into this permit in order to deal with a engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine, "Temporary" is defined as in the same service for 270 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 270 operating days in any 12 month period. The 270 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 270-day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state-only requirements set forth in this permit (including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five(5)years and made available to the Division upon request. The permittee shall maintain a log on-site and contemporaneously record the start and stop date of any engine replacement,the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the permittee shall maintain a copy of all Applicability Reports required under section A.1.2 and make them available to the Division upon request. A.I.1 The permittee may temporarily replace an existing compressor engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying this permit, so long as the emissions from the temporary replacement engine comply with the emission limitations for the existing permitted engine as determined in section A.2. Measurement of emissions from the temporary replacement engine shall be made as set forth in section A.2. A.1.2 The permittee may permanently replace the existing compressor engine with an engine that is of the same manufacturer, model and horsepower without modifying this permit so long as the emissions from the permanent replacement engine comply with I) the permitted annual emission limitations for the existing engine, 2) any permitted short-term emission limitations for the existing permitted engine, and 3)the applicable emission limitations as set forth in the Applicability Report submitted to the Division with the Air Pollutant Emissions Notice (APEN) for the replacement engine (see http://www.cdphe.sstate.co.us/ap/oileaspermitting.html for example applicability report formats). Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section A.2. The AOS cannot be used for the permanent replacement of an entire engine at any source that is currently a major stationary source for purposes of Prevention of Significant Deterioration or Non-Attainment Area New Source AIRS ID: 123/0079/010 - 012 Page 9 of 14 Timberline Energy, LLC Colorado Department of Publi ent Per mit No.10WE1096 Air : DRAFT ion Initial Approval PERMIT Review("PSD/NANSR")unless the existing engine has emission limits that are below the significance levels in Reg 3, Part D, II.A.42. An Air Pollutant Emissions Notice (APEN)that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the permittee is exercising an alternative operating scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the replacement engine. Example Applicability Reports can be found at http://www.cdphe.state.co.us/ap/oilgaspermitting.html. This submittal shall be accompanied by a certification from a person legally authorized to act on behalf of the source indicating that"based on the information and belief formed after reasonable inquiry, the statements and information included in the submittal are true, accurate and complete". This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The permittee shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. Nothing in this AOS shall preclude the Division from taking an action,based on any permanent engine replacement(s), for circumvention of any state or federal PSD/NANSR requirement. Additionally, in the event that any permanent engine replacement(s)constitute(s)a circumvention of applicable PSD/NANSR requirements, nothing in this AOS shall excuse the permittee from complying with PSD/NANSR and applicable permitting requirements. A.2 Portable Analyzer Testing Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time period(i.e. if the permit requires quarterly portable analyzer testing,this test conducted under the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months). The permittee may conduct a reference method test, in lieu of the portable analyzer test required by this Condition, if approved in advance by the Division. The permittee shall measure nitrogen oxide (NOX) and carbon monoxide(CO)emissions in the exhaust from the replacement engine using a portable flue gas analyzer within seven(7)calendar days of commencing operation of the replacement engine. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol(ver March 2006 or newer)as found on the Division's website at: http://www.cdphe.state.co.us/ap/down/portanalyzeproto.pdf Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year)or short term(lbs/unit of time)emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year(whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year(8760), whichever applies. For comparison with a short-term limit that is either input based (Ib/mtnBtu), output based (g/hp-hr)or concentration based (ppmvd @ 15%O2) that the existing unit is currently subject to or the replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above-mentioned Portable Analyzer Monitoring Protocol document. AIRS ID: 123/0079//010 -012 Page 10 of 14 Timberline Energy, LLC Colorado Department of Publi ent • PetmitNO.!OWE1096 Air DRAFT ion Initial Approval PERMIT If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary,the source may certify that the engine is in compliance with both the NOX and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations,the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or until the engine is taken offline. A.3 Applicable Regulations for Permanent Engine Replacements A.3.I Reasonably Available Control Technology(RACT): Reg 3, Part B § 1I.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology(RACT)for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOX are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM 10 attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOX and SO2,as precursors to PMIO,O, if the potential to emit of NOX or SO2 exceeds 40 tons/yr. For purposes of this AOS,the following shall be considered RACT for natural-gas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOX: The emission limitations in NSPS JJJJ SO2: Use of natural gas as fuel PM 10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GO (§ 60.331)and 40 CFR Part 72 (§ 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. A.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E(State-Only conditions). Control Requirements:Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: - Rich bum engines with a manufacturer's design rate greater than 500 hp shall use a non-selective catalyst and air fuel controller to reduce emission. Lean bum engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. The source shall submit copies of the relevant Applicability Reports required under Condition A.I2. Emission Standards: Section XVII.E State-only requirements Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after .hc date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good AIRS ID: 123/0079/010- 012 Page 11 of 14 Timberline Energy, LLC Colorado Department of Publi ent Permit No.10WE1096 E 1096 Air DRAFT ion Initial Approval PERMIT engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Construction or Emission Standards in G/hp-hr Max Engine HP Relocation Date NOx CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 July 1,2007 2,0 4.0 1.0 500≤Hp July 1,2010 1.0 2.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition A.I.2 A.3.3 NSPS for spark ignition internal combustion engines: 40 CFR 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject 40 CFR 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition A.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition A.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition A.2, Note that under the provisions of Regulation No. 6. Part B, section I.B.that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e.,the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of November 1, 2008 the Division has not yet adopted NSPS JJJJ Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, §LB (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPSJJJ./. A.3.4 Reciprocating internal combustion engine(RICE) MACT: 40 CFR Part 63, Subpart ZZZZ A.3.4.1 Area Source for HAPs • A permanent replacement engine located at an area source that commenced construction or reconstruction after June 12,2006 as defined in § 63.2, will meet the requirements of 40 CFR Part 63, Subpart ZZZZ by meeting the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of the applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition A.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition A.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition A.2. A.3.4.2 Major source for HAPs A permanent replacement engine that is located at major source is subject to the requirements in 40 CFR Part 63 Subpart ZZZZ as follows: Existing, new or reconstructed spark ignition 4 stroke rich burn engines with a site rating of more than 500 hp are subject to the requirements in 40 CFR Part 63 Subpart ZZZZ. AIRS ID: 123/0079/010 - 012 Page 12 of 14 • Timberline Energy, LLC Colorado Department of Publi ent Permit No.10WE1096 Air , DRAFT ion Initial Approval PERMIT New or reconstructed (construction or reconstruction commenced after 12/19/02)2 stroke and 4 stroke lean burn engines with a site rating of more than 500 hp are subject to the requirements in 40 CFR Part 63 Subpart ZZZZ. New or reconstructed(construction or reconstruction commenced after 6/12/06)4 stroke lean burn engines with a site rating of greater than or equal to 250 but less or equal to 500 hp and were manufactured on or after 1/1/08 are subject to the requirements in 40 CFR Part 63 Subpart ZZZZ. New or reconstructed (construction or reconstruction commenced after 6/12/06)2 stroke lean burn or 4 stroke rich burn engines with a site rating of 500 hp or less will meet the requirements of 40 CFR 63, Subpart ZZZZ by meeting the requirements of 40 CFR 60, Subpart JJJJ. New or reconstructed (construction or reconstruction commenced after 6/12/06)4 stroke lean burn engines with a site rating of less than 250 hp will meet the requirements of 40 CFR 63, Subpart ZZZZ by meeting the requirements of 40 CFR 60, Subpart JJJJ. An analysis of the applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition A.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition A.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition A.2. A.3.5 Additional Sources The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit, not"routine replacement"of an existing unit. The AOS is therefore essentially an advanced construction permit review. The AOS cannot be used for additional new emission points for any site; an engine that is being installed as an entirely new emission point and not as part of an AOS-approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation. AIRS ID: 123/0079/010-012 Page 13 of 14 Timberline Energy, LLC Colorado Department of Pub" DRAFT ent Permit No.10WE1096 Air ion Initial Approval PERMIT ATTACHMENT B: FENCELINE SITE PLAN . t_ It- 7 y 1 �k 1 16 I'E�„. z "Yap. e�F�r' 1 i 4 Ii 1 l 44 1 24/ 4. r _ II 1 I 7 4 ..:: . I tñjL 1 H.. �/ 1 I • • I • 1 SS I • 1 1 1. I alp. F,1 411i. ;;• r ';a � ' ; 1 ` ti , . lr 7e zf '� ;, g _ - j i "GI® - wi ! AIRS ID: 123/0079'010- 012 Page 14 of 14 Hello