The URL can be used to link to this page

Browse Search

Home My WebLink About20182665.tiffCOLORADO Department of Public Health it Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 11500 St PO Box 758 Greeley, CO 80632 August 13, 2018 Dear Sir or Madam: RECEIVED AUG 17 2018 WELD COUNTY COMMISSIONERS On August 16, 2018, the Air Pollution Control Division will begin a 30 -day public notice period for Discovery DJ Services LLC - Keenesburg Gas Plant. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty (30) days from the beginning of the public notice period. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health Et Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe John W. Hickenlooper, Governor FulDct�evi J pg-��-1� Larry Wolk, MD, MSPH, Executive Director and Chief Medical Officer ex,'. Pt -CLAW -r ), NL(ST), pW ( Ic i 7 -Mach, 2018-2665 Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Discovery DJ Services LLC - Keenesburg Gas Plant - Weld County Notice Period Begins: August 16, 2018 Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: Applicant: Discovery DJ Services LLC Facility: Keenesburg Gas Plant Natural Gas Processing Sec 17 T2N R63W Weld County The proposed project or activity is as follows: Proposed New Natural Gas Processing Facility The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section III.C due to the following reason(s): • permitted emissions exceed public notice threshold values in Regulation No. 3, Part B, Section III.C.1.a (25 tpy in a non -attainment area and/or 50 tpy in an attainment area) the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements The Division has made a preliminary determination of approval of the application. A copy of the application, the Division's analysis, and a draft of Construction Permit 18WE0274 have been filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Any such comment must be submitted in writing to the following addressee: Timothy Sharp . Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us RA 6O ,af Colorado Air Permitting Project PRELIMINARY ANALYSIS - PROJECT SUMMARY Project Details Review Engineer: Timothy Sharp Package #: 376273 Received Date: 3/12/2018. Review Start Date: 3/22%2018.; Section 01- Facility Information Company Name: ,Discoveiy Di Services LLC. County AIRS ID: 123. Plant AIRS ID: -9EA7` Facility Name: ,I}iscoveryKiowe Physical Address/Location: County: Type of Facility: What industry segment? pi Is this facility located in a NAAQS non -attainment area? If yes, for what pollutant? Section 29, Township ON, Range 63W Weld County Quadrant Section Township Range 1N. Carbon Monoxide (C0) fl Particulate Matter (PM) 2 Ozone (NOx & VOC) Section 02 - Emissions Units In Permit Application AIRS Point # Emissions Source Type Equipment Name Emissions Control? Permit # Issuance 3 Self Cert Required? Action Engineering Remarks 001 A Al 18 W E0274 -:.::gz : ,a,. Section 03 - Description of Project Section 04 - Public Comment Requirements Is Public Comment Required? If yes, why? equeshng Synthetic Mrnoripe[ri3; Section 05 - Ambient Air Impact Analysis Requirement: Was a quantitative modeling analysis required? If yes, for what pollutants? If yes, attach a copy of Technical Services Unit modeling results summary. Section 06 - Facility -Wide Stationary Source Classification Is this stationary source a true minor? Is this stationary source a synthetic minor? If yes, indicate programs and which pollutants: Prevention of Significant Deterioration (PSD) Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) Is this stationary source a major source? If yes, explain what programs and which pollutants hers 5O2 Prevention of Significant Deterioration (P5D) Title V Operating Permits (OP) 5O2 N0x CO VOC PM2.5 PM10 TIP HAPs NOx rc Dn CO VOC PM2.5 PM10 TSP HAPs 8H8 1n Colorado Air Permitting Project Non -Attainment New Source Review (NANSR) Amine Unit Emissions Inventory Section 01- klmlnistratras Information Lou Po S 02 Boulomont ates Amino ectIon Information prinn o Serial Number: Design peaty: NUmber of Pumps ren/ma. mee rculaaon itare. Ras, Tank Railer Boner StriPP,n8 Gas woizlM ne(MDEA,naturalgas sweetening unhisl iMaxa:rgo. Mode, reo.seeal T60)wItn desIgn cap.,/ 01430 MIMs, deVea..4Bnmm ce ev combine, nrnis emrwtons prime en pce wltnnlznale: reo, Model. ao) eiectne driven aminepumplpl with Amine Unit Eyep nt L,crIptIon are routed to the Footmen Flare Emlnleos from the :Wall lank are rOute.cl Ol7ectly to the Thermal 0.1zer. Ps a secondary control device, flash tank ErnIsslon Control ['nylon 0.crlialion: emissions are roirted to the Encbsed Hare. acim.rvemww,,, ani., unrznn v.nt aria aeeuesearermnumcrnrouehput ,,,,, ,,. .'�BaX'A.d rnMSKcerrYar Secondary Embsion, Combustion oe.tcet.l for(Jr Pollution Control Still Vent Control Condenser omission redaction aalmea: control device: Secondary control devIceoperatio, Still Vent Gas Heating Value, Still,. Wag. Gas Vent itrtm. Rash tank Control Primary control *lox Primary control device Secondary cornrolewi�n n.Flash Tank Gas Pleating value bfl046.WeaUmateemWkns pbb,n . .! ed a35pF weig4app W llwfore bein8 mpM Iraaf Gcglr -' Input Para Inlet Gas Input Pressure Inlet Gas InputTemperanme Requested Leen Arnfne Recirculate Rate Flash Tank Temperature Lean Amine weight% STILL VENT Pollutant VOC Bemene Control Scenario Uncontmlled lm/nrl Sour Gas roeaceect Still Vent Vilma, Control: 147,825.0 MAilscl/yr Sufi Vent Secondary MnIsd/yr mnsrol Efficiency% yea Still Vent PrImary Control: 0.00 Mtvlscf/yr T.9, Control Efficiency% still vent SecondaryControl: d.adm m sef/yr u'. Conn.. Efficiency primary Controlled P./ 03412,96 0.076171 66596526 Controlled nmrt 039085, Ethyl bemene Xylenes 0.01463462 00695.62 410624,60 0.0741731 2 06112E-07 0371302 Control xen 73, continent Uncontrolled lm/n1 Contraries Uctml Contraned Oa/T1 VOL 1_307S. esainsa Toluene at .: 0583072 oosss336 Toluene n. " __,,,,-- ur..ma3ere doznao oma eneene - 7 / 969 X fen n-lienne 0.0.3042 sour eu Prx :: Flash TankPrIrnary Control: .197.Z25.0 eelvr nosh -can k:acona ry noniron ts.ozs.p MIN.efnr FlasK Tank PrInlary Control: 0.0 MMsct/yr Flash rank Secondary canvol. 0_043 MMscf/yr 17.06906 199263 0.259609 0.741731 0.029131 3 71302 65.3684 0.2115 0.143136 0.0121909 0.023471 0.253042 0.00915741 Flash 4.672,01 2.712,02 Toluene 3.671,01 1.755E. Mylene 9,0995,02 18,905-03 Amine Uclit Emissions Inventory Section 05 -Emissions Inventor, Did operator request bubuffer,Requested eufhr Criteria PollutanO CO VOC Potental to Emit Uncontrolled oun Actual Emissions Uncontrolled ltov/yea1/ MOO 0.00 000 0 00 0.00 0.00 0.00 0.00 11.63 5535 Requinted Permit.. Uncontroned Controlled (Wes/Year/ 100/000/ 0.00 600 0.00 0.00 0.00 1100 000 060 000 3303.0 55 23,12 55.35 55.35 55 35 Hazardous illr Pollutants ens PoMntal in Emit (mdnshea/ Actual Erniss.ns Uncontrolled Controlled 0.57 0.44 Requested Permlt Um. ulmnshmrl (09x009001 0.57 Requested Permit timIts Uncontrolled co lb/00) 61.1.98.17 1136.77 31.59 3.74 3,74 3.93962 199961 3.74 7,1 517639 76.87 61.1 2,4 3.666,2 5.6.39-06 0.65 0.01 3.0 Section 06- PagulatorySummary Analysis Regulation l Sdion - rone.below, no owner or operator of a source shall amworense me emission mmmeatmosphere of any elr pollutint which is in eneuofm.% opacity. This standard Is based on 34 consecutive opacity readings taken at 15.second intervals for six minutes ',approved reference testrnethod for visible emssions meuurement is 9PA method9(40 CFR, Part gq Appendp Ayuly,199z11 in all subsecdons of Ycdon ll.A and 9 of mu reguladon. • period or pedd aggreegpang more Mans ix minuteseinn any ...fon RAS-Smokeless Hare or flares for the Comhusrion of Wate Gases No owner or operator less or offier for Me mbusdon slaty m� ecumesmnutesbns Mall or Into theatmosphere a any po eat which is n aces: of9 paory fora Regulation z o o ta r s�yasnrsezutnu0.uu10 aevaoeleaaors whim w wmesorodorraeeeom handy for residential or romnmercla purposes it Is avlolabn if odors are detected after me odorous vn (Jlo following Regulationa Cr.. Pollutan ts: For cr.. pollutants, Air Pollutant Engssion No.. are required for: each Ihdlvidual emIssion palm In a non -attainment emissions of one ton per year or more of any a pollutant (pollutants re not sumMed)ror whnh Mew.. no.,ettainmenc awl'unwnwuea actual A0Wicem is required t.fOaan AP. ,rrc,.miasin5 exceed 01099.00900000 Part 6— Constniction Pen. Exemptions Applicant is requiredto ohmn a permitsmm uncontrolled Voc emisslonz from this lamer are greater man toe z.oTn mreshm(Regulation 9, Part El, Section u.o.zal rant, &t According to §cosagd)'ate provisions tempt)a)b nw onxwgunz3No vxinasso.aning Umm.lunnnmisfacnfrywlu mmmncecene aiun,x.. i,u.awe u, result,themines sweetening "not =ed. to th(s subpart. n5P90000 oa/J3/..and on or before 09/18/15 (See 4e03360)1,1amine unit will commence conStrucdon after o8/23/11� applicable this south. MPS 0000, 0U0C aapplies to 0s/zg/00. appir,bl.ntns„uns ammo ornn soucted, mmad, or reconswcteo anal. us/1u/1e. rho amine unit wad commence construceon atter according to 905./,/(91 'Paclllaes maths,. a design cape, less than z long tine per clay (1170) of hydrdgar self id. IHzsl le the add ys(e passed a serur) am requIred to comply wiM keep6 and reporting requIremenh specified In 030340000 but are not requladtommply wen 4450.5405a through OM.,OM.,and 4330.0 00./Sl and coa15a(g). in source wIll a desran raped,' less Man 'Jong tons/day y daa(gm keep far me life clad q p corn analysis ermnsv g tmefaclnry's design npalry is less' submitted req men Ppry rd l ttiir/oof Hu expressed s zonal.! uo other./ 6ased on Me Process simuiadem in Me application. Me gas processed by Mem, unit MI paten., contain 0.000.x25. aced on this mncen Tenon me Praecox slmulaton resulted lntotal xu emissions ofie.J9m:/yeer In deflate tankk and still vent waste gas sveams.Thefollowing demonstrates me conversion of misnlueto long tons per day, (16.79 tons xz0/Vearl'pl. Ms/MO.(11one ton/0040Ibsr(1 year/9e9 days). 0.0459 Ong tons Ha/day ',calculation above demonstrates Mewl. unit will have a design cauatIty less man 3 longtons/day ofHa Seetion 07 -Initial and Periodic Sampling and Testing Requirements Was the extended sour gas sample used In Me Process model sIte-specift and collected will. a year of applicator, I, � ; rwSae notes nSection OR far addnlon,lInformation. It no. the permit VII contain an Intel [ample ce'•testIng requIrement. demonstrate compliance wlth errdssion Ilm16 I.nry greater man 95%for a flare or combustion device? dyes. Me permit will contaln and MItial compliance em, condllion M demonstmte the d.m.icdon efficie, of Me combusdon device based on inlet and oudet concentraton sampling on 06 I Sectie,Rlgkation• ? z Notas Rteeledare[ Ole ....not Cove.. .; StlnvenrewtslenemxcakLlneauodevaposnconaencerspeamtrrrlpapmgvlaxelmolatmndttemode pslrtn0Yutsdto'rani¢vewarandbf0CAtttn ttleVezawastegassuaat,Th 90000nOntoncstteadtta ,.m�ms<cxueamsalnw�?awmelion-mrc+xnaaveamrzsmnd«masrrmpgemssr,8areaeea� imxcl2 mwn,lnme�ax?n .. re nit req ef.teney for Ss 1000 trVen (Pe Nd1 stlngwlRbe req Od"ohskdktbe N<[malomdlxacapeOtnot ac}t eMn 9g;id R 'tat' 3Y .. fTm.00pi#9 xd M, utanon0 rpt nt.Asv to *009/ ae000 .Anso l.spekgllep e 11 man madyideinw� .... ISSeok0M'dhfi&.Won repton+nS`Pmvfd.xlpggrmayon0neem'mpfiem0aotdKde5uSta 0Hastift spwtedaithpa(o{9001n600001kbodn. ' arttraiRbg mi M ,dflgskbnk miWdnsivm44p awlreislas G am4,i«tie I - son vengwasmgacikeam rerouterit amneaverpdos tnneivgmutetEMMetiie mdorfaker, ibonpemWri; not 0000 n ikandngafrr Era&cion coptrnlA 000n/00txds,n wli/0000re,441:/;.f.O.,71,9.030444murreoutilt conkers pre ;''Tfitsaezami-ioaudorais;eacwRhtlreasssssm.rttmade Mtw� .Mo - - ;;311yit)1d113? ndale.. td ,min odic aoft-tesengrequMemeneformermaioxNiaet .,040**/lt Mpn¢ r ,eymo aaespnotedntaGpee "up „ p-rf9dtd hsttngsettioad�t5k pes+ltle � .. ..." z . eppnan 060 m fn ATd Fe b tad atu n0090ndms not pt '*0/1 s0 w/nd eswn „fn w .a0E roes n asrq n!c 0 P mav) h m)s'anaaepta0esfmmadans0Msam m redngern aordEn. os dpetator,x0.aminednicfseq "3vT1 0 dvee&l alto: Iulak0OZ0 nl 000300etdtr.. R aa rod �a misn kmanrm req sni.... wndeer.m crt anmple a d,manGteral Natgaamteneocrooeoset®aeSi O....lx;tlsi.ionvalr ,. 6tMetholedtbaclootnpte<ePpreeestFattbeffi2 artes(ontacmc °nxumes 3emisstdtt0Cte %91030011ze deVelazcondeno0S0 extended eos a00µ30 0110000el09000* e00eumt'106.006,1,0 axm loot A185 Point. 001 01 ddkapmat IliarvrTartea[aaysvw 1aCSnwAfb.l one x conk 000/000000 mrwl1 0600011 uncontroned lnoi tad Flash38.3673327 2231753.4 0.537143 0.031345 ash Still SactIon 09- inventor,SCC Coale and Emissions Factors ogvmhsbw+' m,emfneun iz {asswttanag p[aess j 33: Mtfi 3*0*0±0tWagn �II 1 /bi00en.t�dP .�09aaYgs:x3s.. „t nLSereetenin du�l=02>bib00j0090'p�'pywk`sm'kiCyhabl oveslil6NnIt45 EY6in thee Uncontrolled Units PINIO EIIIISMORSFactor mlv/om h/MMzcf mIV/0I p.m WNW, /Mntscf voc lot 96. b/0Mscf /MMscf Bemene 68.. h/mMxr Toluene 0385 98.6% b/MMscf Ethylbemene 0.033 99.6% b/MMstf Mylene 0.094 98,6% b/MMscf n-Nexane nom 48.6% b/MMscf 04 PAP 5.1479.06 98.6% b/MMxf 025 0.4n 98.6% a/MMscf Hot Oil Heater Emissions Inventory Section 01- Administrative Information Facility AIRs ID: 123 County 9FA7 Plant 017 Point Section 02- Equipment Description Details Detailed Emissions Unit Description: Two (2) natural gas firedhot oil heaters (Make: TBD, Model:. TBD, SN: TBD). The heaters each have a design rate of 65. MMBtu/hr each. The heaters provide heat for hot oil that circulated throughout the plant as a heat transfer medium. _._. Emission Control Device Equipped with a low NOs combustion system for minimizingemissions of Nitrogen Oxides. The low NOx comb Description: system is considered integral to the process and not an add-on control device. Requested Overall VOC & HAP Control Efficiency %: ow NOx combustion system is considered an integral control device. Section 03 - Processing Rate Information for Emissions Estimates Number of Heaters: Heat Input Rate = Heat content of waste gas = Actual Hours of Operation = Requested Hours of Operation = Actual heat input rate = Requested heat input rate = Potential to Emit (PTE) heat input rate = Actual Fuel Consumption = Requested Fuel Consumption = Potential to Emit (PTE) Fuel Consmption = Section 04 - Emissions Factors & Methodologies 2 65 MMBtu/hr 130 Btu/scf 0 hrs/year 8760'. hrs/year New Source - not yet installed 0.00 MMBTU per year 1,138,800.00 MMBTU per year 1,138,800.00 MMBTU per year 0.00 MMscf/year 1,007.79 MMscf/year 1,007.79 MMscf/year Emission Factors Section 05 - Emissions Inventory Pollutant VOC PM10 PM2.5 SOx NOx CO Formaldeh de Benzene Toluene n -Hexane Hot Oil Heaters Uncontrolled Uncontrolled lb/MMBtu lb/MMscf (Fuel Heat Combusted) (Fuel Consumption) 6.220 .8.590 8.590 0.680 19.933 41.245 Emission Factor Source Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) VOC PM10 PM2.5 SOx NOx CO 3.13 4.33 4.33 0.34 10.04 20.78 0.00 0.00 0.00 0.00 0.00 0.60 0.00 0.00 0.00 0.00 0.00 0.00 3.13 4.33 4.33 0.34 10.04 20.78 3.13 4.33 4.33 0.34 10.04 20.78 Hazardous Air Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Umits Uncontrolled Controlled (lbs/year) (lbs/year) Formaldehyde 4.198E-02 1.172E-03 1.898E-03 1.005E+00 0.000E+00 0.000E+00 0.000E+00 0.000E+00 0.000E+00 0.000E+00 0.000E+00 0.000E+00 4.198E-02 1.172E-03 1.898E-03 1.005E+00 4.198E-02 1.172E-03 1.898E-03 1.005E+00 83.9586 2.3446 3.7960 83.9586 2.3446 3.7960 • Benzene Toluene n -Hexane 2009.6471 2009.6471 Section 06 - Regulatory Summary Analysis Section 11.4.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation. 5 of 34 K:\PA\2018\18W E0274.CP1.xlsm Hot Oil Heater Emissions Inventory Regulation 1 Section III.A. No owner or operator shall cause or permit to be emitted into the atmosphere from any fuel -burning equipment, particulate matter in the flue gases which exceeds the following: III.A.1.b. For fuel burning equipment with designed heat inputs greater than 1x106 BTU per hour, but less than or equal to 500010' BTU per hour, the following equation will be used to determine the allowable particulate emission limitation. PE=0.5(FI)°'zs Where: PE = Particulate Emission in Pounds per million BTU heat input. Fl = Fuel Input in Million BTU per hour. The hot oil heaters covered under point 017 each have a design heat input rate of 50 MMBtu/hr. As a result, the heater is subject to this portion of the regulation. Using the above equation, the allowable particulate emission limitation is 0.1808 lb/MMBtu. The AP -42 emission factor of 7.6 lb/MMscf (7.45x10' lb/MMBtu) used in the calculations above is below this particulate emission threshold. Section VI.B.5. Any new source of sulfur dioxide not specifically regulated above. shall: VI.B.5.a. Limit emissions to not more than two (2) tons per day of sulfur dioxide. Based on the calculations above, this source will emit 0.13 tons per year of sulfur dioxide. This is below the requirement of 2 tons per day and therefore the source is in compliance with the above regulation. Regulation 2 Section I.A - No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. Regulation 3 • Part A-APEN Requirements Criteria Pollutants: For criteria pollutants, Air Pollutant Emission Notices are required for: each individual emission point in a non - attainment area with uncontrolled actual emissions of one ton per year or more of any individual criteria pollutant (pollutants are not summed) for which the area is non -attainment. Applicant is required to file an APEN since emissions exceed 1 ton per year NOx. Part B —Construction Permit Exemptions Applicant is required to obtain a permit since uncontrolled NOx emissions from this facility are greater than the 2.0 TPY threshold (Reg. 3, Part B, Section II.D.2.a) Regulation 6 Part B Section II: Standards of Performance for New Fuel Burning Equipment: II.C. Standard for Particulate Matter: On and after the date on which the required performance testis completed, no owner or operator subject to the provisions of this regulation may discharge, or cause the discharge into the atmosphere of any particulate matter which is: II.C.2. For fuel burning equipment generating greater than one million but less than 250 million Btu per hour heat input, the following equation will be used to determine the allowable particulate emission limitation: PE=0.5(FI)-0.26 Where: PE is the allowable particulate emission in pounds per million Btu heat Input. Fl Is the fuel input in million Btu per hour. If two or more units connect to any opening, the maximum allowable emission rate shag be the sum of the individual emission rates. II.C.3. Greater than 20 percent opacity. The hot oil heaters covered under point 017 each have a design heat input rate of 50 MMBtu/hr. As a result, the heater is subject to this portion of the regulation. Using the above equation, the allowable particulate emission limitation is 0.1808 Ib/MMBtu. The AP -42 emission factor of 7.6 lb/MMscf (7.45x10-3 lb/MMBtu) used in the calculations above is below this particulate emission threshold. NSPS Do: Except as provided in paragraphs (d), (e), (f), and (g) of this section, the affected facility to which this subpart applies is each steam generating unit for which construction, modification, or reconstruction is commenced after June 9, 1989 and that has a maximum design heat input capacity of 29 megawatts (MW) (100 million British thermal units per hour (MMBtu/h)) or less, but greater than or equal to 2.9 MW (10 MMBtu/h). The design heat input rate for each hot oil heater is 50 MMBtu/hr which is greater than 10 MMBtu/hr. Additionally, the heaters will be constructed after 06/09/89. According to NSPS Dc, a steam generating unit is defined as "a device that combusts any fuel and produces steam or heats water or heats any heat transfer medium. This term includes any duct burner that combusts fuel and is part of a combined cycle system. This term does not include process heaters as defined in this subpart." Since these hot oil heaters are used to heat a heat transfer medium (hot oil in this instance), the heaters meet the definition of a steam generating unit. As a result, the hot oil heater is subject to NSPS Dc. Please see section 07 for the discussion of specific requirements. Regulation 7 Section XVI.D. Combustion Process Adjustment XVI.D.1. As of January 1, 2017, this Section XVI.D. applies to the following combustion equipment with uncontrolled actual emissions of NOx equal to or greater than five (5) tons per year, and that are located at existing major sources of NOx, as listed in Section XIX.A. This facility is not an existing major source of NOx listed in Section XIX.A. As a result, this section of the regulation does not apply to this facility. MACE MACT DDDDD: This subpart establishes national emission limitations and work practice standards for hazardous air pollutants (HAP) emitted from industrial, commercial, and institutional boilers and process heaters located at major sources of HAP. This subpart also establishes requirements to demonstrate initial and continuous compliance with the emission limitations and work practice standards The hot oil heaters covered under point 017 are not subject to MACT DDDDD because this facility is classified as an area source of HAP. Section 07- Technical Analysis Notes 1. The sulftlydJloxide (5O,) requirements of 9960.42c apply to affected facdrtres that combust coal, oit or walled with other fuels . The particulate matter(PM)requirements or'§a0.43c apply to affected facilities that combust coal, oil, wood, a mixture of these fuels or a mixture of these fuels with any other fuels. Since these hot oil heaters ai'li only combustion natural gas 'it, produce heat, they are not subject tothe sulfur dioxide or particulate matter emission limits of NSPS Dc. As such, the source is only subject to the reporting and recordkeeping requirements of §53.43c. The heater will comply 6 of 34 K:\PA\2018\18 WE0274.CP1.xlsm Hot Oil Heater Emissions Inventory with the following requirements of §60.48cr (€) §60.48c(a) "The owner or operator of each affected facility shall submit notification of the date of construction or reconstruction and actual startup, as provided by 560.7 of this part." (111§60.48c(g)(2) "As an alternative to meeting the requirements of paragraph (g)(1}of this section, the owner or operator of an affected facility that combusts only natural gas, wood, fuels racing fuel certification €n560.4$c(fjto demonstrate compliance with the SO,standard, fuels not subject to an emissions standard (excluding opacity(, or a mixture of these fuels may elect to record and maintain records of the amount of each fuel combusted during each calendar month. (1hr §60:48c(I) "All records required under this section shallbe maintained by the owner or operator of the affected facility for a period of two years following the date of such record, `Discovery has expressed they will comply with the above mentioned requirements. 2. N -Hexane is the only HHAP for which an emission factor will be included in the permit since it is the only HAP that is above reporting thresholds (250 lb/year}, 3. The emissions factors -torn AP -42 Chapter 1.4 used to calculate emissions from this source are based on an average natural gas higher heating value of 1,020 Btu/scf. The operator based their calculations on a heating value of 1,130 Btu/scf. As a result, the emissions factors were converted to this heating value by multiplying the emission factors by a ratio of 1130/1020=1.1078 as prescribed by footnote "a" under tables 1.4-1, 2, and 3. 4, Based on the source grouping criteria outlined in Regulation 3 Part A Section 11.8.4,, it was determined the grouping of the two heaters reported on this APEN would be allowed, The two heaters mee the following criteria outlined in this section of the regulation: (i) 11.8.4.x. All of aggregated sources have identical source classification codes and emission factors for criteria pollutants -The two engines have the same heat input rating, both heat hat oil and emissions are calculated using identical emissions factors from AP -42. (8) tf 8.4.b. Each of the aggregated sources share a similar location within the facility- Based an the facility wide diagram provided, the heaters appear to be located at a similar -location. (iii)ll.B.4.c. Similar sources regulated under the New Source Performance' Standards (Regulation Number 6} and non -New Source Performance Standard sources should col be grouped - Bath of these heaters are subjectta 145P5 Dc. (iv)YL6,4.d_ None ofthe individuol sources is required to monitor emissions through the use of continuo. emission monitors -Emissions wBI be calculated using monitored throughput and emissions factors provided in the notes to permit holden. (v)yf.8.4. e. Each of the individual emission points has fuel usage, production, and a consumption level, which are indistinguishable from the other points, which hove been grouped on. the Air Pollutant Emission Notice - Each heater will be equipped with a fuel meter to track natura€gas combusted as fuel. This information will be used to demonstrate compliance with the permitted throughput limit which includes total maximum throughput for both omits combined. (vi) I1.8.4.f None of the individual sources grouped on the Air Pollutant Emission Notice has previously been issued its own separate emissions permit, - These heaters are new units that are part of the phase II construction of this gas processingfaclity. 5. Initial testing will be required to assess the emissions of NOx and CO emitted by these heaters. This test will be used to confirm the heater is capable of meeting the emission manufacturer in actual operation. Itwas determined VOC does not need to be tested for because the operator is using the AP -42 emission factor to. estimate VOC emissions. 6, The operator did not provide a manufacturer specification sheet in order to support the manufacturer specified emissions factors for NOx and CO. The operator indicatedthutthe hot oil heater specification was out for bid during time of review and the vendor information not be evaluated until the bids were assessed. The operator did provide the specif cations requested for the heaters. This information alongwith initial compliance testingwas deemed acceptable for permitting purposes. AIRS Point 8 017 Process 8 SCC Code 01 111-tt44.1i4=Note Section 88- Inventory SCC Coding and Emissions Factors Uncontrolled Emissions Pollutant Factor Control % Units PM10 8.59 0 lb/MMscf Burned PM2.5 8.59 0 lb/MMscf Burned NOx 19.93 0 lb/MMscf Burned VOC 6.22 0 lb/MMscf Burned CO 41.25 0 lb/MMscf Burned SOx 0.68 0 lb/MMscf Burned Formaldehyde 8.33E-02 0 lb/MMscf Burned Benzene 2.33E-03 0 lb/MMscf Burned Toluene 3.77E-03 0 Ib/MMscf Burned n -Hexane 2.0 0 lb/MMscf Burned 7 of 34 K:\PA\2018\ 18WE0274.CPl.xlsm Regenerator Heater Emissions Inventory Section 01- Administrative Information Facility AIRS ID: 9699 Plant Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: Two (2) natural gas firedregenerator heater(s) (Make: TED, Model: TED, SN: TED). The heater(s) have a design rate of 24 MMEtu/hr each, The heater provide heat for mole sieve regeneration. Emission Control Device Equipped with a low NOx combustion system for minimizing emissions of Nitrogen O,udes. The low NOx combustion Description: system is considered integral to the process and oat an add-sinfcontrol device. Requested Overall VOC & HAP Control Efficiency %: ' low NOx combustion system is considered an integral control device. Section 03- Processing Rate Information for Emissions Estimates Number of Heaters: 2 Heat Input Rate = 24 MMBtu/hr Heat content of waste gas= 1130 Btu/scf Actual Hours of Operation = Requested Hours of Operation = Actual heat input rate = Requested heat input rate = Potential to Emit (PTE) heat input rate = Actual Fuel Consumption = Requested Fuel Consumption = Potential to Emit (PTE) Fuel Consmption = Section 04- Emissions Factors & Methodologies 0 hrs/year 8760', hrs/year New Source - not yet installed 0.00 MMBTU per year 420,480.00 MMBTU per year 420,480.00 MMBTU per year 0.00 MMscf/year 372.11 MMscf/year 372.11 MMscf/year Emission Factors Pollutant Hot Oil Heaters Uncontrolled Uncontrolled Ib/MMBtu lb/MMscf (Fuel Heat (Fuel Combusted) Consumption) Emission Factor Source VOC PM10 PM2.5 0.006 0.008 0.008 6.78 9.04 9.04 5Ox NOx CO Formaldehyde Benzene Toluene n -Hexane 0.018 20.34 0.037 ' 41.81 8.33E-02 2,33E-03 3.77E-03 2.0 Mangfactu Manu€i Mannfactu lop-42.Cftap Mahnfaet€ir Niaoefactu AP -42, AP Ri* RP=42'. Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) VOC PM10 PM2.5 SOx NOx CO 1.26 1.68 1.68 0.12 3.78 7.78 0.00 0,00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1.26 1.68 1.68 0.12 3.78 7.78 1.26 1.68 1.68 0.12 3.78 7.78 Hazardous Air Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Umits Uncontrolled Controlled (tons/year) (tans/year) Requested Permit Umits Uncontrolled Controlled (Ibs/year) (Ibs/year) Formaldehyde Benzene Toluene 1.550E-02 4.328E-04 7.008E-04 3.710E-01 0.000E+00 0.000E+00 0.000E+00 0.000E+00 0.000E+00 0.000E+00 0.000E+00 0.000E+00 1.550E-02 4.328E-04 7.008E-04 3.710E-01 1.550E-02 4.328E-04 7.008E-04 3.710E-01 31.0001 0.8657 1.4016 31.0001 0.8657 1.4016 • n -Hexane 742.0235 7420235 Section 06 - Regulatory Summary Analysis Section II.A.1- Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation. 8 of 34 K:\PA\2018\18W E0274.CP1.xlsm Regenerator Heater Emissions Inventory Regulation 1 Section III.A. No owner or operator shall cause or permit to be emitted into the atmosphere from any fuel -burning equipment, particulate matter in the flue gases which exceeds the following: III.A.1.b. For fuel burning equipment with designed heat inputs greater than 1x10' BTU per hour, but less than or equal to 500x106 BTU per hour, the following equation will be used to determine the allowable particulate emission limitation. PE=0.5(FlI o.zs Where: PE = Particulate Emission in Pounds per million BTU heat input. Fl = Fuel Input in Million BTU per hour. The regeneration heater covered under point 003 has a design heat input rate of 24 MMBtu/hr. As a result, the heater is subject to this portion of the regulation. Using the above equation, the allowable particulate emission limitation is 0.2473 lb/MMBtu. The manufacturer provided emission factor of 1.3x10 z Ib/MMBtu used in the calculations above is below this particulate emission threshold. Section VI.B.5. Any new source of sulfur dioxide not specifically regulated above shall: VI.B.S.a. Limit emissions to not more than two (2) tons per day of sulfur dioxide. Based on the calculations above, this source will emit 0.12 tons per year of sulfur dioxide. This is below the requirement of 2 tons per day and therefore the source is in compliance with the above regulation. Regulation 2 Section I.A - No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. Regulation 3 Part A-APEN Requirements Criteria Pollutants: For criteria pollutants, Air Pollutant Emission Notices are required for: each individual emission point in a non - attainment area with uncontrolled actual emissions of one ton per year or more of any individual criteria pollutant (pollutants are not summed) for which the area is non -attainment. Applicant is required to file an APEN since emissions exceed 1 ton per year NOx. Part B —Construction Permit Exemptions Applicant is required to obtain a permit since uncontrolled NOx emissions from this facility are greater than the 2.0 TPY threshold (Reg. 3, Part B, Section II.D.2.a) Regulation 6 Part B Section II: Standards of Performance for New Fuel Burning Equipment: II.C. Standard for Particulate Matter: On and after the date on which the required performance test is completed, no owner or operator subject to the provisions of this regulation may discharge, or cause the discharge into the atmosphere of any particulate matter which is: tI.C.2. For fuel burning equipment generating greater than one million but less than 250 million Btu per hour heat input, the following equation will be used to determine the allowable particulate emission limitation: PE=0.5(FI)-0.26 Where: PE is the allowable particulate emission in pounds per million Btu heat input. Ft is the fuel input in million Btu per hour. If two or more units connect to any opening, the maximum allowable emission rate shall be the sum of the individual emission rates. II.C.3. Greater than 20 percent opacity. The regeneration heater covered under point 003 has a design heat input rate of 24 MMBtu/hr. As a result, the heater is subject to this portion of the regulation. Using the above equation, the allowable particulate emission limitation is 0.2473 lb/MMBtu. The manufacturer provided emission factor used in the calculations above is below this particulate emission threshold. NSPS Dc: Except as provided in paragraphs (d), (e), (f), and (g) of this section, the affected facility to which this subpart applies is each steam generating unit for which construction, modification, or reconstruction is commenced after June 9, 1989 and that has a maximum design heat input capacity of 29 megawatts (MW) (100 million British thermal units per hour (MMBtu/h)) or less, but greater than or equal to 2.9 MW (10 MMBtu/h). The design heat input rate for the regenerator heater is 24 MMBtu/hr which is greater than 10 MMBtu/hr. Additionally, the heater will be constructed after 06/09/89. According to NSPS Dc, a steam generating unit is defined as "a device that combusts any fuel and produces steam or heats water or heats any heat transfer medium. This term includes any duct burner that combusts fuel and is part of a combined cycle system. This term does not include process heaters as defined in this subpart." Since this regenerator heater is used to heat a heat transfer medium (natural gas), the heater meets the definition of a steam generating unit. As a result, the regenerator heater is subject to NSPS Dc. Please see section 07 for the discussion of specific requirements. Regulation 7 Section XVI.D. Combustion Process Adjustment XVI.D.1. As of January 1, 2017, this Section XVI.D. applies to the following combustion equipment with uncontrolled actual emissions of NOx equal to or greater than five (5) tons per year, and that are located at existing major sources of NOx, as listed in Section XIX.A. This facility is not an existing major source of NOx listed in Section XIX.A. As a result, this section of the regulation does not apply to this facility. MALT MACE DDDDD: This subpart establishes national emission limitatims and work practice standards for hazardous air pollutants (HAP) emitted from industrial, commercial, and institutional boilers and process heaters located at major sources of HAP. This subpart also establishes requirements to demonstrate initial and continuous compliance with the emission limitations and work practice standards The regeneration heater covered under point 003 is not subject to MACE DDDDD because this facility is classified as an area source of HAP. Section 07 -Technical Analysis Notes 1.. The operator provided the following infornlatio,n regarding the mole sieve -.dehydration process The mole sieve regeneration system uses a portion of the gasthat-was already dried inthe operational. bedsto remove the mater f om the bed that rs no laver in use: The heater heats that gas to add the regeneration (at higher temperature) Here is an excerpt from our Plant Design Crrtenothat explains ` ! the mole sieve system: 9 of 34 K:\PA\2018\18 W E0274. CP 1.xlsm Regenerator Heater Emissions Inventory The molecular sieveunit will be designed to retriove water from the water-s`oturvted treated gas to prevent formation of hydrates and to limit corrosion from low temperature operations in the crya unit:` Three mole sieve dehydrator beds will be used. As one bed is adsorbing, one will be in the regeneration process and the otherbed will be on standby, Each dehydration bed will have 100',capacity, Saturated inlet gas will flow through the adsorbing bed fortimed cycle, adsorbingwater: present in the gas. =Once water has been stripped off, the gas will go through dust filters located downstream to remove any mole sieve dust prior to entering the eryo volt. in the regeneration process, regen gas from downstream of the dust fitters will be heated using a direct fired regeneration gas heater. Regen gas will flow through the water saturated bed, stripping = adsorbed water from the molecular sieve. Regen gas will then be cooled, and liquid will be separated in the regeneration you scrubber. The gas will be compressed and recycled back to the dehydration inlet filter/coalescer. Compression will be electric -motor driven. The liquid will be routed to the closed drain system. An option to use residue gas for regeneration is included in the design as the regeneration compressor is not redundant."The operator further expressedthat the heat from the combustion gases is transferred to the regeneration gas across a physical barrier that prevents direct contact or intermixing. According to the EPA Applicability determination index document control number PS36, "devices which combust fuel and transfer heat front the combustion gases to a heat transfer medium across a physical barrier which prevents direct contact or intermixing of the combustion gases and the heat transfer medium are considered steam generating units under Subparts Db and Dc.' This determination is reiterated in the EPA Applicability determination index document control number 0800027. This information supports the determination that this regeneration heater is subject to NSPS Dc 2, The sulfur dioxide (SOt) requirements of §66,42c apply to affected facilitiesthat combust coal, oil or coal/oil with other fuels : The particulate matter (PM) requirements of §60,43capply to affected facilities that combust coal, oil, wood, a mixture of these fuels or a mixture of these fuels with any other fuels. Since this regeneration heater will only combustion natural gas to produce heat, it is not subject to the sulfur dioxide or particulate matter emission limits of NSPS Dc. As such, the source is only subject to the reporting and recordkeeping requirements of 560.43c, The heater will comply with the following requirements of §60.48ce(i) §60.48c(a) "The owner or operator of each affected facitityshall submit notification of the date of construction or reconstruction and actual startup, as provided by §60,7 of this part." (ii) §60.48c(g)(2) "As art alternative to meetingthe requirements of paragraph (g)(1) of this section, the owner oroperatorof an affected facility that combusts only natural gas, wood, fuels using fuel certification in §60.48c(f) to demonstrate compliance with the SO, standard, fuels not subject to an emissions standard (excluding opacity), or a mixture of these fuels may elect to record and maintain records of the amount of each fuel combusted during each calendar month." (iii)§60.48c(i) "All records required under this section shall be maintained by the owner or operator of the affected facility fora period of two yearsfollowing the date of such record." Discovery has expressed they will comply with the above mentioned requirements. 3. The permit will not contain emissions factors forthe HAPs associated with this source because the emissions are below reporting thresholds jilt l6/year). -, 4.Even though the PM (10 and 2.5) emissions factors are based on manufacturer data, the initial testing requirement will not require testing for PM,," or PM,., for the following reasons: (i) The manufacturer provided emissions factors are more conservative than the values typically used from AP -42 chapter 1.4. (ii) The emissionsare below APEN reporting thresholds (2 tpy) even when the more '. conservative manufacturer provided emissions factors are used to calculate emissions. (iii) This heater uses natural gas as fue€. As a result, the amount of PM emitted as a result of the combustion process is less of a concern. (iv) PM emissions not close to a modeling or major source threshold. 5. The emissions factors from AP -42 Chapter 1.4 used to calculate SOx and HAP emissions from this source are based on an average natural gas higher heating value of 1,020 Btu/scf. The operator based their calculations on a heating value of 1,130 Btu/scf. As a result, the emissions factors were converted to this heating value bymultiplying the emission facteas by a ratio of 1130/1020 =1.1078 as. prescribed by footnote"a" under tables 1.4-1, 2, and 3. manufacturer in actual operation. Section 08 - Inventory SCC Coding and Emissions Factors AIRS Point # Process # SCC Code 018 01,tanl'. will; be used to confirm the heateres capable of meeting the emission lends specified by the Uncontrolled Emissions Pollutant Factor Control % Units PM10 9.0 0 lb/MMscf Burned PM2.5 9.0 0 lb/MMscf Burned NOx 20.3 0 lb/MMscf Burned VOC 6.8 0 lb/MMscf Burned CO 41.8 0 Ib/MMscf Burned SOx 0.7 0 Ib/MMscf Burned Formaldehyde 8.33E-02 0 lb/MMscf Burned Benzene 2.33E-03 0 lb/MMscf Burned Toluene 3.77E-03 0 lb/MMscf Burned n -Hexane 2.0 0 lb/MMscf Burned 10 of 34 K:\PA\2018\18WE0274.CP1.xlsm Produced Water Storage Tank(s) Emissions Inventory 001 Produced Water Tank Facility AIRs ID: 123. 9E47 005 Plant Point Section 02 • Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Two )2) 1,000 bane Enclosed comb, Description: Requested Overall VOC & HAP Control Efficiency %: Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Storage Tank(s) Actual Produced Water Throughput = Requested Permit Limit Throughput = zessels-connected via liquid man 0; Barrels (bbl) per year Actual Produced Water Throughput While Emissions Controls Operating = 31934 Barrels (bbl) per month 376,000'. Barrels (bbl) per year Requested Monthly Throughput = Potential to Emit (PTE) Produced Water Throughput= Secondary Emissions - Combustion Device(s) Heat content of waste gas= Volume of waste gas emitted per BBL of liquids produced = 36:!. scf/bbl Actual heat content of waste gas routed to combustion device = Requested heat content of waste gas routed to combustion device = 376,000 Barrels (bbl) per year Btu/scf 0 MMBTU per year 27,069 MMBTU per year Potential to Emit (PTE) heat content of waste gas routed to combustion device = 27,069 MMBTU per year Section 04- Emissions Factors & Methodologies Will this storage tank emit flash emissions? Emission Factors Produced Water Tank Pollutant Uncontrolled Controlled (lb/bbl) (lb/bbl) (Produced (Produced Water Water Throughput) Throughput) VOC rO.070 0.00 0.000 0.000 0.000 0.000 0.000 0.000 Control Device Benzene Toluene 0.000 0.000 Ethylbenzene 0.000 0.000 Xylene n -Hexane 0.008 224 TMP I0,000__�; Pollutant Emission Factor Source Uncontrolled Uncontrolled (Ib/MMBtu) (lb/bbl) (Produced (waste heat Water combusted) Throughput) Emission FactorSource PM10 PM2.5 NOx CO ' r O.3100 '• 0080 (i. Section 05 - Emissions Inventory Potential to Emit Actual Emissions Requested Permit Limits Requested Monthly Limits Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) (lbs/month) VOC 13.2 0.0 0.0 13-2 0.7 112 PM10 0.0 0.0 0.0 0.0 0.0 0 PM2.5 0.0 0.0 0.0 0,0 0.0 0 NOx 0.9 0.0 0.0 0.9 0.9 1.56 CO 4.2 0.0 0.0 4.2 4.2 713 Potential to Emit Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (Ibs/year) (lbs/year) (lbs/year) (Ibs/year) (Ibs/year) Benzene 180 0 0 - 180 9 Toluene 98 0 0 98 5 Ethylbenzene 8 0 0 8 0 Xylene 16 0 0 16 1 n -Hexane 2948 0 0 2948 147 224 TMP 1 0 0 1 0 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, 8 Not enough information Regulation 7, Section XVII.0, C.1, C.3 Storage tank is subject to Regulation 7, Section XVII, B, Cl & C.3 Regulation 7, Section XVII.C.2 Storage Tank is not subject to Regulation 7, Section XVII.C.2 Regulation 6, Part A, NSPS Subpart 0000 Storage Tank is not subject to NSPS 0000 (See regulatory applicability worksheet for detailed analysis) 0!. 11af 34 K:\PA\2018\18 W E0274.CP1.xl sm Produced Water Storage Tank(s) Emissions Inventory Section 07 - Initial and Periodic Sampling and Testing Requirements Does the company use a site specific emissions factor to estimate emissions? If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid water sample drawn at the facility being permitted and analyzed using flash liberation analysis? This sample should be considered representative which generally means site -specific and collected within one year of the application received date. However, if the facility has not been modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample. If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor. See PS Memo 14-03, Questions 5.9 and 5.12 for additional guidance on testing. Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08 -Technical Analysis Notes Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # 005 Process II SCC Code 01 4-04-003-15 Fixed Roof Tank, Produced Water, working+breathing+flashing losses Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.00 0 lb/1,000 gallons liquid throughput PM2.5 0.00 0 lb/1,000 gallons liquid throughput NOx 0.12 0 lb/1,000 gallons liquid throughput VOC 1.7 95 lb/1,000 gallons liquid throughput CO 0.53 0 lb/1,000 gallons liquid throughput Benzene 0.01 95 lb/1,000 gallons liquid throughput Toluene 0.01 95 lb/1,000 gallons liquid throughput Ethylbenzene 0.00 95 lb/1,000 gallons liquid throughput Xylene 0.00 95 lb/1,000 gallons liquid throughput n -Hexane 0.19 95 lb/1,000 gallons liquid throughput 224 TMP 0.00 95 lb/1,000 gallons liquid throughput 12 of 34 K:\PA\2018\18WE0274.CP1.xlsm Produced Water Storage Tank Regulatory Analysis Worksheet Please note that NSPS Kb might be might be applicable for certain tanks at water management and injection facilities. If the tanks you are reviewing are at one of these facilities, please review NSPS Kb. Colorado Regulation 3 Parts A and B- AP EN end Permit Requirements Source is In the Non -Attainment Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the operator claiming less than 1% crude oil and is the tank located at a non-commercial facility for processing oil and gas wastewater? (Regulation 3, Part B, Section II.D.1.M) 3.. Are total fachity uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.0.3)? IYou have Indicated that source Is in the Non -Attainment Area NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this Individual source greater than 1 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the operator claiming less than 1% crude oil and is the tank located at a non-commercial facility for processing oil and gaswastewater? (Regulation 3, Part B, Section II.D.1.M) 3. Are total facgity uncontrolled VOC emissions greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 5 TPY (Regulation 3, Part B, Section 11.0.2)? Nut enough Information Colorado Regulation 7, Section XVII 1. Is this tank located at a transmission/storage facility? 2. Is this produced water storage tank' located at an oh and gas exploration and production operation , well production facility', natural gas compressor station' or natural gas processing plant? 3. Is this produced water storage tank a fixed roof storage tank? 4. Are uncontrolled actual emissions' of this storage tank equal to or greater than 6 tons per year VOC? 'Storage tank is subject to Regulation 7, Section XV II, B, C.1 & C.3 Section %VIIS— General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section XVllt1- Emissions Control and Monitoring Provisions Section XVIlt3 - Recordkeeping Requirements 5. Does the produced water storage tank contain only 'stabilized" liquids? If no, the following additional provisions apply. Storage Tank is not subject to Regulatton 7, Section XVII.C.2 Section 0Vlit2 - Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment 40 CFR, Part 60, Subpart 0000, Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution 1. Is this produced water storage vessel located at a facility In the onshore oil and natural gas production segment, natural gas proressing segment or natural gas transmission and storage segment of the Industry? 2. Was this produced water storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) between August 23, 2011 and September 18, 2015? 3. Are potential VOC emissions' from the individual storage vessel greater than or equal to 6 tons per year? 4. Does this produced water storage vessel meet the definition of "storage vessel"' per 60.5430? 'Storage Tank is not subject to NSPS 0000 Subpart A, General Provisions per §60.5425 Table 3 §60.5395 - Emissions Control Standards for VOC §60.5413 Testing and Procedures §60.5395(g) - Notification, Reporting and Recordkeeping Requirements §60.5416(o) - Cover and Closed Vent System Monitoring Requirements §60.5417 -Control Device Monitoring Requirements [Note: If a storage vessel Is previously determined to be subject to NSPS 0000 due to emissions above 6 tons per year VOC on the applicability determination date, it should remain subject to NSfss 0000 per 60.5365(02) even If potential VOC emissions drop below 6tons per year( RACT Review PAR reviewis required if Regulation 7 does not apply AND if the tank is in the non -attainment area. If the tank meets both criteria, then review RACT requirements. Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a paiicular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend,' 'may," 'should,' and "can," is intended to describe APCD interpretations and recommendations. Mandatory terminology such as 'must' and 'required" are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and ofitsed. NA' No Yes Yes Source Req Continue -' Continue-' Go to then Source is st retinue-' forage Tar Hydrocarbon Loadout Emissions Inventory s ton01- Administrative Information IFaclllry AIRS ID: 123 County Section 02- Equipment Description Penile Detailed Emissions Unit teadout of stab lined bonde Description: Emission Control Device trnitc onohom thin source am Description: is the leadout controlled? Collection Efficiency: Control Efficiency: Requested Overall VOC & HAP Control Efficiency 96: 95.00 9h] 006 Plant Pomt biked condensate an oiled by an enclosed combusto Section 03- Processing Rate Information for Emissions Estimates Primary Emissions - Hydmorben Loadout Actual Volume Loaded= Requested Permit LimitThraughput = Potential to Emit (PTE) Volume Loaded = 100.0 Sesondary Emissions - Combustion Device(s) Heat content of waste gas = Volume of waste gas emitted per year= 517 Actual heat content of waste gas routed to combustion device= Requested heat content of waste gas routed to combustion device= 95 376,000-. Bartels lbbll per year 376000. Barrek (bbl) per year 375,000'. Barrels(bbl) per year Section 04- Emissions Factors &Methodologies Does the company we the state default emissions factors to estimate emissions/ Does the hydrocarbon liquid loading operation utilize submerged fill] Section 05- Emissibns Inventory Actual Volume Loaded While Emissions Controb Operating= 452 MMBTU per year 1,035 MMBTU per year 1,035 MMBTU per year /The state default emissions factors may be used to estimate emissions. Criteria Pollutants Potential to Emit Uncontrolled (tom/year) Actual missions Uncontrolled Controlled (tors/year) (tort/year) Requested Permit Limits Uncontrolled Controlled (tom/year) from/Karl PM10 PM2.5 SOx HOx VOC Co 0,00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 44.37 44.37 25.96 44.37 2.22 0.00 000 0.00 0.00 0.00 Hazardous Air Pollutants Potential to Emit Uncontrolled Rhs/year) Actual missions Uncontrolled Controlled Obs/year) (Ibs/year) Requested Permit Limits Uncontrolled Controlled Ohs/year) Ohs/Year) Benzene Toluene Ethylbenzene XVlene n -Hexane 224 TMP 154.16 154.16 90.18 154.16 7.71 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1353.60 1353.60 791.87 1353.60 67.66 0.00 0.00 0.00 0.00 0.00 14 of 34 K:\PA\2018\18WE0274.CP1xkm Hydrocarbon Loadout Emissions Inventory Section 05- Regulatory Summary Analysis Regulation 3, Parts A, B RACT- Regulation 3, Part B, Section III.O.2.a (See regulatory applicability worksheet for detailed analysis) Source requires a permit The loadaut must operate with submerged fill and loadout emissions must be routed to flare to satisfy RACT. Section 07 - Inkhl and Pedodk Sampling and Testing Raoul amens Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section Os- Technical Analyse Notes This source covers the loadou frmthe stabilized condensate and step bricture o. stabilize AIRS Point p 006 Section 09- Inventory SCC Coding and Emissions Factors Process It SCC Cade 01 4-06-00132 Crude Oil: Submerged Loading Normal Service (3=0.61 Uncontrolled Emissions Pollutant Factor Control% Units PM10 0.00 0 b/1,000 gallons transferred PM2.5 0.00 0 b/1,000 gallons transferred SOx 0.00 0 b/1,000 gallons transferred NOx 0.00 0 b/1,000 gallons transferred VOC 5.6 95 b/1,000 gallons transferred CO 0.00 0 b/1,000 gallons transferred Benzene 9.76E-03 95 b/1,000 gallons transferred Toluene 0.06 95 b/1,000 gallons transferred Ethylbenzene 0.00 95 b/1,000 gallons transferred Xylene 0.00 95 0/1,000 gallons transferred n -Hexane 8.57E-02 95 b/1,000 gallons transferred 224TMP 5.00 95 b/1,000 gallons transferred 15 of 34 K:\PA\2018\I8 W E0274.CP1xbm Hydrocarbon Loadout Regulatory Analysis Worksheet its A and B-APgN anti Permit Requirements Colorado Re�giYi na �einin/ed ego-: snirua i", is Me redo>.�Atrainniir. ATTAINMENT 1. uncontrolled actual emissions from any criteria pollutants front tNs ind Victual source greater Man 2TPY (Regulation 3, Pan A, Sect,.IO1 elf 2. �theIwdoatloated at aneaploration and production see (e.g., pad) (Regulation 3, Part 6, Section gallonsn.o.l.lil s (232 BEM) of crude oil per my on an minim/ average bOsie? the dadat operation loading less Nan 6,,7501 Ibis year of condensate via splash fill? 5. Is Me Iwdout operation loading less Nan 16,308 eels per year of cendema a via submerged 311 procedure? 6. Are total facility uncontrolled VOC emissions greater than 5 TM% NO. greater than 101-71 or co emissions greater Man to Toe(Remlation 3, Part 3, Section lL7.31? kon have im3lcea Met amt. One.enre.nt Araa NON -ATTAINMENT 1. Are emissions from any criteriapollutantsfrom c individual source than 1 PY (Reg 3 on Part A, Mct..I/.7.1,0(7 2. Is the loadMan ou/ located an ev7lora on and ucdon site (e.g., well 002/(7050107.. 3e Part 0,Secti7711.7.1.11? the loadou, operation loading less Nan 10,707 gallons (238 Bets(of crude oil per day .n an annual average bads? Is the loadout operationloading lass 50 bbs per year of condense. nie Me.R2 NUN loadou, operation loading less Nan 16,30g hies per year of condensate via submerged NI procedure? 6. Pre total aclty uncontrolled POC emissions from me greater than 2 Ter, Noe greater han 5 TH., Co emnsztm greater than 5 TPr(Reguahnn 3, Part El, Section oil? knumeonsere6 pond/ 7. RACT-Are uncontrolled V0C em02070 from Me leadout operation greater than 20/77(Regulation 7.P 2,12, Motion III.D.207 IThe Mattous mat v.,e,e.uwit/,sebane•gv27tit aid kmd7:,tendmki::..dust10 raidedse Mee to x:077 FACT. Cascfaimer This daumant assists operators with detemAni,g applicability dcertaln /equiaemenfs ether Clean Alr Act, ifs implementing regulations, and Alr Qualify Control Commission regulations. This daumenf is not a rule or regulation, anc the analysis it contains may not apply Ma particular situation based upon the I/dN7Lal fats andeiaamstems, This document ideas not change or substitute gor any law, regulation, a any other legally bl/drg requirement and is not legally enforceable. In the event of any conflict between the language of this daument end. language of the Clean Air Act., ifs lmpbmenllrg regulations, and Alr Quality Canhd Commission regulations, the language d the stela n/egulafim stall cal.!. The use 027 ,7mendaloy language such as 7030077,0727'"may.""should'. and tan. /s Intended. describe APC0 lnlenemtatlo,s and recommendations. Mandatory Ie/mlnu'ogy such as "must'and ',equlrad'ere intended to dascnbe controlling requirements underfhe temps of the Clean Air Act and Mr Quality Control Commission regulations. but this _orient dace not establish legally blnosrg requirements in and ofitself Yes •,'Yt NA'i:i{27h: Go tumid question Go to question 6 he lmdout require: a permit Yese.".'':?The wdout must operate with submergel and loadout emsa,u mustbe rated toccata to sats175ACr./f,wtw,0,2(d,072C7 analysis V requireda 3,02(40tlscussmn Section a. Fugitives Emissions Inventory Section 01- Adminstrative Information (Facility AIRs ID: Court 9F -A7 009 Plant Pain Section 02- Equipment Description Details Detailed Emissions Unit Description: Equipmet tteaks (fugitive VOCs) from a natural gas processing facility.' Emission Control Device Emissionsfronathis source are not controlled, Description: Requested Overall VOC & HAP Control Efficiency 86: : 0 Section 03- Processing Rate Information for Emissions Estimates This section in net applicable to fugitives. Section 04- Emissions Factors & Methodologies Regulation 7 Information Operating Hours: Emission Factor Source Standard EFs--EPA O5 90-(t17Y. Control Efficiency Source: Tel:ie5-3 Mon51 yMori-10 4'9i 4j 00000 Calculations . -4 Emission Factor (kgrer- Service Component Type Count source) Control (%) Pollutant Mass Fraction Uncontrolled Controlled Table 24 Table 2-U Emissions (tpy) Emissions (tpy) Connectors 1500 2.00E-04 1.00E-05 81.0% VOC 3.36E-01 5.377762778 1.089167145 Flanges , 600 3.90E-04 5.70E-05 0.0% Benzene 9.11E-04 0.014601339 0.002957233 Open -Ended Lines 0 2.00E-03 1.50E-05 0.0% Toluene 1.56E-03 0.024926419 0.005048389 Gas Pump Seals 0 2.40E-03 3.50E-04 0.0% Ethylbenzene - 3.74E-04 0.005991312 0.00121343 Valves i 250 4.50E-03 2.50E-6 96.0% Xylenes 8.48E-04 0.013590986 0.002752605 Other ,,o; : 8.80E-03 1.20E-04 0.0% n -Hexane 1.30052 0.208383902 0.042204335 — -- -- — -- 2,2,4-TMP 103E-05 0.000165001 3.3418E-05 Connectors 30 e--3 7.50E-06 7.50E-06 81.0% VOC 1.00E.+00 0.005463449 0.003703616 Flanges 400 ." 3.90E-07 3.90E 0.0% Benzene 000E+00 0 0 Open -Ended Lines 0 1.40E-04 7.20E-6 0.0% Toluene 0.00E+00 0 0 Heavy Oil Pump Seals 16 0.00E+00 0.00E+00 0.0% Ethylbenzene 0.00E+00 0 0 Valves 22 ''. 8.413E-06 8.40E-6 0.0% Xylenes 0.00E+00 0 0 Other 0 3.20E-05 3.20E-6 0.0% n -Hexane 0.00E+00 0 0 - -- - - - 2,2,4-TMP 0.00E+00 0 0 Connectors 100.:''. 2.10E-04 9.70E -0b 81.0% VOC 1.00E+00. 6.95242656 0.612972275 Flanges ' = 200 J 1.10E-04 2.40E-6 0.0% Benzene 1.41E-02 0.098260035 0.00866326 Open -Ended Lines 0, 1.40E-03 1.40E-6 0.0% Toluene 2.79E-02 0.194205607 0.017122461 Condensate (Light Oil) Pump Seal , 4 "- 1.30E-02 5.10E-04 88.0% Ethylbenzene 7.25E-03 0.050416216 0.00444003 Valves 1 250 - 2.50E-03 1.90E-6 950% Xylenes 1.84E-02 0.114099748 0.010059794 Other tiiII 0,_ 7.50E-03 1.10E-04 0.0% n -Hexane 2.00E-01 1.388534461 0.122422455 - - - - 2,2,4-TMP ,. _.1.37E-04 0.000951787 8.39159E-05 Connectors 0 1.10E-04 1.00E-6 81.0% VOC 1,00E+00 : 0 0 Flanges 0 2.90E-06 2.90E-6 0.0% Benzene 0.00E+00 0 0 Open -Ended Lines 0 2.50E-04 3.50E-06 0.0% Toluene 0.00E+00 0 0 Water/Oil Pump Seals 0 2.40E-05 2.40E-6 0.0% Ethylbenzene 0.00E+00 0 0 Valves 0 9.80E-05 9.70E-6 0.0% Xylenes. 0.00E+00 :. 0 0 Other q 1.40E -D2 5.90E-6 0.0% n -Hexane .0.00E+00 -. : 0 0 - -- - - - 2,2,4-TMP 0.00E+00 0 0 Connectors --; 100 2.10E-04 9.70E-06 81.0% VOC 5.72E-01 3.073311779 0.350313655 Flanges ', 2(10 1.10E-04 2.40E-06 0.0% Benzene 2.44E-03' : 0.016931731 0.001492814 Open -Ended Lines 0 1.40E-03 1.40E-6 0.0% Toluene 1.69E-03. 0.011734445 0.001034587 NGL (Light Oil) Pump Seals - 4 1.30E-02 5.10E-04 88.0% Ethylbenzene 4.39E-04 - 0.003051823 0.000269069 Valves 250 2.50E-03 1.90E-05 950% Xylenes 1.15E-03 0.007973808 0.000703024 Other 0' 7.50E-03 1.10E-04 0.0% n -Hexane 6.72E-03 :. 0.046719125 0.004119069 - -- - -- -- 2,2,4-TMP ...2.41E-03 0.016789623 0.001480285 Section 05 - Enissions Inventory Pollutant Uncontrolled Emissions Controlled Emissions Source I VOC 16.31 tpy 2.06 tpV Standard EF Benzene 259.59 lb/yr 26.23 lb/yr Standard EF. Toluene 461.73 I5/1r 46.41 Ib/yr Standard EF Ethylbenzene 118.92 lbyr 11.86 lb/yr Standard EF. Xylenes 271.33 lb/yr 27.03 lb/yr Standard EF. n -Hexane 3287.27 lb/yr 337.49 lb/yr Standard EF. 2,2,4-TMP 35.81 lb/yr 3.20 lb/yr Standard OF. Section 06 - Re; ulater Summa r Ana Review Regulation 3, Part B, Section III. D.2 to determine is RACT is required? iew 40 CFR, Part 60, Subpart KKK to determine if applicable to this source? Review 40 CFR, Part 60, Subpart 0000 to determine if 605380 and/or 605385 is applicable? Review Section XVII.F to determine is LDAR is applicable? - EPA453/R-95.017 Table 2-4 - EPA453/R-95-017 Table 2-4 - EPA -453/R-95-017 Table 2-4 - EPA453/R-95-017 Table 2-4 - EPA -453/R-90-017 Table 2-4 - EPA453/R-95-017 Table 2-4 - EPA453/R-95-017 Table 24 Additional Reoulatory Considerations Regulation 1 Section II.4-1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess 0620% opacity. This standard is based on 24 consecutive opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)1 in all subsections of Section II. A and B of this regulation. Regulation 2 Section I.A- No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odorswhich are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. Part A-APEN Requirements Criteria Pollutants: For criteria pollutants, Air Pollutant Emission Notices are required for each individual emission point in a non -attainment area with uncontrolled actual emissions of one ton per year or more of any inolvidual criteria pollutant (pollutants are not summed: for which the area is non -attainment. Applicant is required to file an APEN since emissions exceed 1 ton per year VOC TPY Uncontrolled Controlled 0.129793105 0.0131133 0.230866471 0.0232054 0.059459351 0.0059275 0.135664542 0.0135154 1.643637488 0.1587459 0.017906412 0.0015976 Fugitives Emissions Inventory Regulation 3 Part B — Construction Permit Exemptions Applicant is required to obtain a permit since uncontrolled VOC emissions from this facility are greater than the 2.0 TPY threshold (Reg. 3, Part B, Section II.D.2.a) Is this source located in an ozone non -attainment area or attainment maintenance area? -. Y If yes, is this source subject to leak detection and repair (LDAR) requirements per Regulation 7, Section XVI I.F or XII.G or 40 CFR, Part 60, Subparts KKK, 0000, or 0000a? .Yes Part B, 111.0.2 - RACY requirements for new or modified minor sources This section of Regulation 3 requires RACT for new or modified minor sources located in nonattainment or attainment/maintenance areas. This source is located in the 8 -hour ozone nonattainment area. The date of interest for determining whether the source Is new or modified is therefore November 20, 2007 (the date of the &hour ozone NA area designation). Since the fugitives will be in service after the date above, this source is considered "new or modified." This facility is subject to NSPS 0000a. Following the leak detection and repair program per NSPS 0000a satisifies the RACT requirements of Regulation 3. The permit will contain a condition reflecting this determination. Regulation 6 Is this source at an onshore 'natural gas processing plant' as defined in 40 CFR, Part 60.631? Yes Did this source commences construction, reconstruction, or modification after January 20, 1984, and on or before August 23, 2011? No „ This source is not subject to NSPS KKK because the facility will commence construction after August 23, 2014. Did this source commences construction, reconstruction or modification after August 23, 2011 and on or before September 18, 2015? No Source is not subject to NSPS 0000 because this is a new that facility will commenco construction after September 18, 2015. Regulation 7 Is this source located in an ozone non -attainment area or attainment maintenance area? - Yes is this source at an onshore 'natural gas processing plant' as defined in 40 CFR, Part 60.631? Yes Facility is classified as a natural gas processing plant Therefore, this source is subject to Regulation 7 Section XII.G. Is the facility classified as a well production facility or natural gas compressor station?jjj-N0 Since this facility is not classified as a well production facility or natural gas compressor station, it is not subject to Regulation 7 Section XVII.F. Regulation 8 Is this source at a 'natural gas processing plant" as defined in 40 CFR, Part63.761? Yes Is this facility considered a "major source" of HAP as specifically defined in 40 CFR, Part 63.761 for sites that are not prodcution field facilities? No If you repond "yes" to both questions above, further review if the provisions of 40 CFR, Part 63.769 "Equipment Leak Standards" apply? Source is not subject to MACT HH because the facility is classified as a synthetic minor source of HAPs. NSPS 0000a Did this source commence construction, reconstruction, or modification after September 18, 2015? :Yes Is this source eta well site, compressor station or onshore "natural gas processing plant' as defined in 40 CFR, Part 60. 5430a? ...._Yes,......... This facility meets the definition of onshore"natural gas processing plant" as defined by 40 CFR, Part 80.5430a. Therefore, the fugitive emissions at this facility subject to NSPS 0000a. Section 07- Technical Analysis Notes AdditionalNotes, 1. New source. application. 2. The operator calculated'. VOC emissions'. associated With the condensate light oil service, water/oils Since this the mast conservative estimate for Poe, I determined it wasonnecessary for the operatd and heavy oil service based ova VOC weight content of 100°.6. blob an initial sample for these servicestoverify the VOC.. 3. The gas --.service composition is based on fa representative Inlet gas sa. ples. Since the entire gas service is based on inlet gas, the emissions calculated are likely nsentattve,Boweyer,thcoperatoris assuming less than 100%VOCand thesampie is not site specific. As a result, initial testing will be included in the permit requiring semplebe-obtained from thisservuete demonstrate compliance with the limits contained in the permit Annual testing will also be required 5. As discussed above,this facility is subject to NSPS 0000a. However, :chic federel regulation has not been adopted into Colorado state regulation, As such, this regulation will be addressed in the retest, permit holder. 6. Colorado Regulation.7Sectlon 511.131 requires the following: "Forfug(pve VOC emissions from leaking equipment, the leak detection and repair (LDAR)program.as,.. provided at40 CFR Part 60, Subpart KKK @July 1, 2016) Shall apply, regardless of the date of construction of -the affected facility, unlosssubjeettoapplicable WAR Program as provided at 40 CFR Part 60, Subparts 00000r.0000a (tolyS, 20I6j," As discussed above, this source issubject to NSPS 00000, Following the requirementS of NSPS 0000a satisfies the requirements under Colorado Regulation 7 Section Sirs. 7, According to Colorado Regulatlend Part ASection t,B.25,b,"Fugitive emissions shall not be considered in determining whether asourceisa major source for the purposes of this Sectlon£.6.20.b.,, unless the source belongs to one of the following categories of stationary sources `This facility Is not included Elie-tistedsources and therefore fugitive emissions are not Included whendetermining Whether or not this facility Is a major source. 8. The operator did not provide HAP -composition for the heavy oil or water/oil services. This was deemed acceptable for the following -reasons: I£kTbMfacility is sot elate to the indivjdaal or total HAP major (ii(These- two 'services contribute toss than 1 tpy of VOCto the total emissions from this source. As such, the HAPs diet would result fromthese services 9.' Theoperatorurbmitted an O&M plan for fugitives with this application. According to the second paragraph on the first page of the fugitive. O&M plan,"£fthe facility has NSPS or MACE requirements farteak Detectiomand Repair je.g.,NSP310fK and/or 0000 and/or 0000a and/or other), then the operator shag follow the federal. requirenieetsapdthis 0&M Plan does not need to be submitted."Thissourceis subject to NSPS 00000 as indicated above. Asa result, theoperatoragreed to remove the O&M plan front the applicationastheywllf follow (OAR requirements pas AIRS Point k 009 Process 8 SEC Code 01 Eterufecficu#s Seieisz`Tk`, Section 08- Inventory 5CC Coding and Emissions Factors Uncontrolled Pollutant Emissions Factor Control % Units Varies by Varies by VOC component type component type Standard EFs - EPA -453/R-95-017 Table 2-4 Varies by Varies by Benzene component type component type Standard EFs - EPA -453/R-95-017 Table 2-4 Fugitives Emissions Inventory Varies by Varies by Toluene component type component type Standard EFs - EPA -453/R-95-017 Table 2-4 Varies by Varies by Ethylbenzene component type component type Standard EFs - EPA -453/R-95-017 Table 2-4 Varies by Varies by %ylene component type component type Standard EFs - EPA -453/R-95-017 Table 2-4 Varies by Varies by n -Hexane component type component type Standard EFs - EPA -453/R-95-017 Table 2-4 Varies by Varies by 224 TMP component type component type Standard EFs - EPA -453/R -9S-017 Table 2-4 Amine Unit Thermal Oxidizer Emissions Inventory Emission Factor Source Section 01- Administrative Information Facility AIRS ID: 123 9fa7 008 -i County Plant Point Section 02- Equipment Description Details Detailed Emissions Unit Description: Two (2) thermal oxidizer (Make: TOD, Model: TOD,SN: TOD) used to control still vent and flash tank emissions from the amine unit(s) covered under point 001. Eachthermal oxidizer has a design rate of 25 MMBtu/hr. Flash tank wastegas is routed directly to the thermal oxidizer. Emission Control Device None - this point functions as the emission contra l device for point 001. Description: Requested Overall VOC & HAP Control Efficiency °A: Heat content of Supplemental Fuel= Acid Gas (Still Vent) Flow Rate = Acid Gas (Still Vent) Heat Content = Flash Tank Waste Gas Flow Rate = Flash Tank Waste Gas Heat Content = Pilot Light Rating = Heat Content of Pilot Light Fuel = Actual Hours of Operation = Requested Hours of Operation = Actual heat input rate = Requested heatinput rate = Potential to Emit (PTE) heat input rate = Total Actual Waste Gas Combusted = Total Requested Waste Gas Combusted = Total Potential to Emit (PTE) Waste Gas Combusted = Section 04- Emissions Factors & Methodologies Process 0l:' GOSIShitStioit Of supplemetital tuefi, • •, i 31 MMBtu/hr 240.3185841 MMscf/year 1130'. Btu/scf 4.944152'. MMscf/day 5454.61548 MMscf/year 6.53'. Btu/scf 0.316584 MMsd/day 11,555316 MMscf/year 1159 Btu/scf 45.19 MMBtu/hr 395864.4 MMscf/year 1 Btu/scf 0 hrs/year New Source - not yet installed ''--8760J hrs/year 835.33 MMBTU per year 668,259.82 MMBTU per year 668,259.73 MMBTU per year 401,330.57 MMscf/year 401,570.89 MMscf/year 401,570.89 MMscf/year Amine Unit TO Pollutant PM2.5 500 (Waste Heat (Waste Gas Combusted) combusted) Formaldehyde Benzene Toluene n -Hexane Uncontrolled Uncontrolled Ib/MMBtu - Ib/MMscf 2.0 Section 05 - Emissions Inventory Process 02, Combustion, of still vent and flash tank waste gas x2 units 14.944152 Average Waste G. 8.966285935 0.316584 Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit limits Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) VOC PM10 0.00 0.00 0.00 I 0.00 0.00 I 0.00 0. 0 I 0.00 20 of 34 K:\PA\2018\18W E0274.CP1.xism Amine Unit Thermal Oxidizer Emissions Inventory PM2.5 500 - NOx CO 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.09 0.09 0.09 0.09 0.09 0.19 0.19 12.82 12.82 12.82 12.82 12.82 25.65 25.65 16.03 16.03 16.03 16.03 16.03 32.06 32.06 Hazardous Air Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (Ins/year) (lbs/year) Formaldehyde 1.182E-02 1.182E -0Z 1.182E-02 1.182E-02 1.182E-02 23.6343 23.6343 Benzene 3.300E-04 3.300E-04 3.300E-04 3.300E-04 3.300E-04 0,6600 0.6600 Toluene 5.343E-04 5.343E-04 5.343E-04 5.343E-04 5.343E-04 1.0686 1.0686 n -Hexane 2.940E-01 2.940E-01 2.940E-01 2.940E-01 2.940E-01 588.0003 588.0003 Section 06 - Regulatory Summary Analysis Regulation 1 Section II.A.1- Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation. Section II.A.5 - Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. Regulation 2 Section I.A - No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. Regulation 3 Part A-APEN Requirements Criteria Pollutants: For criteria pollutants, Air Pollutant Emission Notices are required for: each individual emission point in a non - attainment area with uncontrolled actual emissions of one ton per year or more of any individual criteria pollutant (pollutants are not summed) for which the area is non -attainment. Applicant is required to file an APEN since emissions exceed 1 ton per year NOx. Part B — Construction Permit Exemptions Applicant is required to obtain a permit since uncontrolled NOx emissions from this facility are greater than the 2.0 TPY threshold (Reg. 3, Part B, Section II.D.2.a) Section 07- Technical Analysis Notes 1, VOC is not included in the calculations above because the. VOC emissions associated with the amine unit are accounted for under point 015. 2, AP -42 Chapter 5.3 provides information with regards to mine units. In section 5.3.3, paragraph 2, the document states "Most plants employ elevated smokeless flares or tail gas incinerators for complete combustion of ai waste gas constituents, including virtually 100 percent conversion of 1125 to 5O2. Little particulate, smoke, or hydrocarbons result from these devices a This is further supported by table 5.3.1[ which provides emission factors for gas sweetening plants. This table expresses the particulate emission factor for amine units controlled by smokeless flares and tail gas incinerators is negligible.. It should be noted that thepermit requires that daily checks be conducted to determine if the thermal oxidizer is smoking. If smoke is observed during the daily check the source is required toeither conduct a formal opacity observation or immediately shut in the equipment to investigate the cause of the smoke and conduct repairs as necessary. Based on this requirement for the thermal oxidizer it can safely be assumed that the thermal oxidizer will operate without smoke on a regular basis. Also, if smoke is observed, the operator will be required to assess the problem and perform necessary maintenance to prevent the thermal oxidizer from smoking. As such, I am comfortable assuming the particulate emitted from this source is negligible. The O&M plan also sets a minimum combustion chamber temperature for the TO. By maintaining this temperature and other good combustion practices,. the TO is unlikely to emit significant amounts of particulate as a result of the combustion of still' vent waste gas. If the total PM emission' factor of 7.0 lb/MMscf from AP 42. Chapter l.4 were used, the total PM emissions (for both PM 10 and 2.5) associated with the combustion of flash tank and stillvent waste gas would be 09 tpy. This is a very small amount of emissions and would not result in permit limits for PM or result in additional regulatory requirements. Based on the informationdiscussed above, it was determined that any PM generated from this combustion device is likely negligible and does not need to be calculated. 3. 4. The operator indicatedthatthere will be two flow meters associated with this thermal oxidizer. One flow meter will measure total still vent and flash tank waste gas routed tathe TO. The second flow meter will measure total supplemental fuel combusted bythe TO. Based on this information,Ilhere will be two throughput limits in the permit for this source. One will limit the total amount of waste gas combusted and the otherwill limit the amount of supplemental fuel combusted. Based on the location of the flow meter for the waste gas, it was determined that VRU downtime would not be required. to be recorded, This is because the total flow of waste gas routed to the thermal oxidizer will be recorded using a flow meter. S. The operator indicated that the pilot fuel combusted by the thermal oxidizer is accounted for with the supplemental fuel 6. Typically HAP emissions are only calculated for the combustion of the supplemental fuel Mr these sources since the HAP missions associated with the still vent and flash tank waste gas are calculated with the amine unit inthe instance the operator chose to calculate HAPs associated with the combustion of the still vent and flash tank waste gas. This leads to a conservative estsmate and Is therefore acceptablefor permitting purposes. - - - - - 7. The operator is requesting a 99% control efficiency for the thermal oxidizer that is used to control the still vent and flash tank. Since this control value is greaterthan the standard 95% control granted by the Division, Initial testing wilt be required to demonstrate the thermal oxidizer is capable of achieving a 99% destruction efficiency when controlling still vent and flash tank emissions from the amine. unit - B. SO2 emissions are calculated with the amine unit (point 001) because the operator used; the 502 emission factor from Table 5,3.1 -of AP 42. cf1 by the amine unft and not waste gas combusted. Please see additional discussion with the amine unit regarding this calculation. AIRSPoint # Process # SCC Code Section 08 - Inventory SCC Coding and Emissions Factors on gas processed Uncontrolled Emissions Pollutant Factor Control % Units 21 of 34 K:\PA\2018\18W E0274.CP1.xlsm Amine Unit Thermal Oxidizer Emissions Inventory 008 01 02 The processes above are as follow: (i) 01- Combustion of supplemental fuel, (ii) 02 Combustion of still vent and lash tank waste gas PM10 0.0 0 lb/MMscf Burned PM2.5 0.0 0 Ib/MMscf Burned NOx 90.4 0 lb/MMscf Burned VOC 0.0 0 lb/MMscf Burned CO 113.0 0 Ib/MMscf Burned 500 0.7 0 Ib/MMscf Burned Formaldehyde 8.33E-02 0 lb/MMscf Burned Benzene 2.33E-03 0 lb/MMscf Burned Toluene 3.77E-03 0 Ib/MMscf Burned n -Hexane 2.0 0 lb/MMscf Burned PM10 0.0 0 lb/MMscf Burned PM2.5 0.0 0 lb/MMscf Burned NOx 0.7 0 lb/MMscf Burned VOC 0.0 0 lb/MMscf Burned CO 0.9 0 lb/MMscf Burned 5Ox 0.0 0 lb/MMscf Burned Formaldehyde 6.61E-04 0 Ib/MMsd Burned Benzene 1.85E-05 0 lb/MMscf Burned Toluene 2.99E-05 0 Ib/MMscf Burned n -Hexane 1.99E-02 0 lb/MMscf Burned 22 of 34 K:\PA\2018\ 18WE0274.CP1.xlsrn Section 01- Adminstrative Information Facility AIRs ID: 123 9fa7 E. .009 County Plant Point Section 02 - Equipment Description Details Detailed Emissions Unit Natural gas venting from mole sieve blowdowns. Emissions from this source are vented to the Description: atmosphere. Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: Emissions from this source are not controlled. Section 03- Processing Rate Information for Emissions Estimates Compressor Blowdown Volume= 2.50E-02. MMscf Requested Compressor Blowdown Events= 8 events/year Actual Compressor Blowdown Events= 0< everrts/year Actual Gas Throughput = 0 MMscf per year Requested Permit Limit Throughput = 2.00E-01 MMscf per year Potential to Emit (PTE) Throughput = 2.00E-01 MMscf per year Actual Gas Throughput While Emissions Controls Operating = Section 04 - Emissions Factors & Methodologies Emission Calculation Method EPA Emission Inventory Improvement Program Publication: Volume II, Chapter 10 - Displacement Equation (10.4-3) Ex=Q*MW*Xx/C Ex = emissions of pollutant x Q= Volumetric flow rate/volume of gas processed MW = Molecular weight of gas = SG of gas * MW of air Xx = mass fraction of x in gas C = molar volume of ideal gas (379 scf/Ib-mol) at 60F and 1 atm Throughput (Q) MW 2.00E-01 MMscf/yr Ib/Ib-mol 2.28E+01 sof/yr MMscf/d 24.3 0.000547945 mole % MW Ibx/Ibmol mass fraction lb/hr lb/yr tpy Helium :; 0.00 4, 4,0026! 0.000 0.000 0.00 0.00 0.00 CO2 1.73 -- " 44.01 0.762 0.031 0.05 402.24 0.20 N2 0.44 28.013! 0.123 0.005 0.01 65.04 0.03 methane 67.78 16.041 10.873 0.447 0.65 5737.77 2.87 ethane 14,58 =- 30,063: 4.384 0.180 0.26 2313.66 1.16 propane - 9.49 '! 44.092 4.186 0.172 0.25 2208.79 1.10 isobutane : 1.03 58.118: 0.598 0.025 0.04 315.59 0.15 n -butane 2.75 '- 58.1181 1.599 0.066 0.10 843.71 0.42 isopentane 0.58 ! 72.114 0.417 0.017 0.03 219.96 0.11 n -pentane 0.66 ':' 72.114 0.475 0.020 0.03 250.40 0.13 cyclopentane ',: 0.04 70.13: 0.029 0.001 0.00 15.17 0.01 n -Hexane 0.37 86.18! 0.316 0.013 0.02 166.90 0.08 cyclohexane 0.04 84.16 0.035 0.001 0.00 18.65 0.01 Other hexanes '.'."' 0.00 86,18 0.000 0.000 0.00 0.00 0.00 heptanes -''_-=- 0.27 100.21 0.266 0.011 0.02 140.14 0.07 methylcyclohexane 0:06 98.19 0.061 0.003 0.00 32.13 0:02 224-TMP ':' 0.00 114.23. 0.000 0.000 0.00 0.00 0.00 Benzene 0.03 78.12' 0.022 0.001 0.00 11.54 0.01 Toluene : 0.04 92.15: 0.038 0.002 0.00 19.94 0.01 Ethylbenzene 0.01 106.17: 0.010 0.000 0.00 5.04 0.00 Xylenes 0.02 106.17 0.020 0.001 0.00 10.65 0.01 C8+ Heavies - - 0.08 114 0.088 0.004 0.01 46.32 0.02 VOCmass fractic 0.3357 MW 24.300 Total VOC (Uncontrolled) 2.15 Notes Mole %, MW, and mass fractions are based on a representative gas sample . Emissions are based on 8 Molesieve blowdown events per year. The MW of 18+ used for calculations is based on the operator designated value of 114. This is within the expected range and therefore acceptable. Section 05- Emissions Inventory Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 538.11 lb/event 538.11 lb/event 2.15 tpy 2.15 tpy Gas Analysis Benzene 1.443 lb/event 1.443 lb/event 11.5 lb/yr 11.5 lb/yr Mass Balance Toluene 2.492 lb/event 2.492 lb/event 19.94 lb/yr 19.94 lb/yr Mass Balance Ethylbenzene 0.630 lb/event 0.630 lb/event 5.04 lb/yr 5.04 lb/yr Mass Balance Xylenes 1.331 lb/event 1.331 lb/event 10.65 lb/yr 10.65 lb/yr Mass Balance n -Hexane 20.863 lb/event 20.863 lb/event 166.90 lb/yr 166.90 lb/yr Mass Balance 2,2,4-TMP 0.000 lb/event 0.000 lb/event 0.00 lb/yr 0.00 lb/yr Mass Balance Section 06 - Regulatory Summary Analysis 18WE0274.CP1.xlsm AQCC Regulation 1 Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation. AQCC Regulation 2 Section I.A applies to all emission sources. "No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air." Section 07 - Technical Analysis Notes 1. The operator expressed that to demonstrate compliance with blowdown permit limits, each blowdown even of events by the emission factor provided in the notes to permit holder (lb/event).: This supports the use of an ev ill be recorded and ends t basis for the processii ons will be estimated by multiplying the number rit contained in the permit. 18WE0274.CP1.xlsm Section 01- Adminstrative Information Facility AIRs ID: 123 County 9af7 010. Plant Point Section 02 - Equipment Description Details Detailed Emissions Unit Natural gas yanking from compressor Slowdowns. Emissions from this source are vented to th Description: atmosphere. s. Emission Control Device €mitsinns from this -source are not controlled. Description: Requested Overall VOC & HAP Control Efficiency %: Section 03 - Processing Rate Information for Emissions Estimates Compressor Blowdown Volume= Requested Compressor Blowdown Events= Actual Compressor Blowdown Events= Actual Gas Throughput= Requested Permit Limit Throughput = Potential to Emit (PTE) Throughput = , 3 ,`4430€-03' MMscf 576:: events/year a _ events/year 0 MMscf per year 2.30E+00 MMscf per year 2.30E+00 MMscf per year Actual Gas Throughput While Emissions Controls Operating = Section 04 - Emissions Factors & Methodologies Emission Calculation Method EPA Emission Inventory Improvement Program Publication: Volume II, Chapter 10- Displacement Equation (10.4-3) Ex=Q' MW`Xx/C Ex = emissions of pollutant x Q = Volumetric flow rate/volume of gas processed MW = Molecular weight of gas = SG of gas * MW of air Xx = mass fraction of x in gas C= molar volume of ideal gas (379 scf/lb-mol) at 60F and 1 atm Throughput (Q) MW 2.30E+00 MMscf/yr Ib/Ib-mal 2.63E+02 sd/yr MMsd/d 16.9 0.006312329 mole % MW Ibx/Ibmol 4.0026! 44.01. mass fraction lb/hr 0.000 lb/yr tpy 0.00 Helium 0.00 0.06 0.000 0.00 0.00 CO2 0.027 0.002 0.02 163.20 0.08 N2 0.00 .;':':....28.013'. 0.000 0.000 0.00 0.00 0.00 methane 95.86 3.39 6. 15.378 0.912 10.67 93482.29 46.74 ethane 30.063 1.019 0.060 0.71 6191.65 3.10 propane isobutane n -butane 0.06 44.092: 0.027 0.002 0.02 166.45 0.08 0.00 58118' 58.118. 72.114 72.114 0.000 0.000 0.00 1.41 0.00 0.00 0.00 0.00 0.00 0.000 0.000 0.00 2.12 0.00 isopentane n -pentane cyclopentane n -Hexane 0.000 0.000 0.00 0.00 0.00 0.00 0.000 0.000 0.00 0.00 70€13 .86.10 0.000 0.000 0.00 0.00 0.00 0.37 0.316 0.013 0.15 1332.15 0.67 cyclohexane Other hexanes heptanes methylcyclohexane 224-TMP 0.00 84.16 0.000 0.000 0.00 0.00 0.00 0.00 86.18 0.000 0.000 0.00 0.00 0.00 0.00 ..:...100.21; ':...... 94.19] 0.000 0.000 0.00 0.00 0.00 0.00 0.000 0.000 0.00 0.00 0.00 0.00 0.000 0.000 0.08 0.01 0.02 0.00 0.00 0.00 Benzene Toluene Ethylbenzene Xylenes C8+ Heavies 0.03 0.04 78,12 92.15'. 0.022 0.038 0.001 0.002 0.000 92.23 0.05 0.08 163.96 0.01 06.17 0.010 40.99 0.02 0.02 106.17 0.020 0.001 0.01 0.00 81.98 0.04 0.00 114 0.000 0.000 0.00 0.00 VOC mass fractio MW 16.856 Notes 0.0184 Total VOC (Uncontrolled) 0.94 Mole %, MW, and mass fractions are based on a representative gas sample average from 5 facilities, Emissions are based on (48 x 12) compressor blowdown events per year. The MW of C8+ used for calculations is based on the operator designated value of 114. Thisis within the expected range and therefore acceptable. Section 05 - Emissions Inventory Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 3.27 lb/event 3.27 lb/event 0.94 tpy 0.94 tpy Gas Analysis Benzene 0.160 lb/event 0.160 lb/event 92.2 Ib/yr 92.2 lb/yr Mass Balance Toluene 0.285 lb/event 0.285 lb/event 163.96 lb/yr 163.96 lb/yr Mass Balance Ethylbenzene 0.071 lb/event 0.071 lb/event 40.99 lb/yr 40.99 lb/yr Mass Balance Xylenes 0.142 lb/event 0.142 lb/event 81.98 lb/yr 81.98 lb/yr Mass Balance n -Hexane 2.313 lb/event 2.313 lb/event 1332.15 lb/yr 1332.15 lb/yr Mass Balance 2,2,4-TMP 0.000 lb/event 0.000 lb/event 0.00 lb/yr 0.00 lb/yr Mass Balance Section 06 - Regulatory Summary Analysis 18WE0274.CP1.xlsm AQCC Regulation 1 Section II.A.1- Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation. AQCC Regulation 2 Section I.A applies to all emission sources. "No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air." Section 07 - Technical Analysis Notes 1. The operator expressed that the compressor volume was calculatedbased on the piping and instrumentation diagrams for the Ariel IG64 2 compressor. The operator did not provide" specifications for the Ariel JGE4-2compressor but expressed that the volume used in this application is consistent other applications submitted in Wyoming in the past. I confirmed this assertion by referencing the permit application forthe Clarkelen Central Compressor Station (2016) in Wyoming, which contains identical calculations for compressorblowdowns. In this application the compressor volume was calculated and then converted to standard conditiars.. After review of the . calculations, I determined the calculated volume was a reasonable estimate and acceptable for permitting purposes. The operator expressed that to demonstrate compliance with blowdown permit limits, each blowdown event will be recorded and emissions will be estimated by multiplying the number events by the emission factor provided in the notes to permit holder (lb/event).. This supports the use of an event basis for the process hmt contained in the permit. The operators supplied calculation assumed inlet gas upeciation (in weight %) of HAPs for the residue gasstream which does not have HAPs initally. This approach is conservative and cceptable. Values for weight% were modified to reflect those in the inlet gas stream composition. 18WE0274.CP1.xlsm Section 01- Adminstrative Information Facility AIRS 8): 13 County 11 Plant Point Section 02 - Equipment Description Details Detailed Emissions Unit Natural gas venting from compressor rod packing. Emissions from this source are vented Description: atmosphere. Emission Control Device Emissions from this source are Description: Requested Overall VOC & HAP Control Efficiency %: Section 03 - Processing Rate Information for Emissions Estimates Compressor rod packing vent rate= Number of compressors= Actual rod packing vent rate= Actual Gas Vent Rate Requested Permit Limit Throughput = Potential to Emit (PTE) Throughput = 14:_ scf/hr 12?? 0 scf/hr 0 MMscf per year 11.984 MMscf per year 11.984 MMscf per year Actual Gas Throughput While Emissions Controls Operating = Section 04 - Emissions Factors & Methodologies Emission Calculation Method EPA Emission Inventory Improvement Program Publication: Volume II, Chapter 10 - Displacement Equation (10.4-3) Ex=Q*MW*Xx/C Ex = emissions of pollutant x Q = Volumetric flow rate/volume of gas processed MW = Molecular weight of gas = SG of gas * MW of air Xx = mass fraction of x in gas C = molar volume of ideal gas (379 scf/Ib-mol) at S0F and 1 atm Throughput (Q) MW 1.20E+01 MMscf/yr Ib/Ib-mol 1.37E+03 0.032832 scf/yr MMscf/d 16.9 mole % MW Ibo/Ibmol mass fraction Ib/hr lb/yr tpy Helium -' 0.00 II 4.0026! 0.000 0.000 0.00 0.00 0.00 CO2 0.06 44.01! 0.027 0.002 0.10 848.85 0.42 N2 0.00 :! 28.013'. 0.000 0.000 0.00 0.00 0.00 methane 95.86 16.041'. 15.378 0.912 55.51 486224.76 243.11 ethane 3.39-- 00.063! 1.019 0.060 3.68 32204.30 16.10 propane 0.06 r' 44.0921 0.027 0.002 0.10 865.77 0.43 isobutane ='. 0.00 ". 58.118 0.000 0.000 0.00 7.35 0.00 n -butane 0.00 08.118 0.000 0.000 0.00 11.03 0.01 isopentane 0.00 ! 72.114 0.000 0.000 0.00 0.00 0.00 n -pentane : 0.00 72.114 0.000 0.000 0.00 0.00 0.00 cyclopentane 0.00 70.13! 0.000 0.000 0.00 0.00 0.00 n -Hexane 0.37 66.18 0.316 0.013000 0.79 6928.85 3.46 cyclohexane i 0.00 84.16 0.000 0.000 0.00 0.00 0.00 Other hexanes ''-= 0.00 86.18. 0.000 0.000 0.00 0.00 0.00 heptanes 0.00 100.21 0.000 0.000 0.00 0.00 0.00 methylcyclohexane 0.00 98.14 0.000 0.000 0.00 0.00 0.00 224-TMP 0.00 114.23. 0.000 0.000 0.00 0.00 0.00 Benzene 0.03 78.12. 0.022 0.001 0.05 479.69 0.24 Toluene :! 0.04 - 92.15' 0,038 0.002 0.10 852.78 0.43 Ethylbenzene ' 0.01 106.17: 0.010 0.000 0.02 213.20 0.11 Xylenes 0.02 106.17. 0.020 0.001 0.05 426.39 0.21 C8+ Heavies 0.00 ...114 0.000 0.000 0.00 0.00 0.00 VOC mass fractio MW 16.856 Notes 0.0184 Mole %, MW, and mass fractions are based on a representative gas sample average from 5 facilities. Emissions are based on a total of 12 compressors each with an assumed vent rate of 114 scf/hir. Section 05 - Emissions Inventory Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 816.53 lb/MMscf 816.53 lb/MMscf 4.89 tpy 4.89 tpy Gas Analysis Benzene 40.029 lb/MMscf 40.029 lb/MMscf 479.69 lb/yr 479.69 lb/yr Mass Balance Toluene 71.162 lb/MMscf 71.162 lb/MMscf 852.78 lb/yr 852.78 lb/yr Mass Balance Ethylbenzene 17.790 Ib/MMscf 17.790 lb/MMscf 213.20 lb/yr 213.20 lb/yr Mass Balance Xylenes 35.581 lb/MMscf 35.581 lb/MMscf 426.39 lb/yr 426.39 lb/yr Mass Balance n -Hexane 578.191 lb/MMscf 578.191 lb/MMscf 6928.85 lb/yr 6928.85 lb/yr Mass Balance 2,2,4 -IMP 0.000 lb/MMscf 0.000 Ib/MMscf 0.00 lb/yr 0.00 lb/yr Mass Balance Total VOC (Uncontrolled) 4.89 Section 06 - Regulatory Summary Analysis 18WE0274.O1.xlsm AQCC Regulation 1 Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which Is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation. AQCC Regulation 2 Section I.A applies to all emission sources. "No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air." AQCC Regulation 3 Part A-APEN Requirements Criteria Pollutants: For criteria pollutants, Air Pollutant Emission Notices are required for: each individual emission point in a non -attainment area with uncontrolled actual emissions of one ton per year or more of any individual criteria pollutant (pollutants are not summed) for which the area is non -attainment. Applicant is required to file an APEN since emissions exceed 1 tan per year VOC. Part B —Construction Permit Exemptions Applicant is required to obtain a permit since uncontrolled VOC emissions from this facility are greater than the 2.0 TPY threshold (Reg. 3, Part B, Section I I.D.2.a) Part B, III.D.2 - RACT requirements for new or modified minor sources This section of Regulation 3 requires RACT for new or modified minor sources located in nonattainment or attainment/maintenance areas. This source is located in the 8 -hour ozone nonattainment area. The date of interest for determining whether the source is new or modified is therefore November 20, 2007 (the date of the 8 -hour ozone NA area designation). Since the fugitives will be in service after the date above, this source is considered "new or modified." This source is subject to the reciprocating compressor requirements of NSPS 0000a , which requires replacement of compressor rod packing at specified intervals. These requirements satisfy the RAC -requirements under Regulation 3. Regulation 6 Is this source at an onshore "natural gas processing plant" as defined in 40 CFR, Part 60.631? Yes Did this source commence construction, reconstruction, or modification after January 20, 1984, and on or before August 23, 2011? No This source is not subject to NSPS KKK because the facility will commence construction after August 23, 2011. Did this source commences construction, reconstruction, or modification after August 23, 2011 and on or before September 18, 2015? No Source is not subject to NSPS OOOO because this is a new that facility will commence construction after September 18, 2015. Regulation 7: Section XII: Is this source located in an ozone non -attainment area or attainment maintenance area? Yes Is this source at an onshore "natural gas processing plant" as defined in 40 CFR, Part 60.631? Yes Facility is located in the non -attainment area and classified as a natural gas processing plant. Therefore, this source is subject to Regulation 7 Section XII.G. Section XVII: Is the reciprocating compressor located at a natural gas compressor station? No The reciprocating compressors are located at a natural gas processing plant and are therefore not subject to Regulation 7 Section XVII.B.3.c. Regulation 8 Is this source at a "natural gas processing plant" as defined in 40 CFR, Part 63./61? Yes Is this facility considered a "major source" of HAP as specifically defined in 40 CFR, Part 63.761 for sites that are not prodcution field facilities? No Source is not subject to MACF HH because the facility is classified as a synthetic minor source of HAPs. NSPS 0000a Did this source commence construction, reconstruction, or modification after September 18, 2015? Yes Is this source at a well site, compressor station or onshore "natural gas processing plant" as defined in 40 CFR, Part 60.5430a? Yes This facility meets the definition of onshore "natural gas processing plant" as defined by 40 CFR, Part 60.5430a. Therefore, the emissions of this source are subject to the reciprocating compressor affected facility requirements under §60.5385a of NSPS OOOOa. Since NIPS 0000a has not been adopted by the State of Colorado, the requirements will be referenced in the notes to permit holder. Section 07 - Technical Analysis Notes :1. According to the application, the 'compressor rod packing seals leak a small amount of gas almost continuously at very low pressures making this type of emission source very difficult to apply any type of emission control." The NSPS OOOO backrgound technical support document reviewed the following control techniques for limiting the leaking of natural gas past the piston rod packing: (i) Replacement of compressor rod packing, (ii( Replacement of the piston rod, and (iii) Refitting or realignment of the pastor rod. This supports the operator's claim that the emissions from this source would be difficult to route to an add-on control device (i.e, combustor, VRU, etc). Based on this information, along with the definition of fugitive emissions in the Colorado Common Provisions, I determined this emission source would be classified as fugitive emissions. As a result, the applicable NSPS 0000a requirements to replacethe reciprocating compressor rod packing every 26,000 hours or 36 months was determined to been acceptable mechanism for minimizing the emissions from this source. 2. According to the Natural gas STAR lessons learned document "Reducing Methane Emissions from Compressor Rod Packing Systems," leakage typically occurs from four areas: (i) Around the packing case through the nose gasket. (ii) Between the packing cups which are typically mounted metal -to -metal against each other. (3u) Around the rings from slight movement In the cup groove as the rod moves back and forth; (iv) Between the rings and shaft." This document also indicates that a "new packing system, properly aligned and fitted may lose approximately 11 to 12 standard cubic feet per hour (scfh). 3. Typically rod packing emissions associated with compressors are accounted for with the 'other" category under the fugitive emission source at a facility, This is supported by note "C" under Table 2-4 of the EPA Protocol for Equipment Leak Emission Estimates (EPA -4531R-95-017) which states "The 'other' equipment type was derived from compressors, diaphrams, drains, dump arms, hatches, instruments, meters, pressure relief valves, polished rods, relief valves, and vents." If this method were used to estimate rod packing emissions, an emission factor of 0,0088 kg/hr-source would be utilized. The opperators emissions have been calculated to be more conservative and thus acceptable with this regard.. 4. As discussed above, this facility s subject to NSPS OOOOx. However, this federal regulation has not been adopted into Colorado state regulation, A in the notes to permit holder determined above, this: facility is subject to regulation 7 Section XII.G. This regulation indicates the facility must follow NSPS KKK to demonstrate compliance. Since this facility Is subject to more stringent requirements under NSPS OOOOa, it was determined that following the requirements of NSPS .OOOOawould satisfy the requirements of Regulation 7 Section XII.G. The condition in the permit referencing Regulation 7 Section X11.0 will indicate that by meeting the requirements of NIPS OOOOa, the source will be in compliance. 6. The operator confirmed that each of the compressors at this facility will be classified as reciprocating compressors.. 7. Colorado Regulation 7 Section XIf.G.1 requires the source to comply the leak detection and repair program (LDAR( per NSPS KKK for the fugitive VOC emissions at the facility. However, this source is subject to NIPS 0000a based on the construction date ofthe facility, This„ federa£aegulation is more stringent eS compared to NSPS KKK. Asa result, I determined the source would demonstrate compliance with Regulation 7 Section 011.0,1 by complying with NSPS`0000a)`he permit will contain an appropriate condition pertaining to this determination. Further, it was determined unnecessary for the source to comply with two different LDAR programs when one program (NSPS OOOOa) is more stringent than the other (NSPS KKK). 18WE0274.CP1.xlsm demonst 7 plying with NSPS 000ep'ono_permit wilho,ontain an appropriate condition pertaining to this_,eterrn determined xrnecessaryfortthe smarace to comkilan y coin P� 8 py different LBfiR programs when one program(NSP50004aj is more stringent than the=other(NSPa P PP d & f weight }of ... i . e .. , gas stream which -does not hau S Thpaoerat�rs su #ied cgalouktton assumednleG as spe�ciation 3n g's streamPcom oseition due _ eHAPs onita;lly Thrsappcoach is acce to dle.. Values for weight %we re madifietl to reftect those in the inlet 18W E0274.CP1.xlsm Condensate Storage Tank(s) Emissions Inventory Section 01- Adminstrative Information Facility AIRs ID: County Plant Point Section 02- Equipment Description Details Detailed Emissions Unit Three'. Description: Emission Control Device n/a Description: Requested Overall VOC & HAP Control Efficiency 0 for VRU (Process 01): Requested Overall VOC & HAP Control'. Efficiency %for enclosed f lore (Process'. Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Storage Tank(s) Actual Condensate Throughput = Total Requested Permit Limit Throughput = Requested. Permit Limit Throughput while VRU is operational (Process 01). Requested==PermitUmitThroughputOuting VRU downtime (Process 02) Potential to Emit (PTE) Condensate Throughput = torage vessels connected via liquid manifohl. Barrels (bbl) per year Actual Condensate Throughput While Emissions Controls Operating = Barrels (bbl) per year r50b Barrels (bbl) per year Barrels (bbl) per year Barrels (bbl) per year Secondary Emissions - Combustion Device(s) Heat content of waste gas= :Btu/scf Vodume of waste gas emitted per BBL of liquid produced = ...:I scf/bbl Actual heat content of waste gas routed to combustion device Request heat content of waste gas routed to combustion device = 0 MMBTU per year 0 MMBTU per year Potential to Emit (PTE) heat content of waste gas routed to combustion device = 0 MMBTU per year Section 04- Emissions Factors & Methodologies Will this storage tank emit flash emissions? Flash Emissions: ProMax Condensate Throughput: Pollutant Flash Emissions Emission Factors VOC D lb/hr 0 lb/bbl Benzene :;:•'i lb/hr 0 lb/bbl Toluene 'D 77.1311 f:(:l?r lb/hr 0 lb/bbl Ethylbenzene ;il l /1/: lb/hr 0 lb/bbl Xylene D. .._ lb/hr 0 lb/bbl n -Hexane ,,; Oi'. ': Ib/hr 0 lb/bbl 224 TMP 0.' ,; lb/hr . 0 lb/bbl 35SfIgl bbl/year Working and Breathing Emissions: Tank Loss Stencil Throughput: 47 bbl/year Pollutant Working and Breathing Emissions Emission Factors VOC 0:15 ','. ton/year 0.00832 lb/bbl Benzene 0 -.ton/year 0 lb/bbl Toluene 0 :;:: ton/year 0 lb/bbl Ethylbenzene 0 '' ton/year 0 lb/bbl Xylene 0 :'ton/year 0 lb/bbl n -Hexane - -0' :::ton/year 0 lb/bbl 224 TMP 0 ." ton/year 0 lb/bbl Note: The representative gas sample was used as an input for the ProMax simulation used to estimate the condensate storage tank emissions as indicated above. Condensate Storage Tanks Control Device Pollutant Controlled E,F.. = Controlled EA while emissions while emissions` are routed to are routed to the Uncontrolled Uncontrolled E.F.-theVRU enclosed flare E.F. (lbs/bbl (Ibs/bbl. (ibs/bbl;.: (Ibs/MMBtu Condensate Condensate - Condensate waste heat Throughput) Throughput) % Throughput) combusted) Uncontrolled E.F. (Ibs/bbl Condensate Throughput) Emissions Factor Source Citation PM10 PM2.5 NOB VOC CO 0.008 0.01 0.008 VALUE! #VALUE! 0.000 0.000E+00 Toluene 0.0000 0.0000 0.0000 0.0000 0.0000 Barrels (bbl) per year 30 of 34 K: \PA\2018\18 W E0274.CP 1,xlsm Condensate Storage Tank(s) Emissions Inventory Section 05 - Emissions Inventory 224 TMP 0.00000 0.00000 0.0084 0.0000 0.000 0.000 0.008 0.000 0.000E+00 0.000E+00 Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) PM10 PM2.5 NOx VOC CO 0.0 0.0 0.0 0.0 0-0 0.0 - 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.2 0.15 0.15 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Hazardous Air Pollutants Potential to Emit Uncontrolled (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Actual Emissions Uncontrolled Controlled _ (tons/year) (tons/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP #VALUE! #VALUE! #VALUE! #VALUE! ((VALUE! 0.0E+00 0.000 0.00E+00 0.0E+00 0.0E+00 0.0E+00 0.000 0.00E+00 0.0E+00 0.0E+00 0.0E+00 0.000 0.00E+00 0.0E+00 0.0E+00 1.8E-01 0.15.3 1.53E-01 0.0E+00 0.0E+00 0.0E+00 0.000 0.00E+00 0.0E+00 0.0E+00 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Source is APEN exempt Regulation 7, Section XII.C, D, E, F Storage Tank is not subject to Regulation 7, Section XII Regulation 7, Section XII.G, C Storage tank is subject to Regulation 7, Section XII.G, as provided belo Regulation 7, Section XVII.B, C.1, C.3 Storage Tank is not subject to Regulation 7, Section XVII Regulation 7, Section XVII.C.2 Storage Tank is not subject to Regulation 7, Section XVII.C.2 Regulation 6, Part A, NIPS Subpart Kb Storage tank is subject to NSPS Kb, including but not limited to, the fo Regulation 6, Part A, N5PS Subpart 0000 Storage Tank is not subject to NSPS 0000 NSPS OOOOa Storage Tank is not subject to NSPS OOOOa Regulation 8, Part E, MACI Subpart NH Storage Tank is not subject to MAR HH (See regulatory applicability worksheet for detailed analysis) Requested Emissions Uncontrolled Controlled (lb/year) (lb/year) #VALUEI #VALUEI 0.000 0.000 0.000 0.000 0.000 0.000 306.600 306.600 0.000 0.000 31 of 34 K:\PA\2018\ 18WE0274.CP1.xlsm Condensate Storage Tank(s) Emissions Inventory Section 07- Initial and Periodic Sampling and Testing Requirements Does the company use the state default emissions factors to estimate emissions? If yes, are the uncontrolled actual or requested emissions estimated to be greater than or equal to 80 tons VOC per year? If yes, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in P5 Memo 05-01. Does the company use a site specific emisions factor to estimate emissions? If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid sample drawn at the facility being permitted? This sample should be considered representative which generally means site -specific and collected within one year of the application received date. However, if the facility has not been modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample. If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01. N/A - Source calculated site -specific emission factors. Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain and intial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08 - Technical Analysis Notes 7. Since this. is a new facility without actual operating Information, the :actua[throughput informafionwasle AIRS Point # 010 Process# SCC Code 01 ui04 00',SN."` Section 09 - Inventory SCC Coding and Emissions Factors Uncontrolled Enclosed Emissions VRU Flare Pollutant Factor Control % Control % Units PM10 0.00 0 0 lb/1,000 gallons condensate throw PM2.5 0.00 0 0 lb/1,000 gallons condensate throu NOx 0.00 0 0 lb/1,000 gallons condensate throu VOC 0.2 0 95 lb/1,000 gallons condensate throu CO 0.00 0 0 lb/1,000 gallons condensate throu Benzene #VALUEI 0 95 lb/1,000 gallons condensate throu Toluene 0.00 0 95 lb/1,000 gallons condensate throu Ethylbenzene 0.00 0 95 lb/1,000 gallons condensate throu Xylene 0.00 0 95 lb/1,000 gallons condensate throu n -Hexane 0.2O 0 95 lb/1,000 gallons condensate throu 224 TMP 0.00 0 95 lb/1,000 gallons condensate throu 32 of 34 K:\PA\2018\ 18WE0274.CP1.xlsm Condensate Tank Regulatory Analysis Worksheet Colorado Regulation 3 Parts A and B -OPEN and Permit Requirements ATTAINMENT -CO emissions associated with combustion of waste gas from the condensate tanks are amounted for under point 013. Asa result all questions in this section are marked as N/A 1. Are uncontrolled actual emissions from any criteria pollutants from this Individual source greater than 2 TP9(Regulation 3, Part A, Section II.D.1.a)? 2. Is the construction date [section date( prior to 12/30/2002 and not modified after 12/31/2002 (See PS Memo 05-01 Definitions 1.12 and1.14 and Section 2 for additional guidance on grandfather applicability)? • 3. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10TPY (Regulation 3, Part 8, Section 11.0.310 loot enough information NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1TPY (Regulation 3, Part A, Section lI.D.1.a)? 2. Is the construction date (rewire date) prior to 12/30/2002 and not modified after 12/31/2002 (See PS Memo 05-01 Definitions 1.12 and1.14 and Section 2 for additional guidance on grandfather applicability)? 3. Are total facility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 5 TPY (Regulation 3, Part B, Section 11.1.2)? CHq....,,, 'i.,.. Yfs 50,0.00 is APEN exernlrt Colorado Regulation 7, Section XII I. Is this storage tank located in the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area? 2. Is this storage tank located at an oil and gas exploration and production operation', natural gas compressor station or natural gas drip station? 3. Is this storage tank located upstream of a natural gas processing plant? Jsurrage Tank is nor cui[ertto Reruletioo T, Sartiou Oil Section X11.C.1 -General Requirements for Air Pollution Control Equipment -Prevention of Leakage Section XII.C.2-Emission Estimation Procedures Section KII.O -Emissions Control Requirements Section MIX - Monitoring Section Xll.F- Recordkeeping and Reporting Colorado Regulation 7, Section XII.G 1. Is this storage tank located in the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area? 2. Is this storage tank located at a natural gas processing plant? 3. Does this storage tank exhibit Flash (eg storing non -stabilized liquids) emissions and have uncontrolled actual emissions greater than or equal to 2 tons per year VOC? (Storage tank is sabpvt to Regolation'7, Section 011.0, 2, provided below Rggynn Yrll-fi-y - Fmliilnni FRnYrAI RPHHIrfmfny§ Section XII.C.1 -General Requirements for. Air Pollution Control Equipment -Prevention of Leakage Section KJI.C.2- Emission Estimation Procedures Colorado Regulation 7, Section XVII 1. Is this tank located at a transmission/storage facility? 2. Is this condensate storage tank' located at an oil and gas exploration and production operation, well production facility', natural gas compressor station' or natural gas processing plant? 3. Is this condensate storage tank fixed roof storage tank? 4. Are uncontrolled actual emissions° of this storage tank equal to or greater than 6 tons per year VOC? IStorago'rnnk is 001 sub ]echo Section %VII.B- General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section %VII.C.1- Emission Control and Monitoring Provisions Section XVII.C.3 -Recordkeeping Requirements 5. Does the condensate storage tank contain only "etahilired" liquids? (Storage bank is not subject to Regulation' 7, 00001011 XVii.C.2 Section KVII.C.2 -Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment 40 CFR, Part 60, Subpart Kb, Standards of Performance for Volatile Organic Squid Storage Vessels 1. Is the individual storagevessel capacity greater than or equal to 75 cubic meters (m) [`411 Bgls]? 2. Does the storage vessel meet the following exemption in 60.111b(d)(4)? a. Does thevessel has a design capacity less than or equal to 1,589.874 ma h10,000 BBL] used for petroleum' or ondensate stored,processed, or treated prior to custody transfer' as defined in 60.111b? 3. Was this condensate storagetank constructed,reconstructed, or modified (see definitions 90 CFR, 60.2) after July 23, 1984? 4. Doesthetank meet the definition of"storage vesser'a in 60.1116? 5. Does the storage vessel store a"volatile organic liquid (VOL)"' as defined in 60.1116? 6. Does the storage vessel meet any one of the following additional exemptions: a. Is the storagevessel a pressure vessel designed to operate in excess of 204.9 kPa [-29.7 psi] and without emissions to the atmosphere (60.110b(d)(2))?; or b. The design capacity isgreater than or equal to 151 ma ["950 BBL] and stores a liquid with a maximum auevapor pressures less than 3.5 kPa (60.11Db(b))?; or L. The Assign goatsiSy IF greater than .2[ equal to 751,1° ['473 @@4 Sgt Igt thgn 151 ma I-@SM e@,I?, ggd k)o(g g iis:i7 olti a maximum [Ito 00000 erelsurea Iran than 15,4 IsPal?4,114b1b11? I5totaga tank in vubpck to `l iP500, indcdiog Gut not Maitt d to, the follawing provisions Subpart A, General Provisions §50.1120- Emissions Control Standards for VOC §60.113b -Testing and Procedures §60.1196 - Reporting and Recordkeeping Requirements §60.116b - Monitoring of Operations 40 CFR, Part 00, Selman 0000 Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution a. Was this condensatestorage vessel constructed,reconstructed, or modihed(see definitions 40CFR, 60.2) after August 23, 2011 and prior to September 18, 2015? 2. Does this condensate storage vessel meet the definition of "storage vessel"' per 00.5430? 3. Is this condensate storage vessel located at a facility in the onshore oil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment of the Industry? 4. Are potential VOC emissions' from the individual storage vessel greater than or equal to 6 tons per year? S. Is the storage vessel subjectto and controlled in accordance with requirements for storagevessels In 40 CFR Part 60 Subpart Kb or 40 CFR Part 63 Sub art NH? Istorage Tank Or Oct subicct to NSPS 0000 Subpart A, General Provisions per 060.5425 Table 3 §00.5395 - Emissions Control Standards for VOC §60.5413 -Testing and Procedures §60.5395(g)- Notification, Reporting and Recordkeeping Requirements 460.5416(c)- Cover and Closed Vent System Monitoring Requirements §60.5417 -Control Device Monitoring Requirements Source does not need an APEN and is OPEN and permit exempt Go to next question Source Requires a permit Go to the next question Storage Tank is not subject to Regulation 7, Section XII Storage Tank is not subject to Regulator 7, Section XII Go to the next question Go to the next question Sources subject Go to next question Go to the next question Go to the next question Storage Tank Is not subject to Regulation 7, Section XVII Storage Tank is not suhjectto Regulation 7, Section RVII.C.2 Go to the next question Go to the next question Go to the next question Go to the next question Go to the next question Source Is subject to NSPS Kb Storage Tank Is not subject NSPS 0000 -This tank was constructed after the applicability date of September 18, 2015. (Note: If a storage vessel is previously determined to be subjectto NSPS 0000 due to emissions above 6 tons per year VOC on the applicability determination date, It should remain subject to NIPS 0000 per 60.53651e)l21 even If potential VOC emissions drop below 6 tons per year] 40 CFR, Part60, Subpart 0000a, Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modifiradon, or Reconstruction Commenced After September 18, 2015 1. Was this condensate storagevessel constructed,reconstructed, or modifiied(5ee definitions 40 CFR, 60.2) after September 18,2015? 2. Does this condensate storage vessel meet the definition of 'storage vessel's per 60.5430a? Peq.......,'...,. Go to the next question Go to the next question 3. I5 this condensate storage vessel located at a facility in the crude oil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment of the Industry? Y2s.......i''. Go to the next question 4. Are potential VOCemissions' from the individual storage vessel greater than or equal to 6 tons per year? 5. Is the storage vessel subject to and controlled in accordance with requirements for store a vessels In 40 CFR Part 60 Sub art Kb or 40 CFR Part 63 Sub art NH? (Storage Tank isnod subject to 5.,PS OCrOt3a 40 CFR, Part 63, Subpart MALT HO Oil and Gas Production Facilities 1. Is the tank located at a facility that b majors for HAPs? 2. Is the storage tank located at an oil and natural gas production facility that meets either of the following criteria: a. Afacility thatprocesses, upgrades or stores hydrocarbon liquids' (63.760)a)(2)(; OR b. Afacllity that processes, upgrades or stores natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category or is delivered to a final end user' (63.760ja)(3)l? 3. Does the tank meet the definition of "storage vessel ° in 63.761? 4. Does the tank meet the definition of"storage vessel with the potential for flash emissions"s per 63.761? 5. Is the tank subject to control requirements under 40 CFR Part 60, Subpart Kb or Subpart 0000? IOeu'.age Tank is' nry xubjoot to t.ACT Ed₹i Subpart A, General provisions per §63.764 (a) Table 2 §63.766 - Emissions Control Standards §63.773 -Monitoring §63.774- Recordkeeping §63.775 -Reporting RACT Review RACT review Is required If Regulation 7 does not apply AND ifthe tank is in the non -attainment area. lithe tank meets both criteria, then review RACT requirements. Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is note rule or regulation, and the analysib it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation Mil control. The use of non -mandatory language such as"recommend,""may," "should," and "can," is intended to describe APCD interpretations and recommendations. Mandatory terminology such as "must" and "required" are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself Definitions for Drop Down Lists Yes No NA t/A.....,,,''i Storage Tank is not subject MPS 0000. Storage Tank is not subject MACn HH -There are no MACT HH requirements for tanks at area sources Permit number: Date issued: Issued to: COLORADO Air Pollution Control Division Department of Public Health & Environment. CONSTRUCTION PERMIT 18WE0274 Facility Name: Plant AIRS ID: Physical Location: County: General Description: Issuance: 1 Discovery DJ Services LLC Discovery Keenesburg Gas Plant 123/9FA7 SEC 17 T2N R63W Weld County Natural Gas Processing Plant Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description A1/A2 001 Two (2) Methyldiethanolamine (MDEA) natural gas sweetening"unit(s) (Make: TBD, Model: TBD, Serial Number: TBD) with a design capacity of 225 MMscf per day each, 450 MMscf per day combined. Each emissions unit is equipped with an electric lean amine recirculation pump capable of 750 gallons per minute. This amine unit is equipped with a still vent, flash tank, and reboiler burner. Emissions from the still vent are routed to an air-cooled condenser, and then to the Thermal Oxidizer. Emissions from the flash tank are routed directly to the Thermal Oxidizer. H1/H2 002 Two (2) natural gas fired hot oil heaters (Make: TBD, Model: TBD, SN: TBD). The heaters each have a design rate of 65 MMBtu/hr each. Each heater is equipped with a low-NOx combustion system. The heaters provide heat for hot oil that is circulated throughout the plant as a heat transfer medium. None H3/H4 003 Two (2) natural gas fired regenerator heater(s) (Make: TBD, Model: TBD, SN: TBD). The heater(s) have a design rate of 24 MMBtu/hr each. Each heater is equipped with None a low-NOx combustion system. The heater provide heat for mole sieve regeneration. ST 005 Two (2) 1,000 barrel fixed roof produced water storage vessels connected via liquid manifold. Enclosed Combustor LT 006 Loadout of stabilized condensate and slop (mixture of stabilized condensate and water) to tank trucks. Enclosed Combustor FUG 007 Equipment leaks (fugitive VOCs) from a natural gas processing facility. LDAR C1/C2 008 Two (2) thermal oxidizer (Make: TBD, Model: TBD, SN: TBD) used to control still vent and flash tank emissions from the amine unit(s) covered under point 001. Each thermal oxidizer has a design rate of 31 MMBtu/hr. Flash tank waste gas is routed directly to the thermal oxidizer. None MSS 009 Natural gas venting from mole sieve blowdowns. Emissions from this source are vented to the atmosphere. None CB 010 Natural gas venting from compressor blowdowns. Emissions from this source are vented to the atmosphere. None RP 011 Natural gas venting from compressor rod packing. Emissions from this source are vented to the atmosphere. None 012 Three (3) 1,000 bbl fixed roof methanol storage vessels connected via liquid manifold. None 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 the specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1 YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the latter of commencement of operation or issuance of this permit, by submitting, a Notice of Startup form to the Division for the equipment covered by this permit. The Notice of Startup form may be downloaded online at www.colorado.gov/pacific/cdphe/other-air-permitting- notices. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation Number 3, Part B, Section III.G.1. and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at www.colorado.gov/pacific/cdphe/air-permit-self- certification. (Regulation Number 3, Part B, Section III.G.2.) 3. 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 construction 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. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to -the Division as part of the self -certification process. (Regulation Number 3, Part B, Section III.E.) 5. Point 001: The following information shall be provided to the Division within fifteen (15) days of the latter of commencement of operation or issuance of this permit. • The amine unit manufacturer name, model number and serial number • The amine circulation pump manufacturer name and model number This information shall be included with the Notice of Startup submitted for the equipment. (Reference: Regulation Number 3, Part B, III.E.) 6. Point 002, 003, 008, 009: The following information shall be provided to the Division within fifteen (15) days of the latter of commencement of operation or issuance of this permit. • manufacturer • model number • serial number This information shall be included with the Notice of Startup submitted for the equipment. (Reference: Regulation Number 3, Part B, III.E.) 7. The operator shall retain the permit final authorization letter issued by the Division, after completion of self -certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 8. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) Monthly Limits: Facility Equipment ID AIRS Point Pounds per Month Emission Type PM2.5 PM,o SOX H25 NO. VOC CO A1/A2 001 ___ 951 68 5,894 Point H1/H2 002 747 747 68 --- 1,716 544 3,533 Point H3/H4 003 272 272 34 --- 628 204 1,308 Point ST 005 ___ ___ ___ ___ ___ 119 --- Point ICL0RADO Air Pollution Control Division Page 3 of 24 LT 006 --- --- --- --- --- 391 ___ Point FUG 007 --- --_ ___ --- 442 ___ Fugitive C1/C2 008 --- 3,691 --- 4,613 Point MSS 009 --- --- ___ _-_ ___ 374 --- Point CB 010 --- --- 170 --- Point RP 011 ___ ___ 815 ___ Fugitive 012 -__ ___ 34 _-- Point Note: Monthly limits are based on a 31 -day month. The owner or operator shall calculate monthly emissions based on the calendar month. Facility -wide emissions of each individual hazardous air pollutant shall not exceed 1,359 pounds per month. Facility -wide emissions of total hazardous air pollutants shall not exceed 3,398 pounds per month. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 PM,o SO, H25 NO, VOC CO A1/A2 001 --- --- 5.6 0.4 --- 34.7 --- Point H1/H2 002 4.4 4.4 0.4 --- 10.1 3.2 20.8 Point H3/H4 003 1.6 1.6 0.2 --- 3.7 1.2 7.7 Point ST 005 --- --- --- --- --- 0.7 --- Point LT 006 --- --- --- --- --- 2.3 --- Point FUG 007 --- --- --- --- --- 2.6 --- Fugitive C1/C2 008 --- --- --- --- 21.7 --- 27.2 Point MSS 009 --- --- --- --- --- 2.2 --- Point CB 010 --- --- --- --- --- 1.0 --- Point RP 011 --- --- --- --- --- 4.8 --- Fugitive 012 --- --- --- --- --- 0.2 --- Point Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. !COLORADO Air Pollution Control Division rtc qE H4;sC're,:�:rri a?ta`bct r1MOtt Page 4 of 24 Facility -wide emissions of each individual hazardous air pollutant shall not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. During the first twelve (12) months of operation, compliance with both the monthly and annual emission limitations is required. After the first twelve (12) months of operation, compliance with only the annual limitation is required. Compliance with the annual limits, for both criteria and hazardous air pollutants, 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 actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 9. Point 001: Compliance with the emission limits in this permit shall be demonstrated by running the ProMax model version 4.0.16071.0 or higher on a monthly basis using the most recent amine unit inlet extended sour gas analysis and recorded operational values, including: gas throughput, lean amine circulation rate, MDEA weight concentration in the lean amine stream, flash tank temperature and pressure, sour gas inlet temperature, and sour gas inlet pressure. Recorded operational values, except for gas throughput, shall be averaged on a monthly basis for input into the ProMax model and be provided to the Division upon request. 10. Point 007: The operator shall calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent gas and liquids analyses, as required in the Compliance Testing and Sampling section of this permit. The operator shall maintain records of the results of component counts and sampling events used to calculate actual emissions and the dates that these counts and events were completed. These records shall be provided to the Division upon request. 11. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled A1/A2 001 Routed to thermal oxidizer covered under point 123/9FA7/008. VOC and HAP ST 005 Enclosed Combustor VOC and HAP LT 006 Enclosed Combustor VOC and HAP FUG 007 Implementing LDAR program as specified in NSPS 0000a VOC and HAP PROCESS LIMITATIONS AND RECORDS 12. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) COLORADO UUn Ccnttstil Division Page 5 of 24 Process Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit Monthly Limit (31 days) Al/A2 001 Natural Gas Throughput 82,125 MMscf/unit 6,975 MMscf/unit H1/H2 002 Consumption of natural gas as fuel 526.3 MMscf/unit 44.7 MMscf/unit H3/H4 003 Consumption of natural gas as fuel 116.3 MMscf 9.9 MMscf ST 005 Stabilized condensate and water throughput 376,000 bbl 31,935 bbl LT 006 Condensate Loading 376,000 bbl 31,935 bbl C1/C2 008 Combined Combustion of supplemental fuel 349.0 MMscf 29.7 MMscf Combined Combustion of amine unit still vent and flash tank waste gas 3,464 MMscf 294.2 MMscf MSS 009 Number of Events 8 events 1 event CB 010 Number of Events 576 events 49 Events 012 Methanol Throughput 36,500 barrels 3,100 barrels The owner or operator shall monitor monthly process rates based on the calendar month. Point 001: The owner or operator shall monitor monthly process rates based on the calendar month. The volume of gas processed by each unit shall be measured by gas meter or by assuming the maximum design rate of each amine unit to be 225 MMscf/d. During the first twelve (12) months of operation, compliance with both the monthly and annual throughput limitations is required. After the first twelve (12) months of operation, compliance with only the annual limitation is required. Compliance with the annual throughput 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 throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. 13. Point 001: This point shall be limited to the maximum lean amine circulation rate of 750 gallons per minute total. The lean amine circulation rate shall be recorded daily in a log maintained on site and made available to the Division for inspection upon request. Amine circulation rate shall be monitored by one of the following methods: assuming maximum design pump rate, using amine flow meter(s), or recording strokes per minute and converting to circulation rate. (Reference: Regulation Number 3, Part B, II.A.4) 14. Point 001: On a weekly basis, the owner or operator shall monitor and record operational values including: flash tank temperature and pressure, MDEA weight concentration in the lean amine stream, and sour gas inlet temperature and pressure. These records shall be maintained for a period of five years. 15. Point 002, 003: The owner or operator shall continuously monitor and record the volumetric flow rate of natural gas combusted as fuel for each heater using an operational continuous flow meter at the inlet of each heater. The owner or operator shall use monthly throughput records to demonstrate compliance with the process limits contained in this permit and to calculate emissions as described in this permit. COLORADO .Air Pollution Control Division Page 6 of 24 16. Point 008: The owner or operator shall continuously monitor and record the volumetric flow rate of still vent and flash tank waste gas vented from the amine unit and routed to the thermal oxidizer using an operational continuous flow meter. The owner or operator shall use monthly throughput records to demonstrate compliance with the process limits contained in this permit and to calculate emissions as described in this permit. 17. Point 008: The owner or operator shall continuously monitor and record the volumetric flow rate of supplemental fuel combusted by the thermal oxidizer using an operational continuous flow meter. The owner or operator shall use monthly throughput records to demonstrate compliance with the process limits contained in this permit and to calculate emissions as described in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 18. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 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, III.D.2. The following requirements were determined to be RACT for this source: Facility Equipment AIRS RACT Pollutants ID Point Routing amine still vent and flash tank A1/A2 001 waste -gas to thermal oxidizer covered under point 123/9FA7/008. VOC H1/HZ 002 Natural gas as fuel, low NOX burners, good VOC, NOx H3/H4 003 combustion practices VOC, NOx ST 005 Enclosed Combustor VOC LT 006 Enclosed Combustor VOC FUG 007 LDAR as provided at 40 CFR Part 60 Subpart 0000a VOC 20. The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/4567/001) shall be marked on the subject equipment for ease of identification. (Regulation Number 3, Part B, Section III.E.) (State only enforceable) 21. 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. (Reference: Regulation Number 1, Section II.A.1. Ft 4.) 22. Point 001: The inlet gas stream to the amine unit shall have a total sulfurs concentration, including H2S, of less than or equal to 4.0 ppm. 23. Point 001, 008: No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. (Reference: Regulation Number 1, Section II.A.5.) 24. Point 002, 003: This source is subject to the Particulate Matter and Sulfur Dioxide Emission Regulations of Regulation 1 including, but not limited to, the following (Regulation 1, Section III.A.1 and VI.B.5. ): COLORADO Air Pollution Control Division Page 7 of 24 • No owner or operator shall cause or permit to be emitted into the atmosphere from any fuel -burning equipment, particulate matter in the flue gases which exceeds the following (Regulation 1, Section III.A.1): (i) For fuel burning equipment with designed heat inputs greater than 1x106 BTU per hour, but less than or equal to 500x106 BTU per hour, the following equation will be used to determine the allowable particulate emission limitation. PE=0.5(FI )-0.26 Where: PE = Particulate Emission in Pounds per million BTU heat input. Fl = Fuel Input in Million BTU per hour. • New sources of sulfur dioxide shall not emit or cause to be emitted sulfur dioxide in excess of the following process -specific limitations: (i) Limit emissions to not more than two (2) tons per day of sulfur dioxide. (Regulation 1 Section VI.B.5.a.) 25. Points 002, 003: This source is subject to the New Source Performance Standards requirements of Regulation 6, Part B including, but not limited to, the following (Regulation 6, Part B, Section II): • Standard for Particulate Matter - On and after the date on which the required performance test is completed, no owner or operator subject to the provisions of this regulation may discharge, or cause the discharge into the atmosphere of any particulate matter which is: (i) For fuel burning equipment generating greater than one million but less than 250 million Btu per hour heat input, the following equation will be used to determine the allowable particulate emission limitation: PE=0.5(FI )-0.26 Where: PE is the allowable particulate emission in pounds per million Btu heat input. Fl is the fuel input in million Btu per hour. If two or more units connect to any opening, the maximum allowable emission rate shall be the sum of the individual emission rates. (ii) Greater than 20 percent opacity. 26. Points 002, 003: This source is subject to the New Source Performance Standards requirements of Regulation Number 6, Part A Subpart Dc, Standards of Performance for Small Industrial - Commercial -Institutional Steam Generating Units including, but not limited to, the following: • 40 CFR, Part 60, Subpart A - General Provisions • 40 CFR 60.48c(a) The owner or operator of each affected facility shall submit notification of the date of construction or reconstruction and actual startup, as provided by §60.7 of this part. • 40 CFR Part 60.48c(g) The owner or operator of the facility shall record and maintain records of the amount of fuel combusted during each month. • 40 CFR Part 60.48c(i) Monthly records of fuel combusted required under the previous condition shall be maintained by the owner or operator of the facility for a period of two years following the date of such record. 27. Points 005, 006: The combustion device covered by this permit is subject to Regulation Number 7, Section XVII.B.2 General Provisions (State only enforceable). If a flare or other combustion device is used to control emissions of volatile organic compounds to comply with Section XVII, it shall be enclosed; have no visible emissions during normal operations, as defined under (COLORADO E Air Pollution Control Division DKwtmont r)t 1,1; „7E.W.fOrrl4On Page 8 of 24 Regulation Number 7, XVII.A.16; and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare or combustion device, or by other convenient means approved by the Division, determine whether it is operating properly. This flare must be equipped with an operational auto -igniter according to the following schedule: • All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto -igniter upon installation of the combustion device; • All combustion devices installed before May 1, 2014, must be equipped with an operational auto -igniter by or before May 1, 2016, or after the next combustion device planned shutdown, whichever comes first. 28. Points 006: This source is located in an ozone non -attainment or attainment -maintenance area and is subject to the Reasonably Available Control Technology (RACT) requirements of Regulation Number 3, Part B, III.D.2.a. Condensate loading to truck tanks shall be conducted by submerged fill. (Regulation Number 3, Part B, III.D.2.) 29. Points 006: The owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Regulation Number 3, Part B, III.E.): a) Hoses, couplings, and valves shall be maintained to prevent dripping, leaking, or other liquid or vapor loss during loading and unloading. b) All compartment hatches at the facility (including thief hatches) shall be closed and latched at all times when loading operations are not active, except for periods of maintenance, gauging, or safety of personnel and equipment. c) The owner or operator shall inspect onsite loading equipment during loading operations to monitor compliance with above conditions. The inspections shall occur at least monthly. Each inspection shall be documented in a log available to the Division on request. 30. Points 006: All hydrocarbon liquid loading operations, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. 31. Point 006: The owner or operator shall: Install and operate the vapor collection and return equipment to collect vapors during loading of tank compartments of outbound transport trucks. Include devices to prevent the release of vapor from vapor recovery hoses not in use. • Use operating procedures to ensure that hydrocarbon liquid cannot be transferred unless the vapor collection equipment is in use. • Operate all recovery and disposal equipment at a back -pressure less than the pressure relief valve setting of transport vehicles. 32. Point 007, 010: These sources are subject to Regulation Number 7, Section XII.G.1 (State only enforceable). For fugitive VOC emissions from leaking equipment, the leak detection and repair (LDAR) program as provided at 40 CFR Part 60, Subpart KKK (July 1, 2016) shall apply, regardless of the date of construction of the affected facility, unless subject to applicable LDAR program as provided at 40 CFR Part 60, Subparts OOOO or OOOOa (July 1, 2016). The operator shall comply with all applicable requirements of Section XII. 33. Point 007: This source is subject to Regulation Number 7, Section XII.C General Provisions (State only enforceable). All condensate collection, storage, processing and handling operations, :COLORADO Air Pollution; Control Division Page 9 of 24 regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. The operator shall comply with all applicable requirements of Section XII. 34. Point 007: This source is subject to Regulation No. 7, Section XII.G.1 (State only enforceable). For fugitive VOC emissions from leaking equipment, the leak detection and repair (LDAR) program as provided at 40 CFR Part 60, Subpart OOOO(July 1, 2017) shall apply, regardless of the date of construction of the affected facility, unless subject to applicable LDAR program as provided at 40 CFR Part 60, Subpart OOOOa (July 1, 2017). The operator shall comply with all applicable requirements of Section XII.G. • This facility is subject to 40 C.F.R. Part 60, Subpart OOOOa, and compliance with that rule shall satisfy the requirements of Regulation No. 7, Section XII.G.1. 35. Point 011: This source is subject to the applicable requirements of Regulation Number 7, Section VI.B.2. 36. Point 011: This source is subject to the New Source Performance Standards requirements of Regulation Number 6, Part A, Subpart Kb, Standards of Performance for Volatile Organic Liquid Storage Vessels for which construction, reconstruction or modification commenced after July 23, 1984, including, but not limited to, the following: • 40 CFR, Part 60, Subpart A - General Provisions • §60.112b - Standard for volatile organic compounds (VOC) o §60.112b(a) The owner or operator of each storage vessel with a....design capacity greater than or equal to 75 m3 but less than 151 m3 containing a VOL that, as stored, has a maximum true vapor pressure equal to or greater than 27.6 kPa but less than 76.6 kPa, shall equip each storage vessel with one of the following: ■ §60.112b(a)(3) A closed vent system and control device meeting the following specifications: • §60.112b(a)(3)(i) The closed vent system shall be designed to collect all VOC vapors and gases discharged from the storage vessel and operated with no detectable emissions as indicated by an instrument reading of less than 500 ppm above background and visual inspections, as determined in part 60, subpart VV, §60.485(b). • $60.112b(a)(3)(ii) The control device shall be designed and operated to reduce inlet VOC emissions by 95 percent or greater. If a flare is used as the control device, it shall meet the specifications described in the general control device requirements (S60.18) of the General Provisions. o §6O.113b - Testing and procedures • The owner or operator of each storage vessel as specified in §60.112b(a) shall meet the requirements of paragraph (a), (b), or (c) of this section. The applicable paragraph for a particular storage vessel depends on the control equipment installed to meet the requirements of §60.112b. ■ §60.113b(d) The owner or operator of each source that is equipped with a closed vent system and a flare to meet the requirements in §60.112b (a)(3) or (b)(2) shall meet the requirements as specified in the general control device requirements, §60.18 (e) and (f). o §60.115b - Reporting and recordkeeping requirements • The owner or operator of each storage vessel as specified in §60.112b(a) shall keep records and furnish reports as required by paragraphs (a), (b), or (c) of this section depending upon the control equipment installed to meet the COLORADO Air Pollution Control Division Page 10 of 24 requirements of §60.112b. The owner or operator shall keep copies of all reports and records required by this section, except for the record required by (c)(1), for at least 2 years. The record required by (c)(1) will be kept for the life of the control equipment. • §60.115b(d) After installing a closed vent system and flare to comply with §60.112b, the owner or operator shall meet the following requirements. • §60.115b(d)(1) A report containing the measurements required by §60.18(f) (1), (2), (3), (4), (5), and (6) shall be furnished to the Administrator as required by §60.8 of the General Provisions. This report shall be submitted within 6 months of the initial start-up date. • §60.115b(d)(2) Records shall be kept of all periods of operation during which the flare pilot flame is absent. • §60.115b(d)(3) Semiannual reports of all periods recorded under §60.115b(d)(2) in which the pilot flame was absent shall be furnished to the Administrator. o §60.116b - Monitoring of operations • §60.116b(a) The owner or operator shall keep copies of all records required by this section, except for the record required by paragraph (b) of this section, for at least 2 years. The record required by paragraph (b) of this section will be kept for the life of the source. • §60.116b(b) The owner or operator of each storage vessel as specified in §60.110b(a) shall keep readily accessible records showing the dimension of the storage vessel and an analysis showing the capacity of the storage vessel. • §60.116b(g) The owner or operator of each vessel equipped with a closed vent system and control device meeting the specification of §60.112b or with emissions reductions equipment as specified in 40 CFR 65.42(b)(4), (b)(5), (b)(6), or (c) is exempt from the requirements of paragraphs (c) and (d) of this section. 37. Point 012: This source is subject to Regulation Number 7, Section XII.G. The operator shall comply wi th all applicable requirements of Section XII. OPERATING Et MAINTENANCE REQUIREMENTS 38. Points 001, 002, 005, 006, 008: Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (0&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to the O&M plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 39. Points 001: The owner or operator shall complete an initial extended sour gas analysis from the inlet to the amine unit within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit. The owner or operator shall use this analysis to calculate actual emissions, as prescribed in the Emission Limitation and Records section of this permit, to verify initial compliance with the emission limits. The owner or operator shall submit the analysis and the emission calculation results to the Division as part of the self -certification process. (Reference: Regulation Number 3, Part B, Section III.E.) =COLORADO Aix Po€€ution Cant t Page 11 of 24 40. Points 001: Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, the operator shall complete an initial sample of the inlet gas to the amine unit to determine the concentration of hydrogen sulfide (H2S) in the gas stream. The owner or operator shall use the sample results to calculate actual emissions, as prescribed in the Emission Limitations and Records section of this permit, to verify initial compliance with the emission limits. The sample results shall also be monitored to demonstrate that this amine unit qualifies for the exemption from the Standards of Performance for Crude Oil and Natural Gas Facilities (§60.5365a(g)(3)) and to demonstrate compliance with the limit for total sulfurs concentration, including H2S. The owner or operator shall submit the analysis and the emission calculation results to the Division as part of the self -certification process. The testing required by the condition above may be used for this demonstration. 41. Points 001: A source initial compliance test shall be conducted on this emissions point to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with the emissions limits in this permit. The operator shall also demonstrate the thermal oxidizer (TO) achieves a minimum destruction efficiency of 99% for VOC. The operator shall measure and record, using EPA approved methods, VOC mass emission rates at the thermal oxidizer inlet and outlet to determine the destruction and removal efficiency of the thermal oxidizer (process models shall not be used to determine the flow rate or composition of waste gas (waste gas stream from the still vent and flash tank) sent to the thermal oxidizer for the purposes of this test). The natural gas throughput, lean amine recirculation rate, MDEA concentration, sulfur content of the sour gas entering the amine unit, and thermal oxidizer combustion chamber temperature shall be monitored and recorded during this test. This test shall be run with the thermal oxidizer operating at the minimum combustion chamber temperature of 1,400°F as indicated in the OEM plan for this point. 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. No compliance test shall be conducted without prior approval from the Division. Any compliance 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 Number 3, Part B., Section III.G.3) Sulfur Dioxide using EPA approved methods. Oxides of Nitrogen using EPA approved methods. Volatile Organic Compounds using EPA approved methods. Carbon Monoxide using EPA approved methods. 42. Point 002: A source initial compliance test shall be conducted on each of the heaters covered by this point to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with the emissions limits contained in this permit. 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. No compliance test shall be conducted without prior approval from the Division. Any compliance 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 Number 3, Part B., Section III.G.3) Oxides of Nitrogen using EPA approved methods. Carbon Monoxide using EPA approved methods. 43. Point 003: A source initial compliance test shall be conducted on this heater to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with the emissions limits contained in this permit. The test protocol must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual and shall be submitted COLORADO tution Control D vis on 4tx Page 12 of 24 to the Division for review and approval at least thirty (30) days prior to testing. No compliance test shall be conducted without prior approval from the Division. Any compliance 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 Number 3, Part B., Section III.G.3) Oxides of Nitrogen using EPA approved methods. Carbon Monoxide using EPA approved methods. Volatile Organic Compounds using EPA approved methods. 44. Points 005: The owner or operator shall demonstrate compliance with opacity standards, using EPA Reference Method 22, 40 C.F.R. Part 60, Appendix A, to determine the presence or absence of visible emissions. "Visible Emissions" means observations of smoke for any period or periods of duration greater than or equal to one minute in any fifteen minute period during normal operation. (Regulation Number 7, Sections XII.C, XVII.B.2. and XVII.A.16) 45. Point 005: The owner or operator shall complete site specific sampling including a compositional analysis of the pre -flash pressurized condensate routed to these storage tanks and a sales oil analysis to determine RVP and API gravity. Testing shall be in accordance with the guidance contained in PS Memo 05-01. Results of testing shall be used to determine a site -specific emissions factor using Division approved methods. Results of site -specific sampling and analysis shall be submitted to the Division as part of the self -certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. 46. Points 007: Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, the owner or operator shall complete the initial extended gas analysis of gas samples and extended natural gas liquids analysis of NGL (light oil service) that are representative of volatile organic compound (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. These extended gas and liquids analyses shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. The operator shall submit the results of the gas and liquids analyses and emission calculations to the Division as part of the self -certification process to ensure compliance with emissions limits. 47. Point 007: Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, the operator shall complete a hard count of components at the source and establish the number of components that are operated in "heavy liquid service", "condensate light liquid service", "NGL light liquid service", "water/oil service" and "gas service". The operator shall submit the results to the Division as part of the self -certification process to ensure compliance with emissions limits. 48. Points 008: The owner or operator shall demonstrate compliance with opacity standards using EPA Method 9 to measure opacity from the thermal oxidizer. (Regulation Number 1, Section II.A.1 and 5) 49. Point 011: The owner or operator shall complete an initial extended residue gas analysis within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit. The owner or operator shall use this analysis to calculate actual emissions, as prescribed in the Emission Limitation and Records section of this permit, to verify initial compliance with the emission limits. The owner or operator shall submit the analysis and the emission calculation results to the Division as part of the self -certification process. (Regulation Number 3, Part B, Section III.E.) Periodic Testing Requirements 50. Point 001: On a daily basis, the owner or operator shall conduct an inspection for presence or absence of smoke, and, if smoke is observed, the operator has the option to (1) immediately conduct repairs and maintain records of the specific repairs completed; (2) shut-in the equipment COLORADO Air ution Control Division Page 13 of 24 to investigate the cause of the smoke, conduct any necessary repairs, and maintain records of the specific repairs completed; or (3) conduct a formal EPA Method 9 observation to determine the opacity of the visible emissions, and conduct repairs if necessary. 51. Point 001: The owner or operator shalt sample the inlet gas to the amine unit on an annual basis to determine the concentration of hydrogen sulfide (H2S) in the gas stream. The sample results shall be monitored to demonstrate that this amine unit qualifies for the exemption from the Standards of Performance for Crude Oil and Natural Gas Facilities (§60.5365a(g)(3)). The testing required the following condition may be used for this demonstration. 52. Point 001: The owner or operator shall complete an extended sour gas analysis prior to the inlet of the amine unit on an annual basis. Results of the sour gas analysis shall be used to calculate emissions of criteria pollutants and hazardous air pollutants per this permit. 53. Point 007: On an annual basis, the owner or operator shall complete an extended gas analysis of gas samples and an extended natural gas liquids analysis of NGL (light oil service) that are representative of volatile organic compounds (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. These extended gas and liquids analyses shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. ADDITIONAL REQUIREMENTS 54. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOr) in ozone nonattainment areas emitting less than 100 tons of VOC or NO„ per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or 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. • Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. • 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 owner or operator is exercising an alternative -operating scenario and is installing a permanent replacement engine. COLORADO .Air Pollution Control Division Page 14 of 24 55. The requirements of Colorado Regulation No. 3, Part D shall apply at such time that any stationary source or modification becomes a major stationary source or major modification solely by virtue of a relaxation in any enforceable limitation that was established after August 7, 1980, on the capacity of the source or modification to otherwise emit a pollutant such as a restriction on hours of operation (Reference: Regulation Number 3, Part D, V.A.7.B). 56. MACT Subpart HH - National Emission Standards for Hazardous Air Pollutants From Oil and Natural Gas Production Facilities major stationary source requirements shall apply to this stationary source at any such time that this stationary source becomes major solely by virtue of a relaxation in any permit limitation and shall be subject to all appropriate applicable requirements of Subpart HH. (Reference: Regulation No. 8, Part E) 57. Points 002, 003: MACT DDDDD - National Emission Standards for Hazardous Air Pollutants for Major Sources: Industrial, Commercial, and Institutional Boilers and Process Heaters requirements shall apply to this source at any such time that this source becomes a major source of hazardous air pollutants (HAP) solely by virtue of a relaxation in any permit limitation and shall be subject to all appropriate applicable requirements of that Subpart on the date as stated in the rule as published in the Federal Register. (Reference: Regulation Number 8, Part E) GENERAL TERMS AND CONDITIONS 58. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation Number 3, Part B, Section II.B. upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 59. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7- 114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final authorization 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. Once self -certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self -Certify for Final Authorization section of this permit. 60. This permit is issued in reliance upon the accuracy and completeness of information supplied by the owner or operator 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 owner or operator or owner or operator's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 61. 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 25-7-114.5(7)(a), C.R.S. 62. 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 self -certification and final authorization 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 owner or operator, or the Division revokes a permit, the owner or operator of a source may request a hearing before the AQCC for review of the Division's action. COLORADO Air Po o Page 15 of 24 63. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 64. 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. By: Timothy Sharp Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Discovery DJ Services LLC Permit for a new natural gas processing facility located in the ozone non -attainment area. COLORADO Aix Pollution Collins Divssinaa 'Np... eM'Art! 1, jilt„'1,emtrt zrt rtr'tti"�it Page 16 of 24 Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator 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 complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division 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 next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/ pacific/cdphe/aqcc-regs 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) 001 Benzene 71432 81,198 991 Toluene 108883 63,177 747 Ethylbenzene 100414 5,476 65 Xylenes 1330207 15,417 173 n -Hexane 110543 5,685 261 002 Formaldehyde 50000 84 84 Benzene 71432 2 2 Toluene 108883 4 4 n -Hexane 110543 2010 2010 003 Formaldehyde 50000 31 31 Benzene 71432 1 1 Toluene 108883 1 1 n -Hexane 110543 742 742 005 Benzene 71432 180 9 Toluene 108883 98 5 Ethylbenzene 100414 8 0 COLORADO Pollution Control Dnnsion adr 3aex&Y S 'fzt+s rfsr; Page 17 of 24 Xylenes 1330207 16 1 n -Hexane 110543 2,947 147 006 Benzene 71432 156 8 n -Hexane 110543 1,358 68 007 Benzene 71432 267 25 Toluene 108883 475 44 Ethylbenzene 100414 122 11 Xylenes 1330207 279 25 n -Hexane 110543 3398 329 2,2,4- Trimethylpentane 540841 36 2 008 Formaldehyde 50000 40 40 Benzene 71432 1 1 Toluene 108883 2 2 n -Hexane 110543 958 958 009 Benzene 71432 12 12 Toluene 108883 20 20 Ethylbenzene 100414 5 5 Xylenes 1330207 11 11 n -Hexane 110543 167 167 010 Benzene 71432 91 91 Toluene 108883 156 156 Ethylbenzene 100414 37 37 Xylenes 1330207 85 85 n -Hexane 110543 1301 1301 2,2,4- Trimethylpentane 540841 1 1 011 Benzene 71432 476 476 Toluene 108883 810 810 Ethylbenzene 100414 195 195 Xylenes 1330207 442 442 n -Hexane 110543 6,775 6,775 012 Benzene 71432 0 0 n -Hexane 110543 304 304 COLORADO Air Pollution Control Division Page 18 of 24 Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year (lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 5) The emission levels contained in this permit are based on the following emission factors: Point 001: The emission levels contained in this permit are based on information provided in the application and the ProMax simulation. The emissions levels in this permit were buffered by multiplying the simulation results by a factor of 1.15. Controlled flash tank emissions are based on 99% control when emissions are routed to the thermal oxidizer. Controlled still vent emissions are based on 99% control efficiency when emissions are routed to the thermal oxidizer. The following table summarizes the control efficiency for each scenario: Control Scenario V0C Control Efficiency Still vent emissions routed to the thermal oxidizer 99% Flash tank emissions routed to the thermal oxidizer. S02 emissions resulting from the combustion of H2S in the waste gas are based on the 502 emission factor presented in table 5.3.1 in AP -42 Chapter 5.3. The S02 emission factor is as follows: CAS # Pollutant Uncontrolled Emission Factors lb/MMscf gas processed Source S02 0.674 AP -42 Chapter 5.3 Table 5.3.1 Note: The SO2 emission factor is based on the amine unit inlet H2S concentration of 4 ppm. Point 002: CAS # Pollutant Uncontrolled Emission Factors lb/MMscf Source PM10 8.590 Manufacturer PM2.5 8.590 Manufacturer N0X 19.933 Manufacturer CO 41.245 Manufacturer V0C 6.22 Manufacturer 110543 n -Hexane 1.99 AP -42 Chapter 1 Table 1.4-3 Note: Emissions factors are based on a rated heat input of 65 MMBtu/hr x (2) units, a higher heating value of 1,130 Btu/scf and 8,760 hours of operation per year. Point 003: CAS # Pollutant Uncontrolled Emission Factors lb/MMscf Source PM10 9.04 Manufacturer PM25 9.04 Manufacturer COLORADO. AizPoltution:Control Division CAS # Pollutant Uncontrolled Emission Factors lb/MMscf Source NO), 20.34 Manufacturer CO 41.81 Manufacturer VOC 6.78 Manufacturer 110543 n -Hexane 1.99 AP -42 Chapter 1 Table 1.4-3 Note: Emissions factors are based on a rated heat input of 25 MMBtu/hr x (2) units, a higher heating value of 1,130 Btu/scf and 8,760 hours of operation per year. Point 005: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Source VOC 7.00x1O2 Site specific 110543 n -Hexane 8.00x10-3 Site specific Note: The controlled emissions factors for this point are based on the enclosed flare control efficiency of 95%. Point 006: Pollutant CAS # Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source VOC 2.36x10-1 4.72x10-3 CDPHE PS Memo 14-02 n -Hexane 110543 3.6x1O3 7.2x10-5 CDPHE PS Memo 14-02 Note: Controlled emission factors are based on the enclosed flare efficiency of 95% and a collection efficiency of 100%. Point 007: This facility is subject to 40 CFR, Part 60, Subpart 0000a — Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction Commenced After September 18, 2015 (Effective August 2, 2016). This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. The emission control percentages for fugitive emission leaks contained in this permit are granted on the basis of implementation and ongoing compliance with an LDAR program meeting the requirements of 40 CFR, Part 60, Subpart OOOOa. In the event that this facility becomes a major source of hazardous air pollutants (HAPs), this source will be subject to the requirements of 40 CFR Part 63, subpart HH, for fugitive equipment leaks at facilities not subject to 4O CFR Part 60, Subpart OOOO, including, but not limited to, S 63.769 (a) - (c). Component Gas Service Heavy Oil Condensate (Light Oil) NGL (Light Oil) Water/Oil Service Connectors 1500 30 100 100 0 Flanges 600 400 200 200 0 Open-ended Lines 0 0 0 0 0 COLORADO Air Pollution Control Z3zvisaan Awl -mental I^V.:7= Page 20 of 24 Pump Seals 0 16 4 4 0 Valves 250 22 250 250 0 Other* 0 0 0 0 0 VOC Content (wt. fraction) 3.36E-01 1.00E+00 1.00E+00 5.72E-01 1.00E+00 Benzene Content (wt. fraction) 9.11E-04 0.00E+00 1.41 E-02 2.44E-03 0.00E+00 Toluene Content (wt. fraction) 1.56E-03 0.00E+00 2.79E-02 1.69E-03 0.00E+00 Ethylbenzene (wt. fraction) 3.74E-04 0.00E+00 7.25E-03 4.39E-04 0.00E+00 Xylenes Content (wt. fraction) 8.48E-04 0.00E+00 1.64E-02 1.15E-03 0.00E+00 n -Hexane Content (wt. fraction) 1.30E-02 0.00E+00 2.00E-01 6.72E-03 0.00E+00 2,2,4- Trimethylpentane Content (wt. fraction) 1.03E-05 0.00E+00 1.37E-04 2.41 E-03 0.00E+00 *Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms, hatches, instrument meters, polish rods and vents TOC Emission Factors (kg/hr-component): Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 2.0E-04 7.5E-06 2.1E-04 1.1E-04 Flanges 3.9E-04 3.9E-07 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 1.4E-04 1.4E-03 2.5E-04 Pump Seals 2.4E-03 NA 1.3E-02 2.4E-05 Valves 4.5E-03 8.4E-06 2.5E-03 9.8E-05 Other 8.8E-03 3.2E-05 7.5E-03 1.4E-02 Source: EPA -453/R95-017 Table 2-4 Compliance with emissions limits in this permit will be demonstrated by using the TOC emission factors listed in the table above with representative component counts, multiplied by the VOC content from the most recent gas and liquids analyses. Control Percentages Granted for Compliance with OOOOa, LDAR Program: Component Gas Service Heavy Oil Light Oil Connectors 81% 81% 81% Flanges 81% 81% 81% Pump Seals - - - 88% Valves 96% - 95% €COLORADO Air Pollution Control Division .an_nth.; UCHeRIMb Erv.rr mc st Page 21 of 24 Point 008: Total actual combustion emissions are based on the sum of the emissions calculated for the combustion of supplemental fuel (process 01) and the combustion of amine unit still vent and flash tank waste gas (process 02). Process 01: CAS # Pollutant Uncontrolled Emission Factors lb/MMscf Source N0X 90.4 Manufacturer CO 113 Manufacturer n -Hexane 2.0 AP -42 Chapter 1 Table 1.4-3 Note: The combustion emissions factors are based on a higher heating value of 1,130 Btu/scf. Actual emissions are calculated by multiplying the emission factors in the table above by the total supplemental fuel combusted by the thermal oxidizer as measured by flow meter. Process 02: CAS # Pollutant Uncontrolled Emission Factors Ib/MMscf Source N0X 0.72 Manufacturer CO 0.90 Manufacturer n -Hexane 1.99x10-2 AP 42 Chapter 1 Table 1.4-3 Note: The combustion emissions factors are based on an average higher heating value of 8.97 Btu/scf. Actual emissions are calculated by multiplying the emission factors in the table above by the total amine unit flash tank and still vent waste gas combusted by the thermal oxidizer as measured by flow meter. Point 011: CAS # Weight Fraction of Gas Pollutant Uncontrolled Emission Factors (lb/MMscf) Source 0.0184 VOC 816.53 Gas Analysis 110543 0.013 n -Hexane 578.191 Mass Balance Note: The VOC content is based on an engineering estimate of residue gas composition and HAP mass fractions from the inlet gas composition which is based on an average of five representative samples. Emissions are based on a rod packing vent rate of 50 scf/hr for phase I residue compressors and 72 scf/hr for phase II electric residue compressors and the weight fraction of gas indicated in the table above. Point 012: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Source V0C 8.32x10-3 ProMax 110543 n -Hexane 8.40x10-3 ProMax 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN !COLORADO Aar Pollution Control Division L b.artnlo ..Ot ',I:ilia': r,r•�?: & Page 22 of 24 expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This permit fulfills the requirement to hold a valid permit reflecting the storage tank and associated control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(A) when applicable. 8) Points 007: These sources are subject to 40 CFR, Part 60, Subpart 0000a —Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction Commenced After September 18, 2015 (See June 3, 2016 Federal Register posting - effective August 02, 2016). 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: https://www.gpo.gov/fdsys/pkg/FR-2016-06- 03/pdf/2016-11971.pdf 9) Point 001: This amine unit is subject to 40 CFR, Part 60, Subpart 0000a —Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction Commenced After September 18, 2015 (See June 3, 2016 Federal Register posting - effective August 02, 2016). 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: https://www.gpo.gov/fdsys/pkg/FR-2016-06- 03/pdf/2016-11971.pdf 10) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: V0C, Benzene, Toluene, n -Hexane, H2S and Total HAPs NANSR Synthetic Minor Source of: V0C PSD Synthetic Minor Source: V0C MACT HH Major Source Requirements: Not Applicable Area Source Requirements: Applicable MACT ZZZZ Major Source Requirements: Not Applicable Area Source Requirements: Applicable MACT DDDDD Not Applicable NSPS KKK Not Applicable NSPS 0000 Not Applicable NSPS 0000a Applicable to point 007. Recordkeeping and reporting requirements for point 001. NSPS Dc Applicable to points 002, 003 NSPS LLL Not Applicable NSPS JJJJ Not Applicable NSPS Kb Applicable to point 012 COLORADO Air Pollution Control Diviskald '.Jt"Ort ,2 Ptfi:Y; f nntC'i fr Fivgnrme,T, Page 23 of 24 11) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A - Subpart KKKK NSPS Part 60, Appendixes Appendix A - Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A - Subpart Z MACT 63.600-63.1199 Subpart AA - Subpart DDD MACT 63.1200-63.1439 Subpart EEE - Subpart PPP MACT 63.1440-63.6175 Subpart QQQ - Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ - Subpart MMMMM MACT 63.8980 -End Subpart NNNNN - Subpart XXXXXX COLORADO totior, Control Division Page 24 of 24 g,p. -s4d - Nee) /46).e•-14uvk i.k 1-e J {s fa -+p) (7-5-117) 41401 ? ?ore; kiN d AR sections of this APEN and application must be completed for both new and existing. f,�cilities clung APENI. updates. An application with missing information may be determined incomplete and may be returned or resuhiin longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for Amine Sweetening Units only. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. Amine Sweetening Unit - Form APCD-206 Air Pollutant Emission Notice (APEN) and Application for Construction Permit This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportal>!e change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: W O2 19 AIRS ID Number: ( Z3 /' PM./ a O I [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: Al [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Namel: Discovery DJ Services LLC Site Name: Discovery Kiowa Gas Plant Site Location: Section 29, T1 N, R63W Mailing clulade Zip Code) Address: de (ing ac 3601 Stagecoach Road, Ste. 202 Longmont, CO 80504 E Mail Address': mnorton@discoverymidstream.com Site Location County: Weld NAICS or SIC Code: 213112 Permit Contact: Matthew Norton Phone Number: (817) 455-5799 'Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. 36 261 Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 1 I A®I COLORADO mat« Public Heat.b emuona+nv .41 Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action ❑✓ NEW permit OR newly -reported emission source -OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit 0 Transfer of ownership3 ❑ Other (describe below) OR APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - DI Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info ft Notes: 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: 440 MMSCFD Amine Treater Facility equipment Identification: For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Al / / 10 /1 / 2018 Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day Will this equipment be operated in any NAAQS nonattainment area Does this facility have a design capacity less than 2 long tons/day of H2S in the acid gas? Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 days/week Yes Yes 0 weeks/year No No 21 COLORADO Pulatic Pea. Enx4 ransx Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Dehydration Unit Equipment Information Manufacturer: TBD Model : TBD Serial Number: TBD Reboiler Rating: Amine Type: 25.71 MMBtu/hr Absorber Column Stages: 21 ❑ MEA Pump Make and Model: TBD ❑ DEA ❑ TEA stages L MDEA ❑ DGA # of pumps: 2 Sweet Gas Throughput4: Design Capacity: 440 MMSCF/day Requested: 160,600 MMSCF/year Actual: MMSCF/year 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth Inlet Gas: Pressure: 1,014.5 Psig Temperature: 65.64 ° F Rich Amine Feed: Pressure: 1,017.3 Psia Flowrate: Gal/min Temperature: 121 °F Lean Amine Stream: Pressure: 1,012.3 psia Temperature: Flowrate: 500 Gal/min Wt. % amine: Mole Loading CO2 Mote loading H2S 2,48E-04 mot% 121.57 50 °F 1.8291 - mom Sour Gas Input: Pressure: 1,026.8 psia Temperature: 65.64 °F Flowrate: 440 MMSCF/Day NGL Input: Pressure: Flowrate: psia Gal/min Temperature: °F Flash Tank: ❑ No Flash Tank Pressure: 202.3 psia Temperature: 285.8 °F Additional Required Information: Attach a Process Flow Diagram ❑� Attach the simulation model inputs Et emission report ❑r Attach composition reports for the rich amine feed, sour gas feed, NGL feed, Et outlet stream (emissions) El Attach the extended gas analysis (including BMX Et n -Hexane, H2S, CO2, temperature, and pressure) Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 31 4 co C COLORADO oey ®.md r°bil. Heal. b EnnYmurau Permit Number: AIRS ID Number: / [Leave blank unless APCD has already assigned a permit # and AIRS ID] 't= Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 545330.22 E, 4429974.51 N t } �' Operator ac Stack ID No a� ischarge Hugh ound L�eve : � Temp �) �� = Flow � CFM t eloc�ty� ) z t sec !�Above A1 TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) El Upward 0 Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Upward with obstructing raincap p Circular Interior stack diameter (inches): TBD 0 Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 COLORADO 4 Departmental Pubilc Hebb Fm1'nnnenne Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Control Device Information VRU: Used for control of: Flash Gas Size: TBD Make/Model: TBD Requested Control Efficiency 95 % VRU Downtime or Bypassed 10 ❑ Combustion Device: Used for control of: Flash (secondary) and Acid Gas Rating: 30.10 Type: Oxidizer Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: 1,400 MMBtu/hr Make/Model: TBD 99 99 Waste Gas Heat Content 180.38 Btu/scf scf Constant Pilot Light: El Yes ✓❑ No Pilot burner Rating MMBtu/hr El Other: Used for control of: Description: Control Efficiency Requested Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 COLORADO 5 141±7 I°'4"®man.w. w,.usu.w.,e.m PM PM Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 -Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑r Yes ❑ No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): Control Equipment Description Overall Requested Control Efficiency (% reduction in`'emissions) SOx H2S NOX VOC VRU and Oxidizer 95% VRU, 99% Oxidizer CO HAPs VRU and Oxidizer 95% VRU, 99% Oxidizer Other: From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Criteria Pollutant Emissions'invento Uncontrolled Emission Factor Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) Uncontrolled (Tons/year) Controlled5 (Tons/year) Requested Annual Permit' Emission Limit(s)4 *y „ Uncontrolled (Tons/year) " Controlled `! (Tons/year) SOx 0.417 Ib/MuISCF AP -42 30.47 15.23 H2S 0.11 lb/MMSCF ProMax 9.19 0.09 NOX VOC 4.41 Ib/MMSCF ProMax 353.73 14.66 CO 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 COLORADO 6I �me,� i WLL1SS EneLmmeN Benzene Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 (continued) Non-Cnteria! Reportable Pollutant Emissions Inventory Chemical Abstract Service (CAS) Number Uncontrolled Emission ,Factor Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) Uncontrolled (lbs/year) 71432 0.23 Ib/MMSCF ProMax ontrolled5. (Ibs/year) Toluene 108883 0.18 Ib/MMSCF ProMax Ethylbenzene 100414 0.02 Ib/MMSCF ProMax Xylenes 1330207 0.05 Ib/MMSCF ProMax n -Hexane 110543 0.02 Ib/MMSCF ProMax 2,2,4- Trimethylpentane 540841 0.00 Ib/MMSCF ProMax Other: 5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. - T. Signature of Legally Auth ed Person (not a vendor or consultant) 3-c,-rg Date Matthew T. Berghorn, P.E. VP - Engineering and Construction Name (please print) Title Check the appropriate box to request a copy of the: O Draft permit prior to issuance ✓❑ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 7 COLORADO D.p.nm.md ruak Amine Sweetening Unit - Form APCD-206 Air iPollutant Emission YNoyticce]((AYPYtF (APEN) and Application for Construction Permit i. All sections of this APEN and application must be completed for both new and existing facilities, incl updates. An application with missing information may be determined incomplete and may be returned or re longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for Amine Sweetening Units only. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-2OO1 is available if the specialty APEN options will not satisfy your reporting needs- A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.Jovicdohe accd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part. A, II.C. for revised APEN requirements. Permit Number: 18WE0274 Company equipment Identification: AIRS ID Number: `a3 /CO(k/ v0\ Al/A2 Section 1 - Administrative Information Company Name': Discovery DJ Services LLC Site Name: Discovery Kiowa Gas Plant Site Location: Section 29, Ti N, R63W Mailing Address: (Include r . ccuQ) 3601 Stagecoach Road, Ste. 202 Longmont, CO 80504 E -Mail Address'-: mnorton@discoverymidstream.com Site Location County: Weld NAICS or SIC Code: 213112 Permit Contact: Matthew Norton Phone Number: (817) 455-5799 1Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes wilt require additional paperwork 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. �w� 0=0 CC 00 Permit Number: 18WEO274 AIRS ID Number: Section 2- Requested Action ❑ NEW permit OR newly -reported emission source -Oa- l1 MODIFICATION to existing permit (check each box below that appies) O Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit O Transfer of ownership' ❑ Other (describe below) OR - • ADEN submittal for update only (Please note blank APENs will not be accepted) - ADDmONAL PERMIT ACTIONS - • Limit Hazardous Mr Pollutants (I-lAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info a Notes: 3 For transfer of ownership, a completed Transfer of Ownership Certification Form {Form. A?CD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: 2 x 225 MMSCF© Amine Treating Units Facility equipment Identification: For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Al/A2 10 /1 /2018 ❑ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day Will this equipment be operated in any NAAQS nonattainment area Does this facility have a design capacity less than 2 long tons/day of H2S in the acid gas? days/week weeks/year Yes ❑ No 0 Yes No CO^ G4a0u' Permit Number: 18WE0274 AIRS ID Number: I Section 4 - Dehydration Unit Equipment Information Manufacturer: TBD Reboiler Rating: 40 Amine Type: Mode( : "TBD Serial Number: TBD MMEtulhr Absorber Column Stages; 21 ❑ MEA ❑ DEA Pump Make and Model: TBD El TEA 0 MDEA stages ❑ DGA of pumps: 2 Sweet Gas Throughput': • Design Capacity: 225 MMSCF/ day Requested: 82,12' MA SCFiyear Actual: MMSCF/year 1. Requested values wilt become permit limitations_ Requested limit(s) should consider future process growth Inlet Gas: Pressure: 000 psig , Temperature: 67 Rich Amine Feed: Pressure: 1,007.3 psia Flowrate: Gal/min Temperature: 120 Lean Amine Stream: Pressure: 1,007.3 psia Temperature: 120 Flowrate: 750 Gal/min Wt. amine: 50 Mote loading H_S 4.aE-04 rpathrol Mote Loading Cng 0.018159 mol/mol Sour Gas Input: Pressure: 1,012.3 psia Flowrate: 225 MMSCF/Day Temperature: 67 NGL Input: Pressure: Flowrate: psia Gat/ min Temperature: Flash Tank: ❑ No Flash Tank Pressure: 72.3 psia Temperature: 123 Additional Required Information: ❑ Attach a Process Flow Diagram 0 Attach the simulation model inputs a emission report ❑ Attach composition reports for the rich amine feed, sour gas feed, NGL feed, E outlet stream {emissions) 0 Attach the extended gas analysis (including BTEX ti n -Hexane, H25. COz, temperature, and pressure) e Permit Number: 18WE0274 MRS ID Number: I I Section 5 - Stack information 545339,22 E, 4429974.51 N tc r. i sc ar He ht e emu act FeSt) Flow Rate Velod Al/A2 TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) QQ Upward O Horizontal Downward O Other (describe): Upward with obstructing raincap Indicate the stack opening and size: (check one) Q Circular Interior stack diameter (inches): TBD O Square/rectangle Interior stack width (inches): interior stack depth (inches): Other (describe): Permit Number: 18WE0274 AIRS ID Number: / / ion 6 - Control Device Information ❑ VRU: Used for control of: Size: Requested Control Efficiency VRU Downtime or Bypassed Make./Model: ❑ Combustion Device: Used for control of: Flash and Acid Gas Rating: 64.54 total MMBtu/hr Type: Two Thermal Oxuliier Make/Model: TBD Requested Control Efficiency: 99 Manufacturer Guaranteed Control Efficiency 99 Minimum Temperature: 1,400 Waste Gas Heat Content 95.26 Btulscf Constant Pilot Light: Q Yes ❑ No Pilot burner Rating MMStu/hr • Other: Used for control of: Description: Control Efficiency Requested a PM Permit Number: 18WE0274 AIRS ID Number: J Section 7 -Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? 0 Yes © No If yes, please describe the control equipment AND state the overall control efficiency i% reduction): verall Requested Conti Efficiency rrriuctio in ernissionv PM SO< H25 V0C Two Tnermal. Oxidizers 99% CO RAPS Two Thermal Oxidizers 99% Other: From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Criteria Pollutant €missions invertte Uncontrolled Emission Factor Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) Uncontrolled- " controlleds (Toros/year) (Tons/year) RequestedAnnual Per Emission Limit(s)4 U ncontrc (isslye Controlled (Tans/year) S0n 1.20 iSCF AP -42 49.20 4.92 H25 • 0.91 ib/MMSCF ProMax 37,50 0.38 NO; V0C 20.23 Ib/MMSCF ProMax 830.80 34.66 CO Requested values will become permit limitations. Requested limitisi should consider future process growth. 'Annual emission fees will be based on actual controlled emissions reported_ If source has not yet started operating, leave blank. Benzene Permit Number: 18WE0274 AIRS ID Number: / Section 7 (continued) n -Criteria Reportabl Invent3 Uncontr Emission Factor Emission Factor! Units Emission Factor Source (AF -4Z, Mfg, Uncontrolled etc) (tbs/yesrr) ontrolleds (lbs/yeer,i Toluene 71432 3 0,99 0.77 IbiMMSCF ProMax ib/MMSCFi ProMax Ethytbenzene 100414 0.07 Ib/MMSCF ProMax Xytenes 1330207 0.19 ib/MMSCF ProMax n -Hexane 110543 0.07 Ib/MMSCF ProMax 2,2,4- Trirrethylpentane 540841 1,0E-05 Ib/MMSCF ProMax Other: 'annual emission fees wi.l be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. /1//t_ Signature of Legally Authorizer Person (not a vendor or consultant) Matthew T. Bergharn, P.E. Ts -ID - re5' Date VP Engineering and Construction Name (please print) Title Check the appropriate box to request a copy of the: Draft permit prior to issuance Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment. Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303)692-3148 Or visit the APCD website at: https: //www.colorado.gov /cdphei apcd Amine Sweetening Unit - Form APCD-206 Air Pollutant Emission Notice (APEN) and Application for Construction Permit ,1N15Ni3 All sections of this APEN and application must be completed for both new and existing facilities, Ir1Clu mg APEN updates. An application with missing information may be determined incomplete and may be returnedr result longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for Amine Sweetening Units only. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase., increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 18WE0274 AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit 4' and AIRS ID] Company equipment Identification: Al/A2 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Site Name: Discovery DJ Services LLC Discovery Kiowa Gas Plant Site Location: Section 29, T1 N, R63W Mailing Address: (Include Zip Code) 3601 Stagecoach Road, Ste. 202 Longmont, CO 80504 E -Mail Address'-: mnorton@discoverymidstream.com Site Location County: Weld NAICS or SIC Code: 213112 Permit Contact: Matthew Norton Phone Number: (817) 455-5799 'Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 1 4Fi7 �Y. COLORADO ul. 4 Erty , `, Permit Number: 18WE0274 AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action ❑ NEW permit OR newly -reported emission source - OR - Q MODIFICATION to existing permit (check each box below that applies) • Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership' ❑ Other (describe below) -OR- ❑ APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - • Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info & Notes: 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: 2 x 225 MMSCFD Amine Treating Units Facility equipment Identification: For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Al /A2 / / 10 /1 /2018 ❑✓ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day Will this equipment be operated in any NAAQS nonattainment area Does this facility have a design capacity less than 2 long tons/day of H25 in the acid gas? Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 days/week Yes Yes weeks/year No No ®COLORADO Permit Number: 18WE0274 AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Dehydration Unit Equipment Information Manufacturer: TBD Model : TBD Serial Number: TBD Reboiler Rating: 40 Amine Type: ❑ MEA Pump Make and Model: TBD MMBtu/hr Absorber Column Stages: 21 ❑ DEA ❑ TEA stages E MDEA ❑ DGA # of pumps: 2 Sweet Gas Throughput4: Design Capacity: Requested: 225 MMSCF/day 82,125 MMSCF/year Actual: MMSCF/year 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth Inlet Gas: Pressure: 1,000 psig Temperature: 67 °F Rich Amine Feed: Pressure: 1,007.3 Psia Flowrate: Gal/min Temperature: 120 °F Lean Amine Stream: Pressure: Flowrate: Mole loading HIS 1,007.3 Psia 750 Gal/min Temperature: Wt. % amine: Mole Loading CO2 120 50 °F Sour Gas Input: Pressure: 1,012.3 Psia Temperature: 67 °F Flowrate: MMSCF/Day NGL Input: Pressure: Flowrate: psia Gal/min Temperature: °F Flash Tank: ❑ No Flash Tank Pressure: 72.3 psia Temperature: 123 °F Additional Required Information: O Attach a Process Flow Diagram E Attach the simulation model inputs & emission report ❑ Attach composition reports for the rich amine feed, sour gas feed, NGL feed, Et outlet stream (emissions) ❑ Attach the extended gas analysis (including BTEX & n -Hexane, H2S, CO2, temperature, and pressure) Form APCD-206 - Amine Sweetening UnitAPEN - Revision 04/2017 3 AY COLORADO HuiN S Erv�cnm°.:, Permit Number: 1 8WE0274 AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 545330.22 E, 4429974.51 N F. Operator Stack ID No xFeet)S .4 - Discharge Height s Above Grourf l a Temp #1 �p � ,� ate: Flow Rate g . CF ) ti 4s e octtjr •. sec Al/A2 TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) O Upward ❑ Horizontal El Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Upward with obstructing raincap ❑ Circular Interior stack diameter (inches): TBD ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 ��.COLORADO 4 � µ�.�.w Permit Number: 18WE0274 AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Control Device Information ❑ VRU: Used for control of: Size: Make/Model: Requested Control Efficiency VRU Downtime or Bypassed % ❑ Combustion Device: Used for control of: Flash,and Acid Gas Rating: 64.54 total MMBtu/hr Type: Two Thermal Oxidizers Make/Model: TBD Requested Control Efficiency: 99 Manufacturer Guaranteed Control Efficiency 99 Minimum Temperature: 1,400 Waste Gas Heat Content 95.26 Btu/scf Constant Pilot Light: ❑✓ Yes ❑ No Pilot burner Rating MMBtu/hr ❑ Other: Used for control of: Description: Control Efficiency Requested 0/0 Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 5 I COLORADO Ertri.aroarl PM Permit Number: 18W E0274 AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 -Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑✓ Yes ❑ No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): PM SOX H2S NO. VOC Two Thermal Oxidizers 99% CO HAPs Two Thermal Oxidizers 99% Other: From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Criteria PoltutantEmissions=Inventor Uncontrolled Emission Factor ' Emission Factor Units Emission - Factor Source -_ (AP -42, Mfg. etc) ualy Annual- Emissions fncontrolle0 `(Toffs/year) , Incontrolled (Tonsfyear) , Controlled5 (Taos/year) Controlled (Tons/year) SOX 0.67 lb/MMSCF AP -42 55.35 5.54 H2S 0.46 lb/MMSCF Pro Max 37.50 0.38 NO. VOC 10.12 lb/MMSCF ProMax 830.80 34.66 CO 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 AY COLORADO 6 I =n;'�n, Benzene Permit Number: 18WE0274 AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 (continued) Non -Criteria Reportable Pollutant _Emissions litvento Chemical Abstract Service (CAS) Number Uncontro• lled Emission Factor . Emission' Factor'', Units ," mission actor urce 2. Mfg ctual Annual Emissions ncontrolled (Ibsrar)'` 71432 0.49 lb/MMSCF ProMax Toluene 108883 0.38 ib/MMSCF ProMax Ethylbenzene 100414 0.03 lb/MMSCF ProMax Xylenes 1330207 0.09 Ib/MMSCF ProMax n -Hexane 110543 0.03 Ib/MMSCF ProMax 2,2,4- Trimethylpentane 540841 5.15E-06 Ib/MMSCF ProMax Other: 5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. Signature of Legally Authorized Person (not a vendor or consultant) Date Matthew T. Berghorn, P.E. VP - Engineering and Construction Name (please print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance ❑� Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 Augigy,cO1.ORADO 7 IDelDartaarst Mai licaa. .v,r, Amine Sweetening Unit - Form APCD-206 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existin updates. An application with missing information may be determined incomplete and may b longer application processing times. You may be charged an additional APEN fee if the APEN is fil incorrectly, or is missing information and requires re -submittal. This APEN is to be used for Amine Sweetening Units only. if your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms canbe found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part. A, II.G. for revised APEN requirements. Permit Number: 18WE0274 AIRS ID Number: 1 )1 l 6O1/ 00 [Leave blank unless APCD has already assigned a permit tf and AIRS ID] Company equipment Identification: Al /A2. [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Discovery DJ Services. LLC Site Name: Discovery Keenesburg Gas Plant Site Location: Section 17, T2N, R63W Mailing Address: (Include Zip Code) 3601 Stagecoach Road, Ste. 202 Longmont, CO 80504 E -Mail Address': mnorton@discoverymidstream.com Site Location County: Weld NAICS or SIC Code: 213112 Permit Contact: Matthew Norton Phone Number: (817) 455-5799 'Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name thatwill appear on all documents issued by the APCD. Any changes will require additional paperwork. 2. Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 tCI ORADO r,,, 1= Permit. Number: 18WE0274 AIRS ID Number:. / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action ❑ NEW permit OR newly -reported emission source - OR - O MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit O Transfer of ownership3 0 Other (describe below) OR - • APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional info £t Notes: Updates to reflect new plant name, change in location. 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 General information General description of equipment and purpose: 2 x 225 MMSCFD Amine Treating Units Facility equipment Identification: Al /A2 For existing sources, operation began on: / / For new or reconstructed sources, the projected start-up date is: 10 /1 / 2018 0 Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day Will this equipment be operated in any NAAQ5 nonattainment area Does this facility have a design capacity less than 2 long. tons/day of H25 in the acid gas? days/week Yes Yes O Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 2 I A weeks/year No No COLORADO if.ri} b EA,cnrArn: Permit Number: 181NE0274 AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Dehydration Unit Equipment Information Manufacturer: TBD Model : TBD Serial Number: TBD Reboiler Rating: 65 Amine Type: _ MEA Pump Make and Model: TBD MMBtu/hr Absorber Column Stages: 21 stages O DEA ❑ TEA O MDEA ❑ DGA # of pumps: 2 Sweet Gas Throughput4: Design Capacity: 225 MMSCF/day Requested: 82,125 MMSCF/year Actual: MMSCF/year 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth Inlet Gas: Pressure: 1,000 psig Temperature: 67 °F Rich Amine Feed: Pressure: 1,007.3 Psia Flowrate:. Gal/min Temperature: 120 °F Lean Amine. Stream: Mole loading H2S Pressure: 1,007.3 psis Temperature: Flowrate: 750 GaUmin Wt. % amine:. Mole Loading CO2 120 50 °F Sour Gas Input: Pressure: 1,012.3 Psia Temperature: 67 -F Flowrate: MMSCF/Day NGL Input: Pressure: Flowrate: psia GaUmin Temperature: °F Flash Tank: 0 No Flash Tank Pressure: 72.3 psia Temperature: 123 °F Additional Required Information:. 2 Attach a Process Flow Diagram Attach the simulation model inputs Et emission report Attach composition reports for the rich amine feed, sour gas feed, NGL feed, Et outlet stream (emissions) Attach the extended gas analysis (including BTEX Et n -Hexane, HZS, CO2, temperature, and pressure) Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 3 IA COLORADO Wpu:ewn;°1 itu.^5Y [nr�,n r..m Permit Number: 1.8WE0274 AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 545686.83 E, 4443647.11 N operator Stack ID No Discharge Height Above Ground Level (Feet) Temp ( F) Flow Rate (4cpri Velocity (ft/sec) Al/A2 TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) ❑✓ Upward 0 Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) 0 Upward with obstructing raincap 0 Circular Interior stack diameter (inches): TBD 0 Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): to Co flACIO Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 4 I Permit Number: 18WE0274 AIRS ID Number: / [Leave blank unless APCD has already assigned a permit f and AIRS ID] Section 6 - Control Device Information ❑ VRU: Used for control of: Size: Make/Model: Requested Control Efficiency VRU Downtime or Bypassed ❑ Combustion Device: Used for control of: Flash and Acid Gas Rating: 64.54 total MMBtu/hr Type: Two Thermal Oxidizers Make/Model: TBD Requested Control Efficiency: 99 Manufacturer Guaranteed Control Efficiency 99 % Minimum Temperature: 1,400 Waste Gas -Heat Content 95.26 Btu/scf Constant Pilot Light: ❑✓ Yes 0 No Pilot burner Rating MMBtu/hr 0 Other: Used for -control of: Description: Control Efficiency Requested Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 5 I A COLORADO Permit Number: 18WE0274 AIRS ID Number: I [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 -Emissions Inventory information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? Yes ❑ No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) PM SOX H2S NOX VOC Two Thermal Oxidizers 99% CO HAPs Two Thermal Oxidizers 99% Other: From what year is the following reported actualannual emissions data? Use the following table to report the criteria pollutant emissions from source:. (Use the data reported in Sections 4 and 6 to calculate these emissions.) Criteria Pollutant Emissions Inventory Pollutant Uncontrolled Emission Factor Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) - Actual Annual Emissions Requested Annual Permit Emission Limit(s)4 Uncontrolled (Tons/year) Controlled5 (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) PM SO,, 0.67 Ib/MMSCF AP -42 55.35 5.54 H2S 0.46 lb/MMSCF ProMax 37.50 0.38 NOX VOC 10.12 Ib/MMSCF ProMax 830,80 34.66 CO 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Asw_COLORADO Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 Permit Number: 'J 8WE0274 AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID]. Section 7 (continued) Non -Criteria Reportable Pollutant Emissions Inventory Pollutant Chemical Abstract Service (CAS) Number Uncontrolled Emission Factor Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) ,, Actual Annual Emissions Uncontrolled (lbs/year) Controlled5 (Ws/year) .., Benzene 71432 0.49 lb/MMSCF ProMax Toluene 108883 0.38 lb/MMSCF ProMax Ethylbenzene 100414 0.03 lb/MMSCF ProMax Xylenes 1330207 0.09 Ib/MMSCF ProMax n -Hexane 110543 0.03 Ib/MMSCF ProMax 2,2,4- Trimethylpentane 540841 5.15E-06 Ib/MMSCF ProMax Other: 5Annual emission fees wilt be based on actualcontrolled emissions reported. If source has not yet started operating, leave blank. Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. f-t1:44.--/T—tte Signature of Legally Authorized Pherson (not a vendor or consultant) Date Matthew T. Berghorn, P.E. VP - Engineering and Construction Name (please print) Title Check the appropriate box to request a copy of the: O Draft permit prior to issuance 0 Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1.530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 COLORADO 7 I...,r r, Boiler APEN - Form APC220 Air Pollutant Emission Notice (APEN) a Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facititi , • jy OPEN . updates. An application with missing information may be determined incomplete and may be rett in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for boilers, hot oil heaters, process heaters, and similar equipment. If your emission unit does not fall into one of these categories, there may be a more specific APEN for your source (e.g. paint booths, mining operations, engines, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. Do not complete this form for the following source categories: - Heaters or boilers with a design capacity less than or equal to 5 MMBtu/hour that are fueled solely by natural gas or liquid petroleum gas (LPG). Heaters or boilers with a design capacity less than or equal to 10 MMBtu/hour used solely for heating buildings for personal comfort that is fueled solely by natural gas or liquid petroleum gas (LPG). More information can be found in the APEN exempt/permit exempt checklist: https: / /www.colorado.Rov/pacific/cdphe/apen-or-air-permit-exemptions. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: AIRS ID Number: (23 rfA--i-/ 00 - [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Discovery DJ Services LLC Site Name: Discovery Kiowa Gas Plant Site Location: Section 29, Ti N, R63W Mailing Address: (include Zip code) 3601 Stagecoach Road, Ste. 202 Longmont, CO 80504 E -Mail Address2: mnorton@discoverymidstream.com Site Location County: Weld NAILS or SIC Code: 213112 Permit Contact: Matthew Norton Phone Number: (817) 455-5799 I Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-220 - Boiler APEN - Revision 11/2017 ZU-2-71 100. COLORADO nW.roonuollebc Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source -OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below) - OR • APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) • APEN submittal for permit exempt/grandfathered source Additional Info Et Notes: 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Boiler Information General description of equipment and purpose: for the Hot Oil System System includes 2 x 50.0 MMBtu/hr heaters Manufacturer: TBD Model No.: TBD Serial No.: TBD Company equipment Identification No. (optional): H1 and H2 For existing sources, operation began on: For new, modified, or reconstructed sources, the projected start-up date is: 10/1/2018 2 Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: - hours/day Seasonal use percentage: Dec -Feb: Mar -May: days/week weeks/year June -Aug: Sept -Nov: Are you reporting multiple identical boilers on this APEN? 0 Yes ❑ No If yes, please describe how the fuel usage will be measured for each boiler (i.e., one meter for all boilers or separate meters for each unit): Separate fuel usage meters for each unit Form APCD-220 - Boiler APEN - Revision 11/2017 2 I A® COLORADO HaM 6 kllwronrtMm Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Stack Information eographical Coordinates 'Latitude /Longitude or UTM) 545372.27 E, 4429852.90 N .. � Ope atom 9 O , ar Discharge.l ei ht. g Above ou eel (Feet) .,,.. ....1 s� ..� T � �k emFlow ( a Ra e•. cF � .1- 1/e ocit Y � sec Hl/H2 TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) ❑✓ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) 0 Circular Interior stack diameter (inches): ❑ Square/rectangle Interior stack width (inches): ❑ Other (describe): ❑ Upward with obstructing raincap Interior stack depth (inches): Section 5 - Fuel Consumption Information Design' In ut Rate _ g PLirra (MMBTU/hr) Actual Annual Fuel Use4. (Specify Units) . °_ Requested Annual Permit (Specify Units) 50.0 (each unit) 387.61 MMSCF/yr/unit From what year is the actual annual fuel use data? Fuel consumption values entered above are for: ❑✓ Each Boiler ❑ All Boilers O N/A Indicate the type(s) of fuel used6: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) ❑ Field Natural Gas Heating value: BTU/SCF ❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTU/SCF) O Coal Heating value: BTU/lb Ash content: Sulfur Content: ❑✓ Other (describe): Residue Natural Gas Heating value (give units): 1,130 Btu/scf 4 If you are reporting multiple identical boilers on one APEN, be sure to clarify if the values in this section are on an individual boiler basis, or if the values represent total fuel usage for multiple boilers. 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 If fuel heating value is different than the listed assumed value, please provide this information in the "Other" field. Form APCD-220 - Boiler APEN - Revision 11/2017 3 I AV COLORADO Dnartemat Pubtic FiW1n6AWronmini , Ft TSP (PM) Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6- Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? D Yes ® No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): Control Equipment Description Overall Control Efficiency, (% reduction in emissions) PM10 PM2.s SOX NOX CO VOC Other: From what year is the following reported actual annual emissions data? Use the following tables to report the criteria pollutant emissions from source: (Use the data reported in Section 5 to calculate these emissions.) Primary.Fuel e TSP (PM) Pollutant Uncontrolled Emission Factor (Specify Units) Emission Factor Source (AP -42, Mfg. etc) Uncontrolled (Tons/year) Controlled7, (Tons/year) . Uncontrolled (Tons/year). Controlled:: (Tons/year) Residue natural gas 8.42 Ib/MMSCF AP -42 3.26 3.26 PM -to 8.42 Ib/MMSCF AP -42 3.26 3.26 PM2.5 8.42 Ib/MMSCF AP -42 3.26 3.26 SOX 0.66 Ib/MMSCF AP -42 0.26 0.26 NOX 33.9 Ib/MMSCF Mfg. 13.14 13.14 CO 67.8 Ib/MMSCF Mfg. 26.28 26.28 VOC 6.09 Ib/MMSCF AP -42 2.36 2.36 Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 7 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-220 - Boiler APEN - Revision 11/2017 4I COLORADO Departs.. eihMic NW%6 Elvis no Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] , ES ED Check this box if the boiler did not combust a secondary fuel during this reporting period and skip to Section 7. If multiple fuels were fired during this reporting period, complete this secondary fuel emissions table and the total criteria emissions table below: Secondary Fuel Type (#2 diesel, waste, oil, ,retc.)'‘ Pollutant Uncontrolled Emission Factor (Specify Units) Emission Factor Source (AP -42, Mfg. etc) Uncontrolled (Tons/year) Controlled? (Tons/year) UnualrPer it: A11-45g i Uncontrolled (Tons/year) Controlled (Ions/year) ; TSP (PM) PM10 PM2.5 SOX NOx CO VOC Other: If multiple fuels were fired during this reporting period, use the following table to report the TOTAL criteria pollutant emissions from the source. Values listed below should be the sum of the reported emissions from the primary and secondary fuels' emissions tables in this Section 6: TSP (PM) Uncontrolled (Tons/year) Controlled7- (Tons/year) equested AnhualrP_ermit missionimit s 5 — Uncontrolled-- (Tons/year) Controlled (Tons/year) PM10 PM2.5 SO. NOx CO VOC Other: 5 Requested values will become permit limitations. Requested Limit(s) should consider future process growth. 7 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-220 - Boiler APEN - Revision 11/2017 51 co COLORADO NgM6 EmUpuxn, Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP- hazardous air pollutant) equal to or greater than 250 lbs/year? ® Yes ❑ No If yes, use the foltowinQ table to report the non -criteria pollutant (HAP) emissions from source: CAS Number Chemical Name Overall Control Efficiency Uncontrolled Emission Factor (specify units) Emission Factor ., . Source (AP7-42i Mfg• etc) '> Uncontrolled iu,Actual ;, Emissions (lbs/year) Controlled Actual Emissions7, (lbs/year) ' 110543 Hexane 0 1.99 Ib/MMSCF AP -42 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-220 - Boiler APEN - Revision 11/2017 6 I Co COLORADO KOMI ET�itamnoN Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. fn aI .'T • 3- co- Ll Signature of Legally Aut .r •ed Person (not a vendor or consultant) Date Matthew T. Berghorn, P.E. VP - Engineering and Construction Name (please print) Title Check the appropriate box if you want: ❑✓ Draft permit prior to public notice ❑ Draft of the permit prior to issuance (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692- 3148 Or visit the APCD website at: httos://www.colorado. ov/cd he/a cd Form APCD-220 - Boiler APEN - Revision 11/2017 7 I CO COLORADO Dqpnamadentdre. nwa r ahrenn.n+ VA( 0 2016 7,.P( D Boiler APEN - Form APCD-220 Air Pollutant Emission Notice (APEN) and Application fox Construction Peanuit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may t�retur longer application processing times. You may be charged an additional APEN fee if the A� incorrectly or is missing information and requires re -submittal_ This APEN is to be used for boilers. hot oil heaters, process heaters, and similar equipmenflfyt:ur5ission unit does not fall into one of these categories, there may be a more specific APEN for your source (e.g. paint booths, mining operations, engines, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.coiorado.eovicdohelapcd. Do not complete this form for the following source categories: - Heaters or boilers with a design capacity less than or equal to 5 MM3tu/hour that are fueled solely by natural gas or liquid petroleum gas (LPG). Heaters or boilers with a design capacity less than or equal to 10 MMBtuihour used solely for heating buildings for personal comfort that is fueled solely by natural gas or liquid petroleum gas (LPG). More information can be found in the APEN exempt/permit exempt checklist: https://www.colorado. goy /oaciicicdche/apen-or-air-oermit-exenict1ons. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 1 8WE0274 AIRS ID Number: / / Section 1 - Administrative Information Company Name: Discovery DJ Services LLC Site Name: Discovery Kiowa Gas Plant Site Location: Section 29, Ti N, R63W Mailing Address: (Include Zip Coda) 3601 Stagecoach Road, Ste. 202 Longmont, CO 80504 E -Mail Address: mnorton@discoverymidstream.com Site Location1 County: Weld NAILS or SIC Code: 213112 Permit Contact: Matthew Norton Phone Number: (817) 455-5799 Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. LGR DO AYCJA-. Permit Number: 18WE0274 AIRS iD Number: 1 I Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source - OR - El MODIFICATION to existing permit (cheek ecch box .not aDaile_) • Change fuel or equipment ❑ Change company name O Chancre permit limit ❑ Transfer of ownership' - OR - • APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) • APEN submittal for permit exempt/grandfathered source Additional Info & Notes:' ❑ Add point to existing permit ❑ Other (describe below) 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-04) must be submitted. Section 3 - General Boiler Information General description of equipment and purpose: for the Hot Oil System System includes 2 x 65.0 MMBtu/hr heaters Manufacturer: TBD Model No.: TBD Company equipment Identification No. (optional): H1 and H2 For existing sources, operation began on: Serial No.: TBD For new, modified, or reconstructed sources, the projected start-up date is: 10/1/2015 E Check this box if operating hours are 8,760 hours per year;. if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day Seasonal use percentage: Dec -Feb: Mar -May:. daysl week weeks/year June -Aug: Are you reporting multiple identical boilers on this APEN? Yes No Sept -Nov: If yes, please describe how the fuel usage will be measured for each boiler (i.e., one meter for all boilers or separate meters for each unit): Separate fuel usage meters for each unit E Upward D. Horizontal Permit Number: 1 8WE0274 AIRS ID Number: / 1 Section 4 - Stack Information phical Coordinates de/Longitude or uTM) 545372.27 E, 4429852.90 N ifigerasr taclti Rio t s arge ₹lei �' Above round L +et _- iRip�} (.`F aX #fie (ACiMJ Y c' }i H1/H2 TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) Circular Square/rectangle ❑ Other (describe): Interior stack diameter (inches): Interior stack width (inches): O Upward with obstructing raincap Interior stack depth (inches): Section 5 - Fuel Consumption Information Design'Input Rate (MMBTLJ/hr) Actual Annual Fuel itse (Specify Units) Requested Annual Permit Limit5 Units) 65.0 (each unit) 526.21 MMSCF/yr/unit From what year is the actual annual fuel use data? Fuel consumption values entered above are for: Q Each Boiler ❑ All Boilers ❑ N/A Indicate the type(s) of fuel used6: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) ❑ Field Natural Gas ❑ Ultra Low Sulfur Diesel O Propane ❑ Coal Other (describe): Heating value: BTUISCF (assumed fuel heating value of 138,000 BTU/gallon) (assumed fuel heating value of 2,300 BTU/SCF) Heating value: BTU/lb Ash content: Sulfur Content: Residue Natural. Gas Heating value (give units): 1 ,130 Btu/sef 4 If you are reporting multiple identical boilers on one APEN, be sure to clarify if the values in this section are on an individual boiler basis, or if the values represent total fuel usage for multiple boilers. 5 Requested values will become permit limitations. Requested limits) should consider future process growth. 6 If fuel heating value is different than the listed assumed value, please provide this information in the "Other" field. ligf COLORADO Permit Number: 18WE0274 AIRS ID Number: r Section 6- Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑ Yes ® No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): allutant Control': Equipment Description Co TSP (PM) PKc PM2_; SO, NOS CO VOC Other: From what year is the following reported actual annual emissions data? Use the following tables to report the criteria pollutant emissions from source: fUse the data reported in Section 5 to calculate these emissions.) Primary Fuel Type ral gas, 2 diesel, •etc.) Residue natural gas Pollu Uncont Ernissi Factor ecify.lnits) ed TSP (PM) 8.59 Ib/MMSCF Emission Factor Source { -42, Mfg. etc) Mfg. Uncontrolled (Tons/year) Bed Uncontrolled (Twsrstyeas•)' Controlled' (Tons'year) Coni l77 4.33 4-33 PM:o 8.59lb/MMSCF Mfg. 4.33 4.33 PM"s 8.59Ib/MMSCF Mfg. 4.33 4.33 SOS 0.68 Ib/MMSCF Mfg. 0.34 0.34 NO,, CO ; 41.2 Ib/MMSCF I Mfg. 19.9 Ib/MMSCF Mfg. 10.02 10.02 20.78 20.78 VOC 6.22 Ib/MMSCF Mfg. 3.13 3.13 • Other: ' Requested values will become permit limitations. Requested limits) should consider future procs growth. t Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. IRAaa Permit Number: j 8WE0274 AIRS ID Number: 2 Check this box if the boiler did not combust a secondary fuel during this reporting period and skip to Section 7. if multiple fuels were fired during this reporting period, complete this secondary fuel emissions table and the total criteria emissions table below: Secondary Fuel Type (#2 diesel,; waste oil, etc.) TSP (PM) Uncontrolled Emissic Facthr Pert! -Units) Emission factor Source • (AP -42, Mfg. etc) Uncontrolled (Tatrs/year) Controlled? (Terrslyear) Uncontrolled (Tons/year) Controlled (Tans/year) PM -.s SO NO„ CO VOC Other: If multiple fuels were fired during this reporting period, use the following table to report the TOTAL criteria pollutant emissions from the source. Values listed below should be the sum of the reported emissions from the primary and secondary fuels' emissions tables in this Section 6: :ontrolled' ons/year) (T olied? year) Uncontrolled (Tons/yenrj Controlled (Tonslyear) TSP (PM) PrM1.5 PiW5 SOS NO„ CO VOC Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 7 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Permit Number: 18WE0274 AIRS ID Number: I I Section 7 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP- hazardous air pollutant) equal to or greater than 250 lbs/year? Yes Q No If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: Uncontrolled Chemical Name Actual Emissions (7hs/year)'', f A5 Number Overall Control Efficiency UncontrGI ed Emission Factor (specify units) Emission Factor Source (AP -42, Mfg. etc) Controlled Actual Ensissions7 (lbsiyear) 110543 Hexane 0 1.99 Ib/MMSCF AP -42 Annual emission fees will be based on actual controlled emissions reported. If source has not yet smarted operating, leave blank. Permit Number: 18WE0274 AIRS ID Number; Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct.. c-lv- rg Signature of Legally Authorized Pe so (n a vendor or consultant) Date Matthew T. Berghorn, P.E. VP - Engineering and Construction Name (please print) Title Check the appropriate box if you want: ill Draft permit prior to public notice ❑ Draft of the permit prior to issuance (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) yews. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production; new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692- 3148 Or visit the APCD website at: h ttps: / /www.coborado.Rovicdoheiac,,cd t,3 Boiler APEN - Form APCD-220 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existin ' iti updates. An application with missing information may be determined incomplete an a longer application processing times. You may be charged an additional APEN fee if t incorrectly or is missing information and requires re -submittal. This APEN is to be used for boilers, hot oil heaters, process heaters, and similar equipment. If your emission unit does not fall into one of these categories, there may be a more specific APEN for your source (e.g. paint booths, mining operations, engines, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. Do not complete this form for the following source categories: - Heaters or boilers with a design capacity less than or equal to 5 MMBtu/hour that are fueled solely by natural gas or liquid petroleum gas (LPG). Heaters or boilers with a design capacity less than or equal to 10 MMBtu/hour used solely for heating buildings for personal comfort that is fueled solely by natural gas or liquid petroleum gas (LPG). More information can be found in the APEN exempt/permit exempt checklist: https: / /www.colorado.gov/pacific/cdphe/apen-or-air-permit-exemptions. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 18WE0274 AIRS ID Number: 1a� / iI �/ OO1, [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 Administrative Information Company Name': Discovery DJ Services LLC Site Name: Discovery Keenesburg Gas Plant Site Location: Section 17, T2N, R63W Mailing Address: (Include Zip code) 3601 Stagecoach Road, Ste. 202 Longmont CO 80504 E -Mail Address?: mnorton@discoverymidstream.com Site Location County: Weld. NAICS or SIC Code: 213112 Permit Contact: Matthew Norton Phone Number: (817) 455-5799 1 Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-220 - Boiler APEN - Revision 11/2017 COLORADO II.+�t Y f ,ccorwnf Permit Number: 18WE0274 AIRS ID Number: / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source -OR- Q MODIFICATION to existing permit (check each box below that applies) ❑ Changefuel or equipment ❑ Change company name O Change permit limit 0 Transfer of ownership3 -OR - ❑ APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - O Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) O APEN submittal for permit exempt/grandfathered source O Add point to existing permit O Other (describe below) Additional Info Ft Notes: Updates to reflect new plant name, change in location. 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Boiler Information General description of equipment and purpose: for the Hot Oil System System includes 2 x 65.0 MMBtu/hr heaters Manufacturer: TBD Model No.: TBD Serial No.: TBD Company equipment Identification No. (optional): H1 and H2 For existing sources, operation began on: For new, modified, or reconstructed sources, the projected start-up date is: 10/1/2018 (] Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day days/week weeks/year Seasonal use percentage: Dec -Feb: Mar -May: June -Aug: Sept -Nov: Are you reporting multiple identical boilers on this APEN? ✓ Yes ❑ No If yes, please describe how the fuel usage will be measured for each boiler (i.e., one meter for all boilers or separate meters for each unit):. Separate fuel usage meters for each unit Form APCD-220 - Boiler APEN - Revision 11/2017 COLORADO 2 I dier r:rn=.', Permit Number: 18WE0274 AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit H and AIRS ID] Section 4 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 545685.41 E, 4443658.96 N Operator Stack ID No Discharge Height Above Ground Level (Feet) Temp ('F) Flow Rate (ACFM) Velocity (ft/sec)' Hl/H2 TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) ❑✓ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) 2 Circular ❑ Square/rectangle Interior stack width (inches): 0 Other (describe): Interior stack diameter (inches): ❑ Upward with obstructing raincap Interior stack depth (inches): Section 5 - Fuel Consumption Information Design Input Rate (MMBTU/hr) Actual Annual Fuel Use4 (Specify Units) Requested Ann 5aC Permit Limit (Specify Units). 65.0 (each unit) 526.21 MMSCF/yr/unit From what year is the actual annual fuel use data? Fuel consumption values entered above are for: 2 Each Boiler 0 All Boilers 0 N/A Indicate the type(s) of fuel used6: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) 0 Field Natural Gas Heating value: BTU/SCF ❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTU/SCF) ❑ Coal Heating value: BTU/lb Ash content: Sulfur Content: 0 Other (describe): Residue Natural Gas Heating value (give units): 1,130 Btu/scf 4 If you are reporting multiple identical boilers on one APEN, be sure to clarify if the values in this section are on an individual. boiler basis, or if the values represent total fuel usage for multiple boilers. 5 Requested values wilt become permit limitations. Requested limit(s) should consider future process growth. 6 If fuel heating value is different than the listed assumed value, please provide this information in the "Other" field. Form APCD-220 - Boiler APEN - Revision 11/2017 COLORADO 3 uwn rr, ci r. Permit Number: 18WE0274 AIRS ID Number: / [Leave blank unless APCD has already assigned a permit t! and AIRS ID] Section 6- Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? O Yes ® No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Control Efficiency (% reduction in emissions) TSP (PM) PMK() PM2.5 SOx NOx CO VOC Other: From what year is the following reported actual annual emissions data? Use the following tables to report the criteria pollutant emissions from source: (Use the data reported in Section 5 to calculate these emissions.) Primary Fuel Type (natural gas, #2 diesel, etc.) Pollutant Uncontrolled Emission Factor (Specify Units) Emission Factor Source (AP -42, Mfg. etc) Uncontrolled (Tons/year) Controlled7 (Tons/year) nested Annua mission Limits; Uncontrolled (Tons/year) Controlled (Tons/year) Residue natural gas TSP (PM) 8.59 lb/MMSCF Mfg. 4.33 4.33 PM10 8.59 Ib/MMSCF Mfg. 4.33 4.33 PM2.5 8.59 Ib/L1MSCF Mfg. 4.33 4.33 sox 0.68 Ib/IAIMSCF Mfg. 0.34 0.34 NOX 19.9 Ib/LIMSCF Mfg. 10.02 10.02 CO 41.2 Ib/MMSCF Mfg. 20.78 20.78 VOC 6.22 Ib/MMSCF Mfg. 3.13 3.13 Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 7 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-220 - Boiler APEN - Revision 11/2017 viRViCOLORAPO A 1 u+�m.�.mrcic Permit Number: 18WE0274 AIRS ID Number: I I [Leave blank ustess APCD has already assigned a permit # and AIRS ID) Check this box if the boiler did not combust a secondary fuel during this reporting period and skip to Section 7. If multiple fuels were fired during this reporting period, complete this secondary fuel emissions table and the total criteria emissions table below: Secondary Fuel Type (#2 diesel, waste oil etc.) Pollutant Uncontrolled Emission Factor (Specify Units) Emission Factor Source (AP -42, Mfg. etc) Uncontrolled (Tons/year) Controlled7 (Tons/year) Requested Annual Permit " ' Emission'Limit(s5„ Uncontrolled (Tons/year) Controlled (Tons/year) TSP (PM) PM1 o PM2.5 SOx NO. CO VOC Other: If multiple fuels were fired during this reporting period, use the following table to report the TOTAL criteriapollutant emissions from the source. Values listed below should be the sum of the reported emissions from the primary and secondary fuels' emissions tables in this Section 6: Uncontrolled (Torts/year) TSP (PM) Controlled7 (Tons/year) Requested Annual Permit.'. Emission Limits Uncontrolled (Tons/year) Controlled (Tons/year) PMio PM2.5 SO. NO), CO VOC Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 7 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-220 - Boiler APEN - Revision 11/2017 .COLORADO 51 o<:.r. ...::< � � 14t_�anSi:nr:rv:.�ac..r., Permit Number: 18WE0274 AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP- hazardous air pollutant) equal to or greater than 250 lbs/year? J Yes ❑ No If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: LAS Number Chemical Name Overall Control Efficiency Uncontrolled Emission' Factor (specify units) Emission Factor Source (AP -42, Mfg. etc). Uncontrolled Actual Emissions (lbs/year) Controlled Actual Emissions? (lbs/year) 110543 Hexane 0 1.99 Ib/MMSCF AP -42 7Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-220 - Boiler APEN - Revision 11/2017 COLORADO 6 1 �=-7,..v- Permit Number: 'j 8WE0274 AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I.hereby certify that all information contained herein and information submitted with this application is complete, true and correct. - i I 7- ?,_/ Signature of Legally Xfuthori ed Peen (not a vendor or consultant) Date �(' � .� 9 � , 1 1, 1G/Agin I1 ( '� Lt Dsrd1 , : E., 11P (:s14 6 2eyr r s C'-vv;1 4u[_T(oi i 2Title Name (please prin ) Check the appropriate box if you want: O Draft permit prior to public notice ❑ Draft of the permit prior to issuance (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692- 3148 Or visit the APCD website at: Make check payable to: https://www.colorado.Rov/cdphe/aped Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form APCD-220 - Boiler APEN - Revision 11/2017 COLORADO 7I - . - fipFit) Mh. ) CIA. 14)M Boiler APEN - Form APCD-220 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities updates. An application with missing information may be determined incomplete and may be r longer application processing times. You may be charged an additional APEN fee if the AP€N is incorrectly or is missing information and requires re -submittal. This APEN is to be used for boilers, hot oil heaters, process heaters, and similar equipment. If your emission unit does not fall into one of these categories, there may be a more specific APEN for your source (e.g. paint booths, mining operations, engines, etc.). In addition, the General APEN (Form APCD-2OO) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado:gov/cdphe/apcd. Do not complete this form for the following source categories: - Heaters or boilers with a design capacity less than or equal to 5 MMBtu/hour that are fueled solely by natural gas or liquid petroleum gas (LPG). Heaters or boilers with a design capacity less than or equal to 10 MMBtu/hour used solely for heating buildings for personal comfort that is fueled solely by natural gas or liquid petroleum gas (LPG). More information can be found in the APEN exempt/permit exempt checklist: https: //www.colorado.Rov/ pacific/cdphe/apen-or-air-permit-exemptions. This emission notice is valid for five (5) years.. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: AIRS ID Number: 11.3 i F4 i 093 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name: Discovery DJ Services LLC Site Name: Discovery Kiowa Gas Plant Site Location: Section 29, Ti N, R63W Mailing Address: (Include Zip code) 3601 Stagecoach Road, Ste. 202 Longmont, CO 80504 E -Mail Address2: mnorton@discoveiymidstream.com Site Location County: Weld NAICS or SIC Code: 213112 Permit Contact: Matthew Norton Phone Number: (817) 455-5799 1 Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-220 - Boiler APEN - Revision 11/2017 376263) co COLORADO Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action 0 NEW permit OR newly -reported emission source - OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below) - OR - • APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info Et Notes: 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Boiler Information General description of equipment and purpose: 2 x 15.0 MMBtu/hr Natural Gas -Fired Regenerator Heaters for the Molecular Sieve Dehydration System Manufacturer: TBD Model No.: TBD Serial No.: TBD Company equipment Identification No. (optional): H3/H4 For existing sources, operation began on: For new, modified, or reconstructed sources, the projected start-up date is: 10/1/2018 2 Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day Seasonal use percentage: Dec -Feb: Mar -May: days/week weeks/year June -Aug: Sept -Nov: Are you reporting multiple identical boilers on this APEN? 2 Yes ❑ No If yes, please describe how the fuel usage will be measured for each boiler (i.e., one meter for all boilers or separate meters for each unit): Separate meters for each unit Form APCD-220 - Boiler APEN - Revision 11/2017 2'AV Department COLORADO af Nprti16 EMrOnM1wN Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Stack Information eographtcal Coordinates, Latitude/Longitude or UTM) 545384.06 E, 4429853.14 N Operator - " S c D o' hie D>Ischarget.tfelght Above Gro d eve! `a �� em p ( f Flow Rate [FM) Velocity z Use H3/H4 TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) E Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) 2 Circular ❑ Square/rectangle Interior stack width (inches): ❑ Other (describe): Interior stack diameter (inches): 0 Upward with obstructing raincap 24" Interior stack depth (inches): Section 5 - Fuel Consumption Information Design Input Rate. (MMBTU/hr) Actual Annual Fuel Use4 (Specify Units) "Regluested Annual Permit =5 Llmi (Specify Units) , - 15.0 MMBtu/hr (each) 116.28 MMscf/yr/unit From what year is the actual annual fuel use data? Fuel consumption values entered above are for: ✓❑ Each Boiler ❑ All Boilers Indicate the type(s) of fuel used6: ❑ Pipeline Natural Gas ❑ Field Natural Gas ❑ Ultra Low Sulfur Diesel ❑ Propane ❑ Coal ❑✓ Other (describe): (assumed fuel heating value of 1,020 BTU/SCF) Heating value: BTU/SCF (assumed fuel heating value of 138,000 BTU/gallon) (assumed fuel heating value of 2,300 BTU/SCF) Heating value: 0 N/A BTU/lb Ash content: Sulfur Content: Residue Natural Gas Heating value (give units): 1,130 Btu/scf 4 If you are reporting multiple identical boilers on one APEN, be sure to clarify if the values in this section are on an individual boiler basis, or if the values represent total fuel usage for multiple boilers. 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 If fuel heating value is different than the listed assumed value, please provide this information in the "Other" field. Form APCD-220 - Boiler APEN - Revision 11/2017 3 COLORADO o.y...m.tt PkoM ET.Ironnam TSP (PM) Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6- Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? O Yes ® No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): Control Equipment Description Overall Control Efficiency (% reduction in emissions) �M1 Q PM2. 5 SOX NO. CO VOC Other: From what year is the following reported actual annual emissions data? Use the following tables to report the criteria pollutant emissions from source: (Use the data reported in Section 5 to calculate these emissions.) Primary_Fuel Type , (natural _gas, etc.): .. TSP (PM) Uncontrolled Emission Factor, (Specify Units) Emission Factor Source (AP -42, Mfg. etc) Uncontrolled (Tons/year) 'Controlled? (Tons%year). equ(ested,finualPermt, Uncontrolled (Tons/year) ri. -Controlled , (Tons/year) Residue Natural Gas 14.69 Ib/MMSCF Mfg. 1.71 1.71 PM10 14.69 Ib/MMSCF Mfg. 1.71 1.71 PM2.5 14.69 Ib/MMSCF Mfg. 1.71 1.71 SOX 0.66 Ib/MMSCF AP -42 0.08 0.08 NO. 45.2 Ib/MMSCF Mfg. 5.26 5.26 CO 45.2 Ib/MMSCF Mfg. 5.26 5.26 VOC 21.47 Ib/MMSCF Mfg. 21.47 21.47 Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 7 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-220 - Boiler APEN - Revision 11/2017 DepareerataLhabbc COLORADO Na446nrworx rma Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] 0 Check this box if the boiler did not combust a secondary fuel during this reporting period and skip to Section 7. If multiple fuels were fired during this reporting period, complete this secondary fuel emissions table and the total criteria emissions table below: Secondary Fuel Type (#24diesel, waste oil, etc.) TSP (PM) Uncontrolled Emission Factor (Specify Units) Emission Factor Source (AP -42, Mfg. etc) ctual Annual:Emisstons3 Uncontrolled (Tons/year) Controlled (Tons/year) Uncontrolled (Tons/year) Controlled? (Tons/year) PM10 PM2.5 Sax NOx CO VOC Other: If multiple fuels were fired during this reporting period, use the following table to report the TOTAL criteria pollutant emissions from the source. Values listed below should be the sum of the reported emissions from the primary and secondary fuels' emissions tables in this Section 6: TSP (PM) Uncontrolled= (Tons/year) Controlled? (Tons/year) -Uncontrolled- (Tons/year) Controlled-` (Tons/year) PM10 PM2.s SOX NO. CO VOC Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 7 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-220 - Boiler APEN - Revision 11/2017 5 I Al, COLORADO n,64 MOM 6 EmhONMiu Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP- hazardous air pollutant) equal to or greater than 250 lbs/year? ❑ Yes ❑ No If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: CAS Number Chemical Name Overall Control Efficiency Uncontrolled Emission Factor (specify units) Emission Factor Source (AP-42,'Mfg. etc) Uncontrolled Actual. Emissions abs/year) Controlled._ Actual Emissions? (lbs/year) 110543 Hexane N/A 1.99 Ib/MMSCF AP -42 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-220 - Boiler APEN - Revision 11/2017 6 I Co Departmeat al Pair COLORADO AuntbIMMO mrn+ Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS IN Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. ig Signature of legally Autho iz Person (not a vendor or consultant) Date Matthew T. Berghorn, P.E. VP - Engineering and Construction Name (please print) Title Check the appropriate box if you want: 0 Draft permit prior to public notice 0 Draft of the permit prior to issuance (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years, Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692- 3148 Or visit the APCD website at: Make check payable to: httos://www.colorado.vv/cdohe/apcci Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form APCD-220 - Boiler APEN - Revision 11/2017 7!COLORA06 i f , t3�=, 3/16/2018 State.co.us Executive Branch Mail - Kiowa Gas Plant — APEN is missing a signature STATE OF COLORADO Gruel - CDPHE, Andrew <andrew.gruel@state.cb.us> Kiowa Gas Plant -- APEN is missing a signature Matthew Norton <MNorton@discoverymidstream.com> To: Andy Gruel - CDPHE <andrew.gruel@state.co.us> Cc: Matthew Berghorn <MBerghorn@discoverymidstream.com> G23- F-4-ox>3 Andy Fri, Mar 16, 2018 at 1:47 PM Thank you for catching this and allowing us to turn this around quickly. Attached is the signed document. I have the original here and can mail the hardcopy if needed. Have a good weekend sir. Matt Norton I Compliance Manager Discovery Midstream Partners (817) 455-5799 cell 3601 Stagecoach Road, Ste. 202 Longmont, CO 80504 From: Andy Gruel - CDPHE[mailto:andrew.gruel@state.co.us] Sent: Friday, March 16, 2018 9:37 AM To: Matthew Norton <MNorton@discoverymidstream.com> Subject: Kiowa Gas Plant -- APEN is missing a signature Mr. Norton, One of the APENs for the Kiowa Gas Plant is missing the required signature. I've attached a scan of the entire APEN as well as the single signature page. Please have Mr. Berghorn (or another legally authorized person) sign the APEN, scan it, and email it back to me. You can just send me the single signature page. Thank You, Andy Gruel, P.E. Oil and Gas Permit Engineer Stationary Sources Program hops://mail.google.com/mail/u/Mui=2&ik=9030c1528b&jsver-7NKBhY4B7p8.en.&view=pt&msg=162305a4f1091754&search=inbox&sim1=162305a4f7091754 Boiler APEN - Form APCD Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for boilers, hot oil heaters, process heaters, and similar equipment. if your emission unit does not fall into one of these categories, there may be a more specific APEN for your source (e.g_ paint booths, mining operations, engines, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: wwvw.colarado.eov/cdohe!aocd. Do not complete this form for the following source categories: - Heaters or boilers with a design capacity less than or equal to 5 WMBtu/hour that are fueled solely by natural gas or liquid petroleum gas (LPG). Heaters or boilers with a design capacity less than or equal to 10 M,M8tu/hour used solely for heating buildings for personal comfort that is fueled solely by natural gas or liquid petroleum gas (LPG). More information can be found in the APEN exemptlpermit exempt checklist: https: / l www. colorado. eov' oacfic f cdohe! aoen-or-air-permit-exemptions. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, ll.C. for revised APEN requirements. Permit Number: 18WE0274 AIRS ID Number: / Section 1 - Administrative Information Company Name`: Discovery DJ Services LLC Site Name: Discovery Kiowa Gas Plant Site Location: Section 29, TIN, R63W Mailing Address: (include sip Code) 3601 Stagecoach Road, Ste. 202 Longmont, CO 80504 E -Mail Address2: mnorton@discoverymidstream.com Site Location County: Weld NAICS or SIC Code: 213112 Permit Contact, Matthew Norton Phone Number. (817) 455-5799 Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices willbe issued by APCD via e-mail to the address provided. COLOR. O Permit Number: 18WE©274 AIRS ID Number: / Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source - OR - ❑ MODIFICATION to existing permit icaecx _ : c.x below rhos applies) • Change fuel or equipment ❑ . Change company name ❑ Add point to existing permit ❑ Change permit limit 0 Transfer of ownership' ❑ Other (describe below) - Oa - • APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) O APEN submittal for permit exempt/grandfathered source Additional Info 8 Notes: ' For transfer of ownership, a completed Transfer of Ownership Certification Form )Form APCO-104) must be submitted. Section 3 - General Boiler Information General description of equipment and purpose:. 2 x 24.0 MMBtu/hr Natural Gas -Fired Regenerator Heaters for the Molecular Sieve Dehydration System Manufacturer: TBD Model No.: TBD Serial No.: TBD Company equipment Identification No. (optional): H3/H4 For existing sources, operation began on: For new, modified, or reconstructed sources, the projected start-up date is: 10/1/2018 • Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: Seasonal use percentage: Dec -Feb: hours/day Mar -May: days/ week weeks/year June -Aug: Sept -Nov: Are you reporting multiple identical boilers on this APEN? r Yes No if yes, please describe how the fuel usage will be measured for each boiler (Le., one meter for all boilers or separate meters for each unit): Separate meters for each unit a Permit Number: 18WE0274 AIRS ID Number: / / Section 4 - Stack information Geographical Coordinates (iatitudeliangitade or UTM) 545384.06 E, 4429853.14 N erator SCack.ID I$o� scha )eight Ati�iv Grotsrid ,evel (Fees) Temp• F) Flogs Rate Veior y H3/H4 TBD TBD TBD i TBD Indicate the direction of the stack outlet: ich_ckone) 0 Upward O Horizontal ❑ Downward O Other (describe): Indicate the stack opening and size: (check one) El Circular Interior stack diameter (inches): ❑ Upward with obstructing raincap 24" O Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): Section 5 - Fuel Consumption Information Design Input Rate (MMETUThr) ' Actual Annual Fuel Use (Specify Units) Requested Permit Ann uual t unit (specify Units) 24.0 M IRtu/hr (each) 186.05 NIMscf/yr/unit From what year is the actual annual fuel use data? Fuel consumption values entered above are for: 0 Each Boiler O All Boilers ❑ NIA Indicate the type -is) of fuel used°: • Pipeline Natural Gas (assumed filet heating value of 1.020 BTUJSCF) O Field Natural Gas Heating value: BTU/SCF ❑ Ultra. Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) O Propane O Coal 0 Other (describe): (assumed fuel heating value of 2,300 BTU/SCF) Heating value: BTU/lb Ash content: Sulfur Content: Residue Natural Gas Heating value (give units): 1,130 Btu/scf 4 If you are reporting multiple identical boilers on one APEN, be sure to clarify if the values in this section are on an individual boiler basis, or if the values represent total fuel usage for multiple boilers. 5 Requested values will become permit limitations. Requested limits) should consider future process growth. 6 If fuel heating value is different than the listed assumed value, please provide this information in the "Other" field. YCOLOR .DC Permit Number: 18WE 0274 AIRS ID Number: Section 6- Criteria Pollutant Emissions information Attach alt emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑ Yes ® No If yes, please describe the control equipment AND state the overall control efficiency l% reduction): Pollutant Control Equipment Description Overall Control Efficiency (x reductidn in 2rriissiwfs) TSP (PM) PMio PM2.5 So' NO, CO VOC Other: From what year is the following reported actual annual emissions data? Use the following tables to report the criteria pollutant emissions from source: (Use the data reported in Section 5 to calculate these emissions.) Primary Fuel; Type {natural gas, #2 diesel, etc.} TSP (PM) Uncontrolled Emission Factor (Specify Units) Emission Factor Source (AP -42, Mfg. etc) • Uncontrolled (Tours/year) Controlled' (Tans/year) Uncontrolled (Torsi year) Controlled (Tonslyear),I Residue Natural Gas 8.59 Ib/MMSCF Mfg. 1.60 1.60 PM10 8.59 Ib/MMSCF Mfg. 1.60 1.60 P,M≥.s 8.59 lb/MMSCF Mfg. 1.60 1.60 SO, 0.68 lb/MMSCF AP -42 0.13 0.13 NO, 19.9 Ib/MMSCF Mfg. 3.70 3.70 CO 41.3 lb/MMSCF Mfg. 7.67 7.67 VOC 6.22 Ib/NIMSCF Mfg. 1.16 1.16 Other: .Requested values will become permit limitations. Requested limits) should consider future process growth. 7 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Permit Number: 18WE0274 AIRS ID Number: / / Check this box if the boiler did not combust a secondary fuel during this reporting period and skip to Section 7. If multiple fuels were fired during this reporting period, complete this secondary fuel emissions table and the total criteria emissions table below: Se€ondary' Fuel Type {#2 diesel, waste oil etc.) TSP (PM) Uncontrolled Emission Factor (Specify units) Factor Source F 4�, Adff, etc) Controlled' (Tans/year) Uncontrolled • (Tats/year)! Controlled (T year) Uncontrolled (Tans/year) PM,= P'v4__5 SOS NO, CO YOC. Other: If multiple fuels were fired during this reporting period, use the following table to report the TOTAL criteria pollutant emissions from the source. Values listed below should be the sum of the reported emissions from the primary and secondary fuels' emissions tables in this Section 6: TSP (PM) Uncontrolled - (Tons/year) Contralie& fTans/year) Uncontrolled (Tons/year) Controlled (Tons/year) PM3_ PM2.5 SO, NO, CO VOC. Other: 5 Requested values will become permit limitations. Requested limitls) should consider future process growth. Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. COLOCADO Permit Number: 1 $WE0274 AIRS ID Number: / 1 Section 7 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP- hazardous air pollutant) equal to or greater than 250 ibs/year? ID Yes 11 No f yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: CAS Number Hexane Overall Control Efficiency Uncontrolled Emission Factor (specify units) AP -42 Emission Factor Source -42, Mfg. etc) Uncontrolled Actual Emissions (!bel year) Controlled Actual sions7 (dbslyear) 110543 N/A 1-99 Ib/MMSCF `'Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating; leave blank. oRnco Permit Number: 18WE0274 AIRS ID Number: Section 8 - Applicant Certification 1 hereby certify that all information contained herein and information submitted with this application is complete, true and correct. Signature of Legally Authorize Person (not a vendor or consultant) Date Matthew T. Berghorn, P.E. VP - Engineering and Construction Name (please print) Title Check the appropriate box if you want: ✓� Draft permit prior to public notice ❑ Draft of the permit prior to issuance (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type., etc.). See Regulation No, 3, Part A, II. C. for revised APEN requirements. Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692- 3148 Or visit the APCD website at: httos: / /Www, colorado. oovi cdphe/aped JI4�Ji C0lOR....r¢ , Discovery DJ Services LLC Discovery Kiowa Gas Plant Emission Calculations Molecular Sieve Regeneration Gas Heaters Table 4.0. - Natural Gas -Fired Regenerator Heaters .,.' P;dramefery,' ' 2 "',Xtalite..z enn Number of Units 2 Heat Rating a 24.00 MMBtu/hr Maximum Monthly Gas Usage' 15.80 MMSCF/month/unit Maximum Annual Gas Usage2 186.05 MMSCF/yr/unit Hours per year/unit operated 8,760 - hr/yr Heat rating and gas volume calculated via normal design values and project specifications. a Based on a natural gas heating value of 1,130 Btu/scf, the average sales gas heat value for the proposed facility, as this provides a more conservative estimate of emissions than the Fulton specification sheet. Maximum Monthly Gas Usage =31 days x 24 hr/day x Heat Rating (MMBtu/hr)/1,130 (Btu/scf) Maximum Annual Gas Usage = Heat Rating (MM Btu/hr) • 8760 hr/yr/ 1,130 (Btu/scf) Table 4.b. - Natural Gas -Fired Regenerator Heater - Emissions ' Defauit£mibsmnFactors4 UtuontrolledEmtssonsPdrUnhf, .f ",Tbta111neontroBerl'Emtsswns 2AB* ilbJ10e sct} .. ,: (Ib/MtABtu)X... ^�` ...ilb/hi) . r .. VeaP , ,� ^ Albf l+) Yf. ttons/Year) `° CO° - 0.037 0.88 3.84 1.75 7.67 NO5v - 0.018 0.42 1.85 0.84 3.70 PM/PM2o/PM5s 0.008 0.18 0.80 0.36 1.60 505 - 0.001 0.01 0.06 0.03 0.13 VOC - 0.006 0.13 0.58 0.26 1.16 ' Emission factors for NOx, CO, PM/PM5o/PM5s, 50, and VOC are from the Regenerator Heater Data Sheet provided by BCCK on April 27, 2018. 'Annual emissions are based on an eperat ng schedule of 24 hours/day, 365 days/year (i.e., 8,760 hours/year). Table 4.c. - Natural Gas -Fired Regenerator Heater - GHG emissions ti: ar U*0:irthalfed'Emtssons±?Fer.Umt A"r'.� x f btal3I *ito D ',missions" ftittErnrstonFactors NtriBiiirl3 S". � �'-i39liA[,.. ` � r1 :sM"� �n2 b % ir"a4 Q , CO2 53.06 2,807.43 12,296.53 5,614.85 24,593.05 CH,, 1.00E-03 5.29E-02 2.32E-01 0.11 0.46 N20 1.00E-04 5.29E-03 2.32E-02 0.01 0.05 CO5e - 2,810.33 12,309.22 5,620.65 24,618.45 'CO, emission factor obtained from 40 CFR 98 Subpart C, Table C3 for natural gas. a CH4 and N50 emission factors from 40 CFR 98 Subpart C, Table C-2 for natural gas. a Global warming potentials obtained from Table A-1 to Subpart 90- Global Warming Potentials Equation A-1 CO5e= FGHGi x GWPi Where: • CO5e =Carbon dioxide equivalent (tons/year) GHGi = Mass emissions of each GHG (tons/year)• GWPI = Global warming potential for each GHG (1 for CO,; 25 for CH,; 298 for N2O) Table 4.d. - Natural Gas -Fired Regenerator Heater - HAP emissions t'» *- Defatdt StrllsstonFadorSa=`°" UncontmifddEmleDans'AerUNt i 'TotafllncoestrD$edemEsstons•-2// 'Iib,(Mfletuj ...(mlbr' ` � „ IWO) %°s ... >IJi 2-Methylnaphthalene 2.4E-05 2.4E-08 5.6E-07 0.00 1.1E-06 9.89E-03 3-Methylchloranthrene 1.8E-06 1.8E-09 4.2E-08 0.00 8.5E-08 7.42E-04 7,12-Dimethylbenz(a)anthracene 1.6E-05 1.6E-08 3.8E-07 0.00 7.5E-07 6.60E-03 Acenaphthene 1.8E-06 1.8E-09 4.2E-08 0.00 8.5E-08 7.42E-04 Acenaphthylene 1.8E-06 1.8E-09 4.2E-08 0.00 8.5E-08 7.42E-04 Anthracene 2.4E-06 2.4E-09 5.6E-08 0.00 1.1E-07 9.89E-04 Benz(a)anthracene 1.8E-06 1.8E-09 4.2E-08 , 0.00 8.5E-08 7.42E-04 Benzene 2.1E-03 - 2.1E-06 4.9E-05 0.43 9.9E-05 8.66E-01 Benzo(a)pyrene 1.2E-06 1.2E-09 2.8E-08 0.00 5.6E-08 4.95E-04 Benzo(b)fluoranthene 1.8E-06 1.8E-09 4.2E-08 0.00 8.5E-08 7.42E-04 Benzo(g,h,i(perylene 1.2E-06 1.2E-09 2.8E-08 0.00 5.6E-08 4.95E-04 Benzo(k)fluoranthene 1.8E-06 1.8E-09 4.2E-08 0.00 8.5E-08 7.42E-04 Chrysene 1.8E-06 1.8E-09 4.2E-08 0.00 8.5E-08 7.42E-04 Dibenzo(a,h(anthracene 1.2E-06 1.2E-09 2.8E-08 0.00 5.6E-08 4.95E-04 Dichlorobenzene 1.2E-03 1.2E-06 2.8E-05 0.25 5.6E-05 4.95E-01 Fluoranthene 3.0E-06 2.9E-09 7.1E-08 0.00 1.4E-07 1.24E-03 Fluorene 2.8E-06 2.7E-09 6.6E-08 0.00 1.3E-07 1.15E-03 Formaldehyde 7.5E-02 7.4E-05 1.8E-03 15.46 3.5E-03 3.09E+01 Hexane 1.8E+00 1.8E-03 4.2E-02 371.01 8.5E-02 7.42E+02 Indeno(1,2,3-cd)pyrene 1.8E-06 1.8E-09 4.2E-08 0.00 8.5E-08 7.42E-04 Naphthalene 6.1E-04 6.0E-07 1.4E-05 0.13 2.9E-05 2.51E-01 Phenanathrene 1.7E-05 1.7E-08 4.0E-07 0.00 8.0E-07 7.01E-03 Pyrene 5.0E-06 4.9E-09 1.2E-07 0.00 2.4E-07 - 2.06E-03 Toluene 3.4E-03 3.3E-06 8.0E-05 0.70 1.6E-04 1.40E+00 Total HAPs 4.43E-02. 388.00 5.86E-02 775.99 ' Emission factor from AP -42 Chapter 1 Section 4— Natural Gas Combustion Table 1.4-3- Emission Factors for speciated Organic Compounds from Natural Gas Combustion, dated July 1998. To adjust for the natural gas heat rating the emission factor was then multiplied by (1130/1,020). Boiler APEN - Form APCD-220 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing f updates. An application with missing information may be determined incomplete and longer application processing times. You may be charged an additional APEN fee if t incorrectly or is missing information and requires re -submittal. Tities,: including APEN e• suit in This APEN is to be used for boilers, hot oil heaters, process heaters, and similar equipment. If your emission unn does not fall into one of these categories, there may be a more specific APEN for your source (e.g. paint booths, mining operations, engines, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution - Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. Do not complete this form for the following source categories: - Heaters or boilers with a design capacity less than or equal to 5 MMBtu/hour that are fueled solely by natural gas or liquid petroleum gas (LPG). Heaters or boilers with a design capacity less than or equal to 10 MMBtu/hour used solely for heating buildings for personal comfort that is fueled solely by natural gas or liquid petroleum gas (LPG). More information can be found in the APEN exempt/permit exempt checklist: https: //www.colorado.Rov/pacific/cdphe/apen-orair-permit-exemptions. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, ILC. for revised APEN requirements. Permit Number: 18WE0274 AIRS ID Number: t / 6rrn I P3 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 Administrative Information Company Name': Discovery DJ Services LLC Site Name: Discovery Keenesburg Gas Plant Site Location: Section 17, T2N, R63W Mailing Address: (Include Zip code) 3601 Stagecoach Road, Ste. 202 Longmont CO 80504 E -Mail Address2: mnorton@discoverymidstream.com Site Location County: Weld NAILS or SIC Code: 213112 Permit Contact: Matthew Norton Phone Number: (817) 455-5799 I Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear onall documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-220 - Boiler APEN - Revision 11/2017 1 l J . o..,+.: rs,cse iii��.liii!!! ).r.+hht.461crtnnmem. Permit Number: 18WE0274 AIRS ID Number: [Leave blank unless APCD has already assigned a permit ft and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source -OR- ❑✓ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name 0 Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership3 Other (describe below) OR ❑ APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) O APEN submittal for permit exempt/grandfathered source Additional Info Et Notes: Updates to reflect new plant name, change in location. 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCa-104) must be submitted. Section 3 - General Boiler Information General description of equipment and purpose: 2 x 24.0 MMBtu/hr Natural Gas -Fired Regenerator Heaters for the Molecular Sieve Dehydration System Manufacturer: TBD Model No.: TBD Serial No.: TBD Company equipment Identification No. (optional): H3/H4 For existing sources, operation began on: For new, modified, or reconstructed sources, the projected start-up date is: 10/1/2018 El Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day days/week weeks/year Seasonal use percentage: Dec -Feb: Mar -May: June -Aug: Sept -Nov: Are you reporting multiple identical boilers on this APEN? 0 Yes ❑ No If yes, please describe how the fuel usage will be measured for each boiler (i.e., one meter for all boilers or separate meters for each unit): Separate meters for each unit Form APCD-220 - Boiler APEN - Revision 11/2017 AVI,COLORADO Permit Number: 8WE0274 AIRS ID Number: [Leave blank unless APCD has already assigned a permit ft and AIRS ID] Section 4 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 545766.00 E, 4443650.00 N Operator Stack ID: No eig Discharge Hht Above Ground Level (Feet) ,• Temp ( F) Flow Rate , (ACfM) Velocity (ft/sec) H3/H4 TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) ❑✓ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) E Circular ❑ Square/rectangle Interior stack width (inches): 0 Other (describe): Interior stack diameter (inches): 0 Upward with obstructing raincap 24" Interior stack depth (inches): Section 5 - Fuel Consumption Information Design Input Rate (MMBTUIhr) Actual Annual Fuel Use4 (Specify Units) Requested Annual Permit Limits (Specify Units) 24.0 MMBtu/hr (each) 186.05 MMscf/yr/unit From what year is the actual annual fuel use data? Fuel consumption values entered above are for: ❑ Each Boiler 0 All Boilers D N/A Indicate the type(s) of fuel used6: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) ❑ Field Natural Gas Heating value: BTU/SCF 0 Ultra. Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTU/SCF) ❑ Coal Heating value: BTU/lb Ash content: El Other (describe): Residue Natural Gas Heating value (give Sulfur Content: units): 1,130 Btu/scf 4 If you are reporting multiple identical boilers on one APEN, be sure to clarifyy if the values in this section are on an individual boiler basis, or if the values represent total fuelusage for multiple boilers. 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 If fuel heating value is different than the listed assumed value, please provide this information in the "Other" field. •COLOAAoo Form APCD-220 - Boiler APEN - Revision 11/2017 Permit Number: 18WE0274 AIRS ID Number: [Leave blank unless APCD has already assigned a permit N and AIRS ID] Section 6- Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑ Yes ® No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Control Efficiency (% reduction in emissions) TSP (PM) PM -I° PM2.5 50X NO), CO VOC Other: From what year is the following reported actual annual emissions data? Use the following tables to report the criteria pollutant emissions from source: (Use the data reported in Section 5 to calculate these emissions.) Primary Fuel Type (natural gas, #2 diesel, etc.) TSP (PM) Uncontrolled Emission Factor (Specify Units) Emission Factor Source (AP -42, Mfg. etc) Controlled (Tons/year) nested Annual; mission Lim t Uncontrolled (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) Residue Natural Gas 8.59 Ib/MMSCF Mfg, 1.60 1.60 PMio 8.59 lb/MMSCF Mfg. 1.60 1.60 PM2.5 8.59 lb/MMSCF Mfg. 1.60 1.60 SOX 0.68 lb/MMSCF AP -42 0.13 0.13 NO), 19.9 Ib/MMSCF Mfg. 3.70 3.70 CO 41.3 lb/MMSCF Mfg. 7.67 7.67 VOC 6.22 Ib/MMSCF Mfg. 1.16 1.16 Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 7 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-220 - Boiler APEN - Revision 11/2017 COLORADO 4 I,rs TSP (PM) Permit Number: 18WE0274 AIRS ID Number: [Leave blank unless APCD has already assigned a permit N and AIRS ID] Check this box if the boiler did not combust a secondary fuel during this reporting period and skip to Section 7. If multiple fuels were fired during this reporting period, complete this secondary fuel emissions table and the total criteria emissions table below: Secondary Fuel Type. (#2 diesel,. waste oil, etc.) Pollutant. Uncontrolled Emission Factor (Specify Units). Emission Factor Source (AP -42, Mfg. etc) Uncontrolled (Tonslyear) Controlled7 (Tons/year) Requested Annual Permit Emission Limit(s)5 Uncontrolled (Tons/year) Controlled (Tons/year) TSP (PM) PM1 o PM2.s SOx NOx CO VOC Other: If multiple fuels were fired during this reporting period, use the following table to report the TOTAL criteria pollutant emissions from the source. Values listed below should be the sum of the reported emissions from the primary and secondary fuels' emissions tables in this Section 6: Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Uncontrolled (Tons/year) Controlled7 (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) PM10 PM2.5 SOx NO. CO VOC Other: 5 Requested values will become permit limitations. Requested timit(s) should consider future process growth. 7 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. ' Form APCD-220 - Boiler APEN Revision 11/2017 COLORADO 5 I .110717,7,'=,',!,=,„ Permit Number: 18WE0274 AIRS ID Number: [Leave blank unless APCD has already assigned a permit !i and AIRS ID] Section 7 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP- hazardous air pollutant) equal to or greater than 250 lbs/year? ❑ Yes ❑ No If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: CAS Number Chemical Name Overall Control Efficiency Uncontrolled Emission Factor (specify units) Emission Factor Source (AP -42, Mfg. etc) Uncontrolled Actual Emissions (lbs/year) Controlled Actual Emissions? (lbs/year) 110543 Hexane N/A 1.99 lb/MMSCF AP -42 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-220 - Boiler APEN - Revision 11/2017 6 IAlai' :COLORADO Rgwrsmm r.; n_ec w..mntrcrrro��-.,, Permit Number: 18WE0274 AIRS ID Number: [Leave blank unless APCD has already assigned a permit It and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. ,4 Signature of Legally Authorized /1% Name (please print) J erson not a vendor or consultant) 1 i pr EAR, 1Ql.iri+ Title Date 644 C1d1- Check the appropriate box if you want: ❑Q Draft permit prior to public notice O Draft of the permit prior to issuance (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado. Department of Public Health and Environment Telephone: (303) 692-3150 For moreinformation or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692- 3148 Or visit the APCD website at: https: //www.colorado.gov/cdphe/apcd Form APCD-220 - Boiler APEN - Revision 11/2017 7 I AYCOLORADO ue>+-zner .: Emissions Permit/APEN Caneellati©r " co Request - Form APCD-107 Air Pollution Control Division Stationary Sources Program AR sections of this Emissions PermitJAPEN Cancellation Request must be completed for ai Emissions Permit or APEN and submitted to the Colorado Department of Public Health and A Pollution Control Division (APCD). A cancellation request with missing information may be determined incomplete and may be returned or result in a longer cancellation processing time. Section 1 - Administrative Information Please note, specific facility information needed for this section can be found on your facility's emissions permit on the bottom left corner of each page. in the.facility's emissions permit equipment descr i tionis), or on your most recent Annual Emission Fee invoice, AIRS ID(s): Equipment Description: Owner or Operator of Permit: Facility or Equipment Address: Sulfur Treating Process Heater Permit Number(s): 18WE0274 Cory G. Jordan Section 29, TIN. R63W Permit Contact: Matthew Norton • ,Mailing Address: 3601 Stagecoach Road, Ste. 202 Longmont, CO 80504 Phone Number: (817) 455-5799 Email Address: mnorton@discoverymidstream.com Date Facility or Equipment Ceased or Went Below Reporting Thresholds: 4 J 26 / 2018 Section 2 - Reason for Emissions Permit/APEN Cancellation 1] The facility or equipment addressed by the permit or APEN no longer exists. ❑ The facility or equipment has been sold to another party and I do not wish to transfer the permit. ❑. ❑i The facility or equipment has dropped below reporting thresholds. The permit was previously required solely because the emissions unit was subject to NSPS or MACT/NESHAP requirements that were adopted. into Colorado Regulations (see PS Memo 14-01 for more info). This cancellation request is for (check appropriate box): ❑ Permit Only The unit is still active. The permit wilt be cancelled, but the APEN will remain active because emissions are above APEN- reporting threshoids. The emissions unit is now subject to one of the general exemption letters found on the following cage of the APCD website: baps: i»ww._olorado.sovioadficicdohelair-permittine-cancellatto -exem^*-s scesi O Permit a APEN iBoth the permit and the APEN wilt he cancelled. The unit is stilt active, but enessions are below APEN-reperr ing t 0. eshctds-1 ' Please review the information on the following page of the APCD website before selecting this option: httos: !!wsw. colorado.eov/pacifici cdohe ! air -permitting -cancellation -exempt -sources. Section 3 - Owner or Operator Certification I have reviewed this cancellation request in its entirety and 1 hereby certify that all information contained herein is true, accurate, and complete. Signature of Legally Authorized Pers Matthew T. Berghorn, P.E. Hattie (please print) not a vendor or consultant) Date VP - Engineering and Construction Title Send completed form to: CDPHE - Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Telephone: 1303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https:l iwww.colorado. gov! raci`ici cdohe /aocd Form APCD-107 AyY HQ Boiler APEN - Form APCD-220 Atto, Air Pollutant Emission Notice (APEN) and _ X018 Application for Construction Permit /1/5 All sections of this APEN and application must be completed for both new and existing fide updates. An application with missing information may be determined incomplete and may be re longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and rewires re -submittal. This APEN is to be used for boilers, hot oil heaters, process heaters, and similar equipment. If your emission unit does not fall into one of these categories, there may be a more specific APEN for your source (e.g. paint booths, mining operations, engines, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. Do not complete this form for the following source categories: - Heaters or boilers with a design capacity less than or equal to 5 MMBtu/hour that are fueled solely by natural gas or liquid petroleum gas (LPG). Heaters or boilers with a design capacity less than or equal to 10 MMBtu/hour used solely for heating buildings for personal comfort that is fueled solely by natural gas or liquid petroleum gas (LPG). More information can be found in the APEN exempt/permit exempt checklist: https: / /www.colorado.Rov/pacific/cdphe/apen-or-air-permit-exemptions. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: AIRS ID Number: ( Z3 / tFAT/ do`i [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name1: Site Name: Discovery DJ Services LLC Discovery Kiowa Gas Plant Site Location: Section 29, Ti N, R63W Mailing Address: (Include Zip Code) 3601 Stagecoach Road, Ste. 202 Longmont, CO 801504 E -Mail Address2: mnorton@discoverymidstream.com Site Location County: Weld NAICS or SIC Code: 213112 Permit Contact: Matthew Norton Phone Number: (817) 455-5799 I Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-220 - Boiler APEN - Revision 11 /2017 37626a 1 i • CO COLORADO Dcpustmox Kant. bEmlrcnnnRl Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action 0 NEW permit OR newly -reported emission source - OR MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment 0 Change company name ❑ Add point to existing permit ❑ Change permit limit El Transfer of ownership3 0 Other (describe below) OR - • APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) O APEN submittal for permit exempt/grandfathered source Additional Info & Notes: 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Boiler Information General description of equipment and purpose: One 12.0 MMBtu/hr Indirect -Fired Bath - Style Line Heater for the Sulfur Treating System Manufacturer: TBD Model No.: TBD Serial No.: TBD Company equipment Identification No. (optional): H5 For existing sources, operation began on: For new, modified, or reconstructed sources, the projected start-up date is: 10/1/2018 0 Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day Seasonal use percentage: Dec -Feb: Mar -May: days/week June -Aug: Sept -Nov: weeks/year Are you reporting multiple identical boilers on this APEN? ❑ Yes ❑✓ No If yes, please describe how the fuel usage will be measured for each boiler (i.e., one meter for all boilers or separate meters for each unit): Form APCD-220 - Boiler APEN - Revision 11/2017 2 4 co COLORADO NnRA i EmlrenrtwN Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Stack Information eographical Coordinates Latitude/Longitude or UTM)_ 545392.68 E, 4429852.38 N �`. Operator Discharge ', eight , ov o n Level (,4 d � �Te F. A�� Flow ae� � r �,yum, ` �`� � t M Vel • ci tY� �.. H5 TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) ❑✓ Upward ❑ Horizontal Downward ❑ Other (describe): Indicate the stack opening and size: (check one) E] Circular ❑ Square/rectangle Interior stack width (inches): El Other (describe): Interior stack diameter (inches): ❑ Upward with obstructing raincap Interior stack depth (inches): Section 5 - Fuel Consumption Information Design Input Rate. (MMBTU/hr) = .. - �: Actual Annual Fuel Use¢ (Specify Units) Requested Annual Permit ='5 Limit - Specify Units) 12.0 MMBtu/hr 93.03 MMscf/yr From what year is the actual annual fuel use data? Fuel consumption values entered above are for: El Each Boiler ❑ All Boilers ❑� N/A Indicate the type(s) of fuel used6: ❑ Pipeline Natural Gas O Field Natural Gas ❑ Ultra Low Sulfur Diesel ❑ Propane 0 Coal ❑✓ Other (describe): (assumed fuel heating value of 1,020 BTU/SCF) Heating value: BTU/SCF (assumed fuel heating value of 138,000 BTU/gallon) (assumed fuel heating value of 2,300 BTU/SCF) Heating value: BTU/lb Ash content: Sulfur Content: Residue Natural Gas Heating value (give units): 1,130 Btu/scf 4 If you are reporting multiple identical boilers on one APEN, be sure to clarify if the values in this section are on an individual boiler basis, or if the values represent total fuel usage for multiple boilers. 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 If fuel heating value is different than the listed assumed value, please provide this information in the "Other" field. Form APCD: 220 - Boiler APEN - Revision 11/2017 3 COLORADO TSP (PM) Permit Number: AIRS ID Number: / I [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6- Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? O Yes ® No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): Control Equipment Description Overall Control Efficiency (%reduction in emissions) ., PMio PM2.5 SOX NOX CO VOC Other: From what year is the following reported actual annual emissions data? Use the following tables to report the criteria pollutant emissions from source: (Use the data reported in Section 5 to calculate these emissions.) TSP (PM) Residue Natural Gas Uncontrolled Emission Factor (Specify Units) Emission Factor Source (AP -42, -Mfg. etc)-_ Uncontrolled (Tons/year) Controlled `(Tons/year)" Uncontrolled. " (Tons/year) Controlled: (Tins/ye-64'_ 8.42 Ib/MMSCF AP -42 0.39 0.39 PMi o 8.42 Ib/MMSCF AP -42 0.39 0.39 PM2.5 8.42 Ib/MMSCF AP -42 0.39 0.39 SOX 0.66 lb/MMSCF AP -42 0.03 0.03 NOX 110.8 Ib/MMSCF AP -42 5.15 5.15 CO 93.1 lb/MMSCF AP -42 4.33 4.33 VOC 6.09 Ib/MMSCF AP -42 0.28 0.28 Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 7 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-220 - Boiler APEN - Revision 11/2017 4 I Co COLOR A DO Dgparbeentethebik IommDu Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] 0 Check this box if the boiler did not combust a secondary fuel during this reporting period and skip to Section 7. If multiple fuels were fired during this reporting period, complete this secondary fuel emissions table and the total criteria emissions table below: Secondary Fuel Type. (#2 diesel,' waste oil etc.) TSP (PM) Uncontrolled Emission Factor (Specify Units) Emission Factor Source (AP -42, Mfg. etc) Uncontrolled (Tons/year) Controlled' (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year), PM10 PM2.5 SOx NOx CO VOC Other: If multiple fuels were fired during this reporting period, use the following table to report the TOTAL criteria pollutant emissions from the source. Values listed below should be the sum of the reported emissions from the primary and secondary fuels' emissions tables in this Section 6: TSP (PM) Uncontrolled Controlled? (Tons/year) (Tonslyear)' Uncontrolled (Tons/year) Controlled - (Tonslyear) PMio PM2.5 SOX NOx CO VOC Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 7 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-220 - Boiler APEN - Revision 11/2017 5 I COLORADO nepotomee wlmux MORI F.m116nm1N Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP- hazardous air pollutant) equal to or greater than 250 lbs/year? ❑ Yes ® No If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: CAS Number Chemical Name Overall Control Efficiency. Uncontrolled Emission Factor (specify units) Emission Factor Source (AP -42, Mfg. etc) Uncontrolled Actual Emissions (lbslyear) Controlled Actual Emissions (Ibs/year) Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-220 - Boiler APEN - Revision 11/2017 6IAY COLORADO Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. 3-,- g Signature of Legally Au ho zed Person (not a vendor or consultant) Date Matthew T. Berghorn, P.E. VP - Engineering and Construction Name (please print) Title Check the appropriate box if you want: ❑� Draft permit prior to public notice O Draft of the permit prior to issuance (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692- 3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-220 - Boiler APEN - Revision 11/2017 71 Co COLORADO aye.mmmheue xwm►En t enm.M /-t FEN 4.1)e.,.J taw` �td'f ►�c� Produced Water Storage APEN - Form APCD-207 Air Pollutant Emission Notice (APEN) and Application for Construction Permit 00, o„,,, All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for tanks that store produced water associated with oil and gas industry operations. If your emission source does not fall into this category, there may be a more specific APEN available for your source (e.g. crude oil storage tanks, condensate storage tanks, hydrocarbon liquid loading, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/pacific/cdphe/air-permits. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: (6 wo2:4-`f AIRS ID Number: 18/8 113 /IFA- -i 005 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Discovery DJ Services LLC Site Name: Discovery Kiowa Gas Plant Site Location: Section 29, T1 N, R63W Mailing Address: (Include Zip Code) 3601 Stagecoach Road, Ste. 202 Longmont, CO 80504 Site Location County: Weld NAICS or SIC Code: 213112 Permit Contact: Matthew Norton Phone Number: (817) 455-5799 E -Mail Address: mnorton@discoverymidstream.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on alt documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 07/2017 376264 COLORADO i I I»°'d Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑� NEW permit OR newly -reported emission source ✓❑ Request coverage under traditional construction permit ❑ Request coverage under a General Permit ❑ GP05 ❑ GP08 If General Permit coverage is requested, the General Permit registration fee of $250 must be submitted along with the APEN filing fee. -OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change in equipment ❑ Change company name ❑ Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below) - OR ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ID APEN submittal for permit exempt/grandfathered source O Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info a Notes: 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: For existing sources, operation began on: 2 x 1,000 -bbl Slop Storage Tanks For new or reconstructed sources, the projected start-up date is: 10/1/2018 Normal Hours of Source Operation: 24 hours/day 7 days/week 52 Storage tank(s) located at: 0 Exploration Et Production (EftP) site weeks/year ❑✓ Midstream or Downstream (non EftP) site Will this equipment be operated in any NAAQS nonattainment area? • Yes • No Are Flash Emissions anticipated from these storage tanks? ■ Yes TA No Are these storage tanks located at a commercial facility that accepts oil production• wastewater for processing? Yes No MI Do these storage tanks contain less than 1% by volume crude oil on an annual average basis? TA Yes ❑ No Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. Yes No • TA Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual emissions ≥ 6 ton/yr (per storage tank)? Yes No U TA Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 07/2017 2I COLORADO Rm.&Em reemser D Upward ❑ Horizontal Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit +5 and AIRS ID] Section 4 - Storage Tank(s) Information Actual Annual Amount (bbl/year) Requested Annual Permit Limit4 (bbl/year) Produced Water Throughput: 376,000 From what year is the actual annual amount? Tank design: El Fixed roof ❑ Internal floating roof ❑ External floating roof Storage Tank ID # of Liquid Manifold Storage Vessels in Total Volume of (bbl) Installation Date of Most Storage Tank Storage Tank Recent Storage Vessel in Production Storage Tank (month/year) Date of First (month/year) ST 2 2,000 (1,000 each) N/A N/A Wells Serviced by this Storage Tank or Tank Battery5(EftPSites Only) PI Number Name of Well Newly Reported Well 0 0 0 0 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 5 The E&P Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space.is needed to report all wells that are serviced by the equipment reported on this APEN form. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 545262.55 E, 4429981.60 N Operator Stack ID No. Discharge Height Above Ground Level (feet) ` Temp. (°F) Flow Rate (ACFM) Velocity (ft/sec) ST TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) Q Circular ❑ Square/rectangle 0 Other (describe): Interior stack diameter (inches): Interior stack width (inches): ❑ Upward with obstructing raincap TBD Interior stack depth (inches): Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 07/2017 3 1 co COLORADO Deparrnar R. hIIfE Nonieleei Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit rt and AIRS ID] Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Pollutants Controlled: Vapor ❑ Recovery Unit (VRU): Size: Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): Make/Model: ❑ Combustion Device: Pollutants Controlled: VOC, HAPs Rating: 2.0 MMBtu/hr Type: Combustor Make/Model: TBD Requested Control Efficiency: 95 % Manufacturer Guaranteed Control Efficiency: 95 % Minimum Temperature: Waste Gas Heat Content: Constant Pilot Light: E Yes ❑ No Pilot Burner Rating: 1,999.81 0.23 Btu/scf MMBtu/hr ❑ Closed Loop System Description of the closed loop system: ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested: Section 7 -Gas/Liquids Separation Technology Information (E&P Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? psig Describe the separation process between the well and the storage tanks: Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 07/2017 4 I m`_ Depummintahfillbr COLORADO x.. c • Benzene Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form6. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined) control efficiency (% reduction): pollutant Combustor Overall Requested Control Efficiency (% reduction in emissions) VOC 95 NOx CO HAPs Combustor 95 Other: From what year is the following reported actual annual emissions data? Criteria Pollutant Emissions Inventory Pollutant Uncontrolled Basis 0.07 Ib/BBL E&P Tanks Source (AP -42, Mfg. etc) Actual Annual Emissions Requested Annual Permit Emission Limit(s)4 Uncontrolled Emissions (Tons/year) Controlled Emissions? (Tons/year) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) VOC 13.85 0.69 NOx CO Non -Criteria, Reportable Pollutant Emissions Inventory hemicat Abstract -Service (CAS) Number Emission: Factor°;: ActuaLAnnual Emissions_ - Uncontrolled Basis Units Source - (AP -12, - Mfg. etc) Uncontrolled Emissions (Pounds/year) Controlled Emissions? (Pounds/year) -. 71432 4.78E-04 lb/BBL E&P Tanks 179.72 8.99 Toluene 108883 2.61 E-04 lb/BBL E&P Tanks 98.02 4.90 Ethylbenzene 100414 2.17E-05 lb/BBL E&P Tanks 8.16 0.41 Xylene 1330207 4.22E-05 lb/BBL E&P Tanks 15.87 0.79 n -Hexane 110543 7.84E-03 Ib/BBL E&P Tanks 2,946.66 147.33 2,2,4- Trimethylpentane 540841 2.55E-06 Ib/BBL E&P Tanks 0.96 0.05 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 6 Attach produced water laboratory analysis, stack test results, and associated emissions calculations if you are requesting site specific emissions factors according to the guidance in PS Memo 14-03. 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 07/2017 5 CO COLORADO Department. n.b& Permit Number: AIRS ID Number: / I [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under General Permit GP05 or GP08, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. Signature of Legally Aut zed Person (not a vendor or consultant) Date Matthew T. Berghorn, P.E. VP - Engineering and Construction Name (print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance �✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit For more information or assistance call: registration fee of $250, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 07/2017 6 I ICOLORADO fT Produced Water Storage k(s) APEN — Form APCD-2o Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, includingEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for tanks that store produced water associated with oil and gas industry operations. If your emission source does not fall into this category, there may be a more specific APEN available for your source (e.g. crude oil storage tanks, condensate storage tanks, hydrocarbon liquid loading, etc.). bi addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/pacific/cdphe/air-permits. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 18WE0274 AIRS ID Number: k;.3 //) S [Leave blank unless APCD has already assigned a permit i/ and AIRS ID] Section 1 - Administrative Information Company Name': Discovery DJ Services LLC Site Name: Discovery Keenesburg Gas Plant. Site Location: Section 17, T2N, R63W Mailing Address: (include Zip Code) 3601 Stagecoach Road, Ste. 202 Longmont, CO 80504 Site Location County: Weld NAICS or SIC Code: 213112 Permit Contact: Matthew Norton Phone Number: (817) 455-5799 E -Mail Addressz: mnorton@discoverymidstream.com i Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear onall documents issued by the APCD. My changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 07/2017 AW.00L0RAD0 1 i L3' Permit Number: 18 WE0274 AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action El NEW permit OR newly -reported emission source ❑ Request coverage under traditional construction permit ❑ Request coverage under a General Permit O GP05 ❑ GP08 If General Permit coverage is requested, the General Permit registration fee of $250 must be submitted along with the APEN filing fee. -OR- Q MODIFICATION to existing permit (check each box below that applies) O Change in equipment ❑ Change company name O Change permit limit ❑ Transfer of ownership3 0 Other (describe below) -OR - ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - • APEN submittal for permit exempt/grandfathered source ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info a Notes: Updates to reflect new plant name, change in location. 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: For existing sources, operation began on: 2 x 1,000 -bbl Slop Storage Tanks For new or reconstructed sources, the projected start-up date is: 10/1/2018 Normal Hours of Source Operation: 24 Storage tank(s) located at: hours/day 7 days/week 52 ❑ Exploration E Production (E&P) site weeks/year (] Midstream or Downstream (non EEP) site Will this equipment be operated in any NAAQS nonattainment area? GI Yes • No Are Flash Emissions anticipated from these storage tanks? ■ Yes 151 No Are these storage tanks located at a commercial facility that accepts oil productionII wastewater for processing? Yes No D Do these storage tanks contain less than 1% by volume crude oil on an annual average basis? F Yes ■ No Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. Yes No • ® Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual emissions ≥ 6 ton/yr (per storage tank)? Yes No • GI Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 07/2017 CO'LO it ADD 2 I C<i+n-rx.r,r P.,v Permit Number: 18WE0274 AIRS ID Number: [Leave blank unless APCD has already assigned a permit it and AIRS ID] Section 4 - Storage Tank(s) Information Actual Annual Amount (bbl/ year) Requested Annual Permit Limit' (bbl/year) Produced Water Throughput: 376,000 From what year is the actual annual amount? Tank design: ❑r Fixed roof ❑ Internal floating roof O External floating roof Storage Tank ID # of Liquid Manifold Storage Vessels in Storage Tank Total Volume of Storage Tank (bbl) Installation Date of Most Recent Storage Vessel in Storage Tank (month/year) Date of First Production (month/year) ST 2 2,000 (1,000 each) N/A N/A Wells Serviced by this Storage Tank or Tank Battery5'(E>*P Sites On y) API Number Name of Well Newly Reported Well - - ■ - - ■ - - ■ - - • - - ■ 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 5 The EEP Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to report all wellsthat are serviced by the equipment reported on this APEN form. Section 5 Stack Information Geographical Coordinates (Latitude/Longitude.or UTM) 545691.00 E, 4443501.00 N Operator Stack ID No. Discharge Height Above Ground Level (feet) Temp. (°F) Flow Rate (ACFM) Velocity (ft/sec) ST TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) El Upward O Horizontal O Downward O Other (describe): Indicate the stack opening and size: (check one) 0 Circular ❑ Square/rectangle ❑ Other (describe): ❑ Upward with obstructing raincap Interior stack diameter (inches): TBD Interior stack width (inches): Interior stack depth (inches): Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 07/2017 �/�\' COLORADO 3 I . Al i =,;',717-,Z=11, Permit Number: 18WE0274 AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Vapor ❑ Recovery Unit (VRU): Pollutants Controlled: Size: Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): Make/Model: r❑ Combustion Device: Pollutants Controlled: VOC, HAPs Rating: 2.0 Type: Combustor MMBtu/hr Make/Model: T B D Requested Control. Efficiency: 95 Manufacturer Guaranteed Control Efficiency: Minimum Temperature: Constant Pilot Light: IJ Yes O No Pilot Burner Rating: 95 Waste Gas Heat Content: 1,999.81 0.23 Btu/scf MMBtu/hr O Closed Loop System Description of the closed loop system: O Other: Pollutants Controlled: Description: Control Efficiency Requested: Section 7 -Gas/Liquids Separation Technology Information (EttP Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? psig Describe the separation process between the well and the storage tanks: Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 07/2017 �j COtORADO 4 I r}\ , Drpar—v:m _r r�:r Lim Permit Number: 18WE0274 AIRS ID Number: [Leave blank unless APCD has already assigned a permit tl and AIRS ID] Section 8 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form6. if multiple emission control methods were identified in Section 6, the following table can be used to state the overall Pollutant Description of Control Method(s) Overall Requested Control Efficiency . (% reduction in emissions) VOC Combustor 95 NOx CO HAPs Combustor 95 Other: From what year is the following reported actual annual emissions data? Criteria Pollutant Emissions Inventory Pollutant Emission Factor6 Actual Annual Emissions Requested Annual Permit Emission Limi4 t(s) Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Tons/year) Controlled Emissions? (Tons/year) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) VOC 0.07 lb/BBL E&P Tanks 13.85 0.69 NOx CO Non -Criteria Reportable Pollutant Emissions Inventory, Chemical Name Chemical Abstract Service (CAS) Number Emission Factor6 Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Pounds/year) Controlled 7 Emissions.. (Pounds/year) Benzene 71432 4.78E-04 lb/BBL E&P Tanks Toluene 108883 2.61E-04 lb/BBL E&P Tanks Ethylbenzene 100414 2.17E-05 Ib/BBL E&P Tanks Xylene 1330207 4.22E-05 Ib/BBL. E&P Tanks n -Hexane 110543 7.84E-03 lb/BBL E&P Tanks 2,2,4-540841. Trimethyipylpentane 2.55 E-06 Ib/BBL E&P Tanks 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 6 Attach produced water laboratory analysis, stack test results, and associated emissions calculations if you are requesting site specific emissions factors according to the guidance in PS Memo 14-03. 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yetstarted operating, leave blank. Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 07/2017 5 I AV COLORADO ,:m. s trv=.ovm.m Permit Number: 18WE0274 AIRS ID Number: [Leave blank unless APCD has already assigned a permit ft and AIRS ID] Section 9 - Applicant Certification I hereby certify that alt information contained herein and' information submitted with this application is complete, true and correct. If this is a registration for coverage under General Permit GP05 or GP08, I further certify that this source is and will be operated in full compliance with each condition of the applicable General. Permit. 3--/r Signature of Legally AuthorizAl Person (not a vendor or consultant) Date Matthew T. Berghorn, P.E. VP - Engineering and Construction Name (print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance D✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit registration fee of $250, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 07/2017 6 I AV Z.:4',.77,',"::',1;',-- COLORADO 54,-f se.,jC) • A N 11-)d /y f'f t•ccie c f . 5 . A ty ) Hydrocarbon Liquid Loading APEN Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for Hydrocarbon Liquid Loading only. If your emission unit does not fall into this category, there may a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: V v v o 2,1-9 AIRS ID Number: (23 /1F44/ an6 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: LT [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Discovery DJ Services LLC Site Name: Discovery Kiowa Gas Plant Site Location: Section 29, T1 N, R63W Mailing Address: (Include Zip Code) 3601 Stagecoach Road, Ste. 202 Longmont, CO 80504 E -Mail Address`: mnorton@discoverymidstream.com Site Location County: Weld NAICS or SIC Code: 213112 Permit Contact: Matthew Norton Phone Number: (817) 455-5799 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional -paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-208 - Hydrocarbon Liquid Loading APEN - Rev 02/2017 37626511 AycoLoaAao Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action 1 NEW permit OR newly -reported emission source ❑r Request coverage under construction permit ❑ Request coverage under General Permit GP07 If General Permit coverage is requested, the General Permit registration fee of $250 must be submitted along with the APEN Filing fee. -OR - ❑ MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment O Change company name O Change permit limit ❑ Transfer of ownership3 O Other (describe below) - OR • APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - El Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Truck loadout of slop For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: / / 10/ 1 /2018 Will this equipment be operated in any NAAQS nonattainment area? Is this equipment located at a stationary source that is considered a Major Source of (HAP) emissions? Does this source load gasoline into transport vehicles? Is this source located at an oil and gas exploration and production site? If yes: Does this source load less than 10,000 gallons of crude oil per day on an annual average? .- Does this source splash fill less than 6750 BBL of condensate per year? Does this source submerge fill less than 16308 BBL of condensate per year? O Yes O No ❑ Yes O No ❑ Yes 0 No ❑ Yes ❑✓ No O Yes ❑ No O Yes ❑ No O Yes ❑ No Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 Ti Q COLORADO 2IA.• xotmo-snvunnm.wt Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Process Equipment Information Product Loaded: ❑ Condensate O Crude Oil ❑r Other: Slop (50% Water/50% Condensate) If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Requested Volume Loaded4: 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth 376,000 Bbl/yr This product is loaded from tanks at this facility into: (eg, "rail tank cars" or "tank trucks") Actual Volume Loaded: Tank Trucks Bbl/yr If site specific emission factor is used to calculate emissions, complete the following: Saturation Factor: Average temperature of bulk liquid loading: °F True Vapor Pressure Psia @ 60 °F Molecular weight of displaced vapors Lb/lb mol If this APEN is being filed for vapors displaced from pressurized loading lines, complete the following: Requested Volume Loaded5: Bbl/yr Actual Volume Loaded: Bbl/yr 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth_ Product Density: Lb/ft3 Load Line Volume: ft3/truckload Vapor Recovery Line Volume ft3/truckload Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 COLORADO 3 1 per mug Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Geographical Information Geographical Coordinates (Latitude/Longitude orUTM) 545260.40 E, 4429982.88 N y, �schre�e� r ,. Tanks Combustor TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) 0 Upward O Horizontal ❑ Downward O Other (describe): Indicate the stack opening and size: (check one) Q Circular Interior stack diameter (inches): ❑ Other (describe): O Upward with obstructing raincap TBD Section 6 - Control Device Information O Loading occurs using a vapor balance system: Requested Control Efficiency % D Device: Combustion Pollutants Controlled: VOC, HAPs Rating: 2.0 MMBtu/hr Type: Combustor Make/Model: TBD Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: 95 95 Waste Gas Heat Content Constant Pilot Light: ✓❑ Yes O No Pilot burner Rating 1,999.81 0.23 Btu/scf MMBtu/hr ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested 0 Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 �R ,cOLOADD 4 °R"°�"aw"" PM PM Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? (] Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Control Equipment "Description Overall Requested Control Efficiency (% reduction in emissions) SOX NOx CO VOC Combustor 95 HAPs Combustor 95 Other: ❑✓ Using State Emission Factors (Required for GP07) VOC Q Condensate ❑ Crude 0.236 Lbs/BBL 0.104 Lbs/BBL Benzene n -Hexane 0.00041 Lbs/BBL 0.0036 Lbs/BBL 0.00018 Lbs/BBL 0.0016 Lbs/BBL From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Uncontrolled - Emission Factor Emission Factor'" Units Emission- Factor Source (AP -42, Mfg. etc) Controlleds (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) Uncontrolled (Tons/year) • `, SOX NOx VOC 0.236 Ib/BBL CDPHE 44.45 2.22 CO Benzene 0.0041 Ib/BBL CDPHE 0.08 0.00 Toluene Ethylbenzene Xylenes n -Hexane 0.0036 Ib/BBL CDPHE 0.68 0.03 2,2,4- Trimethylpentane Other: 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 gCOLORADO 5 I � ! Honinuu a..,�e at Public wa e m n.m • Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under General Permit GP07, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. Signature of Legally Authotized Person (not a vendor or consultant) Date g g Y Matthew T. Berghorn, P.E. VP - Engineering and Construction Name (print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance Draft permit prior to public notice (Checking any of these boxes may result in as increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit registration fee of $250 as applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 6 I m2 COLORADO e ealth6e`Ew Ha ini Hydrocarbon Liquid Loading APEN — Air Pollutant Emission Notice (APEN) and Application for Construction Permit _5 APCD-k8-,711B All sections of this APEN and application must be completed for both new and existing facilities, inding APEN'y updates. An application with missing information may be determined incomplete and may be returned or remelt in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out. incorrectly or is missing information and requires re -submittal. This APEN is to be used for Hydrocarbon Liquid Loading only. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, Ii.C. for revised APEN requirements. Permit Number: 18WE0274 AIRS ID Number: l / 1EF1./ 00 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: LT [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Discovery DJ Services LLC Site Name: Discovery Keenesburg Gas Plant Site Location: Section 17, T2N, R63W Mailing Address: (Include Zip Code) 3601 Stagecoach Road, Ste. 202 Longmont, CO 80504 E -Mail Address?: mnorton@discoverymidstream.com Site Location County: Weld NAICS or SIC Code: 213112 Permit Contact: Matthew Norton Phone Number: (817) 455-5799 'Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-208 - Hydrocarbon Liquid Loading APEN - Rev 02/2017 COLORADO 1 i a,M.,_„•a x H.�L•}. Ft :.lr�mnw�il Permit Number: 18WEO274 AIRS ID Number: / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action O NEW permit OR newly -reported emission source ❑ Request coverage under construction permit ❑ Request coverage under General Permit GP07 If General Permit coverage is requested, the General Permit registration fee of $250 must be submitted along with the APEN Filing fee. -OR- ❑✓ MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment 0 Change company name ❑ Change permit limit ❑ Transfer of ownership3 ❑✓ Other (describe below) OR - • APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - El Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: Updates to reflect new plant name, change in location. For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Truck loadout of slop For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: / I 10/ 1 /2018 Will this equipment be operated in any NAAQS nonattainment area? Isthis equipment located at a stationary source that is considered a Major Source of (HAP) emissions? Does this source load gasoline into transport vehicles? Is this source located at an oil and gas exploration and production site? If yes: Does this source load less than 10,000 gallons of crude oil per day on an annual average? Does this source splash fill less than 6750 BBL of condensate per year? Does this source submerge fill less than 16308 BBL of condensate per year? Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 l l Yes ❑ ' 'No ❑ Yes 0 No ❑ Yes 0 No ❑ Yes 0 No ❑ Yes 0 No ❑ Yes 0 No ❑ Yes ❑ No V COLORAD-O 2 ' 5efvKncr Yn.r Permit Number: 18WE0274 AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID} Section 4 - Process Equipment Information Product Loaded: ❑ Condensate 0 Crude Oil 0 Other: Slop (50% Water/50% Condensate) If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Requested Volume Loaded4: 4 Requested values will become permit limitations. Requested limits) should consider future process growth 376,000 Bbl/yr Actual Volume Loaded: Bbt/yr This product is loaded from tanks at this facility into: .(eg, "rail tank cars" or "tank trucks") Tank. Trucks If site specific emission factor is used to calculate emissions, complete the following: Saturation Factor: Average temperature of bulk liquid loading: °F True Vapor Pressure Psia ® 60 "F Molecular weight of displaced vapors Lb/lb-mol If this APEN is being filed for vapors displaced from pressurized loading lines, complete the following: Requested Volume Bbl/yr Actual Volume Loadeds : Loaded: 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth Bbl/yr Product Density: Lb/ft3 Load Line Volume: ft3/truckload Vapor Recovery Line Volume ft3/truckload Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 3 I AlCOLORADO v snag_c Permit Number: 18WE0274 AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 Geographical Information Geographical Coordinates (Latitude/Longitude or UTM) 545691.00 E, 4443501.00 N Operator Stack ID No Discharge Height Above Ground Level (Feet). Temp - ('f) Flo*,Rate (ACFM) . Velocity (ft/sec) Tanks Combustor TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) 0 Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) Q Circular Interior stack diameter (inches): ❑ Other (describe): ❑ Upward with obstructing raincap TBD Section 6 - Control Device Information ❑ Loading occurs using a vapor balance system: Requested Control Efficiency Combustion Device: Pollutants Controlled: Rating: Type: VOC, HAPs 2.0 Combustor Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: MMBtu/hr Make/Model: TBD 95 95 Waste Gas Heat Content 1,999.81 Btu/scf Constant Pilot Light: O. Yes O No Pilot burner Rating 0.23 MMBtu/hr Other: Pollutants Controlled:. Description: Control Efficiency Requested 0/0 Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 AY COLORADO 4 I Dq.meracil,rek PM Permit Number: 18WE0274 AIRS ID Number: / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? 0 Yes 0 No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Requested Control Efficiency (% reduction in: emissions) PM SOX NOX CO VOC Combustor 95 HAPs Combustor 95 Other: 0 Using State Emission Factors (Required for GP07) VOC 0 Condensate 0.236 Lbs/BBL ❑ Crude 0.104 Lbs/BBL Benzene n -Hexane 0.00041 Lbs/BBL 0.0036 Lbs/BBL 0.00018 Lbs/BBL 0.0016 Lbs/BBL From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Uncontrolled Emission Factor Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) Actual AnnualEmissions equestedAnnual Permit Emission Limit("s)5 Uncontrolled (Tons/year) Controlled5 (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) SOX NOX. VOC 0.236 b/BBL CDPHE 44.45 2.22 CO Benzene 0.0041 lb/BBL CDPHE 0.08 0.00 Toluene Ethylbenzene Xylenes n -Hexane 0.0036 lb/BBL CDPHE 0.68 0.03 2,2,4- Trimethylpentane Other: a Requested values will become permit limitations. Requested limit(s) should consider future process growth. 5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 5I A COLORADO- aa}-arrh i a e Permit Number: 18WE0274 AIRS ID Number: / [Leave blank unless APCD has already assigned a permit # and. AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under General Permit GP07, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. Signature of Legally Authorized Fjerson (not a vendor or consultant) Date Matthew T. Berghorn, P.E. VP - Engineering and Construction Name (print) Title Check the appropriate box to request a copy of the:. ❑ Draft permit prior to issuance p✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN. is required 30 daysprior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit registration fee of $250 as applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 430O Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 6 I m, c COLORADO D<7_:Incra -1 f,� lie cirC.it . GU l cd (7.5. I8) < Fugitive Component Leakf'ez°'° Emissions APEN — Form A D -2o Air Pollutant Emission Notice (APEN) and Application for Construction Permit14 40. All sections of this APEN and application must be completed for both new and existing facilities, includigAPEN ,;>r updates. An application with missing information may be determined incomplete and may be returned or result. longer application processing times. You may be charged an additional APEN fee if the. APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for fugitive component leak emissions. If your emission source does not fall into this category, there may be a different specialty APEN available for your operation (e.g. natural gas venting, condensate tanks, paint booths, etc.). In addition, the General APEN (Form APCD- 200) is available if the specialty APEN options do not meet your reporting needs. A list of specialty APENs is available on the Air Pollution Control Division (APCD) website at www.colorado.Qov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: etjuo23-1 AIRS ID Number: C 2,3 / 1 FA -11 (.2O + [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name1: Site Name: Discovery DJ Services LLC Discovery Kiowa Gas Plant Site Location: Section 29, T1 N, R63W Mailing Address: 3601 Stagecoach Road, Ste. 202 (Include Zip Code) Longmont, CO 80504 Permit Contact: Matthew Norton E -Mail Address2: mnorton@discoverymidstream.com Site Location Weld County: NAICS or SIC Code: 213112 Phone Number: (817) 455-5799 I Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 376268 1, • CO COLORADO n.rtlnt� Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action ❑✓ NEW permit OR newly -reported emission source (check one below) -OR - ❑ MODIFICATION to existing permit (check each box below that applies) O Change process or equipment ❑ Change company name 0 Add point to existing permit O Change permit limit 0 Transfer of ownership3 0 Other (describe below) - OR • APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - • APEN submittal for permit exempt/grandfathered source ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: 10/1/2018 ❑✓ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source hours/day days/week weeks/year Operation: Facility Type: ❑ Well Production Facility4 O Natural Gas Compressor Station4 ❑✓ Natural Gas Processing Plant4 0 Other (describe): 4 When selecting the facility type, refer to definitions in Colorado Regulation No. 7, Section XVII. Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 21Jiff COLORADO cr.uamofnmir Hee@trEmileurem Gas Permit Number: AIRS ID Number: / / [Leaveblank unless APCD has already assigned a permit # and AIRS ID] .c Section 4 - Regulatory Information What is the date that the equipment commenced construction? Will this equipment be operated in any NAAQS nonattainment area?5 ❑✓ Yes ❑ No Will this equipment be located at a stationary source that is considered a ❑ Yes ❑✓ No Major Source of Hazardous Air Pollutant (HAP) emissions? Are there wet seal centrifugal compressors or reciprocating compressors ❑✓ Yes ❑ No located at this facility? Is this equipment subject to 40 CFR Part 60, Subpart KKK? ❑ Yes 0 No Is this equipment subject to 40 CFR Part 60, Subpart OOOO? ❑ Yes 0 No Is this equipment subject to 40 CFR Part 60, Subpart OOOOa? 0 Yes O No Is this equipment subject to 40 CFR Part 63, Subpart HH? ❑ Yes D No Is this equipment subject to Colorado Regulation No. 7, Section XII.G? 0 Yes 0 No Is this equipment subject to Colorado Regulation No. 7, Section XVII.F? ❑ Yes ❑✓ No Is this equipment subject to Colorado Regulation No. 7, Section XVII.B.3? ❑ Yes ❑✓ No 5 See http://www.colorado.gov/cdphe/state-implementation-plans-sips for which areas are designated as attainment/non- attainment. Section 5 - Stream Constituents ❑Q The required representative gas and liquid extended analysis (including BTEX) to support the data below has been attached to this APEN form. Use the following table to report the VOC and HAP weight % content of each applicable stream. C t %) 33.57 Benzene: 0.09 Toluene (wt 96) 0.16 Ethylbenzene (wt %) 0.04 Xylene (wt %) 0.08 n -Hexane (wt %) 1.30 2,2,4 Trimethylpentane (wt %) 0.001 Heavy Oil (or Heavy Liquid) 100- 0 0 0 0 0 0 Light Oil (or Light Liquid) 100 1.41 2.79 0/3 1.64 19.97 0.014 Water/Oil Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 31 bepartarnirol Palk COLORADO Rea.frErni'vnbea Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Geographical Information geographical Coordinates,,•!: Latitude/Longitude or UTM); 545367.38 E, 4429896.08 N Attach a topographic site map showing location Section 7 - Leak Detection and Repair (LDAR) and Control Information Check the appropriate boxes to identify the LDAR program conducted at this site: ' ❑ LDAR per 40 CFR Part 60, Subpart KKK ❑ Monthly Monitoring - Control: 88% gas valve, 76% light liquid valve, 68% light liquid pump ❑ Quarterly Monitoring - Control: 70% gas valve, 61% tight liquid valve, 45% light liquid pump ❑✓ LDAR per 40 CFR Part 60, Subpart 0000/0000a 0 Monthly Monitoring - Control: 96% gas valve, 95% tight liquid valve, 88% light liquid pump, 81% connectors 0 LDAR per Colorado Regulation No. 7, Section XVII.F ❑ Other6: ❑ No LDAR Program 6 Attach other supplemental plan to APEN form if needed. Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 4 , AY COLORADO FiW06Em4on'met Count8 0 Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Emission Factor Information Select which emission factors were used to estimate emissions below. If none apply, use the table below to identify the emission factors used to estimate emissions. Include the units related to the emission factor. ❑✓ Table 2-4 was used to estimate emissions'. ❑ Table 2-8 (< 10,000ppmv) was used to estimate emissions'. Use the following table to report the component count used to calculate emissions. The component counts listed in the following table are representative of: ❑✓ Estimated Component Count ❑ Actual Component Count conducted on the following date: Equipment Type 1500 600 0 0 250 Emission Factor Units Heavy Oil (or Heavy Liquid) Count8 30 400 0 16 22 0 Emission Factor Units Light Oil" (or Light Liquid) Count8 200 400 0 8 500 0 Emission Factor Units Water/Oi Count8 Emission Factor Units 7 Table 2-4 and Table 2-8 are found in U.S. EPA's 1995 Protocol for Equipment Leak Emission Estimates (Document EPA -453/R- 95-017). 8 The count shall be the actual or estimated number of components in each type of service that is used to calculate the "Actual Calendar Year Emissions" below. 9 The Other equipment type should be applied for any equipment other than connectors, flanges, open-ended lines, pump seals, or valves. Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 5I COLORADO n.p.mattaaY flYIA6-- ' - . Benzene Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Criteria and Non -Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions and non -criteria pollutant (HAP) emissions from source: (Use the data reported in Section 8 to calculate these emissions.) Chem►cal Name„_, Number Actual Annual Emissions Requested Annual Permit Emission Limit(s) Uncontrolled (tons/year) Controlled vo (tons/year) Uncontrolled (tons/year) Controlled it ... (tons/year) VOC 17.74 17.74 Does the emissions source have any actual emissions of individual non -criteria pollutants (e.g. HAP- hazardous air pollutant) emissions equal to or greater than 250 ® Yes ❑ No lbs/year? If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: 5' umber cti��lnhu�I Emissions Requested Annual Permit Emission Ltmit(s) ncontrolled - (Ms/year) Controlled9' (lbs/year) Uncontrolled (lbs/year) Controlled-° (lbs/year) 71432 267.46 267.46 Toluene 108883 474.96 474.96 Ethylbenzene 100414 Xylene 1330207 n -Hexane 110543 2,2,4 Trimethylpentane Other: 540841 10 Annual emission fees will be based on z blank. Requested values will become permit I variability, and gas composition variability. 122.10 122.10 ' 278.54 278.54 3,397.81 35.90 3,397.81 35.90 rce has not yet started operating, leave ider future process growth, component count Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 6I AY COLORADO fieatteb FwMron.set Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 10 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. 3-1.12 Signature of Legally Au zed Person (not a vendor or consultant) Date Matthew T. Berghorn, P.E. VP - Engineering and Construction Name (print) Title Check the appropriate box to request a copy of the: O Draft permit prior to issuance ❑✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 to: For more information or assistance call: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https: / /www.colorado.gov/cdphe/apcd Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 COLORADO 7 I rb Discovery DJ Services uC Discovery Slows Gas Plant Emission Calculations Fugitive Component Emissions Table s.-rug.N. Emblem 00C Benzene Toluene Ethylbenzene Xylene n -Henn 2,2,4-Trlmethyipelltane EpulPmemiyp. . mum' E'".. ,� C'111..1'.1 .� .�-- lvc ' ,arwY.d Fmb.lom Cmaled 5nWbm -. we u�,me6d •EmWbm n '•w-%. ...° ml..bn. [m.o d bebn ytX - u mennabd tmlub� eomaW Emivb� Wcx u memmlbd Emh.mm Conwued EmWba wcx nmbnPo,. Ems EnIMO N'c% - ,me6d EIWMm nvolW EnNr'1 --:lbmds )"• ' lani ' Itnl • lib/vd la/rd , IMrd • Imhd nbryd INMI IN/r1 nb/M' n0/ -•• Inlet ax5.30 3...pax apex ppmx IIMEMEETIMME:M= 1:12EMMIIIMIoIIII=MECEIMIIMo MEITI=IIIIfIa0.97 0.97pp 0.71 530 9.01 9.01 7536 7536 0.06 0.116 moo 0.76 1.13 7.03 7.133 169 Lea 3.aa ma56.78 5678 0.115 0.05 o 0.o ago 00.01 e.m am n.an 0001 a.pp nm p.m _ -.. gym.. R �.pa• -��.m>. gyp,. ts.0 - ._ 1s�s =a3p a,3a na, ... Slop (light liquid) es 3 -03 a loo sox0 6.04 >_li% 17039 17039 2]9%20 337.. 337.16 0013%33 37.53 67. >_6.X 198.09 196.09 19.4)f6 2110.65 241.65 165 165 o IIIMMIToEZIEEIIMo lintI0 0 1133 291 6..5 8100 8100 0.06 0.06 0.21 0.21 11.87 11.37 037 114.80 1.35 IIMMIZZEW:2MMI0. �o�o00.n 050 030 l..t� 1..10 �0s �A.m ,.� ,.� >s..E 16.., > tm� n.J. p.J. $n • - .i v 3aan.. a o 201.00 m.a Lubrication 00 (Heavy liquid) ,cox omx pppx ppnx pppx pmX ppmx oa :13131aa =2:==mIMMISECIIo 0.03 0.00 Imo o� ao a,0 �f �,. 0/0 N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A sbonl.-.._ 0000[. ; pm-.. ,.;nm,. .,nm....1.n.00 v'00 - 00.01 vm nm. 0001 0001 ooav am NGL(LlghoLquld) ri a 1E-03 n' 3.15 3.45 0.24% 2939 2939 0. 2037 2037 0.04% 530 5.30 13.84 13.31 p.. x 8111 8111 0.212% 79.15 oa ono moo mended liner a go a a 1-AtAl A 17.71 17.74 267.46 267.46 01_96 04_96 112.10 17110 MS, 23.4 3397.31 3397.1 95.90 35.90 0.24 m M duub110rlba1471dm061100013000 hells Irons Own gss(an Hatt. 0920 m0 0.ml r.mmaretakenhem1,1.34 romml�.Eq. mentLest...Yentnmam, EvA°name.,p..a/.6.01,,ne.emlau1.61 0.24 170 170 not 0.02 Fugitive Component Leak Emissions APEN - Form APC Air Pollutant Emission Notice (APEN) and Application for Construction. Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for fugitive component leak emissions. If your emission source does not fall into this category, there may be a different specialty APEN available for your operation (e.g. natural gas venting, condensate tanks, paint booths, etc.). In addition, the General APEN (Form APCD- 200) is available if the specialty APEN options do not meet your reporting needs. A list of specialty APENs is available on the Air Pollution Control Division (APCD) website at www.colorado.Rov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is. required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 18WE0274 AIRS ID Number: ` 3 /1F117/ OJ 1 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Discovery DJ Services LLC Site Name: Discovery Keenesburg Gas Plant Site Location: Section 17, T2N, R63W Mailing Address: 3601 Stagecoach Road, Ste. 202 (Include Zip Code) 9 Longmont, Co 80504 Permit Contact: Matthew Norton E Mail Address2: mnorton@discoverymidstream.com Site Location Weld County: NAICS or SIC Code: 213112 Phone Number: (817) 455-5799 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. My changes will require additional paperwork. 2 Permits, exemption letters; and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-203 - Fugitive Component Leak Emissions APEN Revision 7/2017 COLORADO Permit Number: 18WE0274 AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit ti and AIRS ID] Section 2- Requested Action ❑ NEW permit OR newly -reported emission source (check one below) - OR - Di MODIFICATION to existing permit (check each box below that applies) 0 Change process or equipment 0 Change company name 0 Add point to existing permit E Change permit limit 0 Transfer of ownership3 2 Other (describe below) OR O APEN submittal for update only (Blank APENs will not be accepted). - ADDITIONAL PERMIT ACTIONS - ❑ APEN submittal for permit exempt/grandfathered source O Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional InfoEt Notes: Updates to reflect new plant name, change in location. Updated APEN to account for 0000a LDAR program control efficiency. 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information. For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: 1 0/1/2018 r❑ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source hours/day days/week Operation: Facility Type: 0 Well Production Facility4 ❑ Natural Gas Compressor Station4 0 Natural Gas Processing Plant4 ❑ Other {describe): weeks/year 4 When selecting the facility type, refer to definitions in Colorado Regulation No. 7, Section XVII. Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 COLORADO 2 I .A Permit Number: 18WE0274 AIRS ID Number: / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Regulatory Information What is the date that the equipment commenced construction? Will this equipment be operated in any NAAQS nonattainment area?5 D Yes O No Will this equipment be located at a stationary source that is considered a ❑ Yes O No Major Source,,sf kiazardous Air Pollutant (HAP) emissions? Are there wet seal centrifugal compressors or reciprocating compressors / Yes ❑ No located at this facility? Is this equipment subject to 40 CFR Part 60, Subpart KKK? O Yes 0 No Is this equipment subject to 40 CFR Part 60, Subpart OOOO? O Yes ❑✓ No Is this equipment subject to 40 CFR Part 60, Subpart OOOOa? D Yes O No Is this equipment subject to 40 CFR Part 63, Subpart HH? O Yes 0 No Is this equipment subject to Colorado Regulation No. 7, Section XII.G? 0 Yes O No Is this equipment subject to Colorado Regulation No. 7, Section XVII.F? O Yes Ej No Is this equipment subject to Colorado Regulation No. 7, Section XVII.B.3? ❑ Yes ❑✓ No 5 See http://www.cotorado_aow/cdphe/state-implementation-plans-sips for which areasare designated as attainment/non- attainment. Section 5 - Stream Constituents Q The required representative gas and liquid extended analysis (including BTEX) to support the data below has been attached to this APEN form. Use the following table to report the VOC and HAP weight % content of each applicable stream. Stream VOC (wt %) Benzene (wt %) Toluene (wt %) Ethylbenzene (wt %) Xylene (wt %) n -Hexane (wt %) 2,2,4 Tnmethylpentane Gas 33.57 0.09 0.16 0.04 0.08 1.30 0.001Heavy Oil (or Heavy Liquid) 1 00 0 0 0 0 . 0 0 Light Oil (or Light Liquid) 100 1.41 2.79 0.73 1.64 19.97 0.014 Water/Oil Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 COLORADO' - 3 I Ay. t,1 &.:-.n::l l`tctr- Nei'tY,btnvue,mtrt Permit Number: 18WE0274 AIRS ID Number: [Leave blank unless APCD has already assigned a permit fi and AIRS ID] Section 6 - Geographical Information Geographical Coordinates (Latitude/Longitude or UTM). 545572.00 E, 4443766.00 l' Attach a topographic site map showing location Section 7 - Leak Detection and Repair (LDAR) and Control Information Check the appropriate boxes to identify the LDAR program conducted at this site: O LDAR per 40 CFR Part 60, Subpart KKK O Monthly Monitoring - Control: 88% gas valve, 76% light liquid valve, 68% light liquid pump O Quarterly Monitoring - Control: 70% gas valve, 61%. light liquid valve, 45% light liquid pump Q LDAR per 40 CFR Part 60, Subpart OOOO/OOOOa El Monthly Monitoring - Control: 96% gas valve, 95% light liquid valve, 88% light liquid pump, 81% connectors ❑ LDAR per Colorado Regulation No. 7, Section XVII.F O Other': ❑ No LDAR Program 6 Attach other supplemental plan to APEN form if needed. Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 COLORADO 4 J ,. ,..:,t,.;z Gas Permit Number: 18WE0274 AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID) Section 8 - Emission Factor Information Select which emission factors were used to estimate emissions below. If none apply, use the table below to identify the emission factors used to estimate emissions. Include the units related to the emission factor. E Table 2-4 was used to estimate emissions'. ❑ Table 2-8 (< 10,000ppmv) was used to estimate emissions'. Use the following table to report the component count used to calculate emissions. The component counts listed in the following table are representative of: 1: Estimated Component Count ❑ Actual Component Count conducted on the following date: Equipment Type Connectors 600 Open -Ended Lines Pump Seals 250 0 Count8 1500 0 0 Emission Factor Units Heavy Oil (or Heavy Liquid)'s. Count8 30 400 0 16 22 0 Emission Factor Units Light Oil (or Light Liquid) Count8 200 400. 0 8 500 0 Emission Factor Units Water/Oil Count8 Emission Factor Units ' Table 2-4 and Table 2-8 are found in U.S. EPA's 1995 Protocol for Equipment Leak Emission Estimates (Document EPA -453/R- 95-017). 8 The count shall be the actual or estimated number of components in each type of service that is used to calculate the "Actual Calendar Year Emissions" below. 9 The Other equipment type should be applied for any equipment other than connectors, flanges, open-ended lines, pump seats, or valves. Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 51 COLORADO Nrusen :ct1 .'rc Permit Number: 18WE0274 AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit II and AIRS ID] Section 9 - Criteria and Non -Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions and non -criteria pollutant (HAP) emissions from source: Use the data reported in Section 8 to calculate these emissions.) Chemical Name. CAS Number Actual Annual Emissions Requested Annual Permit Emission Limit(s) Uncontrolled (tons/year) Controlled1D (tons/year) Uncontrolled (tons/year) Controlledll (tons/year) VOC 17.74 2.60 Does the emissions source have any actual emissions of individual non -criteria pollutants (e.g. HAP- hazardous air pollutant) emissions equal to or greater than 250 ® Yes ❑ No lbs/year? If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: Chemical Name CAS Number Actual Annual Emissions Requested Annual Permit Emission Limits) Uncontrolled (lbs/year) Controlled9 (lbslyear) Uncontrolled (lbs/year) Controlled14 (lbs/year) Benzene 71432 267.46 24.97 Toluene 108883 474.96 43.74 Ethylbenzene 100414 122.10 11.02 Xylene 1330207 278.54 25.09 n -Hexane 110543 3,397.81 329.37 Z, 2,4 Trimethvlpentane 540841 35.90 2.37 Other: 1° Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. 11 Requested values will become permit limitations. Requested limit(s) should consider future process growth, component count variability,. and gas composition variability. _ Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 6 I AV_COLO RADO Neill: S Grtc..am=nt Permit Number: 18WE0274 AIRS ID Number: / [Leave blank unless APCD has already assigned a permit II and AIRS ID] Section 10 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. 7- et Signature of Legally Authorized Person (not a vendor or consultant) Date Matthew T. Berghorn, P.E. VP - Engineering and Construction Name (print) Title Check the appropriate box to request a copy of the: 0 Draft permit prior to issuance 0 Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 to: For more information or assistance call: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.govicdphe/apcd Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 7 I A COLORADO 1 - FA) ,y.,/L�, 11+4 General APEN - Form APCD-200, Ua� Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, i updates. An application with missing information may be determined incomplete and may be returnee or longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. There may be a more specific APEN for your source (e.g. paint booths, mining operations, engines, etc.). A list of specialty APENs is available on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to, expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: (ewvZ7 Lf AIRS ID Number: 23 /1F4.37 008 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Site Name: Discovery DJ Services Discovery Kiowa Gas Plant Site Location: Section 29, T1 N, R63W Mailing Address: 3601 Stagecoach Road, Ste. 202 (Include Zip Code) g Longmont, CO 80504 Portable Source N/A Home Base: Site Location Weld County: NAICS or SIC Code: 213112 Permit Contact: Matthew Norton Phone Number: (817) 455-5799 E -Mail Address2: mnorton@discoverymidstream.com Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. 376267 Form APCD-200 - General APEN - Revision 1/2017 COLORADO 1 ��ihw _.ate NYa11116EmNMlm�u Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action 2 NEW permit OR newly -reported emission source (check one below) 2 STATIONARY source 0 PORTABLE source -OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit El Change permit limit ❑ Transfer of ownership' ❑ Other (describe below) -OR - ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info £t Notes: ' For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Acid Gas Thermal Oxidizer to control VOC and HAPs from Amine Treater (primary control for acid gas and secondary control for flash gas) Manufacturer: TBD Model No.: TBD Serial No.: TBD Company equipment Identification No. (optional): For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: C1 10/1/2018 0 Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: Seasonal use percentage: Dec -Feb: hours/day days/week Mar -May: Jun -Aug: weeks/year Sep -Nov: Form APCD-200 - General APEN - Revision 1/2017 COLORADO 2 I c.P.mkezu a Pub& !• FLiW bDWeMVN Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit f and AIRS ID] Section 4 - Processing/Manufacturing Information Et Material Use ❑ Check box if this information is not applicable to source or process From what year is the actual annual amount? Description Design Process Rate (Specify Units) Actual Annual Amount (Specify Units) Requested Annual Permit Limit4 (Specify Units) Material Consumption: Assist Natural Gas 25.0 MMBtu/hr 193.77 MMSCF/yr Amine Unit Still Vent & Flash Tank Waste Gas 2.10 MMBtu/hr 1,419.68 MMSCF/yr Finished Product(s): 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 545238.57 E, 4429948.10 N El Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Operator Stack ID No Discharge Height Above Ground Level Feet Temp. ("F) Flow Rate (ACFM) Velocity (ft/see) C1 TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Horizontal El Downward El Other (describe): ❑ Upward with obstructing raincap Indicate the stack opening and size: (check one) ▪ Circular Interior stack diameter (inches): TBD ❑ Square/rectangle Interior stack width (inches): ❑ Other (describe): Interior stack depth (inches): Form APCD-200 - General APEN - Revision 1/2017 3 1 COLORADO x�.nw,trc„nuenman, . Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Combustion Equipment £t Fuel Consumption Information 0 Check box if this information is not applicable to the source (e.g. there is no fuel -burning equipment associated with this emission source) Design Input Rate ''(MMBTU/hr) " Actual Annual Fuel Use (Specify Units) Requested Annual Permit Limit4 (Specify Units) 27.10 1,613.45 MMSCF/yr From what year is the actual annual fuel use data? Indicate the type of fuel used5: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) ❑ Field Natural Gas Heating value: BTU/SCF ❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTU/SCF) ❑ Coal Heating value: BTU/lb Ash Content: Sulfur Content: Other (describe): Residue Natural Gas Heating value (give units): 1,130 Btu/scf 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 5 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑ Yes 0 No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment ' , Description Overall Collection Efficiency Overall Control Efficiency (% reduction iii n emssons TSP (PM) PM10 PMZ_5 SO. NO. CO _ VOC Other: Form APCD-200 - General APEN - Revision 1/2017 Q COLORADO 4I m Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit A and AIRS ID] Section 7 (continued) From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Pollutant Uncontrolled Emission Factor (Specify Units) Emission Factor Source (AP -42, Mfg. etc) Actual Annual Emissions Requested Annual Permit Emission Limit(s)4 Uncontrolled (Tons/year) Controlled6 (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) TSP (PM) PM10 PM2.s SOx NO), 113.0 Ib/MMSCF Mfg. 11.87 11.87 Co 113.0 Ib/MMSCF Mfg. 11.87 11.87 VOC Other: 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Section 8 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP- hazardous air pollutant) emissions equal to or greater than 250 lbs/year? ❑ Yes ❑ No If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: CAS Numbere Chemical Name Overall Control Efficiency Uncontrolled Emission Factor (specify units) Emission Factor Source (AP -42, Mfg. etc) Uncontrolled Actual Emissions (lbs/year) Controlled Actual Emissions6 (lbs/year) 110543 Hexane 0 1.991b/MMSCF AP -42 418.9 418.9 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-200 - General APEN - Revision 1/2017 COLORADO 5 �,_. -,oF Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. / • 6-6 - /z , Signature of Legally Autho ed Person (not a vendor or consultant) Date Matthew T. Berghorn, P.E. VP - Engineering and Construction Name (print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance 0 Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 to: For more information or assistance call: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 AVVICOLORADO Form APCD-200 - General APEN - Revision 1/2017 MAY 1 0 2018 PCD General APEN - Form APCD-20 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the .APEN is filled out incorrectly or is missing information and requires re -submittal. There may be a more specific APEN for your source (e.g. paint booths,mining operations, engines, etc.). A list of specialty APENs is available on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/aped. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increacF production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, H.C. for revised APEN requirements. Permit Number: 18WE 0274 AIRS ID Number: ' 13 /9 0O [Leave. Ua k unleds ?CD ?`d_ aiready assigned a permit i s AIRS i01 Section 1 - Administrative Information Company Name': Site Name: Site Location: Discovery DJ Services Discovery Kiowa Gas Plant Section 29, TIN, R63W Mailing Address: (Include Z1,7 Cede/ 3601 Stagecoach Road, Ste. 202 Longmont, CO 80504 Portable Source NJA Home Base: Site Location Weld County: NAICS or SIC Code: 213112 Permit Contact: Matthew Norton Phone Number: (817) 455-5799 E -Mail Address': mnorton@discoverymidstrearn.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-2OO• General APEN - Revision 112017 Permit Number: 18WE0274 AIRS ID Number: I Section 2- Requested Action ❑ NEW permit OR newly -reported emission source tche_:g one below) ❑ STATIONARY source ❑ PORTABLE source -OR - 1] MODIFICATION to existing permit (check each box below tho_ opcueel ❑ Change fuel or equipment ❑ Change permit limit O Change company name ❑ Add point to existing pe O Transfer of ownership' ❑ Other (describe be(ow) -OR- ❑ APEN submittal for update only (Blank APENs will not be accepted) - AoomONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info Et Notes: 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Two (2) Acid Gas Thermal Oxidizers to control VOC and HAPs from Amine Treaters Manufacturer: TBD Model No.: TBD Serial No.: TBD Company equipment Identification No. (optional): Cl/C2 For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: 10/1/2018 Q Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day days/week weeks/year Seasonal use percentage: Dec -Feb: Mar -May: Jun -Aug: Sep -Nov: form AYPCD :tiles General. era -t APEN Fovision 1/2017 21 0O Assist Natural Gas Permit Number: 18WE 0274 AIRS- ID Number: / fLe.ave t duster APCI: s aiready asigne.c.1° pe.,.., # and::!r Section 4 - Processing/Manufacturing Information & Materi4I Use ❑ Check box if this information is not applicable to crunrce or process From what year is the actual annual amount? Design Process Rate (specify Units), Actual Annual Amount (specify Units) Requested Annual Permit Limit4 (Specify Units) Finished Products) 25.0 MMBtu/hr 350.36 MNISCF/yr Arine UnSs 55➢ VErts S Flash Ta:ics Waste Gas 19.35 MMBtu/hr 5,570.18 MMSCF/yr 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Section 5 - Stack Information Geographical Coordinates (Latitude!Longitude or UTM) 545238.57 E, 4429948.10 N ❑ Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. aerator �r Dis a lie in Alex Lesrel Temp. ` f. Flow Ratae fA M Ve ty {��(s C1/C2 TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Horizontal O Downward O Other (describe): ❑ Upward with obstructing raincap Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): TBD ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): Form APCD-„CD -Genera: APEN revision 112017 3 1 W to aeaco TSP (PM) Permit Number: 18WE0274 AIRS ID Number: / / ve k _r _es- CC, .._ _. a __ _ .0 and .. P.SID] Section 6 - Combustion Equipment £t Fuel Consumption Information © Check box if this information is not applicable to the source (e.g. there is no fuel -burning equipment associated with this emission source) Design Input Rate (�iiMBTWhr) ; Actual Annual Fuel Use fSpecify tlnit.$) I Requested Annual #germ# Limit4 Specify Units) 64.84 I i 5,920.53 MMSCF/yr From what year is the actual annual fuel use data? Indicate the type of fuel used': ❑ Pipeline Natural Gas (assumed fuel heating value of 1.020 8TU/SCF) ❑ Field Natural Gas Heating value: BTU/SCF 0 Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTU/SCF) 0 Coat Heating value: BTU/lb Ash Content: Sulfur Content: Other (describe): Residue Natural Gas Heating value (give units): 1,130 Btu/scf 4 Requested values will become permit limitations. Requested limits) should consider future process growth. 5 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Isany emission control equipment or practice used to reduce emissions? 0 Yes 2 No If yes, describe the control equipment AND state the overall control efficiency (% reduction): l Equipmen. Description rol Efficiency in emissions) PM10 PM2.5 SOX NO. CO VOC Other: Form ArCD-208 General APEN Revision ,2017 k COLORADO 4 I &V .Z_ a F.f=r-, 110543 Hexane TSP (PM) Permit Number: 18WE0274 AIRS ID Number: of k.w,:.e _APC_ ?laperrlit , _., _ AIP;. I / Section 7 (continued) From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: ( Use the data reported in Sections 4 and 6 to calculate these emissions.) Uncontrolled Emission Factor (Specify units) Factor Source (AP -42, Mfg. etc) Uncontrolled (Tons/yeur) Controlled- (Toils/Year) PM10 PMzs Sox NO,, 90.4 Ib/MMSCF Mfg. 22.62 22.62 CO 113.0 Ib/MMSCF Mfg. 28.27 28.27 VDC Other; 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank, Section 8 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g, HAP- hazardous air pollutant) emissions equal to or greater than 250 lbs/year? Cl Yes ❑ No If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: Overall Control Efficiency Uncontrolled Emission Factor (specify units) Emission Factor Source -42, Mfg. etc) ncontrolled Actual Emissions abs/year); Controlled Actual Emissions6 (tbs/year) 0 1.99 Ib/MMSCF AP -42 997.8 997.8 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, Leave blank. cOLorz.a�a APCC 2 ,0 ..P rN Revision 1r2017 Permit Number: 18WE 0274 AIRS ID Number: I I AP::..: .. and ... Ew.: Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. Date Signature of Legally Authorized Person tt a vendor or consultant) Matthew T. Berghorn, P.E. VP - Engineering and Construction Name (print) Title Check the appropriate box to request a copy of the: El Draft permit prior to issuance Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, D.C. for revised APEN requirements. Send this form along with $152.90 to: For more information or assistance call: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 8024b-1530 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the. APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form APCD-200 - General APEN - Revision 1/2017 6j AVrotera0 2-Methylnaphthalene NO, Discovery DJ Services LLC Discovery Kiowa Gas Plant Emission Calculations Acid Gas Thermal Oxidizers Table 10.a. - Oxidizer Information Parathe ter .,; , Value o: Acid Gas Flow rate (scfh) 1 622,673 Acid Gas Heat Value (Btu/scf) 1 6.53 Flash Gas Flow Rate (scfh) 1 13,191 Flash Gas Heat Value (Btu/scf) 1 1,159 Vapor Heat Input (MMBtu/hr) 19.35 Pilot/Assist Natural Gas Usage, scfh 2 39,840 Pilot/Assist Natural Gas Heat Value, Btu/scf 1,130 Pilot/Assist Gas (MMBtu/hr) 45.19 Pilot/Assist Gas Usage (MMSCF/yr) 350.36 Design Heat Input Rating, MMBtu/hr 64.54 1 Acid gas flow rate and heat content based on ProMax simulation for both amine oxidizers. 2 Assist gas maximum heat input rate (25.0 MMBtu/hr) based on 1,800 F operation to achieve 99% DRE for both amine oxidizers. Table 10.b. - Oxidizer - Criteria Pollutant Emissions Emission factor, ib/MMSCF;"s' Ib/MMBtu Emission'" Emission Rate toy 0.080 5.16 22.62 CO 0.100 6.45 28.27 CO, 1 Based on EPA AP -42, Section 1.4, Natural Gas Combustion (Tables 1.4-1 and 1.4-2). 2 Emission factor of 0.08 Ib/MMBtu for NOX and 0.10 lb/MMBtu for CO provided by vendor (email from Zeeco dated May 1, 2018). - 120,000 117.647 7,593.27 33,258.53 Table 10.c. - Oxidizer - Hazardous Air Pollutant Emissions Emission Eacto Ib/MMSCF s 2.40E-05 2.35 E-08 Emission;; 1.52E-06 1.33E-02 3-M et hyl ch to ra nth ren e 7,12-Dimethylbenz(a)anthracene Acenaphthene Acenaphthylene Anthracene Benz(a)anthracene Benzene 1.80E-06 1.76E-09 1.14E-07 9.98E-04 1.60E-05 1.57E-08 1.01E-06 8.87E-03 1.80E-06 1.76E-09 1.14E-07 9.98E-04 1.80E-06 1.76E-09 1.14E-07 9.98E-04 2.40E-06 2.35E-09 1.52E-07 1.33E-03 1.80E-06 1.76E-09 1.14E-07 9.98E-04 2.10E-03 2:06E-06 1.33E-04 1.16E+00 Benzo(a)pyrene Benzo(b)fluoranthene Benzo(g,h,i)perylene Benzo(k)fluoranthene Chrysene Dibenzo(a,h)anthracene Dichlorobenzene 1.20E-06 1.18E-09 7.59E-08 6.65E-04 1.80E-06 1.76E-09 1.14E-07 9.98E-04 1.20E-06 1.18E-09 7.59E-08 6.65E-04 1.80E-06 1.76E-09 1.14E-07 9.98E-04 1.80E-06 1.76E-09 1.14E-07 9.98E-04 1.20E-06 1.18E-09 7.59E-08 6.65E-04 1.20E-03 1.18E-06 7.59E-05 6.65E-01 Fluoranthene 3.00E-06 2.94E-09 1.90E-07 1.66E-03 Fluorene 2.80E-06 2.75E-09 1.77E-07 1.55E-03 Formaldehyde Hexane 7.50E-02 7.35E-05 4.75E-03 4.16E+01 1.80E+00 1.76E-03 1.14E-01 9.978E+02 Indeno(1,2,3-cd)pyrene Naphthalene Phenanathrene 1.80E-06 1.76E-09 5.98E-07 1.14E-07 9.98E-04 6.10E-04 3.86E-05 3.38E-01 1.70E-05 1.67E-08 1.08E-06 9.42E-03 Pyrene 'Toluene 5.00E-06 4.90E-09 3.16E-07 2.77E-03 3.40E-03 3.33E-06 2.15E-04 1.88E+00 Total 1.19E-01 1.04E+03 'Emission factor from AP -42 Chapter 1 Section 4 — Natural Gas Combustion Table 1.4-3 - Emission Factors for Speciated Organic Compounds from Natural Gas Combustion, dated July 1998. To adjust for the natural gas heat rating the emission factor was then multiplied by (1,130/1,020). General APEN - Form APCD-200 Air Pollutant Emission Notice (APEN) a Application for Construction Permit All sections of this APEN and application must be completed for both new arid existing facilities;-iniiliding A updates. An application with missing information may be determined incomplete and may be returned or r longer application processing times. You may be charged an additional. APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. There may be a more specific APEN for your source (e.g. paint booths, mining operations, engines, etc.). A list of specialty APENs is available on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, U.C. for revised APEN requirements. • Permit Number: 18WE0274 AIRS ID Number: 1 13 /1 Fin/ oo3 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Discovery DJ Services Site Name: Discovery Keenesburg Gas Plant Site Location: Section 17, T2N, R63W Mailing Address: dd r deg 3601 Stagecoach Road, Ste. 202 Longmont CO 80504 Portable Source N/A Home Base: Site Location Weld County; NAICS or SIC Code: 2131.12 Permit Contact: Matthew Norton Phone Number: (817) 455-5799 E -Mail Address2: mnorton@discoverymidstream.com 1' Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Anychanges will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. COLORADO Form APCD-200 - General APEN - Revision 112017 Permit Number: 18WE0274 AIRS ID Number: [Leave blank unless APCD has already assigned a permit ft and AIRS ID] Section 2- Requested Action ❑ NEW permit OR newly -reported emission source (check one below) ❑ STATIONARY source ❑ PORTABLE source -OR - El MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment 0 Change company name 0 Add point to existing permit El Change permit limit ❑ Transfer of ownership' 0 Other (describe below) -OR- ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDmONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info Et Notes: Updates to reflect new plant name, change in location. Minor PTE calculation update. 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information ' General description of equipment and purpose: Two (2) Acid Gas Thermal Oxidizers to control VOC and HAPs from Amine Treaters Manufacturer: TBD Model No.: TBD Serial No.: TBD Company equipment Identification No. (optional): C1 /C2 For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: 10/1/2018 Q Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day days/week weeks/year Seasonal use percentage: Dec -Feb: Mar -May: Form APCD-200 - General APEN - Revision 1/2017 Jun -Aug: Sep -Nov: COLORADO 2 I eVVVV � Daw-.nOcciclY�'Ic W=k1•F re.lerm.arnt Assist and Pilot Natural Gas Permit Number: 18WE0274 AIRS ID Number: [Leave blank unless APCD has already assigned a permit# and AIRS ID] Section 4 Processing/Manufacturing Information £t Material Use. O Check box if this information is not applicable to source or process From what year is the actual annual amount? Design Process Rate (Specify Units) Actual Annual Amount (Specify Units), Requested Annual Permit Limit4 (Specify Units) Material consumption: 45.0 MMBtu/hr 349.0 MMSCF/yr Amine Unix -Still Vents & Flash Tanks. Waste Gas 17.0 MMBtu/hr 3463.879 MMSCF/yr Finished Product(s): 4 Requested values will become permit limitations. Requested limit(s) shouldconsider future process growth. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or!UTM) 545716.55 E, 4443999.98 N ❑ Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Operator Stack 1D No z Discharge Height Above GroundALevel ert) .. . Temp p {;f) Flaw Rate {ACFi41j Veloci k (ft/sec) C1/C2 TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) ❑✓ Upward O Horizontal. ❑ Downward ❑'Other (describe): ❑ Upward with obstructing raincap Indicate the stack opening and size: (check one) 0 Circular Interior stack diameter (inches): TBD O Square/rectangle Interior stack width (inches): ❑ Other (describe): Interior stack depth (inches): Form APCD-200 - General APED - Revision 1/2017 3 1 A` COLORADO xp-.nucrl n=ao-s, r. c,r:.�•a�.:m Permit Number: '18WE0274 AIRS ID Number: I l [Leave blank unless APCD has already assigned a permit I and AIRS ID] Section 6 - Combustion Equipment Et Fuel Consumption Information ❑ Check box if this information is not applicable to the source (e.g. there is no fuel -burning equipment associated with this emission source) Design Input Rate (MMBTUIhr) ' Actual Annual Fuel Use (Specify Units) Requested Annual Permit Limit4 (Specify Units). 62.0 3812.80 MMSCF/yr From what year is the actual annual fuel use data? Indicate the type of fuel used5: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/5CF) O Field Natural Gas Heating value: BTU/SCF ❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTUlgallon). ❑ Propane (assumed fuel heating value of 2,300 BTU/SCF) O Coal Heating value: BTU/lb Ash Content: Sulfur Content: p Other (describe): Residue Natural Gas Heating value (give units): 1,130 Btu/scf 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. s If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Section 7 - Criteria Pollutant Emissions information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? O Yes O No If yes; describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description „Overall. Collection Efficiency Overall Control Efficiency (% reduction in emissions) TSP (PM) PM1D PM2.5 SOx NOx CO VOC Other: Form APCD-2O0 - General APEN - Revision 1/2017 COLORADO 4 I a�timmt�}el<. ii�11// F1.w:.�kr..;.arc�nnnl TSP (PM) Permit Number: 18WE0274 AIRS iD Number: [Leave blank unless APCD has already assigned a permit if and AIRS ID] Section 7 (continued) From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Uncontrolled Emission Factor (Specify Units) Emission Factor Source (AP -42,: Mfg. etc) Uncontrolled (Tons/year) Controlled6 (Tons/year) equested Annual Permi Emission_Umit(s)4 Uncontrolled (Tons/year) Controlled (Tons/year) PM10 PMzs SOx NOx 90.4 lb/MMSCF Mfg. 21.72 21.72 CO 113.0 IbAv1MSCF Mfg. 27.16 27.16 VOC Other: 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started- operating, leave blank. Section 8 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissionsof non -criteria pollutants (e.g. HAP- hazardous air pollutant) emissions equal to or greater than 250 lbs/year? O Yes O No If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: CAS Numbers Chemical Name Overall Control Efficiency Uncontrolled Emission Factor (specify units) Emission Factor Source (AP -42 Mfg, etc) Uncontrolled Actual Emissions (lbs/year) Controlled Actual Emissions (lbs/year). 110543 Hexane 0 1.991b/MMSCF AP -42 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-200 - General APEN Revision 1/2017 COLORADO 5 I r�r Permit Number: 18WE0274 AIRS ID Number: [Leave blank unless APCD has already assigned a permit it and AIRS ID] Section 9 - Applicant Certification I hereby certify that alt information contained herein and information submitted with this application is complete, true and correct. 1, 7 -> l Signature of Legally Authorize Person (not a vendor or consultant) Date Matthew T. Berghorn, P.E. VP - Engineering and Construction Name (print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance E] Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, D.C. for revised APEN requirements. Send this form along with. $152.90 to: For more information or assistance call: Colorado Department of Public Health and Environment Air Pollution Control Division. APCD-SS-B1. 4300 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (.303) 692 -3150 - Form APCD-200 - General APEN - Revision 1/2017 COLORADO 6 I Li ann. adwie444400, go:4444C7.s. 2pIk') A iep *44)1,e Natural Gas Venting APEN - Form APCD-211 449 Air Pollutant Emission Notice (APEN) and eo� cam_ Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, `1 ludiff updates. An application with missing information may be determined incomplete and may be returned or -sultan longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for Natural Gas Venting only. Natural Gas Venting includes emissions from gas/liquid separators, well head casing, pneumatic pumps, blowdown events, among other events. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.Qov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: I v 2 7t -t AIRS ID Number: `-3 / c F +/ D q [Leave blank unless APCD has already assigned a permit #1 and AIRS ID] Company equipment Identification: MSS [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Discovery DJ Services LLC Site Name: Discovery Kiowa Gas Plant Site Location: Section 29, T1 N, R63W Mailing Address: (Include Zip Code) 3601 Stagecoach Road, Ste. 202 Longmont, CO 80504 E -Mail Address' mnorton@discoverymidstream.com Site Location County: Weld NAICS or SIC Code: 213112 Permit Contact: Matthew Norton Phone Number: (817) 455-5799 'Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-211 - Natural Gas Venting APEN - Rev 03/2017 CO COLORADO a Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action • NEW permit OR newly -reported emission source - OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below) -OR- ❑ APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - • Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: MSS Vessel Blowdowns For existing sources, operation began on: / / For new or reconstructed sources, the projected start-up date is: 10 / 1 / 2018 ❑ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: 24 hours/day Will this equipment be operated in any NAAQS nonattainment area Is -this equipment located at a stationary source that is considered a Major Source of (HAP) Emissions 7 days/week 52 ❑� Yes ❑ Yes weeks/year ❑ No ❑✓ No Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 kw COLORADO 2 I Nut�II6Enrlron,evn Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Process Equipment Information O Gas/Liquid Separator ❑ Well Head Casing ❑ Pneumatic Pump Make: Model: ❑ Compressor Rod Packing Make: Model: E Blowdown Events # of Events/year: ❑ Other Description: Serial #: # of Pistons: 8 Volume per event: Capacity: Leak Rate: 0.25 Gal/min Scf/hr/pist MMscf/event If you are requesting uncontrolled VOC emissions greater than 100 tpy for a Gas/Liquid Separator you must use Natural Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? ❑ Yes Natural Gas Venting Process Parameters4: Liquid Throughput Process Parameters4: 0 No Maximum Vent Rate: SCF/hr Vent Gas Heating Value: BTU/SCF Requested: MMSCF/year Actual: MMSCF/year -OR- Requested: Bbl/yr Actual: Bbl/yr 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth Process Properties: Molecular Weight: VOC (mole %) VOC (Weight %) Benzene (mole %) Benzene (Weight %) Toluene (mole %) Toluene (Weight %) Ethylbenzene (mote %) Ethylbenzene (Weight %) Xylene (mole %) Xylene (Weight %) n -Hexane (mole %) n -Hexane (Weight %) 2,2,4-Trimethylpentane (mole %) 2,2,4-Trimethylpentane (Weight %) Additional Required Information: ❑� Attach a representative gas analysis (including BTEX Et n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX £t n -Hexane, temperature, and pressure) Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 31AY COLORADO n..nm.mafne. RuarlifrErntreemem Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 545231.24 E, 4429855.03 N O p erator StackIDNo Discharge Height ._ .� Above Ground Level ,__ (Feet) Temp. `(`F) �. Flow Rate (ACFM) Velocity, (ft/sec)' Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑ Other (describe): ❑ Upward with obstructing raincap Section 6 - Control Device Information ❑ VRU: Pollutants Controlled: Size: Make/Model: Requested Control Efficiency VRU Downtime or Bypassed ❑ Combustion Device: Pollutants Controlled: Rating: Type: Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: MMBtu / hr Make/Model: % Waste Gas Heat Content Constant Pilot Light: ❑ Yes ❑ No Pilot burner Rating Btu/scf MMBtu/hr Other: Pollutants Controlled: Description: Control Efficiency Requested 0/0 Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 4 COLORADO Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? O Yes ✓❑ No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): PM Control Equipment Description. Overall Requested Control Efficiency (% reduction in emissions) S.O. NO. VOC CO HAPs Other: From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Pollutant _ Uncontrolled Emission - Factor ' Emission Factor Units - - Emission Factor Source (AP -42; ' Mfg. etc) ActualAnnua Emissions RequestedtAnnuaL misSion: a mi mut s ' Uncontrolled (Tonslyear)-' Controlledb - (Tons/year)= Uncontrolled - ; (Tons/year) . Controlled.' (Tons/yea`r) PM SOX NO. VOC 2.15E+04 lb/MMSCF Engineering Est 2.15 2.15 CO Benzene 1.17E+05 Ib/MMSCF Engineering Est 0.006 0.006 Toluene 2.00E+05 Ib/MMSCF Engineering Est. 0.01 0.01 Ethylbenzene 4.80E+04 lb/MMSCF Engineering Est 0.0024 0.0024 Xylenes 1.09E+05 lb/MMSCF Engineering Est. 0.005 0.005 n -Hexane 1.67E+06 Ib/MMSCF Engineering Est 0.0835 0.0835 2'2,4- Trimethylpentane 1.33E+03 Ib/MMSCF Engineering Est 6.65E-05 6.65E-05 Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 5 I Co 'COLORADO HutfIIbEmitmue�N Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all informationcontained herein and information submitted with this application is complete, true and correct. -L-rg Signature of Legally Authc9ed Person (not a vendor or consultant) Date Matthew T. Berghorn, P.E. VP - Engineering and Construction Name (please print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance E Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https: //www.colorado.gov/cdphe/apcd Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 6I Departmental Pa. COLORADO AIL 52018 Natural Gas Venting APEN - Form APC-211 /,,PCD Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal This APEN is to be used for Natural Gas Venting only. Natural Gas Venting includes emissions from gas/liquid separators, welt head casing, pneumatic pumps, blowdown events, among other events. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of alt available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A„ II.C. for revised APEN requirements. Permit Number: 18WE0274 AIRS ID Number: I �3 /41F/1-7/ oo [Leave blank unless APCD has already assigned a permit rY and AIRS ID] Company equipment Identification: MSS [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative information Company Name': Site Name: Site. Location: Discovery DJ Services LLC Discovery Keenesburg Gas Plant Site Location Section 17, T2N, R63W County: Weld Mailing Address: (include Zip Code) 3601 Stagecoach Road, Ste. 202 Longmont, CO:80504 E -Mail Address2: mnorton@discoverymidstream.com NAiCS or SIC Code: 213112 Permit Contact: Matthew Norton Phone Number: (817) 455-5799 'Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will. appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-211 - Natural Gas Venting APEN - Rev 03/2017 r� COLORADO I ae nta 'R t...i R 1- Permit Number: 18WE0274 AIRS ID Number: [Leave blank unless APCD has already assigned a permit it and AIRS ID] Section 2- Requested Action ❑ NEW permit OR newly -reported emission source -OR- Q MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name 0 Add point to existing permit ❑ Change permit limit 0 Transfer of ownership3❑ Other (describe below) -OR - ❑ APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info £t Notes: Updates to reflect new plant name, change in location. 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: MSS Vessel Blowdowns For existing sources, operation began on: / For new or reconstructed sources, the projected start-up date is: 10 / 1 / 2018 ❑ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: 24 hours/day Will this equipment be operated in any NAAQS nonattainment area Is this equipment located at a stationary source that is considered a Major Source of (HAP) Emissions 7 days/week 52 weeks/year ❑✓ Yes ❑ No ❑ Yes ❑✓ No Form APCD-211 -Natural Gas Venting APQ'I - Rev 03/2017 COLORADO 2 I ;; .=7, tl�iti'm p f .r.n.orsai Permit Number: 18WE0274 AIRS ID Number: [Leave blank unless APCD has already assigned a permit N, and AIRS ID] Section 4 - Process Equipment Information ❑ Gas/Liquid Separator O Well Head Casing ❑ Pneumatic Pump Make: Model: ❑ Compressor Rod Packing Make: Model: • Blowdown Events # of Events/year: O Other Description: Serial #: # of Pistons: 8 Volume per event: Capacity: Leak Rate: 0.25 Gal/min Scf/hr/pist MMscf/event If you are requesting uncontrolled VOC emissions greater than 100 tpy for a Gas/Liquid Separator you must use Natural Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? ❑ Yes Natural Gas Venting Process Parameters4: Liquid Throughput Process Parameters4: No Maximum Vent Rate: SCF/hr Vent Gas Heating Value: BTU/SCF Requested: MMSCF/year Actual: MMSCF/year -OR- Requested: Bbl/yr Actual: Bbl/yr 4 Requested values will become permit limitations. Requested limit(s): should consider future process growth Process Properties: Molecular Weight: VOC (mole %) VOC (Weight %) Benzene (mole %) Benzene (Weight %) Toluene (mole %) Toluene (Weight %) Ethylbenzene (mole %) Ethylbenzene (Weight %) Xylene (mole %) Xylene (Weight %) n -Hexane (mole %) n -Hexane (Weight %) 2,2,4-Trimethylpentane (mole %) 2,2,4-Trimethylpentane (Weight %) Additional Required Information: Attach a representative gas analysis (including BTEX Et n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX a n-Hexane,temperature, and pressure) Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 A ' COLORADO 3 VI Gp rall'::lc 11..:f.S tarrontlenl Permit Number: 18WE0274 AIRS ID Number: 1 [Leave blank unless APCD has already assigned a permit it and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 545572.00 E, 4443766.00 N Operator Stack 1D No Discharge Height Above Ground•Level (Feet) Temp ::{ F) Flow Rate (ACFM) Yeloclty #ftisec) Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑ Other (describe): ❑ Upward with obstructing raincap Section 6 - Control Device Information 0 VRU: Pollutants Controlled: Size: Requested Control Efficiency VRU Downtime or Bypassed Make /Model: ❑ Combustion Device: Pollutants Controlled: Rating: Type: MMBtu/hr Make/Model: Requested Control Efficiency: % Manufacturer Guaranteed Control Efficiency Minimum Temperature: Waste Gas Heat Content Constant Pilot Light: 0 Yes 0 No Pilot burner Rating Btu/scf MMBtu/hr 0 Other:. Pollutants Controlled: Description: Control Efficiency Requested Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 Avasy COLORADO PM Permit Number: 18WE0274 AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑ Yes El No If yes, please describe the control equipment. AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) PM SOX NOX VOC CO HAPs Other: From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions:) .Uncontrolled • Emission • Factor Emission, Factor Units Emission:!' Factor Source (AP -42, Mfg. etc) Uncontrolled (Tons/year) Controlled (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) SOX NOX VOC 2,15E+04 lb/MMSCF Engineering Est. 2.15 2.15 CO Benzene 1.17E+05 Ib/MMSCF Engineering Est. 0.006 0,006 Toluene 2.00E+05 Ib/MMSCF Engineering. EsL 0,01 0.01 Ethylbenzene 4.80E+04 Ib/MMSCF Engineering Est 0.0024 0.0024 Xylenes '1.09E+05 lb/MMSCF Engineering Est. 0.005 0.005 n -Hexane 1.67E+06 lb/MMSCF Engineering EsL 0.0835 0.0835 2,2,4- Trimethylpentane 1.33E+03 Ib/MMSCF Engineering Est. 6.65E-05 6.65E-05 Other: 5Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6Annual emission fees wilt be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 - COLORADO 5 I Des.rs::r�sa r_ c. Iir.. ... b Lmn:tner. Permit Number: 1 8WEp274 AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit " and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. /71 7 Signature of Legally Authorized rson (not a vendor or consultant) Date Matthew T. Berghorn, P.E. VP - Engineering and Construction Name (please print) Title Check the appropriate box to request a copy of the: O Draft permit prior to issuance p✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time). Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692.31.50 Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 or visit the APCD website at: https://www.colorado.gov/cdphe/apcd COLORADO A. Sure) _ 4?EeJ C -1-.S.18) 1144, Natural Gas Venting APEN - Form APCD-211 2418 Air Pollutant Emission Notice Application for Construction Permit and �'fQes All sections of this APEN and application must be completed for both new and existi h ing If updates. An application with missing information may be determined incomplete and ay beIreturned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled"but --� incorrectly or is missing information and requires re -submittal. This APEN is to be used for Natural Gas Venting only. Natural Gas Venting includes emissions from gas/liquid separators, well head casing, pneumatic pumps, blowdown events, among other events. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: l 8 I r 0 2 -L AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: CB IF/ y 0(0 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Namel: Discovery DJ Services LLC Site Name: Discovery Kiowa Gas Plant Site Location: Section 29, Ti N, R63W Mailing Address: (Include Zip Code) 3601 Stagecoach Road, Ste. 202 Longmont, CO 80504 E Mail Address': mnorton@discoverymidstream.com Site Location County: Weld NAICS or SIC Code: 213112 Permit Contact: Matthew Norton Phone Number: (817) 455-5799 'Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-211 - Natural Gas Venting APEN - Rev 03/2017 3n269 1 AY MOM terrisesunne COLORADO Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action ,r❑ NEW permit OR newly -reported emission source - OR - MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit O Change permit limit 0 Transfer of ownership' 0 Other (describe below) -OR - ❑ APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ▪ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. .F.3 Section 3 - General Information General description of equipment and purpose: Compressor Blowdowns For existing sources, operation began on: / For new or reconstructed sources, the projected start-up date is: 10 / 1 / 2018 ❑ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day Will this equipment be operated in any NAAQS nonattainment area Is this equipment located at a stationary source that is considered a Major Source of (HAP) Emissions days/week weeks/year ❑✓ Yes 0 Yes ❑ No El No Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 2 COLORADO RaaM6 Emixament Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] 4 . ,f .a Section 4 - Process Equipment Information ❑ Gas/Liquid Separator El Well Head Casing ❑ Pneumatic Pump Make: Model: Serial #: ❑ Compressor Rod Packing Make: Model: # of Pistons: • Blowdown Events # of Events/year: 96 per compressor Volume per event: ❑ Other Description: Capacity: Leak Rate: 0.004 per compressor Gal/min Scf/hr/pist MMscf/event If you are requesting uncontrolled VOC emissions greater than 100 tpy for a Gas/Liquid Separator you must use Natural Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? El Yes Natural Gas Venting Process Parameters4: Liquid Throughput Process Parameters4: ❑✓ No Maximum Vent Rate: SCF/hr Vent Gas Heating Value: BTU/SCF Requested: MMSCF/year Actual: MMSCF/year -OR- Requested: Bbl/yr Actual: Bbl/yr 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth Process Properties: Molecular Weight: VOC (mole %) VOC (Weight %) Benzene (mole %) Benzene (Weight %) Toluene (mole %) Toluene (Weight %) Ethylbenzene (mole %) Ethylbenzene (Weight %) Xylene (mole %) Xylene (Weight %) n -Hexane (mole %) n -Hexane (Weight %) 2,2,4-Trimethylpentane (mole %) 2,2,4-Trimethylpentane (Weight %) Additional Required Information: • Attach a representative gas analysis (including BTEX it n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX a n -Hexane, temperature, and pressure) Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 3IAY COLORADO oep.m.mof wbl. Hu bEa. Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit d and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 545356.74 E, 4429913.03 N Operator Stack ID No.' Discharge Height Above Ground Level (Feet) Temp. (`F) Flow Rate (ACFM) Velocity (ftlsect) Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑ Other (describe): ❑ Upward with obstructing raincap Section 6 - Control Device Information ❑ VRU: Pollutants Controlled: Size: Make/Model: Requested Control Efficiency VRU Downtime or Bypassed ❑ Combustion Device: Pollutants Controlled: Rating: MMBtu/hr Type: Make/Model: Requested Control Efficiency: % Manufacturer Guaranteed Control Efficiency Minimum Temperature: Waste Gas Heat Content Constant Pilot. Light: ❑ Yes ❑ No Pilot burner Rating Btu /scf MMBtu / hr ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested 0/0 Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 COLORADO 4cMY i Ne�i[tSb Ennimue.nx Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit A and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑ Yes ✓E No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) PM Sax NOx VOC CO HAPs Other: From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Pollutant Uncontrolled Emission Factor Emission ' Factor Units Emission Factor Source (AP -42, . Mfg. etc) Actual Annual Emissions Requested Annual Permit Requested Emission`Lnmit(s)5 Uncontrolled (Tons/year) Controlled6 (Tons/year) Uncontrolled (Tons/year) _ Controlled (Tons/year) PM SOX NO. VOC 3.20 lb/event Engineering Est 1.84 1.84 CO Benzene 0.16 lb/event Engineering Est 0.0915 0.0915 Toluene 0.27 lb/event Engineering Est 0.156 0.156 Ethylbenzene 0.06 lb/event Engineering Est. 0.0374 0.0374 Xylenes 0.15 lb/event Engineering Est. 0.0848 0.0848 n -Hexane 2.26 lb/event Engineering Est 1.301 1.301 2,2,4- Trimethylpentane 0.0018 Ib/event. Engineering Est. 0.0010 0.0010 Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 5 I A_ COLORADO tep racamt t nmu, Enrumnmenx . f3 Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. i� Signature of Legally Aut(i9fized Person (not a vendor or consultant) Date Matthew T. Berghorn, P.E. VP - Engineering and Construction Name (please print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance ❑✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https: //www.colorado.gov/cdphe/apcd Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 6 I L�1`� COLORADO neistru ai Public lWtilt Em4bimem Natural Gas Venting APEN Form A Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal This APEN is to be used for Natural Gas Venting only. Natural Gas Venting includes emissions from gas/liquid separators, well head casing, pneumatic pumps, blowdown events, among other events. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increacP production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, IL.C. for revised APEN requirements. Permit Number: 18WE0274 Company equipment Identification: AIRS ID Number:. CB I Section 1 - Administrative Information Company Names: Discovery DJ Services LLC Site Name: Discovery Kiowa Gas Plant Site Location: Section 29, T1 N, R63W Mailing Address: (include z,c coda) 3801 Stagecoach Road, Ste. 202 Longmont, CO 80504 E -Mail Address'`: mnorton@discoverymidstream.com Site Location County: Weld NAICS or SIC Code: 213112 Permit Contact: Matthew Norton Phone Number: (817) 455-5799 1Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on alt documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. 4C£Yk ADO Permit Number: 18WE0274 AIRS ID Number: I / Section 2- Requested Action ❑ NEW permit OR newly -reported emission source -OR- • MODIFICATION to existing permit (check ecc:h pox bei• K that orpt;es) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit Q Change permit limit ❑ Transfer of ownership= ❑ Other (describe below) OR ❑ APEN submittal for update only (Please note blank APENs will not be accepted) - ADDmONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: ' For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Compressor Biowdowns For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: I 10 / 1 / 2018 O Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day days/week weeks/year Will this equipment be operated in any NAAQS nonattainment area Is this equipment located at a stationary source that is considered a Major Source of (HAP) Emissions Q Yes ❑ Yes ❑ No LQ Permit Number: 18WE0274 MRS ID Number: / Section 4 - Process Equipment information Q Gas/Liquid Separator O Well Head Casing O Pneumatic Pump Make: Model: Serial #: ❑ Compressor Rod Packing Make: Model: # of Pistons: • Blowdown Events # of Events/year: 48 per compressor Volume per event: ❑ Other Description: Capacity: Leak Rate: 0.004 per compressor Gal/min Scf/hr/pist MMscf/event If you are requesting uncontrolled VOC emissions greater than 100 tpy for a Gas/Liquid Separator you must use Natural Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? ❑ Yes Natural Gas Venting Process Parameters4: Liquid Throughput Process Parameters4: ❑ No Maximum Vent Rate: SCF/hr Vent Gas Heating Value: 1 BTU/SCF Requested: MMSCF/year Actual: ! MMSCF/year -OR- Requested: Bbl/yr Actual: Bbl/yr 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth Process Properties: Molecular Weight: VOC (mole %) V0C (Weight %) Benzene (mole %) Benzene (Weight %) Toluene (mole %) Toluene (Weight %) Ethylbenzene (mole %) Ethylbenzene (Weight %) Xyler (mole %) Xylene (Weight %) n -Hexane (mole %) n -Hexane (Weight %) 2,2,4-Trimethylpentane (mole %) 2,2,4-Trimethylpentane (Weight %) Additional Required Information: • Attach a representative gas analysis (including BTEX Et n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX Et n -Hexane, temperature, and pressure) Permit Number: 9 8WE0274 AIRS ID Number; / I Section 5 - Stack Information Geographical Coordinates (Latir.arl4ionSitude yr DTA) 545356.74 E. 442999 3.03 N opecir III tia Discharge He> t AM�r+e Ga.lsrel t Wi)". T C Itae tAC Yeloc�ty Indicate the direction of the stack outlet: (,,:heck on9) ❑ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: check cre) ❑ Circular Interior stack diameter (inches): ❑ Other (describe): ❑ Upward with obstructing raincap Section 6 - Control Device Information ❑ VRU: Pollutants Controlled: Size: Requested Control Efficiency VRU Downtime or Bypassed Make /Mode{: O/ ❑ Combustion Device: Pollutants Controlled: Rating: MMBtu/hr Type: Make/Model: Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: Waste Gas Heat Content Constant Pilot Light: ❑ Yes ❑ No Pilot burner Rating Btu/scf MMBtu/hr Other: Pollutants Controlled: Description: Control Efficiency Requested Rey -331i1017 4i COR ADO PM Permit Number: 18WE0274 AIRS ID Number: I Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑ Yes IJ No f yes, please describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Overall Request: Efficiency (% reduction in emissions PM Sax Nax vac CO HAPs Other: From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Uncontrolled Emission actor Emissfon Factor Units Emission Factor Source (AP -42 Mfg.. etc) Uncontralle= (Tons! year)'. Controlled° (Torts/year) uncontrolled irons/year) SOx NO,, voC 3.20 lb/event Engineering Est. 0.92 0.92 CO Benzene 0.16 lb/event EngineerinCEst 0.0457 0.0457 Toluene 0.27 lb/event Engineering Est 0.0778 0.0778 Ethylbenzene 0.06 ib/event Engine_wtng. 0.0187 0.0187 Xylenes 0.15 lb/event Engineering Est 0.0424 0.0424 n -Hexane 2.26 Ibrevent Engineering Est 0.6504 0.6504 2,2,4- Trimethylpentane Other: 0.0018 lb/event Engineering Est, 0.0005 0.0005 s Requested values will become permit limitations. Requested timit(s) should consider future process growth. 6Annual emission fees will be based on actual. controlled emissions reported. If source has not yet started operating, leave blank. Rev 013120 1 7 Permit Number: 18WE0274 AIRS ID Number: Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. -f O rg Signature of Legally Authorized Peso (not a vendor or consultant) Matthew T.Bergh©rn, P.E. Name (please print) Date VP - Engineering and Construction Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 8©246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 APEN Rev For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692.3148 Or visit the APCD website at: https: //www.colorado.govicdphe/apcd 6 K, JUL 5 2018 Natural Gas Venting APEN — Form APC -211 Air Pollutant Emission Notice (APEN) and . -7 'a7 Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may charged an additional APEN fee if the APEN is filled out incorrectly oris missing information and requires re -submittal. This APEN is to be used for Natural Gas Venting only. Natural Gas Venting includes emissions from. gas/liquid separators, well head casing, pneumatic pumps, blowdown events, among other events. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.eov/cdphe/aped. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment,change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number:. 18WE0274 AIRS ID Number: 3 / tl A' a I [Leaveblankunless APCD has already assigned a. permit ' and AIRS ID] Company equipment Identification: CB [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Discovery DJ Services LLC Site Name: Discovery Keenesburg Gas Plant Site Location: Section 17, T2N, R63W Mailing Address: (include Zip Code) 3601 Stagecoach Road, Ste. 202 Site Location County: Weld NAICS or SIC Code: 213112 Longmont CO 80504 Permit Contact: E -Mail Address2: mnorton@discoverymidstream.com Matthew Norton Phone Number: (817) 455-5799 'Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemptionletters, and any processing invoices will be issued by APCD via e-mail to the address. provided: Form APCD-211 - Natural Gas Venting.APEN - Rev 03/2017 p COLORADO 1 Permit Number: 18WE0274 AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action ❑ NEW permit OR newly -reported emission source -OR- Q MODIFICATION to existing permit (check each box below that applies) •❑ Change fuel or equipment ❑ Change company name 0 Add point to existing permit ❑ Change permit limit 0 Transfer of ownership3 0 Other (describe below) - OR • APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - • Limit Hazardous Air Pollutants (NAPS) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info & Notes: Updates to reflect new plant name, change in location. 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Compressor Blowdowns For existing sources, operation began on: For new or reconstructed sources, the projected start -update is: / I 10 / 1 / 2018 O Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day Will this equipment be operated in any NAAQS nonattainment area Is this equipment located at a stationary source that is considered a Majer Source of (HAP) Emissions. Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 days/week weeks/year 2 Yes ❑ Yes ❑ No ❑✓ No 2 I AV(('J�� -. COIORaDo Ur t- ¢= Permit Number: 18WE0274 AIRS ID Number: / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Process Equipment Information ❑ Gas/Liquid Separator ❑ Well Head Casing ❑ Pneumatic Pump Make: Model: Serial #: ❑ Compressor Rod Packing Make: Model: # of Pistons: ❑✓ Blowdown Events # of Events/year: 48 per compressor Volume per event: ❑ Other Description: Capacity:. Leak Rate: 0.004 per compressor Gal/min Scf/hr/gist MMscf/event If you are requesting uncontrolled V0C emissions greater than 100 tpy for a Gas/Liquid Separator you must use Natural Gas Venting as a process parameter. Are requested uncontrolled V0C emissions greater than 100 tpy? 0 Yes Natural Gas Venting Process Parameters4t Liquid Throughput Process Parameters4: 0 No Maximum Vent Rate: SCF/hr Vent Gas Heating Value: BTU/SCF Requested: MMSCF/year Actual: MMSCF/year -OR- Requested: Bbl/yr Actual: Bbl/yr 4 Requested values wilt become permit limitations. Requested limits) should consider future process growth Process Properties: Molecular Weight: V0C (mote%) V0C (Weight %) Benzene (mole %) Benzene (Weight %) Toluene (mole %) Toluene (Weight %) Ethylbenzene (mole %), Ethylbenzene (Weight %) Xylene (mole %) Xylene (Weight %) n -Hexane (mole %). n -Hexane (Weight %) 2,2,4-Trirnethylpentane (mole %) 2,2,4-Trimethylpentane (Weight %) Additional Required Information: 2 Attach a representative gas analysis (including BTEX Ft n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX Ft n -Hexane, temperature, and pressure) a❑ Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 COLORADO - nwErs rasvn:�m.,� Permit Number: 18WE0274 AIRS ID Number: / [Leave blank unless APCD has already assigned a permit if and AIRS ID] Section 5 - Stack Information Geographical Coordinates (LatitudefLongitude or UTM)'._ 545674.80 E, 4443762.47 N OperaCar tack ID- No°{• Discharge [eight Above Ground Level {Feet) Temp F) Flow Rate {ACfM) Veltam {fusee) Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Horizontal. ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑ Other (describe): 0 Upward with obstructing raincap Section 6 - Control Device Information ❑ VRU: Pollutants Controlled: Size: Make/Model: Requested Control Efficiency VRU Downtime or Bypassed ❑ Combustion Device: Pollutants Controlled: Rating: MMBtu/hr Type: Make/Model: Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: Waste Gas Heat Content Constant Pilot Light: 0 Yes 0 No Pilot burner Rating Btu/scf MMBtu/hr 0 Other: Pollutants Controlled: Description: Control Efficiency Requested Form APCD-211 -Natural Gas Venting APEN - Rev 03/20.17 V COLOR ADC 4 I L}SR PM PM Permit Number: 18WE0274 AIRS ID Number: [Leave blank unless APCD has already assigned a permit 1 and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑ Yes E No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) 'SOX NO), VOC CO HAPs Other: From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Uncontrolled Emission Factor Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) ctual Annua Controlled6 (Tons/year) rinu mission Limit. �.� Uncontrolled (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) SOX NOx VOC 3:20 lb/event Engineering Est 0,92. 0.92 CO Benzene 0'A6 lb/event Engineering Eel. 0:0457 0.0457 Toluene 0.27 lb/event Engineering Est. 0.0778 0.0778 Ethylbenzene 0:0.6 lb/event Engineering Est 0:0187 0.0187 Xylenes 0.15 lb/event Engineering Eel. 0.0424 0.0424 n -Hexane 2.26 Ib/event. Engineering Est 0.6504 0.6504 2,2,4- Trimethylpentane 0.0018 lb/event Engineering Est 0.0005 0.0005 Other: 5 Requested values will become permit limitations, Requested timit(s) should consider future process growth. 6Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 5 1 Al COLORADO Ilra!11,3 tX,::=, Permit Number: 18WE0274 AIRS ID Number: I I [Leave blank unless APCD has already assigned a permit It and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. r Date Signature of Legally Authorized per (not a vendor or consultant) Matthew T. Berghorn, RE. VP - Engineering and Construction Name (please print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance ❑✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd A. COLORADO 6 j Lfe)14alleir Gti n (q. S. ' ) Natural Gas Venting APEN - Form APCD Air Pollutant Emission Notice (APEN) and Application for Construction Permit pp18 ' trtyh All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for Natural Gas Venting only. Natural Gas Venting includes emissions from gas/liquid separators, well head casing, pneumatic pumps, blowdown events, among other events. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 2 ? L AIRS ID Number: 0,3 /q Pl-i-i a t [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: RP [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Discovery DJ Services LLC Site Name: Discovery Kiowa Gas Plant Site Location: Section 29, T1 N, R63W Mailing Address: (Include Zip Code) 3601 Stagecoach Road, Ste. 202 Longmont, CO 80504 E -Mail Address'-: mnorton@discoverymidstream.com Site Location County: Weld NAICS or SIC Code: 213112 Permit Contact: Matthew Norton Phone Number: (817) 455-5799 'Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. 376270 0 Form APCD-211 - Natural Gas Venting APEN - Rev 03/2017 COLORADO fftelerd Wt HAba.�6amvenu Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action r❑ NEW permit OR newly -reported emission source -OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name 0 Add point to existing permit 0 Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below) OR ❑ APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - [I Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Compressor Rod Packing For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: / / 10 / 1 / 2018 ❑ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: 24 hours/day 7 Will this equipment be operated in any NAAQS nonattainment area Is this equipment located at a stationary source that is considered a Major Source of (HAP) Emissions days/week 52 weeks/year ❑✓ Yes ❑ No El Yes ❑✓ No Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 2 I COLORADO "ewman, of Pub. Ran. 6 EnvYen'em[ Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Process Equipment Information ❑ Gas/Liquid Separator ❑ Well Head Casing ❑ Pneumatic Pump Make: Model: O Compressor Rod Packing Make: TBD Model: TBD ❑ Blowdown Events # of Events/year: ❑ Other Description: Serial #: # of Pistons: Volume per event: Capacity: Gal/min Leak Rate: 114 set/compressor Scf/hr/pist MMscf/event If you are requesting uncontrolled VOC emissions greater than 100 tpy for a Gas/Liquid Separator you must use Natural Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? ❑ Yes Natural Gas Venting Process Parameters4: Liquid Throughput Process Parameters4: ❑✓ No Maximum Vent Rate: SCF/hr Vent Gas Heating Value: BTU/SCF Requested: MMSCF/year Actual: MMSCF/year -OR- Requested: Bbl/yr Actual: Bbl/yr 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth Process Properties: Molecular Weight: VOC (mole %) VOC (Weight %) Benzene (mole %) Benzene (Weight %) Toluene (mole %) Toluene (Weight %) Ethylbenzene (mote %) Ethylbenzene (Weight %) Xylene (mole %) Xylene (Weight %) n -Hexane (mole %) n -Hexane (Weight %) 2,2,4-Trimethylpentane (mole %) 2,2,4-Trimethylpentane (Weight %) Additional Required Information: ❑✓ Attach a representative gas analysis (including BTEX it n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX £t n -Hexane, temperature, and pressure) Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 3I co COLORADO neparMarmof n aic HW0hL1e1NNmN Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 545356.00 E, 4429917.80 N e�� O�erator tack- D o� � 3 �Discharg�Height f� ove Ground Lever , ,� (Feet).„_#.._.. Temper , ( Fj ke Flow Rate s� (ACFrg Neloc� , tlsec)) Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑ Other (describe): ❑ Upward with obstructing raincap Section 6 - Control Device Information ❑ VRU: Pollutants Controlled: Size: Make/Model: Requested Control Efficiency % VRU Downtime or Bypassed ❑ Combustion Device: Pollutants Controlled: Rating: Type: Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: MMBtu/hr Make/Model: Waste Gas Heat Content Constant Pilot Light: ❑ Yes ❑ No Pilot burner Rating Btu/scf MMBtu/hr ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 41 Co COLORADO Deputmne of NW& XeanII6EmYaveeei PM PM Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? O Yes ✓❑ No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): Control Equipment Description .tt Overall Requested Control Efficiency. (% reduction in emissions) Son NO. VOC CO HAPs Other: From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Uncontrolled Emission Factor'' lb/event mission Factor inits' Emission Factor Source (AP -42, Mfg. etc) Uncontrolled (Tons/year)= Controlled6 (Tons/year) `! Uncontrolled (Tons/year) Controlled (Tons/year). equested=Annual Permit - Son NO. VOC 799.14 Engineering Est. 4.79 4.79 CO Benzene 39.70 lb/event Engineering Est 0.238 0.238 Toluene 67.54 lb/event Engineering Est. 0.405 0.405 Ethylbenzene 16.23 lb/event Engineering Est. 0.097 0.097 Xylenes 36.82 lb/event Engineering Est. 0.221 0.221 n -Hexane 564,60 lb/event Engineering Est. 3.388 3.388 2,2,4- Trimethylpentane 0.45 lb/event Engineering Est. 0.003 0.003 Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 5 1 Co COLORADO oeP.nm.m of Pat. Res. &Environment Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. Signature of Legally Autho d Person (not a vendor or consultant) Date Matthew T. Berghorn, P.E. VP- Engineering and Construction Name (please print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance 0 Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 43O0 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 6I COLORADO o.,.rtmentotnetic Heatthh Eselmmee. Natural Gas Venting APEN .Fo Air Pollutant Emission Notice (APEN) aid Application for Construction Permit All sections of this APEN and application must be completed for both new and existingfacilities, including PEN' updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out. incorrectly or is missing information and requires re -submittal. This APEN is to be used for Natural. Gas Venting only. Natural Gas Venting includes emissions from gas/liquid separators, well head casing, pneumatic pumps, blowdown events, among other events. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www. colorado. qov /cdphe/apcd. This emission notice i3" valid for five (5) years. Submission of a. revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, Ii.C. for revised APEN requirements. Permit Number: 18WE0274 AIRS ID Number: },3 /CI fr7?i U I [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: RP [Provide Facility Equipment ID to. identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Discovery DJ Services LLC Site Name: Discovery Keenesburg Gas Plant Site Location: Section 17, T2N, R63W Mailing Address: (Include Zip Code) 3601 Stagecoach Road, Ste. 202 Longmont, CO 80504 E -Mail Address': mnorton@discoverymidstream.com Site. Location County: Weld NAICS or SIC Code: 213112 Permit Contact: Matthew Norton Phone Number: (817) 455-5799 iPlease use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2: Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. �C0LORA0O Form APCD-211 - Natural Gas Venting APEN - Rev 0.3/2017 Permit Number: 18WE0274 AIRS ID Number: [Leave blank unless APCD has already assigned a permit If and AIRS ID] Section 2- Requested Action ❑ NEW permit OR newly -reported emission source -OR - MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit i0 Transfer of ownership3 ✓❑ Other (describe below) - OR • APEN submittal for update only (Pleasenote blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - • Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional info & Notes: Updates to reflect new plant name, change in location. 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Compressor Rod Packing For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: 10 / 1 / 2018 O Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: 24 hours/day 7 days/week 52 Will this equipment be operated in any NAAQ5 nonattainment area. Is this equipment located at a stationary source that is considered a Major Source of (HAP) Emissions Form-APCD-211 -Natural Gas Venting APEN - Rev 03/2017 ❑� Yes O Yes weeks/year ❑ No ❑✓ No COLOR.A00 2..I Permit Number: 18WE0274 AIRS ID Number: / [Leave blank unless APCD has already assigned a permit tl and AIRS ID] Section 4 - Process Equipment Information ❑ Gas/Liquid Separator ❑ Well Head Casing ❑ Pneumatic Pump Make: Model: 0 Compressor Rod Packing Make: TBD Model: D Blowdown-Events # of Events/year: O Other Description: TBD Serial # # of Pistons: Volume per event: Capacity: Gal/min Leak Rate: M114scficampressor Scf/hr/pist MMscf/event If you are requesting uncontrolled V0C emissions greater than 100 tpy for a Gas/Liquid Separator you must use Natural Gas Venting as a process parameter. Are requested uncontrolled V0C emissions greater than 100 tpy? ❑ Yes Natural Gas Venting Process Parameters4: Liquid Throughput Process Parameters4: ❑� No Maximum Vent Rate: SCF/hr Vent Gas Heating Value: BTU/SCF Requested: MMSCF/year Actual: MMSCF/year -OR- Requested: Bbl/yr Actual: Bbl/yr 4 Requested values will become permit limitations. Requested limits) should consider future process growth Process Properties: Molecular Weight: VOC (mole %) V0C {Weight %) Benzene (mole %) Benzene (Weight %) Toluene (mole %) Toluene (Weight %) Ethylbenzene (mole. %) Ethylbenzene (Weight %) Xylene (mole %) Xylene (Weight %) n -Hexane (mote %) n -Hexane (Weight %) 2,2,4-Trimethylpentane (mote. %) 2,2,4-Trimethylpentane (Weight %) Additional Required Information: 0 Attach a representative gas analysis (including BTEX ft n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX Et n -Hexane, temperature, and pressure) Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 COLORADO ▪ 3 Permit Number: 18WE0274 AIRS ID Number: [Leave blank unless APCD has already assigned a permit f< and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 545674.80 E, 4443762.47 N Operator Stack ID�No Discharge Heigh# . Above Ground Level (Feet), Temp ( F) Ftow Rate k (ACFM) Yeloct s , (ft/sec) Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular ❑ Other (describe): Interior stack diameter (inches): ❑ Upward with obstructing raincap Section 6 - Control Device Information 0 VRU: Pollutants Controlled:. Size: Make/Model: Requested Control Efficiency VRU Downtime or Bypassed "'I Device: Device: Pollutants Controlled: Rating: MMBtu/hr Type: Make/Model: Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: Waste Gas Heat Content Constant Pilot Light: ❑ Yes ❑ No Pilot burner Rating Btu/scf MMBtu/hr 0 Other: Pollutants Controlled: Description: Control Efficiency Requested 0/0 caIoanoo Form APCD-211 -Natural Gas Venting APED - Rev 03/2017 PM Permit Number: 18 WE0274 AIRS ID Number: [Leave blank unless APCD has already assigned a permit k and AIRS iD] Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. is any emission control equipment or practice used to reduce emissions? ❑ Yes IJ No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): Control Equipment Description. Overall Requested Control Efficiency (% reduction in emissions) SOX NO),. VOC CO HAPs Other: From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) PM Pollutant Uncontrolled Emission Factor Emission Factor Units. Emission Factor Source (AP -42, Mfg. etc) Uncontrolled (Tons/year) Controlledf (Tons/year) nual Perm mission Limits„ Uncontrolled (Tons/year) Controlled (Tons/year)';,`. SOX NOX VOC 799.14 lb/event Engineering Est. 4.79 4.79 CO Benzene 39.70. lb/event Engineering Est. 0.238 0.238 Toluene 67.54 lb/event Engineering Est 0.405 0.405 Ethylbenzene 16.23 lb/event Engineering Est. 0.097 0.097 Xylenes 36.82 lb/event Engineering Est. 0.221 0.221 n -Hexane 564.60 lb/event Engineering Est. 3.388 3.388 2,2,4- Trimethylpentane 0.45 lb/event Engineering. Est 0.003 0.003 Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6Annual emission fees will be based on actual controlled emissions reported. if source has not yet started operating, leave blank. Form APCD-211 -natural Gas Venting APEN - Rev 03/2017 AVIV:-CO1.O RA 0O. 1=a;.t;k L,=rr•.r Permit Number: 18WE0274 AIRS ID Number: [Leave blank unless APCD has already assigned a permit n" and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. Signature of Legally Authorizer) rson (not a vendor or consultant) Date Matthew T. Bergho n, P.E. VP- Engineering and Construction Name (please print) Title Check the appropriate box to request a copy of the:. ❑ Draft permit prior to issuance Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and. Environment. Telephone: (303) 692-3150 Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.cotorado.gov/cdphe/apcd ;COLORADO A 6 I General APEN - Form APCD- Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. There may be a more specific APEN for your source (e.g. paint booths, mining operations, engines, etc.). A list of specialty APENs is available on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: AIRS ID Number: 123 / 1FA3/ u t [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Site Name: Discovery DJ Services LLC Discovery Kiowa Gas Plant Site Location: Section 29, Ti N, R63W Mailing Address: 3601 Stagecoach Road, Ste. 202 (Include Zip Code) Longmont, CO 80504 Portable Source N/A Home Base: Site Location WeIA ld County: NAICS or SIC Code: 213112 Permit Contact: Matthew Norton Phone Number: (817) 455-5799 E -Mail Address2: mnorton@discoverymidstream.com Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. 376271 Form APCD-200 - General APEN - Revision 1/2017 COLORADO 1 I V .2�e Enruanwini Fs Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action ❑ NEW permit OR newly -reported emission source (check one below) ❑ STATIONARY source ❑ PORTABLE source -OR- ❑ MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment ❑ Change company name ❑ Add point to existing permit O Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below) -OR - ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) ❑� APEN submittal for permit exempt/grandfathered source Additional Info Et Notes: APEN-reportable but permit -exempt methanol storage tank 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: tanks Three (3) 1,000 -gallon methanol storage Manufacturer: TBD Model No.: TBD Company equipment Identification No. (optional): For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Serial No.: TBD 10/1/2018 ❑,r Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: Seasonal use percentage: Dec -Feb: hours/day days/week Mar -May: Jun -Aug: weeks/year Sep -Nov: Form APCD-200 - General APEN - Revision 1/2017 2 (COLORADO .R,anm wUw.m •- 4 Deput6EwYeDO Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Processing/Manufacturing Information a Material Use ❑ Check box if this information is not applicable to source or process From what year is the actual annual amount? Description Design Process Rate (Specify Units) . Actual Annual Amount (Specify Units) Requested Annual Permit Limit4 (Specify Units) Material Consumption: Finished Product(s): Methanol Storage Tank 100 bbl/day 36,500 bbl/yr 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 545284.30 E, 4429981.60 N Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Operator Stack ID No. ' - Discharge Height Above Ground Level (Feet) Temp. i (° F) "� Flow Rate (ACFM) Velocity (ft/sec) Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): ❑ Upward with obstructing raincap Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): Form APCD-200 - General APEN - Revision 1/2017 VCOLORADO Waal. 6 rmaranrrom TSP (PM) Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Combustion Equipment £t Fuel Consumption Information E Check box if this information is not applicable to the source (e.g. there is no fuel -burning equipment associated with this emission source) - Design Input.Rate '- "=(MMBTU/hr) =; Actual Annual Fuel Use (Specify Units - Requested Annual Permit Limit4.. (Specify Units) From what year is the actual annual fuel use data? Indicate the type of fuel useds: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) ❑ Field Natural Gas Heating value: BTU/SCF ❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTU/SCF) ❑ Coal Heating value: BTU/lb Ash Content: Sulfur Content: ❑ Other (describe): Heating value (give units): a Requested values will become permit limitations. Requested limit(s) should consider future process growth. s If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑ Yes ❑✓ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Control Equipment Description Overall Collection Efficiency Overall Control Efficiency, (% reduction in emissions) PM10 PMz.5 SOX NOx CO VOC Other: Form APCD-200 - General APEN - Revision 1/2017 COLORADO 4I ® f� Neal. 67561 Methanol TSP (PM) Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 (continued) From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Uncontrolled Emission Factor (Specify Units) Emission Factor Source, (AP -42, Mfg. etc) Uncontrolled (Tons/year) Controlledb (Tons/year) Controlled (Tons/year) Uncontrolled (Tons/year) PM10 PM2.s 5OX NOX CO VOC 0.00832 lb/bbl EPA Tanks 0.15 0.15 Other: Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Section 8 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP- hazardous air pollutant) emissions equal to or greater than 250 lbs/year? O Yes E No If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: Overall ,Control Efficiency Uncontrolled Emission Factor (specify units) Emission Factor. Source (AP -42, Mfg: etc), Uncontrolled Actual; Emissions (lbs/year) Controlled Actual- Emissions6 (lbs/year) 0 0.00832 Ib/BBL EPA Tanks 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-200 - General APEN - Revision 1/2017 [COLORADO 5I Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Applicant Certification hereby certify that all information contained herein and information submitted with this application is complete, true and correct. iil � l Signature of Legally Authblized Person (not a vendor or consultant) Date 3 -G-tg Matthew T. Berghorn, P.E. VP Engineering and Construction Name (print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance • Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 to: For more information or assistance call: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form APCD-200 - General APEN - Revision 1/2017 p COLORADO 6 I �� °R.rtmeat fleall� O R JUL 5 2C1 General APEN - Form D-200 Air Pollutant. Emission Notice (APEN) Application for Construction. Permit All sections of this APEN and application must be completed for both new and existing facilities,cludi • EN updates. An application with missing information may be determined incomplete and may be returned esult in longer application processing times. You may be charged an additional APEN fee if the APENis filled out incorrectly or is missing information and requires re -submittal. There may be a more specific APEN for your source (e.g. paint booths, mining operations, engines, etc.). A list of specialty APENs is available on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 18WE0274 AIRS ID Number: , /1F47/ O [Leave blank unless APCD has already assigned a permit n and AIRS ID] Section 1 Administrative Information Company Name: Site Name: Discovery DJ Services LLC Discovery Keenesburg Gas Plant Site Location: Section 17, T2N, R63W Mailing. Address:. 3601 Stagecoach Road, Ste. 202 (Include Zip Code) g Longmont, CO 80504 Portable Source N/A Home Base: Site Location Wed County: NAICS or SIC Code: 2131.1.2 Permit Contact: Matthew Norton Phone Number: (817) 455-5799 E -Mail Address2: mnorton@discoverymidstream.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. My changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-200 - General APEN - Revision 1/2017 COLORADO 1 I A :,7,.r..,F�.'. N :t.F fn.:.nnv....1. Permit dumber: 18WE0274 AIRS ID Number: [Leave blank unless APCD has already assigned a permit if and AIRS ID] Section 2- Requested Action ❑ NEW permit OR newly -reported emission source (check one below) ❑ STATIONARY source ❑ PORTABLE source OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment O Change company name ❑ Add point to existing permit ❑ Change permit limit O Transfer of ownerships ❑ Other (describe below) -OR - ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) ▪ APEN submittal for permit exempt/grandfathered source Additional Info Et Notes: APEN-reportable but permit -exempt methanol storage tank. Updates to reflect new plant name, change in location. 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: tanks Three (3) 1,000 -gallon methanol storage Manufacturer: TBD. Model No.: TBD Serial No.: TBD Company equipment Identification No. (optional): . MT For existing sources, operation began on: For new or reconstructed sources, theprojected start-up date is: 10/1/2018 0 Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day days/week weeks/year Seasonal use percentage: Dec -Feb:. Mar -May: Jun -Aug: Sep -Nov: Form APCD-200 - General APEN - Revision 1/2017 2 I �Q3' COLORADO ❑cpaen<rt<fNa`x Methanol Storage Tank Permit Number: I8 W E 02 74 AIRS ID Number: / I [Leave blank unless APCD has already assigned a permit it and AIRS ID] Section 4 - Processing/Manufacturing Information &t Material Use 0 Check box if this information is not applicable to source or process From what year is the actual annual amount? Design Process Rate (Specify Units) Actual Annual Amount (Specify Units) Requested Annual :. Permit Limit4 (Specify Units): Material Consumption Finished Product(s): 100 bbl/day 36,500 bbl/yr 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 545572.00 E, 4443766.00 N El Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. o erator. Stack ID Nn Discharge Height ` Above Ground Level (Feet) Temp Flow Rate (ACFM) e Velocity (ft/sec Indicate the direction of the stack outlet: (check one) 0 Upward ❑ Horizontal 0 Downward. 0 Other (describe): 0 Upward with obstructing raincap. Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): 0 Square/rectangle Interior stack width (inches): Interior stack depth (inches): O Other (describe): Form. APCD-200 - General APEN - Revision 1/2017 COLORADO - 3I Aw, Permit Number: 18WE0274 AIRS ID Number: / [Leave blank unless APCD has already assigned a permit II and AIRS ID] Section 6 - Combustion Equipment Et Fuel Consumption Information 0 Check box if this information is not applicable to the source (e.g. there is no fuel -burning equipment associated with this emission source) Design Input Rate (MMBTUIhr) Actual Annual Fuel Use (Specify Units) Requested Annual Permit Limit4 (Specify Units) From what year is the actual annual fuel use data? Indicate the type of fuel used5: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) ❑ Field Natural Gas Heating value: BTU/SCF ❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTUISCF) ❑ Coal Heating value: BTU/lb Ash Content: Sulfur Content: ❑ Other (describe): Heating value (give units): 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. S If fuel heating value is different than the listed assumed value, provide this information in the "other" field. Section 7 - Criteria Pollutant Emissions. Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑ Yes ❑✓ No f yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Collection Efficiency Overall Control Efficiency (% reduction in emissions) TSP (PM) PM,o PM2.s 5Ox NO, CO VOC Other: Form APCD-200 - General APEN - Revision 1/2017 COLORADO• 4 I A. G:,.z77,1H. TSP (PM) Permit Number: 18WE0274 AIRS ID Number: / t [Leave blank unless APCD has already assigned a permit fl and AIRS ID] Section 7 (continued) From what year is the following reported actual annual emissions data? Use the following table to report the criteria: pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Uncontrolled Emission Factor (Specify Units) Emission Factor Source (AP -42, Mfg. etc) Controlled' (Tons/year) nested Annual mission. L`tmi Uncontrolled (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) PM10 PMz.s SO,. NO, CO VOC 0.00832 lb/bbl EPA Tanks 0.15 0.15 Other: 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Section 8 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP- hazardous air pollutant) emissions equal to or greater than 250 lbs/year? Q Yes ❑ No If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: CAS Number' Methanol Overall Control Efficiency Uncontrolled Emission Factor (specify units), Emission Factor Source (AP -42, Mfg. etc) Uncontrolled Actual Emissions (Ibs/year) Controlled Actual Emissions' (lbsl year) 67561 0 0.00832 lb/BBL EPA Tanks b Annual emission fees will be based on actual ontrolled emissions reported. If source has not yet started operating, leave blank. Form APCD-200 - General APEN - Revision 1/2017 /�!�� COLORADO 5 l iii. tttt Permit Number: 18WE0274 AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Applicant Certification i hereby certify that all information contained herein and information submitted with this application is complete, true and correct. <3. Signature of Legally Authorized Person (not a vendor or consultant) Date Matthew T_ Berghorn, P.E. 1 VP - Engineering and Construction Name (print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance D Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 to: For more information or assistance call: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form. APCD-200 - General APEN - Revision 1/2017 COLORADO 6 I A'„�� Mr_I:f. f. F.rzrF...n.n.al Hello