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Home My WebLink About20212270Mariah Higgins From: Sent: To: Cc: Subject: Attachments: Kim Ogle Tuesday, September 7, 2021 2:45 PM Jessica Reid; Mariah Higgins; Chloe Rempel; Jan Warwick Esther Gesick Addition to case file DCP - Enterprise Compressor Sign jpg; Coors.Access.pdf Good afternoon, Attached is a supporting document addressing COA 1.E states "The applicant shall indicate specifically on the plat the type of right-of-way/easement and indicate whether it is dedicated, private,ordeededto provide adequate access to the parcel. Section line accesses are considered private lanes with no County maintenance. The right-of-way or easementshall be graded and drained to provide all- weather access." Thank you Kim Ogle Weld County Planning Services 970.400.6100 Office 970.400.3549 Direct kogle@weldgov.com Confidentiality Notice: This electronic transmission and any attached documents or other writings are intended only for the person or entity to which it is addressed and may contain information that is privileged, confidential or otherwise protected from disclosure. If you have received this communication in error, please immediately notify sender by return e-mail and destroy the communication. Any disclosure, copying, distribution or the taking of any action concerning the contents of this communication or any attachments by anyone other than the named recipient is strictly prohibited. CoMl. vy Co.+ ;AS o9/i5/2i 1 202► -2.270 PL. ogg6 1 4 ♦ . J - r ' . x i. a-, • •... `....tit ••♦rw -` ` • -a- I4.- • • ♦ a.-• • — M k. ' " ' 4 at'', ,.F: 4. r 4 • - $y _ 4 1 r` v a.. t], -.l p •V My. » • _ <• , a -c ♦ fi 4.2 � • • • Ham_... .•. e- 1 y�+q� T• 'y .;• • �s.r -••r .rte• 'S� • �a Y� '�• M y;. i �.�• ^YVN1Th. �+ `ro • � 3: w • -airy.-- 'V" V..4 • I IT -at - •-• w •�^.•: Vf_ ...�,�. +�{ r '•' .14�"!^r,A`!• r Ci ' . :3�♦Tt • esattlato .l.:laYk;CA• �•l'1tF. ` wtMy',aj�11 \ ♦ t♦ `t'• L arr. . •i • -o;:—,:. w� Lk • ... NS` 4 ♦ fid x'+•y. l� }- ♦ Xr . a. 1r _„y raa a n•^ '� r.. -� ,3- 4 .:. >�E -'• ♦ _ 'mow •. -'n ti• • .. S- `sa- •� �^ t -a 1 \> `•a . 14, • r. tr. itt • a L 4125440 Pages: 1 of e 0 Carizyt Koppss t Ci: k and Recorder, PM R ;Weed County, CO Ell i Ili II:40131MAIi i III LICENSE AGREEMENT This p �LiICENSE AGREEMENT (this "Agreement") is made and entered into effective the � day of T, May, 2015, by and between COORS ENERGY COMPANY, a Colorado corporation ("Licensor"), and DCP MIDSTREAM, LP, a Delaware limited partnership ("Licensee"). In consideration of the mutual covenants and stipulations herein expressed, the parties hereto agree as follows: I. Grant of License. Licensor hereby grants to Licensee and its agents and employees (collectively, "Licensee Parties") a license to occupy and use, subject to the terms and conditions hereinafter expressed, the Keenesburg Mine Access Road to the extent owned by Licensor, and more particularly depicted on Exhibit A attached hereto and incorporated herein by this reference (the "Licensor Property") for the purposes set forth in Section 2 below (the "License"). 2. Purpose of License. Licensee Parties shall have the right to use the Licensor Property for the sole purpose of accessing Licensee's property ("Licensee's Property"), with commercial vehicles (not to exceed 40 tons). In connection with the License, Licensee shall be permitted to install turn lanes from the Licensor Property in order to access Licensee's Property and a gate (collectively, the "Improvements"), in a location, and pursuant to plans, approved by Licensor in its sole discretion and any applicable governmental or quasi -governmental authorities. 3. Compliance With Laws. Licensee shall obtain, at its sole cost and expense, such permits and authorizations as may be required from federal, state, county, municipal and any other governmental or quasi -governmental authorities in connection with the License (Collectively, the "Approvals"). Licensee shall and shall cause all License Parties to comply with all laws, rules and regulations of governing authorities (collectively, "Laws") relating to the use of the Licensor Property by the Licensee Parties. Licensee shall promptly notify Licensor of any violations of Laws and/or Approvals. 4. Term of Agreement. This Agreement shall commence on the date hereof and shall remain in existence until and unless terminated as herein provided. Either party hereto may provide to the other a notice to terminate, and, upon the passage of thirty (30) days following such giving of a notice to terminate by one party to the other hereunder, this Agreement shall terminate and be of no further force and effect, except for the terms and provisions that expressly survive the expiration or termination of this Agreement. 5. Monetary Consideration. This license is granted to Licensee upon payment of 5500.00 ,peryear due to Licensor upon execution hereof and on each annual anniversary. 'licensee's failure to make such payment shall result in the termination of this Agreement, and Licensee waives any prior notice. Licensee hereby acknowledges the title of Licensor to the Licensor Property and agrees never to assail, resist, or deny such title. 6. License Not Exclusive. This License is not exclusive to Licensee and Licensee Parties, and Licensee shall have the privilege hereunder only of using the Licensor Property in a : Ucji ) 4126440 Pages: 2 of 8 07/21/2015 12:41 P11 R Fee:$46.00 Ell ly �1u1TWltIlrQtiIPRecorder, I I tIANT�M�114P11JIciYilk /I III such manner as is necessary to accomplishment of the purposes hereinabove set forth. Licensor shall have the right to enter upon the Licensor Property for its own purposes or to permit others to enter upon the Licensor Property. 7. Release and Indemnification. a) To the fullest extent permitted by law, Licensee hereby releases Licensor and its parent, subsidiaries, and affiliated companies and their respective officers, agents, representatives, and employees (collectively, the "Licensor Parties Parties"), and no Licensor Party shall be liable in any manner to Licensee or any other person claiming through Licensee for any death, injury, loss, damage, cost or expense of any nature whatsoever (the "Claims") resulting from any act or omission occurring on or about the Licensor Property„ except for those claims arising out of the gross negligence or willful misconduct of Licensor. b) Licensee agrees to and shall indemnify Licensor Parties against, and hold Licensor Parties harmless from, any and all claims, loss, damage (whether direct, indirect, or consequential), causes of action, suits, and liabilities of every kind (including attorneys' fees and expenses incurred in the investigation, defense, and settlement of any claim or suit or for the payment of any judgment), for injuries or death of any person, and all damages to and destruction of Licensor Property by whomsoever owned, including loss of use thereat and violations of any Laws and/or Approvals resulting directly or indirectly, in whole or in part, Licensee's or Licensee's Parties' use of the Licensor Property, except to the extent caused by the gross negligence or willful misconduct of Licensor. Licensee shall defend the Licensor Parties against any claim or litigation in connection with any injury, death, damage, or violation covered by Licensee's indemnity, and at Licensee's expense with counsel reasonably acceptable to Licensor Parties or, at the election of Licensor Parties, shall reimburse the Licensor Parties for legal fees and other costs incurred in Licensor Parties' defense of such claims or litigation. The Licensor Parties shall have the right to participate in the defense of any claims or litigation and shall have the right to approve any settlement. 8. Insurance. Licensee shall purchase and maintain during the performance of this Agreement at least the following minimum limits and types of insurance; a) Commercial General Liability Insurance providing combined single limits or $1,000,000.00 per occurrence for bodily injury and/or property damage liability. Said insurance shall, at minimum, cover liability arising from products and completed operations, personal injury/advertising injury and contractual liability; b) Automobile Liability Insurance with combined single limits of $1,000,000.00 per occurrence for bodily injury and property damage liability; c) Statutory Workers' Compensation and Occupational Disease Disability Insurance; 2 4126440 Pages: 3 of 8 Carly Kopp.,, rClerk and Reoorde , Weld County, CO VIII cti1*,IiaIf!ItPk:h.;1I (Ngf i4 N4L iiaMc III III d) Employer's Liability Insurance providing bodily injury by accident, bodily injury by disease per policy and bodily injury by disease per employee, with liability limits of no less than $1,000,000.00 per occurrence; and e) Excess Liability or Umbrella Liability Insurance with a limit of $7,000,000.00 per occurrence. All insurance policies shall be issued by insurance carriers licensed to do business in Colorado and which have an A.M. Best rating of B+ VIII or better during the Effective Period. Supplier shall furnish to Licensor evidence of such insurance coverage in the form of certificates of Insurance reasonably acceptable to Licensor wherein Licensor shall be named as an additional insured on all insurance policies listed in Items (a), (b) and (d) above and required hereunder. Licensee or its agent(s) will make best efforts to send Licensor 30 days' notice of cancellation of insurance, however, failure to do so will not constitute a breach under this Agreement. Insurance policies in items (a) and (b) above which are secured by Licensee pursuant to this Agreement shall be "occurrence" type policies and shall not be "claims made" policies. Any insurance policies that are "claims made" policies, must contain a two-year "sunset clause." Subsequent renewals of any "claims made" policies must maintain the same "retroactive date" as appears on the policy in place on the Effective Date of this Agreement. All Certificates of Insurance shall provide evidence of the type of policies being provided. 9. No Structures. Except for the Improvements, Licensee shall not erect any permanent structures on the Licensor Property or erect or having erected or installed, permit to remain on the Licensor Property any temporary structures, fixtures, attachments, or other things attached to or being on the Licensor Property and placed thereon by Licensee or the guests, invitees, or Licensees of Licensee that Licensor shall direct Licensee to remove. 10. Heavy Equipment. Should Licensee desire to use Licensor's property for the movement of equipment whose gross weight exceeds 40 tons, Licensee shall so notify Licensor. Representatives of Licensor and Licensee shall meet, prior to such intended use to survey that portion of the property intended for such use, and shall agree on the "present condition" of said portion. Again, following the use as stated, the parties shall survey the same road portion for signs of "damage" resulting from the heavy equipment. Any and all damage (to either the surface or the road base) observed by the parties shall be repaired or replaced by Licensee immediately, so that the property is restored to a condition at least equal to that observed prior to the heavy equipment use. 11. License Not Assignable. Licensee's privileges hereunder are personal in nature and shall not be assignable by Licensee in whole or in part. 12. Hazardous Material; Indemnity a) Licensee shall not cause or permit any Hazardous Material to be brought upon, kept or used in or about the Licensor Property by Licensee, its agents, employees, contractors, or invitees without the prior written consent of Licensor. If Licensee breaches the obligations stated in the preceding sentence, or if the presence of Hazardous Material on the Licensor Property caused or permitted by 3 4126440 Pages: 4 Fee:S 6.(0 of co 07/21/2015 i2:4i PM Carly Keppes. Clerk and Recorder. Weld County �IIINl��II+;.Wl�Jf19Ll�+h1�41�ht'IrNt1�4laili#161, S1 Licensee results in contamination of the Licensor Property, or if contamination of the Licensor Property by Hazardous Material otherwise arises from or relates to the acts of Licensee, its agents, employees, contractors of invitees, for damage resulting therefrom, then Licensee shall indemnify, defend, and hold the Licensor Parties harmless from any and all claims, judgments, damages, penalties, fines, costs, liabilities, or losses which arise during or after the term hereof as a result of such use or contamination This indemnification of the Licensor Parties by Licensee includes, without limitation, costs incurred in connection with any investigation of site conditions or any cleanup, remedial, removal, or restoration work required by any federal, state, or local governmental agency or political subdivision. Without limiting the foregoing, if the presence of any Hazardous Material on the Licensor Property caused or permitted by Licensee results in any contamination of the Licensor Property, Licensee shall promptly take all legal actions at its sole expense as are necessary to return the Licensor Property to the condition existing prior to the introduction of any such Hazardous Material to the Licensor Property; provided that Licensor's approval of such actions shall first be obtained, which approval shall not be unreasonably withheld so long as such actions would not potentially have any material adverse effect on the Licensor Property. Licensee shall not intentionally release any Hazardous Material from or onto the Licensor Property. Notwithstanding anything contained herein to the contrary, Licensee shall comply with all applicable laws related to any Hazardous Material brought upon, kept or used in or about the Licensor Property by Licensee, its agents, employees, contractors or invitees. Licensor hereby consents to the transportation by Licensee of oil, gas, and other hydrocarbons across Licensor Property. b) As used herein, the term "Hazardous Material" means any hazardous or toxic substance, material or waste which is or becomes regulated by any local governmental authority, the State of Colorado, or the United States Government, The term "Hazardous Material" includes, without limitation, any material or substance that is (i) defined as a "pollutant or contaminant" under appropriate state law provisions; (ii) petroleum; (iii) asbestos; (iv) designated as a "pollutant or contaminant" pursuant to Section 311 of the Federal Water Pollution Control Act (33 U.S.C. §1321; (v) defined as a "hazardous waste" pursuant to Section 1004 of the Federal Resource Conservation and Recovery Act (42 U.S.C. §6903); (vi) defined as a "hazardous substance" pursuant to Section 101 of the Comprehensive Environmental Response, Compensation and Liability Act (42 U.S.C. §9601); (vii) defined as a "regulated substance" pursuant to Subchapter IX, Solid Waste Disposal Act (Regulation of Underground Storage Tanks) (42 U.S.C. §6991); (viii) defined as "hazardous material" under the Hazardous Materials Transportation Act, or (ix) defined as a Class I or Class II ozone depleting substance under the Clean Air Act (42 U.S.C. §7661). 13. Taxes. Licensee shall pay any and all taxes and assessments that may be imposed or levied on the Licensor Property by virtue of Licensee's use. /NOTE: Please confirm. It seems that this should be an obligation of Licensee.] 4 4126440 Pages: 5 of 8 07/21/2015 12:41 P11 R Fee:$46.00 Carly Kopp., Clerk and Recorder, Weld County CO IM WIN III: Uhl+ III 14. No Liens. Licensee shall keep the Licensor Property free and clear of any mechanic's or materialmen's liens for labor performed or material furnished at the instance or request of Licensee or anyone claiming under Licensee. 15. No Agency. Nothing contained in this Agreement creates the relationship of principal and agent, of limited or general partners, of joint venturers or of any other association between Licensor and Licensee. 16. Governing Law. It is agreed that this Agreement shall be governed by, construed, and enforced in accordance with the laws of the state of Colorado. 17. Entire Agreement. This Agreement shall constitute the entire Agreement between the parties, and any prior understanding or representation of any kind preceding the date of this Agreement shall not be binding upon either party except to the extent incorporated herein. 18. Modification. Any modification of this Agreement or additional obligations assumed by either party in connection with this Agreement shall be binding only if evidenced in writing and signed by each party or an authorized representative of each party. 19. Partial Invalidity. The invalidity of any portion of this Agreement will not and shall not be deemed to affect the validity of any other provision. In the event that any provision of this Agreement is held to be invalid, the parties agree that the remaining provisions shall be deemed to be in full force and effect as if they had been executed by both parties subsequent to the expungement of the invalid provision. 20. Paragraph Headings. The titles to the paragraphs of this Agreement are solely for the convenience of the parties and shall not be used to explain, modify, simplify, or aid in the interpretation of the provisions of this Agreement. 21. Waiver. The failure of either party to this Agreement to insist upon the performance of any of the terms and conditions of this Agreement or the waiver of any breach of any of the terms and conditions of this Agreement shall not be construed as thereafter waiving any such terms and conditions, but the same shall continue and remain in full force and effect as if no such forbearance or waiver had occurred. 22. Notices. All notices, demands, and requests required to be given by either party to the other shall be in writing. All notices, demands, and requests shall either be hand delivered or shall be sent by certified or registered mail, return receipt requested, postage prepaid, or express service addressed to the parties at the addresses set forth below or at such other addresses as the parties may designate in writing delivered pursuant to the provisions hereof Any notice, when given as provided herein, shall be deemed to have been delivered on the date personally served or five (5) days subsequent to the date that said notice was deposited with the United States Postal Service or two (2) days if served by other means described above. Licensor: Coors Energy Company PO Sox 4030, NH400 Golden, Colorado 80402 Attn: Ben Moline 5 With a copy to: Licensee: With a copy to: E. Lee Reichert, Esq. Legal Department Molson Coors Brewing Company 1225 17th Street, Suite 3200 Denver, Colorado 80202 DCP MIDSTREAM, LP 3026 4TH AVENUE Greeley, Colorado 80631 Attn: Lewis D. Hagenlock Phone: 970-378-6351 Fax: 303-572-3516 Email: LDHagenlock@dcpmidstream.com DCP MIDSTREAM. LP Attn: Allison Barry 370 17th Street, Suite 2500 Denver, CO 80202 Telephone: 303-605-1753 Email: AEbarry @dcpmidstream.com 23. Surrender. Upon termination of this Agreement, Licensee shall peaceably and quietly leave and surrender the Licensor Property and shall deliver the Licensor Property in the same condition as existed at the time of commencement of Licensee's original possession hereunder, ordinary wear and tear excepted. Licensee shall remove all of its vehicles, equipment, fixtures, additions, or alterations made to the Licensor Property during the term of this license and shall restore the Licensor Property to the condition as existed at the commencement of this Agreement, ordinary wear and tear excepted. 24. Survival All indemnities and other unperformed covenants made by Licensee herein shall survive the termination of this Agreement. 25. Counterparts. This Agreement may be executed in counterparts, each of which will constitute an original, but all of which, when taken together, will constitute but one agreement. [Signature Page Follows] 4126440 Pages: R pies s.ea ccu,ty, co �i►� Carlyf K20o5 12:41 Clerk and Recorder, �uN■unty, CO Carly I�( I 1 4126440 Pages: 7 of 8 07/21/2015 12:41 Ceand Reoord4W.Zd County, Co Effective the date first above written. LICENSOR: COORS ENERGY COMPANY, a Colorado corporation By: Name: Title: LICENSEE: DCP MIDSTREAM, LP, a Delaware limited partnership By: l CRcly�� Name: STATE OF COLORADO COUNTY OFfdls-} The foregoin in.strume was ack�noww edged before me this 2X- _ _L , 2015 b ��_ of Coors Energy Company, a corpo ion. Title:..., Fig i } )ss. Witness my hand and official scaL My commission expires: 9-.S -.O/6e STATE OF COLORADO gq t4)e COUNTY OF I C4 The foregoing instrument , 2015 by 2 , partnership. 0e- )ss day of Colorado was acknowledged before me this / day of as a4 na.7,.i of DCP Midstream, LP, a Delaware limited Witness my hand and official seal. My commission expires: Notary Public 7 LORRI CARLSON NOTARY PUBLIC STATE OF COLORADO NOTARY ID 20054008501 MY COMMISSION EXPIRES MARCH 02, 2017 COORS ENERGY COMPANY SE1/'4 SECTION 25 T3N R64W 6TH PM ac DCP GAS MARKER 10'-20' WIDE ASPHALT LANE 100' IN LENGTH 20' WIDE ASPHALT LANE 50' IN LENGTH NE1; 4 SECTION 36 T3N R64W 6TH PM NOTES t.) Locations of utiMks and foreign pipelines WHO determined from dsdle surface evidence. These rotations a shorn moy not be accurate or complete. Other utirdies m exist and ore to be field loaded %by others prior to excavation. 2.) This document is not a toed survey plat or improvement survey plotIt is not ta be relied upon for theeatestablishment of any land boundary. eosemefence, b 7dag, or other (Wore improvement fees. 3.) A9 directions, distances and dmrcreione shown hereon ore booed an eoordnotes from the 'Colorado coordinate system of 1983 north sane' (Article 52 of TAW 38 C.R.S.) AKA "grid'. derived from R.T.K. G.P.S. techniques and/or the Online Positioning User Serdce offered by the N.GS. Combined Factor (CF)"0.999731374 1/CF-1.00026870 4.) NOTICE: According to Colorado tow you must commence any legal action based upon o% defect in this surrey within three years after you first discover such defect. In no event may any action hosed upon any detect in this survey be commenced more than ten years from the dote of the certification shown harem. 5.) TARS EMIR ens prepared by Pau' A Valdez. PLS 37068, to and on behalf of Centerline Surveying. LW 720D McMurry Ranch Rd. 8edwe. CO 80512. 1 x ra DCP GAS MARKER x1 GAS nj_It kvice 1 50' ACCESS E EASEMENT GATE lti ,c1tTELE. PEDESTAL j j �k1 /1 i x a a. Xa TELE. MARKER %DCP GAS MARKER X I51/16 CORNER SEC 25/SEC 30 X 2.0° ALUM. CAP PLS 3970 —1 X DCP ENTERPRISE STATION X 36131 3.25" ALUM. CAP PLS 10855 50' /e1 r i'v le nil I R INE Iry CI Cf16IINIC SURVEYINGLLC 1_25 et PROPOSED ACCESS EASEMENT SITE WCR 28 30 rt COORS COAL MME ROAD —"- X36 SECTION MAP 1"=1/2 MILE LINE BEARING DISTANCE Li S 76'21'22" W 152.59' L2 N 11'52'09" W 50.01' L3 N 76'21'22" E 162.67' L4 S 00'32'42" E 51.32' LEQ:ID+Q - x - FENCE ROAD - " - POWERLINE SE1/4 SECTION 25 T3N R64W 6114 PM WELD COUNTY EXHIBIT A" P_BDPOSED EASEMENT AREA 0.18 ACRES ± dcp Midstream. SCALE: 1"..50' DRAWN BY: PAV JOB NO.: 15000 DATE: 12/04/14 DATE REVISED: AFE: 500213997 COORS ENERGY COMPANY ENTERPRISE ACCESS EASEMENT SE1/4 SEC. 25 UN R64W 6111 PM WELD COUNTY JSHEET 1 OF 1 Mariah Higgins From: Sent: To: Subject: Esther Gesick Wednesday, July 28, 2021 8:31 AM Mariah Higgins FW: Addition to File, AmUSR-897 Esther E. Gesick Clerk to the Board 1150 O Street'P.O. Box 758/Greeley, CO 80632 tel: (970) 400-4226 Confidentiality Notice: This electronic transmission and any and may contain information that is privileged, confidential immediately notify sender by return e-mail and destroy the of this communication or any attachments by anyone other From: Kim Ogle <kogle@weldgov.com> Sent: Wednesday, July 28, 2021 6:15 AM To: Esther Gesick <egesick@weldgov.com> Subject: RE: Addition to File, AmUSR-897 Esther, Great catch from the infield. Maybe try this one USR987 PL0886 Kim Ogle Weld County Planning Services 970.400.6100 Office 970.400.3549 Direct kogle@weldgov.com attached documents or other writings are intended only for the person or entity to which it is addressed or otherwise protected from disclosure. If you have received this communication in error, please communication. Any disclosure, copying, distribution or the taking of any action concerning the contents than the named recipient is strictly prohibited. Confidentiality Notice: This electronic transmission and any attached documents or other writings are intended only for the person or entity to which it is addressed and may contain information that is privileged, confidential or otherwise protected from disclosure. If you have received this communication in error, please immediately notify sender by return e-mail and destroy the communication. Any disclosure, copying, distribution or the taking of any action concerning the contents of this communication or any attachments by anyone other than the named recipient is strictly prohibited. From: Esther Gesick <egesick@weldgov.com> Sent: Tuesday, July 27, 2021 2:42 PM To: Kim Ogle <kogle@weldgov.com> Subject: FW: Addition to File, AmUSR-897 Hey Kim, CoMIMV�:Go.fi�c nS 1 aoa l -x.2.70 PLo g�6 Hope all's well in your world! I'm working on listing this addition on the 8/2 Agenda Communications, but when I pull up case AmUSR-897 the related docs show the applicant as Aggregate Industries — WCR, Inc., but everything in this bundle reflects DCP Midstream / DCP Operating Company, LP. Has it transferred ownership, or should I list both (owner vs. operator)? Esther E. Gesick Clerk to the Board 1150 O Street/P.O. Box 758IGreeley, CO 80632 tel: (970) 400-4226 Confidentiality Notice: This electronic transmission and any attached documents or other writings are intended only for the person or entity to which it is addressed and may contain information that is privileged, confidential or otherwise protected from disclosure. If you have received this communication in error, please immediately notify sender by return e-mail and destroy the communication. Any disclosure, copying, distribution or the taking of any action concerning the contents of this communication or any attachments by anyone other than the named recipient is strictly prohibited. From: Kim Ogle <kogle@weldgov.com> Sent: Monday, July 26, 2021 2:19 PM To: Esther Gesick <egesick@weldgov.com>; Chloe Rempel <crempel@weldgov.com>; Jessica Reid <ireid@weldgov.com>; Jan Warwick <iwarwick@weldgov.com>; Mariah Higgins <mhiggins@weldgov.com> Subject: Addition to File, AmUSR-897 Please add the following to the case file. The USR map is in review. Thank you Kim Ogle Weld County Planning Services 970.400.6100 Office 970.400.3549 Direct kogle@weldgov.com Confidentiality Notice: This electronic transmission and any attached documents or other writings are intended only for the person or entity to which it is addressed and may contain information that is privileged, confidential or otherwise protected from disclosure. If you have received this communication in error, please immediately notify sender by return e-mail and destroy the communication. Any disclosure, copying, distribution or the taking of any action concerning the contents of this communication or any attachments by anyone other than the named recipient is strictly prohibited. 2 DCP Midstream Enterprise Compressor Station AmUSR-987 Waste Handling Plan Waste to be generated: Used Engine Oil -230 gallons/month Spent Filters -6 cubic yards/month Produced Water -190 barrels/week General Refuse -6 cubic yards/week Chemicals to be stored: Condensate -60,000 gallons Lube Oil -2000 gallons Coolant -1000 gallons Tri Ethylene Glycol -500 gallons Methanol -500 gallons Waste handler and disposal facility: Used Oil January Environmental Services, 2701 S. I-35 Service Road, OKC, OK 73129 405-670-2030 Spent Filters January Environmental Services, 2701 S. I-35 Service Road, OKC, OK 73129 405-670-2030 Produced Water, Fosters Trucking, 23436 CR 60.5, Greeley, CO 80631 970-353-1714 Produced Water, High Plains Disposal, 17754 WCR 32, Platteville, CO 80651 970-785-8189 General refuse, Waste Management, 500 E. Vine Dr., Fort Collins, CO 80524 970-482-6319 General refuse, Waste Management, 11655 WCR 59, Keenesburg, CO 80643 800-963-4776 DEPARTMENT OF PLANNING SERVICES BUILDING INSPECTION DIVISION 1555 N 17TH AVENUE, GREELEY, CO 80631 (970) 400-6100 (970) 304-6498 FAX FIRE DISTRICT NOTIFICATION PERMIT NUMBER 6C7 OWNER 0C- ` t .i $4-reativ\ CONTRACTOR 5 cAt-- C AC -rid CONTACTEMAIL Par Kees (��3 SITE ADDRESS UG R 2 e �- C R 61 �v`�'edSCcl Bart c.�..t, co ` o64 3 DESCRIPTION OF WORK Re. }cichn e-1-1 S4-`vt3 cA aACKS ack-e- env gale w �rie W V�RV PLEASE MAIL OR FAX BEFORE ISSUANCE -st-itt, K )-OVt1, \)a err Vte�uover V '�( $K--a1.�i3 %IP.' 1,1 101 1po+ ^02.(73/ <vvock au+ v-0232,, 1 P�� P- 0 81 & ., p��,4.3 FIRE DISTRICT COMPLETE BELOW /I FIRE DISTRICT NAME 301A 1-heas4 Odd 4're 7%lee-Ii�n DISTri G ADDRESS Q5 Lt) • 3mad PHONE NUMBER (.?63-732 / a3 EMAIL SPRINKLERS YES V- NO COMMENTS $1. leeiZbarqCv 040 3CITY STATE ZIP d -g SIGNATURE c/ d PRINTED NAME ( g, DATE I/9 %ae / SOUTHEAST WELD FIRE PROTECTION DISTRICT 95 W. Broadway Ave., Keeaesbulrg CO 50643 (303) 732-4203 APPLICATION FOR PLAN REVIEW Type of Plan Review: C� Site Development LI Kitchen Hood System El Building and Floor Plans El Fire Alarm System ther Date C —IR. / Type of Building Construction —LU- a Occupancy Classification /4/4 r ` e pt. �'e 50 ir Co vi, c.e45QA ' °� la I - d07) Project Name E k.'�`� � �� S � o� s Project Address C l 4 C Gib S NE cometCity/Zip 10 CO 80613 County \-#—) e. k Ct E.�r we•Ct r3ov2 6{ Total EH, rek,pencnih Square Footage Building Square Footage Number of Stories Owner n Owner Name/Representative D C? ttital+r a 14 / Pc i t k_ Mailing Address 3 01.6 9, A ewAlC City CrC e lAl State C Zip 9 3 Tele honel7d'b.3? % ax • Email Address` / ar4 cG f St e e"4 • C a MA% p �! General Contractor Name 5 a wk. q. S et,..\011 Mailing Address _ Telephone City State Zip Fax Email Address Fire Systems Contractor Name /VA Mailing Address City State Zip Telephone Fax Email Address Revised 3/4/2020 Architect Name /v4 - Mailing Address City State Zip NOTE: Subcontractors will not be allowed to start construction until a final set of approved drawings and all applicable fees have been paid to the Southeast Weld Fire Protection District. Failure to comply with this requirement will result in a Stop Work Order and an additional permit fee. By submitting this Application, the applicant represents that all information contained in this application is true and accurate, and that the applicant has full authority to submit this application. The applicant represents and agrees that the owner, contractor, architect, subcontractors and their employees, agents and representatives, will comply with all requirements of the International Fire Code, Building Code, Mechanical Code and any other applicable Codes or standards. The applicant agrees to reimburse the Fire District for all fees (including attorneys' fees) costs and expenses it may incur as a result of a failure of the owner, contractor, architect, subcontractors and their employees, agents and representatives, to comply with all requirements of the International Fire Code, Building Code, Mechanical Code and any other applicable Codes or standards. *All documentation and payment must be received prior to review of the submittal package. Kot p0.64_ Sr inelota� Ato Applicant Name and Title �+c Date Fire Department Use Only Fire Plan Log # Final Approval 41ac/02.0.2. / Plans Received Fees Paid 00-11-,20,021-0,13 dc. )5/77 ' C Revised 3/4/2020 DCP Midstream Fugitive Dust Abatement Plan AmUSR-987 Enterprise Compressor Station 1. Control of unpaved roads on site. a. Watering as needed. b. Application of chemical stabilizer as needed. c. Vehicle speed limited to 10 MPH. d. Gravel will be utilized on facility roadways. 2. Control of disturbed surface areas on site. a. Watering as needed. b. Application of chemical stabilizer as needed. c. Vehicle speed limited to 10 MPH. d. Wind breaks will be utilized as needed. 3. Prevention of mud and dirt carried out onto paved surfaces. a. Gravel or pavement at entrance. b. Cleaning of vehicles as needed. Sign Plan DCP Midstream AmUSR-987 Enterprise Compressor Station DCP Midstream has one facility identification sign located at the facility entrance and facing the roadway. The facility identification sign is four feet in width and three feet in height. Signage contains names, 24 hour emergency response phone numbers, facility address, and facility Latitude & Longitude. Colorado Department of Public Health and Environment OPERATING PERMIT DCP Operating Company, LP Enterprise Compressor Station First Issued: May 1, 1999 Renewed: March 1, 2021 AIR POLLUTION CONTROL DIVISION COLORADO OPERATING PERMIT FACILITY NAME: DCP Operating Company, LP — Enterprise Compressor Station 123/0277 March 1, 2021 March 1, 2026 Nature of Business: Natural Gas Primary SIC: 4922 RESPONSIBLE OFFICIAL Name: Charles A. Job Title: General Manager, North Operations FACILITY ID: RENEWED DATE: EXPIRATION DATE: MODIFICATIONS: See Appendix F of Permit OPERATING PERMIT NUMBER 95OPWE103 Issued in accordance with the provisions of the Colorado Air Pollution Prevention and Control Act, 25-7-101 et sec . and applicable rules and regulations. ISSUED TO: DCP Operating Company, LP 370 17th Street, Suite 2500 FACILITY LOCATION: DCP Operating Company, LP Enterprise Compressor Station SW 1/4 of SW 1/4, Section 30, T3N, R63W Denver, CO 80202 Between Keenesburg and Roggen, Weld County, CO INFORMATION RELIED UPON Operating Permit Renewal Application Received: July 26, 2016 And Additional Information Received: April 26, 2016; November 20, 2018; June 1, 2020; August 24, 2020; October 30, 2020; November 19, 2020 Liquids Processing and Gathering FACILITY CONTACT PERSON Name: Roshini Shankaran Area Title: Senior Environmental Engineer Phone: (303) 605-1964 Phone: (303) 605-2039 SUBMITTAL DEADLINES First Semi -Annual Monitoring Period: Subsequent Semi -Annual Monitoring Periods: Semi -Annual Monitoring Reports: First Annual Compliance Period: Subsequent Annual Compliance Periods: Annual Compliance Certification: Due February 1, 2022 & subsequent years Note that the Semi -Annual Monitoring Reports and Annual Compliance report must be received at the Division office by 5:00 p.m. on the due date. Postmarked dates will not be accepted for the purposes of determining the timely receipt of those reports. March 1, 2021 — June 30, 2021 July 1— December 31; January 1 — June 30 Due August 1, 2021; February 1, 2022 & subsequent years March 1, 2021 — December 31, 2021 January 1 — December 31 Table of Contents: SECTION I - General Activities and Summary 1 1. Permitted Activities 1 2. Alternative Operating Scenarios 3 3. Non -Attainment New Source Review (NANSR) and Prevention of Significant Deterioration (PSD) 9 4. Accidental Release Program (112(r)) 9 5. Compliance Assurance Monitoring (CAM) 10 6. Summary of Emission Units 11 SECTION II - Specific Permit Terms 12 1. C-238 - Caterpillar G3612 3,550 hp Compressor Engine with Oxidation Catalyst, AIRS ID: 053 12 C-235 - Caterpillar G3612 3,550 hp Compressor Engine with Oxidation Catalyst, AIRS ID: 055 12 C-236 - Caterpillar G3612 3,550 hp Compressor Engine with Oxidation Catalyst, AIRS ID: 056 12 C-234 - Caterpillar G3612 3,550 hp Compressor Engine with Oxidation Catalyst, AIRS ID: 070 12 2. C-237 - Caterpillar G3616 4,735 hp Compressor Engine with Oxidation Catalyst, AIRS ID: 071 28 3. D-2 — Forum Triethylene Glycol Dehydration Unit, AIRS ID: 068 51 4. D-3 —Triethylene Glycol Dehydration Unit, AIRS ID: 077 73 5. P016 — Stabilized Condensate Atmospheric Truck Loadout Rack, AIRS ID: 066 97 6. P013 — Eight (8) 300 bbl Stabilized Condensate Storage Tanks, AIRS ID: 063 106 7. SUMP -1/2 — Two (2) 90 bbl Produced Water Storage Tanks, AIRS ID: 075 121 8. COMP -BD — Reciprocating Compressor Blowdowns, AIRS ID: 076 124 9. HAP Emission Limitations for the Stabilized Condensate Storage Tanks, AIRS ID: 063, Produced Water Storage Tanks, AIRS ID: 075 and TEG Dehydration Unit, AIRS ID: 068 or 077 127 10. Facility -Wide Requirements 129 11. Portable Monitoring (ver. 6/26/2014) 145 12. Compliance Assurance Monitoring (ver. 4/16/2009) 146 SECTION III - Permit Shield 151 1. Specific Non -Applicable Requirements 151 2. General Conditions 152 3. Streamlined Conditions 152 SECTION IV - General Permit Conditions (ver. 1/21/2020) 154 1. Administrative Changes 154 2. Certification Requirements 154 3. Common Provisions 154 4. Compliance Requirements 158 5. Emergency Provisions 159 6. Emission Controls for Asbestos 159 7. Emissions Trading, Marketable Permits, Economic Incentives 159 8. Fee Payment 159 9. Fugitive Particulate Emissions 160 10. Inspection and Entry 160 11. Minor Permit Modifications 160 12. New Source Review 160 13. No Property Rights Conveyed 160 Table of Contents: 14. Odor 160 15. Off -Permit Changes to the Source 161 16. Opacity 161 17. Open Burning 161 18. Ozone Depleting Compounds 161 19. Permit Expiration and Renewal 161 20. Portable Sources 161 21. Prompt Deviation Reporting 161 22. Record Keeping and Reporting Requirements 162 23. Reopenings for Cause 163 24. Requirements for Major Stationary Sources 164 25. Section 502(b)(10) Changes 165 26. Severability Clause 165 27. Significant Permit Modifications 165 28. Special Provisions Concerning the Acid Rain Program 165 29. Transfer or Assignment of Ownership 165 30. Volatile Organic Compounds 165 31. Wood Stoves and Wood burning Appliances 166 APPENDIX A Inspection Information 1 APPENDIX B Reporting Requirements and Definitions 5 APPENDIX C Required Format for Annual Compliance Certification Report (ver 8/20/2014) 17 APPENDIX D Notification Addresses 20 APPENDIX E Permit Acronyms 21 APPENDIX F Permit Modifications 23 APPENDIX G Compliance Assurance Monitoring Plans 24 APPENDIX H Applicability Reports 32 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 1. Permitted Activities L1 DCP Operating Company, LP Enterprise Compressor Station Page 1 SECTION I - General Activities and Summary The Enterprise Compressor Station is classified as a natural gas compressor station as set forth under Standard Industrial Classification Code 4922. This facility has a design natural gas throughput of 145 MMscfd and a stabilized condensate production rate of 202,848 bbl/year. The facility uses five (5) natural gas -fired internal combustion engines (AIRS 053, 055, 056, 070 and 071) to drive compressors to boost the inlet gas pressure from about 80 psig to about 1,050 psig, facilitating the movement of natural gas into pipeline transit. These compressors are periodically blown down for routine maintenance activities (AIRS 076). The station also includes one (1) triethylene glycol (TEG) dehydration unit (AIRS 077) which contacts "lean" TEG with the compressed natural gas stream to remove moisture. The "rich" TEG mixture is regenerated in a still for reuse in the process. The TEG dehydration system operates with a flash tank and a still vent. The flash tank emissions are routed back to the facility inlet using a vapor recovery unit (VRU), which is permitted 5% downtime, during which emissions are routed to an enclosed combustion device (COMB -1). The still vent stream is sent through a condenser to an enclosed combustion device (COMB - 1, included under AIRS 077) where it is combusted. This enclosed combustion device is permitted 1% downtime, during which still vent emissions are routed to atmosphere. It should be noted that no emission control from the condenser is claimed for this dehydration unit. A condensate product is generated when the inlet gas is routed through the inlet scrubber and liquids generated via pipeline transit are separated out. This condensate is then stabilized, and transferred to eight (8) 300 barrel stabilized condensate storage tanks (AIRS 063). A loading system (AIRS 066) is provided for moving stabilized condensate from the tanks into a truck for transport offsite. The condensate tanks and loadout are controlled with an enclosed combustion device. Two (2) 90 barrel produced water tanks (AIRS 075) store any water separated from the condensate stream. Emission control devices include: five (5) oxidation catalyst beds to control the compressor engine exhaust emissions, one (1) vapor recovery unit (VRU) permitted 5% downtime to control the dehydration unit flash tank emissions, one (1) enclosed combustion device (COMB -1) permitted 1% downtime to control the dehydration unit still vent emissions, and permitted to control flash tank emissions during VRU downtime (permitted 5%), and one (1) enclosed combustion device to control the stabilized condensate storage tank and loadout emissions. This permit contains provisions for the existing 110 MMscfd TEG dehydration unit D-2 (AIRS 068), which will be decommissioned and replaced with the 145 MMscfd TEG dehydration unit D-3 (AIRS 077). Upon startup of D-3, the conditions governing D-2 set forth in Section II, Condition 3 of this permit will no longer apply and the source shall operate D-3 pursuant to the requirements set forth in Section II, Condition 4. This facility is located one (1) mile north of US Highway 76 on the Gutterson Road between the towns of Keenesburg and Roggen, in Weld County, Colorado. This facility is located in an Area classified as Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 2 attainment for all pollutants except ozone. It is classified as non -attainment for the 8 -hr ozone standard and is part of the 8 -hr Ozone Control Area as defined in Regulation No. 7, Part A, Section II.A.1. The 8 - hr Ozone Control Area has been classified as a serious non -attainment area effective January 27, 2020. There are no affected states within 50 miles of the facility. Rocky Mountain National Park is a Federal Class I designated area within 100 kilometers of the facility. 1.2 Until such time as this permit expires or is modified or revoked, the permittee is allowed to discharge air pollutants from this facility in accordance with the requirements, limitations, and conditions of this permit. 1.3 This Operating Permit incorporates the applicable requirements contained in the underlying construction permits, and does not affect those applicable requirements, except as modified during review of the application or as modified subsequent to permit issuance using the modification procedures found in Regulation No. 3, Part C. These Part C procedures meet all applicable substantive New Source Review requirements of Part B. Any revisions made using the provisions of Regulation No. 3, Part C shall become new applicable requirements for purposes of this Operating Permit and shall survive reissuance. This Operating Permit incorporates the applicable requirements (except as noted in Section II) from the following Colorado Construction Permit(s): 97WE0553 00WE0470 19WE0094 19WE0492 1.4 All conditions in this permit are enforceable by the US Environmental Protection Agency, Colorado Air Pollution Control Division (hereinafter Division) and its agents, and citizens unless otherwise specified. State -only enforceable conditions are: Permit Condition Number(s): Section II — Conditions 1.10.1.2 and 2.9.1.2 (Colorado Regulation No. 7, Part E, Section I.D.) Section II — Conditions 3.12.2 and 4.13.2 (Colorado Regulation No. 7, Part D, Section II.D.) Section II — Condition 4.10.1 (Colorado Construction Permit 19WE0492) Section II — Conditions 6.6.2 and 7.4.1 (Colorado Regulation No. 7, Part D, Section II.C.) Section II — Condition 10.5 (Colorado Regulation No. 7, Part D, Section II.B.) Section II — Condition 10.6 (Colorado Regulation No. 7, Part D, Section II.E.) Section II — Condition 10.7 (Colorado Regulation No. 7, Part D, Section V.) Section IV — Condition 3.g (Colorado Common Provisions Regulation, Affirmative Defense) Section IV — Condition 14 (Colorado Regulation No. 2, as noted) Section IV — Condition 18 (Colorado Regulation No. 15, as noted) Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 3 Section IV — Condition 30 (Colorado Regulation No. 7, Part B, Sections I and III, as noted) 1.5 All information gathered pursuant to the requirements of this permit is subject to the Recordkeeping and Reporting requirements listed under Condition 22 of the General Conditions in Section IV of this permit. Either electronic or hard copy records are acceptable. 2. Alternative Operating Scenarios 2.1 Glycol Circulation Pump Alternative Operating Scenarios (Colorado Construction Permit 19WE0492, as modified under the provisions of Section I, Condition 1.3) The glycol circulation pumps for TEG dehydration units D-2 and D-3 may be replaced in accordance with the alternative operating scenario provisions set forth in Section II, Conditions 3.10 and 4.11, respectively. The facility must, contemporaneously with making a change from one operating scenario to another, maintain records at the facility of the scenario under which it is operating (Colorado Regulation No. 3, Part A, Section IV.A.1). Electronic or hard copy records are acceptable. 2.2 Natural Gas Fired Engine Alternative Operating Scenarios (Ver. 10/12/2012; updated to reflect changes to Colorado Regulation No. 7, NSPS, and MACT rules) The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility -Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the permittee shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. 2.2.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 270 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 270 operating days in any 12 month period. The 270 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 270 -day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state -only requirements set forth in this permit (including monitoring and record keeping), and shall be subject to any shield afforded by this permit. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 4 The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five (5) years and made available to the Division upon request. The permittee shall maintain a log on -site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the permittee shall maintain a copy of all Applicability Reports required under Section 2.2.1.2 and make them available to the Division upon request. 2.2.1.1 The permittee may temporarily replace an existing compressor engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying this permit, so long as the temporary replacement engine complies with all permit limitations and other requirements applicable to the existing engine. Measurement of emissions from the temporary replacement engine shall be made as set forth in Section 2.2.2. The permittee may temporarily replace a grandfathered or permit exempt engine or an engine that is not subject to emission limits without modifying this permit. In this circumstance, potential annual emissions of NOx and CO from the temporary replacement engine must be less than or equal to the potential annual emissions of NOx and CO from the original grandfathered or permit exempt engine or for the engine that is not subject to emission limits, as determined by applying appropriate emission factors (e.g. AP -42 or manufacturer's emission factors). 2.2.1.2 Engines C-234, C-235, C-236 and C-238 only: The permittee may permanently replace the existing compressor engine for the emission points specified in Table 1 with the manufacturer, model, and horsepower engines listed in Table 1 without modifying this permit so long as the permanent replacement engine complies with all permit limitations and other requirements applicable to the existing engine as well as any new applicable requirements for the replacement engine. Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in Section 2.2.2. The AOS cannot be used for the permanent replacement of an entire engine at any source that is currently a major stationary source for purposes of Prevention of Significant Deterioration or Non -Attainment Area New Source Review ("PSD/NANSR") unless the existing engine has emission limits that are below the significance levels in Reg 3, Part D, II.A.44. An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 5 days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the permittee is exercising an alternative operating scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the replacement engine. Example Applicability Reports can be found in Appendix H. This submittal shall be accompanied by a certification from the Responsible Official indicating that "based on the information and belief formed after reasonable inquiry, the statements and information included in the submittal are true, accurate and complete". This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The permittee shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. Nothing in this AOS shall preclude the Division from taking an action, based on any permanent engine replacement(s), for circumvention of any state or federal PSD/NANSR requirement. Additionally, in the event that any permanent engine replacement(s) constitute(s) a circumvention of applicable PSD/NANSR requirements, nothing in this AOS shall excuse the permittee from complying with PSD/NANSR and applicable permitting requirements. 2.2.2 Portable Analyzer Testing Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time period (i.e. if the permit requires quarterly portable analyzer testing, this test conducted under the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months). The permittee may conduct a reference method test, in lieu of the portable analyzer test required by this Condition, if approved in advance by the Division. The permittee shall measure nitrogen oxide (NOx) and carbon monoxide (CO) emissions in the exhaust from the replacement engine using a portable flue gas analyzer within seven (7) calendar days of commencing operation of the replacement engine. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol (ver March 2006 or newer) as found on the Division's web site at: https://www.colorado.gov/pacific/cdphe/portable-analyzer-monitoring-protocol. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 6 Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year (whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year (8,760), whichever applies. For comparison with a short-term limit that is either input based (1b/mmBtu), output based (g/hp- hr) or concentration based (ppmvd @ 15% O2) that the existing unit is currently subject to or the replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above -mentioned Portable Analyzer Monitoring Protocol document. If the portable analyzer results indicate compliance with both the NOx and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOx and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOx or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOx and CO emission limitations or until the engine is taken offline. 2.2.3 Applicable Regulations for Permanent Engine Replacements 2.2.3.1 Reasonably Available Control Technology (RACT): Reg 3, Part B § III.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOx are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PMto at any level of emissions and to NOx and SO2, as precursors to PM10, if the potential to emit of NOx or SO2 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for natural-gas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 7 NOx: The emission limitations in NSPS JJJJ SO2: Use of natural gas as fuel PMio: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (§ 60.331) and 40 CFR Part 72 (§ 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 2.2.3.2 Control Requirements and Emission Standards: Regulation No. 7, Part E, Sections I.B. and I.D. (State -Only conditions). Control Requirements: Section I.B. Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, Part E, section I.B., as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non -selective catalyst and air fuel controller to reduce emission. Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. The source shall submit copies of the relevant Applicability Reports required under Condition 2.2.1.2. Emission Standards: Section I.D. - State -only requirements Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Max Engine HP Construction or Relocation Date Emission Standards in G/hp-hr NOx CO VOC 100<Hp<500 January 1, 2008 2.0 4.0 1.0 January 1, 2011 1.0 2.0 0.7 500<Hp July 1, 2007 2.0 4.0 1.0 July 1, 2010 1.0 2.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Operating Permit Number: 95OPWE 103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 Condition 2.2.1.2. DCP Operating Company, LP Enterprise Compressor Station Page 8 2.2,3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.2.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition 2.2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2.2. Note that under the provisions of Regulation No. 6, Part B, Section I.C., upon adoption of NSPS JJJJ into Regulation No. 6, Part A an internal combustion engine relocated from outside of the State of Colorado into the State of Colorado shall meet the most recent emission standard required in NSPS JJJJ. Engines with a manufacturer's rated horsepower of less than 500 and with a relocation date no later than 5 years after the manufacture date are exempt from this requirement per Regulation No. 6, Part B, Section I.C.2.a. Relocation is defined in Section I.C.1.a. However, as of September 14, 2019 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. 2.2.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart ZZZZ A permanent replacement engine located at either an area or major source is subject to the requirements in 40 CFR Part 63, Subpart ZZZZ. An analysis of the applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.2.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition 2.2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2.2. 2.2.4 Additional Sources The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit, not "routine replacement" of an existing unit. The AOS is Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 9 therefore essentially an advanced construction permit review. The AOS cannot be used for additional new emission points for any site; an engine that is being installed as an entirely new emission point and not as part of an AOS-approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation. Table 1 Internal Combustion Engine Information For AOS Emission Point Replacement Engine Periodic Monitoring Subject to CAM? C-238 Caterpillar Model G3612 Turbocharged Natural Gas Fired Reciprocating Internal Combustion Engine, 4- Cycle, Standard Lean Burn, 3,550 hp, Drive for Natural Gas Compressor Portable Monitoring Quarterly Yes C-235 Caterpillar Model G3612 Turbocharged Natural Gas Fired Reciprocating Internal Combustion Engine, 4- Cycle, Standard Lean Burn, 3,550 hp, Drive for Natural Gas Compressor Portable Monitoring Quarterly Yes C-236 Caterpillar Model G3612 Turbocharged Natural Gas Fired Reciprocating Internal Combustion Engine, 4- Cycle, Standard Lean Burn, 3,550 hp, Drive for Natural Gas Compressor Portable Monitoring Quarterly Yes C-234 Caterpillar Model G3612 Turbocharged Natural Gas Fired Reciprocating Internal Combustion Engine, 4- Cycle, Standard Lean Burn, 3,550 hp, Drive for Natural Gas Compressor Portable Monitoring Quarterly Yes 3. Non -Attainment New Source Review (NANSR) and Prevention of Significant Deterioration (PSD) 3.1 This facility is categorized as a NANSR major stationary source (Potential to Emit of VOC or NOx ≥ 50 Tons/Year). Future modifications at this facility resulting in a significant net emissions increase (see Reg 3, Part D, Sections II.A.27 and 44) for VOC or NOx or a modification which is major by itself (i.e. a Potential to Emit of ≥ 50 TPY of either VOC or NOx) may result in the application of the NANSR review requirements. Based on the information provided by the applicant, this source is categorized as a minor stationary source for PSD as of the issue date of this permit. Any future modification which is major by itself (Potential to Emit of > 250 TPY) for any pollutant listed in Regulation No. 3, Part D, Section II.A.44 for which the area is in attainment or attainment/maintenance may result in the application of the PSD review requirements. 3.2 There are no other Operating Permits associated with this facility for the purposes of determining the applicability of the PSD regulations. 4. Accidental Release Program (112(r)) 4.1 Based upon the information provided by the applicant, this facility is not subject to the provisions of the Accidental Release Prevention Program (Section 112(r) of the Federal Clean Air Act). Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 5. Compliance Assurance Monitoring (CAM) DCP Operating Company, LP Enterprise Compressor Station Page 10 5.1 The following emission points at this facility use a control device to achieve compliance with an emission limitation or standard to which they are subject and have pre -control emissions that exceed or are equivalent to the major source threshold. They are therefore subject to the provisions of the CAM program as set forth in 40 CFR Part 64, as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV: AIRS ID 053 (C-238) — Compressor RICE (3,550 hp) for VOC AIRS ID 055 (C-235) — Compressor RICE (3,550 hp) for VOC AIRS ID 056 (C-236) — Compressor RICE (3,550 hp) for VOC AIRS ID 068 (D-2) — TEG Dehydration Unit (110 MMscfd) for VOC and HAP AIRS ID 070 (C-234) — Compressor RICE (3,550 hp) for VOC AIRS ID 071 (C-237) — Compressor RICE (4,735 hp) for CO and VOC AIRS ID 077 (D-3) — TEG Dehydration Unit (145 MMscfd) for VOC and HAP See Section II, Condition 12 for compliance assurance monitoring requirements. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 11 6. Summary of Emission Units 6.1 The emissions units regulated by this permit are the following: AIRS Stack Number Plant Identifier Description Pollution Control Device Construction Permit 053 C-238 Caterpillar Model G3612 Turbocharged Natural Gas Fired Reciprocating Internal Combustion Engine, 4 -Cycle, Standard Lean Burn, Site Rated at 3,550 hp, Serial No. BKE00356, Drive for Natural Gas Compressor Oxidation Catalyst 97WE0553 055 C-235 Caterpillar Model G3612 Turbocharged Natural Gas Fired Reciprocating Internal Combustion Engine, 4 -Cycle, Standard Lean Burn, Site Rated at 3,550 hp, Serial No. 1YG00047, Drive for Natural Gas Compressor Oxidation Catalyst 97WE0553 056 C-236 Caterpillar Model G3612 Turbocharged Natural Gas Fired Reciprocating Internal Combustion Engine, 4 -Cycle, Standard Lean Burn, Site Rated at 3,550 hp, Serial No. 1YG00028, Drive for Natural Gas Compressor Oxidation Catalyst 97WE0553 063 P013 Eight (8) 300 bbl Stabilized Condensate Atmospheric Storage Tanks Enclosed Combustion Device (ECD) 19WE0492 066 P016 Stabilized Condensate Atmospheric Truck Loadout Enclosed Combustion Device (ECD) 19WE0492 068 D-2 Forum Energy Technologies Custom TEG Dehydration Unit, Rated at 110 MMscfd, equipped with a flash tank, TEG regeneration still, still vent condenser (no control claimed) and one (1) Rotor Tech Model GS2212 electric glycol circulation pump rated at 20 gpm. Flash Tank: VRU (100% CE, 5% DT) Still Vent: COMB -1 (95% CE, 1% DT) 00WE0470 COMB -1 Leed Fabrication Model L30-0018-00 Enclosed Combustion Device used to control still vent emissions, and, during periods of VRU downtime, flash tank emissions. 070 C-234 Caterpillar Model G3612 Turbocharged Natural Gas Fired Reciprocating Internal Combustion Engine, 4 -Cycle, Standard Lean Burn, Site Rated at 3,550 hp, Serial No. 1YG00029, Drive for Natural Gas Compressor Oxidation Catalyst None 071 C-237 Caterpillar Model G3616 Turbocharged Natural Gas Fired Reciprocating Internal Combustion Engine, 4 -Cycle, Standard Lean Burn, Site Rated at 4,735 hp, Serial No. BLB00490, Drive for Natural Gas Compressor Oxidation Catalyst None 075 SUMP -1/2 Two (2) 90 bbl Produced Water Atmospheric Storage Tanks None None 076 COMP -BD Natural gas venting from reciprocating compressor blowdowns None 19WE0094 077 D-3 TEG Dehydration Unit, Rated at 145 MMscfd, equipped with a flash tank, TEG regeneration still, still vent condenser (no control claimed) and two (2) FMC Triplex electric glycol circulation pumps (one primary,Flash p g y p pone backup), rated at 25 gpm each. Tank: VRU (100% CE, 5% DT) Still Vent: COMB -1 (95% CE, 1% DT) 19WE0492 COMB -1 Leed Fabrication Model L30-0018-00 Enclosed Combustion Device used to control still vent emissions, and, during periods of VRU downtime, flash tank emissions. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 1. C-238 - Caterpillar G3612 C-235 - Caterpillar G3612 C-236 - Caterpillar G3612 C-234 - Caterpillar G3612 DCP Operating Company, LP Enterprise Compressor Station Page 12 SECTION II - Specific Permit Terms 3,550 hp Compressor Engine with Oxidation Catalyst, AIRS ID: 053 3,550 hp Compressor Engine with Oxidation Catalyst, AIRS ID: 055 3,550 hp Compressor Engine with Oxidation Catalyst, AIRS ID: 056 3,550 hp Compressor Engine with Oxidation Catalyst, AIRS ID: 070 Parameter Permit Condition Number Compliance Limits Emission Factor Monitoring Method Interval Emission & Consumption Limits" NOx 1.1 24.0 tons/year 0.228 lb/MMBtu Recordkeeping and Twelve Month Rolling Total Calculation Monthly CO 27.4 tons/year 0.261 lb/MMBtu VOC 1.2 24.0 tons/year 0.228 lb/MMBtu Natural Gas Consumption 1.3 206.10 MMscf/year Fuel Meter, Twelve Month Rolling Total Other Requirements' Natural Gas Heat Content 1.4 ASTM or Other Division Approved Method Semi -Annually Hours of Operation 1.5 Recordkeeping Monthly Opacity 1.6 Not to exceed 20%, except as provided for below: Fuel Restriction — Natural Gas Only For Certain Operational Activities - Not to exceed 30% for a period or periods aggregating more than six (6) minutes in any sixty (60) consecutive minutes Control Device Requirements 1.7 See Condition 1.7 Portable Monitoring 1.8 Flue Gas Analyzer Quarterly Compliance Assurance Monitoring (CAM) 1.9 See Condition 1.9 Statewide Controls for Oil and Gas Operations 1.10 See Condition 1.10 40 CFR 63 Subpart ZZZZ MACT 1.11 C-238 only: See Condition 1.11 40 CFR 63 Subpart A General Provisions MACT 1 12 C-238 only: See Condition 1.12 'Emission & Consumption Limits and Other Requirements apply to each engine individually unless otherwise specified. Operating Permit Number: 95OPWE 103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 13 1.1 NOx & CO Emission Limitations & Compliance Monitoring Emissions of Nitrogen Oxides (NOx) and Carbon Monoxide (CO) from each engine shall not exceed the limitations listed in Summary Table 1 above (Colorado Construction Permit 97WE0553). Except as provided for below, the emission factors listed above have been approved by the Division and shall be used to calculate emissions from these engines, as follows: 1.1.1 Monthly determination of NOx and CO emissions shall be conducted by the end of the subsequent month using the emission factors listed in Summary Table 1 above, the monthly natural gas consumption, as required by Condition 1.3 and the heat content of the natural gas obtained from the most recent analysis, as required by Condition 1.4, in the equation below: Lb MMBtu MMscf tons Emission Factor (MMBtu) x Heat Content (MMscf ) x Fuel Use (month) NOx or CO Emissions (month) 2000 Ib Unit Conversion ( ton ) Monthly emissions shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 1.1.2 Portable monitoring shall be conducted quarterly as required by Condition 1.8. If the results of the portable analyzer testing conducted under the provisions of Condition 1.8 show that either the NOx or CO emission rates/factors are greater than the emission rates/factors listed above, and in the absence of subsequent testing results to the contrary (as approved by the Division), the owner or operator shall apply for a modification to this permit to reflect, at a minimum, the higher emission rates/factors within 60 days of the completion of the test. 1.2 VOC Emission Limitations & Compliance Monitoring Emissions of Volatile Organic Compounds (VOC) from each engine shall not exceed the limitations listed in Summary Table 1 above (Colorado Construction Permit 97WE0553). Compliance with the emission limitation shall be monitored as follows: 1.2.1 Monthly determination of VOC emissions shall be conducted by the end of the subsequent month using the emission factors listed in Summary Table 1 above, the monthly natural gas consumption, as required by Condition 1.3, and the heat content of the natural gas obtained from the most recent analysis, as required by Condition 1.4, in the equation below: lb MMBtu MMscf Emission Factor (( x Heat Content x Fuel Use t IMMBtu) MMscf month VOC or HAP Emissions (month) tons — month Unit Conversion (2000 lb) ton Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 14 Monthly emissions shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 1.2.2 Annual emissions of Hazardous Air Pollutants (HAP), for the purposes of APEN reporting and the payment of annual fees, shall be calculated using HAP emissions derived from the same method as required for VOC emissions, except that the compliance emission factor for each HAP species shall be obtained from EPA's AP -42: Compilation of Emission Factors, Section 3.2 for Natural Gas Fired Reciprocating Engines, Final Section, Table 3.2-2 (dated 8/2000). 1.3 Natural Gas Consumption Limitations & Compliance Monitoring Natural gas consumption for each engine shall not exceed the limitations listed in Summary Table 1 above (Colorado Construction Permit 97WE0553, as modified under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3, Part B, Section II.A.6 and Part C, Section X based on requested limitations identified on the APEN received on 11/20/2018). Facility -wide natural gas consumption shall be recorded using the existing fuel meter on a monthly basis. The natural gas usage shall be recorded on the same day that run time hours have been recorded, as required by Condition 1.5. Allocation of natural gas to each engine shall be determined using the following equation: FCEngine Where: Btu /MMscf\ HREngine (m ) MMscf) \month/ Btu l Btu x FCFacility (month) L, HREngine (month) + HRother (month Btu hr HREngine (month) = BSFC ( hr) x Hours of Operation (month) x Site Rated hp (hp) And: FCEngine = Individual Engine Fuel Consumption, MMscf/Month HREngine = Individual Engine Heat Requirement, Btu/Month 'Mother = Other Users Heat Requirement, Btu/Month FCFaciiity = Facility Wide Fuel Consumption (metered), MMscf/Month BSFC = Brake Specific Fuel Consumption, Btu/hp • hr Monthly natural gas consumption for each engine shall be used in a twelve month rolling total to monitor compliance with the annual limitation. Each month, a new twelve month total shall be calculated using , Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 15 the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. Monthly natural gas consumption shall be used to monitor compliance with the NOx, CO and VOC emission limitations, as required by Conditions 1.1 and 1.2. 1.4 Natural Gas Heat Content The heat content of the natural gas used to fuel these engines shall be verified semi-annually using the appropriate ASTM Methods or equivalent, if approved in advance by the Division. At least four (4) months shall separate sequential sampling events. The heat content of the natural gas shall be based on the higher heating value (HHV) of the fuel. Results of the heat content verification shall be maintained and made available to the Division upon request. The heat content used by the Division in determining the emission limitations listed in Summary Table 1 was 1,020 Btu per standard cubic foot of natural gas. The heat content indicated by the most recent analysis shall be used to monitor compliance with the NOx, CO and VOC emission limitations, as required by Conditions 1.1 and 1.2. 1.5 Hours of Operation Hours of operation for each engine shall be monitored and recorded monthly. Hours of operation shall be recorded on the same day that the facility fuel gas consumption is recorded. Records of the monthly hours of operation shall be maintained and made available to the Division upon request. The hours of operation shall be used to monitor compliance with the natural gas consumption limitations, as required by Condition 1.3. 1.6 Opacity The following opacity requirements apply to each engine: 1.6.1 Except as provided for in Condition 1.6.2 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 (Colorado Regulation No. 1, Section II.A.1). 1.6.2 No owner or operator of a source shall allow or cause to be emitted into the atmosphere any air pollutant resulting from the building of a new fire, cleaning of fire boxes, soot blowing, start-up, process modifications, or adjustment or occasional cleaning of control equipment which is excess of 30% opacity for a period or periods aggregating more than six (6) minutes in any sixty (60) consecutive minutes (Colorado Regulation No. 1, Section II.A.4). In the absence of credible evidence to the contrary, compliance with the opacity limit shall be presumed since only natural gas is permitted to be used as fuel for these engines. The owner or operator shall maintain records that verify that only natural gas is used as fuel. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 1.7 Control Device Requirements DCP Operating Company, LP Enterprise Compressor Station Page 16 These engines shall be equipped with an oxidation catalyst, as required by Conditions 1.10.1.1 and 1.10.1.2b. Parameters associated with the catalyst shall be monitored as follows for each engine except C-238: 1.7.1 The catalyst pressure drop shall not exceed 2 inches of water column from the baseline value established by the source when the engine is operating at maximum achievable load. This baseline pressure drop shall be established by the source during each initial compliance and portable analyzer test, and as noted below. The pressure drop across the catalyst shall be monitored and recorded monthly in a log to be made available to the Division upon request. If the pressure is outside this range then the appropriate maintenance shall be performed to bring the pressure back into range. In lieu of maintenance the source may choose to perform a portable analyzer test of the engine to establish a new pressure drop value. If the test demonstrates that the engine is in compliance with its emission limits, the pressure drop value at which the engine is tested shall become the new baseline. The catalyst will be cleaned, reconditioned and replaced per the manufacturer's recommended schedule and a copy of maintenance reports shall be kept for Division review upon request. For new, cleaned or reconditioned catalyst: the new pressure drop baseline must be established by the operator within the first 7 days of engine/catalyst operation and re-established during the next regularly scheduled emission test. 1.7.2 The catalyst inlet temperature shall be maintained between 450°F and 1,350°F. The catalyst inlet temperature shall be monitored and recorded daily in a log to be made available to the Division upon request. 1.7.3 When portable monitoring is scheduled, the above parameters in Conditions 1.7.1 and 1.7.2 shall be recorded during the portable monitoring event. 1.7.4 All control equipment required by Condition 1.7 shall be operated and maintained pursuant to manufacturer specifications or equivalent to the extent practicable, and consistent with technological limitations and good engineering and maintenance practices. Manufacturer specifications or equivalent shall be kept on file. 1.8 Portable Monitoring Portable monitoring shall be conducted quarterly in accordance with the requirements of Condition 11. 1.9 Compliance Assurance Monitoring (CAM) Each engine is subject to the Compliance Assurance Monitoring (CAM) requirements with respect to the annual VOC emission limitations set forth in Condition 1.2. Compliance with the CAM requirements shall be monitored in accordance with Condition 12 and the CAM Plan in Appendix G. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 17 1.10 Statewide Controls for Oil and Gas Operations 1.10.1 Colorado Regulation No. 7, Part E, Section I. Requirements Each engine is subject to the following requirements of Colorado Regulation No. 7, Part E, Section I., "Control of Emissions from Engines": Conditions shown in italic text below represent monitoring, recordkeeping and recording provisions that are not included in Colorado Regulation No. 7 as of the issuance date of this permit, but are being included as per Colorado Regulation No. 3, Part C, Section V.C.5.b. 1.10.1.1 Air Pollution Technology Requirements (Colorado Regulation No. 7, Part E, Section I.B.). a. For lean burn reciprocating internal combustion engines, an oxidation catalyst shall be required. A lean burn reciprocating internal combustion engine is one with a normal exhaust oxygen concentration of 2% by volume, or greater (Colorado Regulation No. 7, Part E, Section I.B.2.). b. The emission control equipment required by this Section I.B. (Condition a above) shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications (Colorado Regulation No. 7, Part E, Section I.B.3.). 1.10.1.2 Control of emissions from new, modified, existing and relocated natural gas fired reciprocating internal combustion engines (Colorado Regulation No. 7, Part E, Section I.D.). a. [State -Only Enforceable] New, Modified and Relocated Natural Gas Fired Reciprocating Internal Combustion Engines (Colorado Regulation No. 7, Part E, Section I.D.2.). (i) Engine C-238 only: Except as provided in Section I.D.2.b. (Condition (ii) below), the owner or operator of any natural gas fired reciprocating internal combustion engine that is either constructed or relocated to the state of Colorado from another state, on or after the date listed in Table 1 shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in Section I.D.2.b. Table 1 Condition (ii) below) (Colorado Regulation No. 7, Part E, Section I.D.2.a.). (ii) Engine C-238 only: Actual emissions from natural gas fired reciprocating internal combustion engines shall not exceed the emission performance standards in Table 1 as expressed in units of Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 18 grams per horsepower -hour (g/hp-hr) (Colorado Regulation No. 7, Part E, Section I.D.2.b.): Table 1 Maximum Engine HP Construction or Relocation Date Emission Standard in g/hp-hr NOx CO VOC > 500 HP On or after July 1, 2007 2.0 4.0 1.0 On or after July 1, 2010 1.0 2.0 0.7 Engine C-238 only: [Compliance Monitoring: Compliance with the NOx and CO emission limitations shall be monitored by conducting portable monitoring quarterly as specified in Condition 1.8. For comparison with the short—term limits in this Condition, the results of the portable monitoring test shall be converted to units of g/hp-hr to assess compliance with the NOx and CO emission limitations in this Condition (ii).] Engine C-238 only: [Compliance Monitoring: In the absence of credible evidence to the contrary, compliance with the VOC limitation is presumed provided the portable monitoring indicates compliance with the NOx and CO emission limitations in this Condition (ii).] b. Existing Natural Gas Fired Reciprocating Internal Combustion Engines (Colorado Regulation No. 7, Part E, Section I.D.3.). (i) [State -Only Enforceable] Except as provided in Section I.D.3.b.(ii) all lean burn reciprocating internal combustion engines with a manufacturer's nameplate design rate greater than 500 horsepower shall install and operate an oxidation catalyst by July 1, 2010. A lean burn reciprocating internal combustion engine is one with a normal exhaust oxygen concentration of 2% by volume, or greater. (Colorado Regulation No. 7, Part E, Section I.D.3.b.(i)). 1.10.2 Colorado Regulation No. 7, Part E, Section II Requirements Each engine is subject to the following requirements of Colorado Regulation No. 7, Part E, Section II., "Control of Emissions from Stationary and Portable Combustion Equipment in the 8 -Hour Ozone Control Area": Conditions shown in italic text below represent monitoring, recordkeeping and recording provisions that are not included in Colorado Regulation No. 7 as of the issuance date of this permit, but are being included as per Colorado Regulation No. 3, Part C, Section V.C.5.b. 1.10.2.1 Exemptions (Colorado Regulation No. 7, Part E, Section II.A.2.) The following stationary combustion equipment are exempt from the emission limitation requirements of Section II.A.4., the compliance demonstration requirements Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 19 in Section II.A.5., and the related recordkeeping and reporting requirements of Sections II.A.7.a-e. and II.A.8, but these sources must maintain any and all records necessary to demonstrate that an exemption applies (Condition 1.10.2.3b). These records must be maintained for a minimum of five years and made available to the Division upon request. Qualifying for an exemption in this section does not preclude the combustion process adjustment requirements of Section II.A.6. (Condition 1.10.2.2), when required by II.A.6.a (Condition 1.10.2.2a). Once stationary combustion equipment no longer qualifies for any exemption, the owner or operator must comply with the applicable requirements of this Section II.A. as expeditiously as practicable but no later than 36 months after any exemption no longer applies. Additionally, once stationary combustion equipment that is not equipped with CEMS or CERMS no longer qualifies for any exemption, the owner or operator must conduct a performance test using EPA test methods within 180 days and notify the Division of the results and whether emission controls will be required to comply with the emission limitations of Section II.A.4. a. Any natural gas -fired reciprocating internal combustion engines subject to a work practice or emission control requirement contained in this Regulation 7, Section I.A. or B. (Condition 1.10.1.1) (Colorado Regulation No. 7, Part E, Section II.A.2.e.). 1.10.2.2 Combustion Process Adjustment (Colorado Regulation No. 7, Part E, Section II.A.6.). a. As of January 1, 2017, this Section II.A.6. (Conditions 1.10.2.2) applies to stationary reciprocating internal combustion engines with uncontrolled actual emissions of NOx equal to or greater than five (5) tons per year that existed at major sources of NOx (greater than or equal to 100 tpy NOx) as of June 3, 2016 (Colorado Regulation No. 7, Part E, Section II.A.6.a.(i)). b. The owner or operator of a stationary internal combustion engine must conduct the following inspections and adjustments, as applicable (Colorado Regulation No. 7, Part E, Section II.A.6.b.(iv)): (1) Change oil and filters as necessary (Colorado Regulation No. 7, Part E, Section II.A.6.b.(iv)(A)). (ii) Inspect air cleaners, fuel filters, hoses, and belts and clean or replace as necessary (Colorado Regulation No. 7, Part E, Section II.A.6.b.(iv)(B)). (iii) Inspect spark plugs and replace as necessary (Colorado Regulation No. 7, Part E, Section II.A.6.b.(iv)(C)). c. The owner or operator must operate and maintain the stationary internal combustion engine consistent with manufacturer's specifications, if available, or good engineering and maintenance practices (Colorado Regulation No. 7, Part E, Section II.A.6.b.(vii)). Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 20 d. Frequency (Colorado Regulation No. 7, Part E, Section II.A.6.b.(viii)). (i) The owner or operator of boilers, duct burners, process heaters, stationary combustion turbines, and stationary reciprocating internal combustion engines with uncontrolled actual emissions of NOx equal to or greater than five (5) tons per year that existed at major sources of NOx (greater than or equal to 100 tpy NOx) as of June 3, 2016, must conduct the initial combustion process adjustment by April 1, 2017. An owner or operator may rely on a combustion process adjustment conducted in accordance with applicable requirements and schedule of a New Source Performance Standard in 40 CFR Part 60 or National Emission Standard for Hazardous Air Pollutants in 40 CFR Part 63 to satisfy the requirement to conduct an initial combustion process adjustment by April 1, 2017 (Colorado Regulation No. 7, Part E, Section II.A.6.b.(viii)(A)). (ii) The owner or operator must conduct subsequent combustion process adjustments at least once every twelve (12) months after the initial combustion adjustment, or on the applicable schedule according to Sections II.A.6.c.(i) (Condition e(i)) or II.A.6.c.(ii) (Condition e(ii)) (Colorado Regulation No. 7, Part E, Section II.A.6.b.(viii)(C)). e. As an alternative to the requirements described in Sections II.A.6.b.(iv) through II.A.6.b.(viii) (Conditions b through d above) (Colorado Regulation No. 7, Part E, Section II.A.6.c.): (i) The owner or operator may conduct the combustion process adjustment according to the manufacturer recommended procedures and schedule (Colorado Regulation No. 7, Part E, Section II.A.6.c.(i)); or (ii) The owner or operator of combustion equipment that is subject to and required to conduct a periodic tune-up or combustion adjustment by the applicable requirements of a New Source Performance Standard in 40 CFR Part 60 or National Emission Standard for Hazardous Air Pollutants in 40 CFR Part 63 may conduct tune-ups or adjustments according to the schedule and procedures of the applicable requirements of 40 CFR Part 60 or 40 CFR Part 63 (Colorado Regulation No. 7, Part E, Section II.A.6.c.(ii)). 1.10.2.3 Recordkeeping. The following records must be kept for a period of five years and made available to the Division upon request (Colorado Regulation No. 7, Part E, Section II.A.7.): a. For stationary combustion equipment subject to the combustion process adjustment requirements in Section II.A.6. (Condition 1.10.2.2), the following recordkeeping requirements apply (Colorado Regulation No. 7, Part E, Section II.A.7.f.): Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 21 (i) The owner or operator must create a record once every calendar year identifying the combustion equipment at the source subject to Section II.A. (Condition 1.10.2.2a) and including for each combustion equipment (Colorado Regulation No. 7, Part E, Section II.A.7.f.(i)): (A)The date of the adjustment (Colorado Regulation No. 7, Part E, Section II.A.7.f.(i)(A)); (B) Whether the combustion process adjustment under Section II.A.6.b.(iv) (Condition 1.10.2.2b) was followed, and what procedures were performed (Colorado Regulation No. 7, Part E, Section II.A.7.f.(i)(B)); (C) Whether a combustion process adjustment under Sections II.A.6.c.(i). and II.A.6.c.(ii). (Conditions 1.10.2.2e(i) through 1.10.2.2e(ii)) was followed, what procedures were performed, and what New Source Performance or National Emission Standard for Hazardous Air Pollutants applied, if any (Colorado Regulation No. 7, Part E, Section II.A.f.(i)(C)); and (D) A description of any corrective action taken (Colorado Regulation No. 7, Part E, Section II.A.7.f.(i)(D)). (E) If the owner or operator conducts the combustion process adjustment according to the manufacturer recommended procedures and schedule and the manufacturer specifies a combustion process adjustment on an operation time schedule, the hours of operation (Colorado Regulation No. 7, Part E, Section II.A.7.f.(i)(E)). (ii) The owner or operator must retain manufacturer recommended procedures, specifications, and maintenance schedule if utilized under Section II.A.6.c.(i). (Condition 1.10.2.2e(i)) for the life of the equipment (Colorado Regulation No. 7, Part E, Section II.A.7.f.(ii)). (iii) As an alternative to the requirements described in Section II.A.7.f.(i) (Condition (i) above), the owner or operator may comply with applicable recordkeeping requirements related to combustion process adjustments conducted according to a New Source Performance Standard in 40 CFR Part 60 or National Emission Standard for Hazardous Air Pollutants in 40 CFR Part 63 (Colorado Regulation No. 7, Part E, Section II.A.7.f.(iii)). b. All sources qualifying for an exemption under Section II.A.2. (Condition 1.10.2.1) must maintain all records necessary to demonstrate that an exemption applies (Colorado Regulation No. 7, Part E, Section II.A.7.g.). 1.11 40 CFR Part 63 Subpart ZZZZ MACT Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 22 Engine C-238 only is subject to the National Emissions Standards for Hazardous Air Pollutants requirements of Regulation No. 8, Part E, Subpart ZZZZ (40 CFR Part 63, Subpart ZZZZ) "National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines", including, but not limited to, the following: The requirements below reflect the current rule language as of the revisions to 40 CFR Part 63 Subpart ZZZZ published in the Federal Register on 2/27/2014. However, if revisions to this Subpart are published at a later date, the owner or operator is subject to the requirements contained in the revised version of 40 CFR Part 63 Subpart ZZZZ. Note that as of the date of revised permit issuance March 1, 2021, the requirements in 40 CFR Part 63 Subpart ZZZZ promulgated on March 3, 2010 and later have not been adopted into Colorado Regulation No. 8, Part E by the Division and are therefore not state -enforceable. In the event that the Division adopts these requirements, they will become both state and federally enforceable. General Requirements: 1.11.1 You must be in compliance with the emission limitations in Condition 1.11.3, operating limitations in Condition 1.11.4, and other requirements in this subpart that apply to you at all times. (§63.6605(a)). 1.11.2 At all times you must operate and maintain any affected source, including associated air pollution control equipment and monitoring equipment, in a manner consistent with safety and good air pollution control practices for minimizing emissions. The general duty to minimize emissions does not require you to make any further efforts to reduce emissions if levels required by this standard have been achieved. Determination of whether such operation and maintenance procedures are being used will be based on information available to the Administrator which may include, but is not limited to, monitoring results, review of operation and maintenance procedures, review of operation and maintenance records, and inspection of the source. (§63.6605(b)). Emission Limitations: 1.11.3 Owners or operators of a new or reconstructed 4SLB stationary RICE with a site rating of more than 500 brake HP located at major source of HAP emissions shall: 1.11.3.1 Reduce CO emissions by 93 percent or more (§63.6600(b), Table 2a, Item 2.a.), or 1.11.3.2 Limit concentration of formaldehyde in the stationary RICE exhaust to 14 ppmvd or less at 15 percent O2 (§63.6600(b), Table 2a, Item 2.b.). Operating Limitations: 1.11.4 Owners or operators of a new or reconstructed 4SLB stationary RICE with a site rating of more than 500 brake HP located at major source of HAP emissions shall: Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 23 1.11.4.1 Maintain your catalyst so that the pressure drop across the catalyst does not change by more than 2 inches of water at 100 percent load plus or minus 10 percent from the pressure drop across the catalyst that was measured during the initial performance test (§63.6600(b), Table 2b, Item1.a.); and 1.11.4.2 Maintain the temperature of your stationary RICE exhaust so that the catalyst inlet temperature is greater than or equal to 450°F and less than or equal to 1,350°F (§63.6600(b), Table 2b, Iteml.b.). Subsequent Performance Test Requirements: 1.11.5 Subsequent performance tests shall be conducted semi-annually (§63.6615, Table 3, Item 1). 1.11.6 After compliance has been demonstrated for two consecutive tests, the frequency of semi-annual tests may be reduced to annually. If the results of any subsequent annual performance test indicates the stationary RICE is not in compliance with the CO emission limitations, or you deviate from any of your operating limitations, you must resume semi-annual performance tests (§63.6615, Table 3, Footnote 1). Performance Tests and Other Procedures 1.11.7 Each performance test must be conducted according to the requirements that this subpart specifies in Table 4 to this subpart. The test must be conducted at any load condition within plus or minus 10 percent of 100 percent load (§63.6620(b)). Monitoring, Installation, Collection, Operation and Maintenance Requirements: 1.11.8 You must install, maintain and operate a continuous parametric monitoring system (CPMS) to continuously monitor catalyst inlet temperature according to the requirements of §63.6625(b)(1) through (6) of this subpart (§63.6625(b), Table 5, Item 1). 1.11.9 If you operate a new, reconstructed, or existing stationary engine, you must minimize the engine's time spent at idle during startup and minimize the engine's startup time to a period needed for appropriate and safe loading of the engine, not to exceed 30 minutes, after which time the emission standards applicable to all times other than startup in Condition 1.11.3 to this subpart apply (§63.6625(h)). Monitoring and Collecting Data for Continuous Compliance: 1.11.10 Data must be monitored and collected in accordance with the following (§63.6635(a)): 1.11.10.1 Except for monitor malfunctions, associated repairs, required performance evaluations, and required quality assurance or control activities, you must monitor continuously at all times that the stationary RICE is operating. A monitoring malfunction is any sudden, infrequent, not reasonably preventable failure of the monitoring to provide valid data. Monitoring failures that are caused in part by poor Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 24 maintenance or careless operation are not malfunctions. (§63.6635(b)). 1.11.10.2 You may not use data recorded during monitoring malfunctions, associated repairs, and required quality assurance or control activities in data averages and calculations used to report emission or operating levels. You must however, use all the valid data collected during all other periods (§63.6635(c)). Demonstrating Continuous Compliance with the Emission and Operating Limitations: 1.11.11 You must demonstrate continuous compliance with each emission and operating limitation in Conditions 1.11.3 and 1.11.4 as follows: 1.11.11.1 Conducting subsequent performance tests as specified in Condition 1.11.5 and demonstrating the required CO reduction in Condition 1.11.3.1 (§63.6640(a), Table 6, Item 1.i.). 1.11.1 1.2 Conducting semiannual performance tests for formaldehyde as specified in Condition 1.11.5 to demonstrate that your emissions remain at or below the formaldehyde concentration limit in Condition 1.11.3.2 (§63.6640(a), Table 6, Item 7.i.). 1.11.11.3 Collecting the catalyst inlet temperature data according to §63.6625(b) (Condition 1.11.8); (§63.6640(a), Table 6, Item 1.a.ii. or 7.a.ii.) and 1.11.11.4 Reducing these data to 4 -hour rolling averages; ((§63.6640(a), Table 6, Item 1.a.iii. or 7.a.iii.) and 1.11.11.5 Maintaining the 4 -hour rolling averages within the operating limitations for the catalyst inlet temperature (Condition 1.11.4.2); (§63.6640(a), Table 6, Item 1.a.iv. or 7.a.iv.) and 1.11.11.6 Measuring the pressure drop across the catalyst once per month and demonstrating that the pressure drop across the catalyst is within the operating limitation established during the performance test (§63.6640(a), Table 6, Item 1.v. and Item 7.v.). 1.11.11.7 After you have demonstrated compliance for two consecutive tests, you may reduce the frequency of subsequent performance tests to annually. If the results of any subsequent annual performance test indicate the stationary RICE is not in compliance with the CO or formaldehyde emission limitation, or you deviate from any of your operating limitations, you must resume semiannual performance tests (§63.6640(a), Table 6, Footnote a). 1.11.12 You must report each instance in which you did not meet each emission limitation or operating limitation in Conditions 1.11.3 and 1.11.4. These instances are deviations from the emission and operating limitations in Conditions 1.11.3 and 1.11.4. These deviations must be reported according to the requirements in Conditions 1.11.18 through 1.11.22. If you change your catalyst, you must reestablish the values of the operating parameters measured during the initial performance test. When you reestablish the values of your operating parameters, you must also conduct a performance test to demonstrate that you are meeting the required emission limitation applicable to your stationary RICE (§63.6640(b)). Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 25 1.11.13 For new, reconstructed, and rebuilt stationary RICE, deviations from the emission (Condition 1.11.3) or operating limitations (Condition 1.11.4) that occur during the first 200 hours of operation from engine startup (engine burn -in period) are not violations. Rebuilt stationary RICE means a stationary RICE that has been rebuilt as that term is defined in 40 CFR § 94.11(a) (§63.6640(d)). 1.11.14 You must also report each instance in which you did not meet the requirements in Condition 1.12 of this permit (§63.6640(e)). What Notifications to Submit and When: 1.11.15 You must submit all of the notifications in §63.7(b) and (c), 63.8(e), (f)(4) and (f)(6), 63.9(b) through (e), and (g) and (h) that apply to you by the dates specified. (§63.6645(a)). 1.11.16 If you are required to conduct a performance test, you must submit a Notification of Intent to conduct a performance test at least 60 days before the performance test is scheduled to begin as required in § 63.7(b)(1) (Condition 1.12.3) (§63.6645(g)). 1.11.17 If you are required to conduct a performance test as specified in Condition 1.11.5, you must submit the Notification of Compliance Status according to §63.6645(h)(1) and (h)(2) of this subpart (§63.6645(h)). What Reports to Submit and When: 1.11.18 You must submit each report in Table 7 of this subpart that applies to you (§63.6650(a)). 1.11.19 Unless the Division has approved a different schedule for submission of reports under §63.10(a) (Condition 1.12.6), you must submit Compliance Reports in accordance with the requirements of §63.6650(b)(1) through (b)(9) of this subpart (§63.6650(b)). 1.11.20 The Compliance Reports must include the information in §63.6650(c)(1) through (c)(6) of this subpart (§63.6650(c)). 1.11.21 For each deviation from any emission or operating limitation that occurs for a stationary RICE where you are using a CPMS to comply with the emission and operating limitations in this subpart you must include information in §63.6650(c)(1) through (4) and (e)(1) through (12) of this subpart (§63.6650(e)). 1.11.22 Each affected source that has obtained a title V operating permit pursuant to 40 CFR part 70 or 71 must report all deviations as defined in this subpart in the semiannual monitoring report required by 40 CFR 70.6 (a)(3)(iii)(A) or 40 CFR 71.6(a)(3)(iii)(A). If an affected source submits a Compliance report pursuant to Condition 1.11.18 along with, or as part of, the semiannual monitoring report required by 40 CFR 70.6(a)(3)(iii)(A) or 40 CFR 71.6(a)(3)(iii)(A), and the Compliance report includes all required information concerning deviations from any emission or operating limitation in this subpart, submission of the Compliance report shall be deemed to Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 26 satisfy any obligation to report the same deviations in the semiannual monitoring report. However, submission of a Compliance report shall not otherwise affect any obligation the affected source may have to report deviations from permit requirements to the permit authority §63.6650(f)). What Records to Keep: 1.11.23 A copy of each notification and report that you submitted to comply with this subpart, including all documentation supporting any Initial Notification or Notification of Compliance Status that you submitted, according to the requirement in §63.10(b)(2)(xiv) (Condition 1.12.6) (§63.6655(a)(1)). 1.11.24 Records of the occurrence and duration of each malfunction of operation (i.e., process equipment) or the air pollution control and monitoring equipment. (§63.6655(a)(2)). 1.11.25 Records of performance tests and performance evaluations as required in §63.10(b)(2)(viii) (Condition 1.12.6) (§63.6655(a)(3)). 1.11.26 Records of all required maintenance performed on the air pollution control and monitoring equipment. (§63.6655(a)(4)). 1.11.27 Records of actions taken during periods of malfunction to minimize emissions in accordance with Condition 1.11.2, including corrective actions to restore malfunctioning process and air pollution control and monitoring equipment to its normal or usual manner of operation (§63.6655(a)(5)). 1.11.28 For each CPMS you must keep the following records (§63.6655(b)): 1.11.28.1 Records described in §63.10(b)(2)(vi) through (xi) (Condition 1.12.6) (§63.6655(b)(1)). 1.11.28.2 Previous (i.e., superseded) versions of the performance evaluation plan as required in §63.8(d)(3) (Condition 1.12.4) (§63.6655(b)(2)). 1.11.28.3 Requests for alternatives to the relative accuracy test for CPMS as required in §63.8(f)(6)(i) (Condition 1.12.4), if applicable (§63.6655(b)(3)). 1.11.29 You must keep the records required in Condition 1.11.11 to show continuous compliance with each emission or operating limitation that applies to you (§63.6655(d)). Form and Length of Recordkeeping: 1.11.30 Your records must be in a form suitable and readily available for expeditious review according to §63.10(b)(1) (Condition 1.12.6) (§63.6660(a)). Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 27 1.11.31 As specified in §63.10(b)(1) (Condition 1.12.6), you must keep each record for 5 years following the date of each occurrence, measurement, maintenance, corrective action, report, or record (§63.6660(b)). 1.11.32 You must keep each record readily accessible in hard copy or electronic form for at least 5 years after the date of each occurrence, measurement, maintenance, corrective action, report, or record, according to §63.10(b)(1) (Condition 1.12.6) (§63.6660(c)). 1.12 40 CFR Part 63 Subpart A MACT Engine C-238 only is subject to the requirements in 40 CFR part 63 Subpart A "General Provisions", as adopted by reference in Colorado Regulation No. 8, Part E, Section I as specified in 40 CFR Part 63 Subpart ZZZZ §63.6665. These requirements include, but are not limited to the following: 1.12.1 Prohibited activities and circumvention (§63.4) 1.12.2 Operation and maintenance requirements (§63.6(e)(1)) 1.12,3 Performance testing requirements (§63.7) 1.12.4 Monitoring requirements (§63.8) 1.12,5 Notification requirements (§63.9) 1.12.6 Recordkeeping and reporting requirements (§63.10) Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 28 2. C-237 - Caterpillar G3616 4,735 hp Compressor Engine with Oxidation Catalyst, AIRS ID: 071 Parameter Permit Condition Number Compliance Limits Emission Factor Monitoring Method Interval Emission & Consumption Limits NOx 2.1 32.01 tons/year 0.206 lb/MMBtu Recordkeeping and Twelve Month Rolling Total Calculation Monthly CO 36.58 tons/year 0.236 lb/MMBtu VOC 2.2 32.01 tons/year 0.206 lb/MMBtu Natural Gas Consumption 2.3 304.22 MMscf/year Fuel Meter, Twelve Month Rolling Total Other Requirements Natural Gas Heat Content 2.4 ASTM or Other Division Approved Method Semi -Annually Hours of Operation 2.5 Recordkeeping Monthly Opacity 2.6 Not to exceed 20%, except as provided for below: Fuel Restriction — Natural Gas Only For Certain Operational Activities - Not to exceed 30% for a period or periods aggregating more than six (6) minutes in any sixty (60) consecutive minutes Portable Monitoring 2.7 Flue Gas Analyzer Quarterly Compliance Assurance Monitoring (CAM) 2.8 See Condition 2.8 Statewide Controls for Oil and Gas Operations 2.9 See Condition 2.9 40 CFR 60 Subpart JJJJ NSPS 2.10 See Condition 2.10 40 CFR 60 Subpart OOOO NSPS 2.11 See Condition 2.11 40 CFR 60 Subpart A General Provisions NSPS 2.12 See Condition 2.12 40 CFR 63 Subpart ZZZZ MACT 2.13 See Condition 2.13 40 CFR 63 Subpart A General Provisions MACT 2.14 See Condition 2.14 2.1 NOx & CO Emission Limitations & Compliance Monitoring Emissions of Nitrogen Oxides (NOx) and Carbon Monoxide (CO) from this engine shall not exceed the limitations listed in Summary Table 2 above. Except as provided for below, the emission factors listed Operating Permit Number: 95OPWE 103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 29 above have been approved by the Division and shall be used to calculate emissions from this engine, as follows: 2.1.1 Monthly determination of NOx and CO emissions shall be conducted by the end of the subsequent month using the emission factors listed in Summary Table 2 above, the monthly natural gas consumption, as required by Condition 2.3 and the heat content of the natural gas obtained from the most recent analysis, as required by Condition 2.4, in the equation below: ( lb MMBtu MMscf tons Emission Factor \MMBtu) x Heat Content (MMscf ) x Fuel Use (month ) NOx or CO Emissions (month) (2000 lb ) Unit Conversion l ton Monthly emissions shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 2.1.2 Portable monitoring shall be conducted quarterly as required by Condition 2.7. If the results of the portable analyzer testing conducted under the provisions of Condition 2.7 show that either the NOx or CO emission rates/factors are greater than the emission rates/factors listed above, and in the absence of subsequent testing results to the contrary (as approved by the Division), the owner or operator shall apply for a modification to this permit to reflect, at a minimum, the higher emission rates/factors within 60 days of the completion of the test. 2.2 VOC Emission Limitations & Compliance Monitoring Emissions of Volatile Organic Compounds (VOC) from this engine shall not exceed the limitation listed in Summary Table 2 above. Compliance with the emission limitation shall be monitored as follows: 2.2.1 Monthly determination of VOC emissions shall be conducted by the end of the subsequent month using the emission factors listed in Summary Table 2 above, the monthly natural gas consumption, as required by Condition 2.3, and the heat content of the natural gas obtained from the most recent analysis, as required by Condition 2.4, in the equation below: Emission Factor (( lb x Heat Content MMBtu x Fuel Use MMscf tons = IMMBtu� (MMscf) (month) VOC or HAP Emissions (month) 2000 lb Unit Conversion ( ton Monthly emissions shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 30 2.2.2 Annual emissions of Hazardous Air Pollutants (HAP), for the purposes of APEN reporting and the payment of annual fees, shall be calculated using HAP emissions derived from the same method as required for VOC emissions, except that the compliance emission factor for each HAP species shall be obtained from EPA's AP -42: Compilation of Emission Factors, Section 3.2 for Natural Gas Fired Reciprocating Engines, Final Section, Table 3.2-2 (dated 8/2000). 2.3 Natural Gas Consumption Limitations & Compliance Monitoring Natural gas consumption from this engine shall not exceed the limitation listed in Summary Table 2 above (as provided for under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3, Part B, Section II.A.6 and Part C, Section X based on requested limitations identified on the APEN received on 11/20/2018). Facility -wide natural gas consumption shall be recorded using the existing fuel meter on a monthly basis. The natural gas usage shall be recorded on the same day that run time hours have been recorded, as required by Condition 2.5. Allocation of natural gas to this engine will be determined using the following equation: Btu MMscf\ HREngine (m ) MMscfl FCEngine (month) Btu Btu x FCFnciiity (month) F HREngine (month) + HRother (month) Where: Btu ) Btu hr HREngine (month) = BSFC (hp hr/ x Hours of Operation (month) x Site Rated hp (hp) And: FCEngine = Individual Engine Fuel Consumption, MMscf/Month HREngine = Individual Engine Heat Requirement, Btu/Month HROther = Other Users Heat Requirement, Btu/Month FCFQcility = Facility Wide Fuel Consumption (metered), MMscf/Month BSFC = Brake Specific Fuel Consumption, Btu/hp • hr Monthly natural gas consumption for this engine shall be used in a twelve month rolling total to monitor compliance with the annual limitation. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. Monthly natural gas consumption shall be used to monitor compliance with the NOx, CO and VOC emission limitations, as required by Conditions 2.1 and 2.2. 2.4 Natural Gas Heat Content Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 31 The heat content of the natural gas used to fuel this engine shall be verified semi-annually, or once every six months, using the appropriate ASTM Methods or equivalent, if approved in advance by the Division. At least four (4) months shall separate sequential sampling events. The heat content of the natural gas shall be based on the higher heating value (HHV) of the fuel. The heat content used by the Division in determining the emission limitations listed in Summary Table 2 was 1,020 Btu per standard cubic foot of natural gas. The heat content indicated by the most recent analysis shall be used to monitor compliance with the NOx, CO and VOC emission limitations, as required by Conditions 2.1 and 2.2. 2.5 Hours of Operation Hours of operation for this engine shall be monitored and recorded monthly. Hours of operation shall be recorded on the same day that the facility fuel gas consumption is recorded. Records of the monthly hours of operation shall be maintained and made available to the Division upon request. The hours of operation shall be used to monitor compliance with the natural gas consumption limitation, as required by Condition 2.3. 2.6 Opacity The following opacity requirements apply to this engine: 2.6.1 Except as provided for in Condition 2.6.2 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 (Colorado Regulation No. 1, Section II.A.1). 2.6.2 No owner or operator of a source shall allow or cause to be emitted into the atmosphere any air pollutant resulting from the building of a new fire, cleaning of fire boxes, soot blowing, start-up, process modifications, or adjustment or occasional cleaning of control equipment which is excess of 30% opacity for a period or periods aggregating more than six (6) minutes in any sixty (60) consecutive minutes (Colorado Regulation No. 1, Section II.A.4). In the absence of credible evidence to the contrary, compliance with the opacity limit shall be presumed since only natural gas is permitted to be used as fuel for this engine. The owner or operator shall maintain records that verify that only natural gas is used as fuel. 2.7 Portable Monitoring Portable monitoring shall be conducted quarterly in accordance with the requirements of Condition 11. 2.8 Compliance Assurance Monitoring (CAM) This engine is subject to the Compliance Assurance Monitoring (CAM) requirements with respect to the annual CO emission limitation set forth in Condition 2.1 and VOC emission limitation set forth in Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 32 Condition 2.2. Compliance with the CAM requirements shall be monitored in accordance with Condition 12 and the CAM Plan in Appendix G. 2.9 Statewide Controls for Oil and Gas Operations 2.9.1 Colorado Regulation No. 7, Part E, Section I. Requirements This engine is subject to the following requirements of Colorado Regulation No. 7, Part E, Section I., "Control of Emissions from Engines": Conditions shown in italic text below represent monitoring, recordkeeping and recording provisions that are not included in Colorado Regulation No. 7 as of the issuance date of this permit, but are being included as per Colorado Regulation No. 3, Part C, Section V.C.5.b. 2.9.1.1 Air Pollution Technology Requirements (Colorado Regulation No. 7, Part E, Section I.B.). a. For lean burn reciprocating internal combustion engines, an oxidation catalyst shall be required. A lean burn reciprocating internal combustion engine is one with a normal exhaust oxygen concentration of 2% by volume, or greater (Colorado Regulation No. 7, Part E, Section I.B.2.). b. The emission control equipment required by this Section I.B. (Condition a above) shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications (Colorado Regulation No. 7, Part E, Section I.B.3.). 2.9.1.2 Control of emissions from new, modified, existing and relocated natural gas fired reciprocating internal combustion engines (Colorado Regulation No. 7, Part E, Section I.D.). a. [State -Only Enforceable] New, Modified and Relocated Natural Gas Fired Reciprocating Internal Combustion Engines (Colorado Regulation No. 7, Part E, Section I.D.2.). (i) Except as provided in Section I.D.2.b. (Condition (ii) below), the owner or operator of any natural gas fired reciprocating internal combustion engine that is either constructed or relocated to the state of Colorado from another state, on or after the date listed in Table 1 shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in Section I.D.2.b. Table 1 Condition (ii) below) (Colorado Regulation No. 7, Part E, Section I.D.2.a.). Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 33 (ii) Actual emissions from natural gas fired reciprocating internal combustion engines shall not exceed the emission performance standards in Table 1 as expressed in units of grams per horsepower - hour (g/hp-hr) (Colorado Regulation No. 7, Part E, Section I.D.2.b.): Table 1 Maximum Engine HP Construction or Relocation Date Emission Standard in g/hp-hr N0x CO V0C > 500 HP — On or after July 1, 2007 2.0 4.0 1.0 On or after July 1, 2010 1.0 2.0 0.7 [Compliance Monitoring: Compliance with the NOx and CO emission limitations shall be monitored by conducting portable monitoring quarterly as specified in Condition 2.7. For comparison with the short—term limits in this Condition, the results of the portable monitoring test shall be converted to units of g/hp-hr to assess compliance with the NOx and CO emission limitations in this Condition (ii).] [Compliance Monitoring: In the absence of credible evidence to the contrary, compliance with the VOC limitation is presumed provided the portable monitoring indicates compliance with the NOx and CO emission limitations in this Condition (ii).] b. Existing Natural Gas Fired Reciprocating Internal Combustion Engines (Colorado Regulation No. 7, Part E, Section I.D.3.). (1) [State -Only Enforceable] Except as provided in Section I.D.3.b.(ii) all lean burn reciprocating internal combustion engines with a manufacturer's nameplate design rate greater than 500 horsepower shall install and operate an oxidation catalyst by July 1, 2010. A lean burn reciprocating internal combustion engine is one with a normal exhaust oxygen concentration of 2% by volume, or greater. (Colorado Regulation No. 7, Part E, Section I.D.3.b.(i)). 2.9.2 Colorado Regulation No. 7, Part E, Section II. Requirements This engine is subject to the following requirements of Colorado Regulation No. 7, Part E, Section II., "Control of Emissions from Stationary and Portable Combustion Equipment in the 8 -Hour Ozone Control Area": Conditions shown in italic text below represent monitoring, recordkeeping and recording provisions that are not included in Colorado Regulation No. 7 as of the issuance date of this permit, but are being included as per Colorado Regulation No. 3, Part C, Section V.C.5.b. 2.9.2.1 Exemptions (Colorado Regulation No. 7, Part E, Section II.A.2.) Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 34 The following stationary combustion equipment are exempt from the emission limitation requirements of Section II.A.4., the compliance demonstration requirements in Section II.A.5., and the related recordkeeping and reporting requirements of Sections II.A.7.a-e. and II.A.8, but these sources must maintain any and all records necessary to demonstrate that an exemption applies (Condition 2.9.2.3b). These records must be maintained for a minimum of five years and made available to the Division upon request. Qualifying for an exemption in this section does not preclude the combustion process adjustment requirements of Section II.A.6. (Condition 2.9.2.2), when required by II.A.6.a (Condition 2.9.2.2a). Once stationary combustion equipment no longer qualifies for any exemption, the owner or operator must comply with the applicable requirements of this Section II.A. as expeditiously as practicable but no later than 36 months after any exemption no longer applies. Additionally, once stationary combustion equipment that is not equipped with CEMS or CERMS no longer qualifies for any exemption, the owner or operator must conduct a performance test using EPA test methods within 180 days and notify the Division of the results and whether emission controls will be required to comply with the emission limitations of Section II.A.4. a. Any natural gas -fired reciprocating internal combustion engines subject to a work practice or emission control requirement contained in this Regulation 7, Section I.A. or B. (Condition 2.9.1.1) (Colorado Regulation No. 7, Part E, Section II.A.2.e.). 2.9.2.2 Combustion Process Adjustment (Colorado Regulation No. 7, Part E, Section II.A.6.). a. As of January 1, 2017, this Section II.A.6. (Conditions 2.9.2.2) applies to stationary reciprocating internal combustion engines with uncontrolled actual emissions of NOx equal to or greater than five (5) tons per year that existed at major sources of NOx (greater than or equal to 100 tpy NOx) as of June 3, 2016 (Colorado Regulation No. 7, Part E, Section II.A.6.a.(i)). b. The owner or operator of a stationary internal combustion engine must conduct the following inspections and adjustments, as applicable (Colorado Regulation No. 7, Part E, Section II.A.6.b.(iv)): (i) Change oil and filters as necessary (Colorado Regulation No. 7, Part E, Section II.A.6.b.(iv)(A)). (ii) Inspect air cleaners, fuel filters, hoses, and belts and clean or replace as necessary (Colorado Regulation No. 7, Part E, Section II.A.6.b.(iv)(B)). (iii) Inspect spark plugs and replace as necessary (Colorado Regulation No. 7, Part E, Section II.A.6.b.(iv)(C)). c. The owner or operator must operate and maintain the stationary internal combustion engine consistent with manufacturer's specifications, if available, Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 35 or good engineering and maintenance practices (Colorado Regulation No. 7, Part E, Section II.A.6.b.(vii)). d. Frequency (Colorado Regulation No. 7, Part E, Section II.A.6.b.(viii)). (i) The owner or operator of boilers, duct burners, process heaters, stationary combustion turbines, and stationary reciprocating internal combustion engines with uncontrolled actual emissions of NOx equal to or greater than five (5) tons per year that existed at major sources of NOx (greater than or equal to 100 tpy NOx) as of June 3, 2016, must conduct the initial combustion process adjustment by April 1, 2017. An owner or operator may rely on a combustion process adjustment conducted in accordance with applicable requirements and schedule of a New Source Performance Standard in 40 CFR Part 60 or National Emission Standard for Hazardous Air Pollutants in 40 CFR Part 63 to satisfy the requirement to conduct an initial combustion process adjustment by April 1, 2017 (Colorado Regulation No. 7, Part E, Section II.A.6.b.(viii)(A)). (ii) The owner or operator must conduct subsequent combustion process adjustments at least once every twelve (12) months after the initial combustion adjustment, or on the applicable schedule according to Sections II.A.6.c.(i) (Condition e(i)) or II.A.6.c.(ii) (Condition e(ii)) (Colorado Regulation No. 7, Part E, Section II.A.6.b.(viii)(C)). e. As an alternative to the requirements described in Sections II.A.6.b.(iv) through II.A.6.b.(viii) (Conditions b through d above) (Colorado Regulation No. 7, Part E, Section II.A.6.c.): (i) The owner or operator may conduct the combustion process adjustment according to the manufacturer recommended procedures and schedule (Colorado Regulation No. 7, Part E, Section II.A.6.c.(i)); or (ii) The owner or operator of combustion equipment that is subject to and required to conduct a periodic tune-up or combustion adjustment by the applicable requirements of a New Source Performance Standard in 40 CFR Part 60 or National Emission Standard for Hazardous Air Pollutants in 40 CFR Part 63 may conduct tune-ups or adjustments according to the schedule and procedures of the applicable requirements of 40 CFR Part 60 or 40 CFR Part 63 (Colorado Regulation No. 7, Part E, Section II.A.6.c.(ii)). 2.9.2.3 Recordkeeping. The following records must be kept for a period of five years and made available to the Division upon request (Colorado Regulation No. 7, Part E, Section II.A.7.): a. For stationary combustion equipment subject to the combustion process adjustment requirements in Section II.A.6. (Condition 2.9.2.2), the following Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 36 recordkeeping requirements apply (Colorado Regulation No. 7, Part E, Section II.A.7.f.): (i) The owner or operator must create a record once every calendar year identifying the combustion equipment at the source subject to Section II.A. (Condition 2.9.2.2a) and including for each combustion equipment (Colorado Regulation No. 7, Part E, Section II.A.7.f.(i)): (A) The date of the adjustment (Colorado Regulation No. 7, Part E, Section II.A.7.f.(i)(A)); (B) Whether the combustion process adjustment under Section II.A.6.b.(iv) (Condition 2.9.2.2b) was followed, and what procedures were performed (Colorado Regulation No. 7, Part E, Section II.A.7.f.(i)(B)); (C) Whether a combustion process adjustment under Sections II.A.6.c.(i). and II.A.6.c.(ii). (Conditions 2.9.2.2e(i) through 2.9.2.2e(ii)) was followed, what procedures were performed, and what New Source Performance or National Emission Standard for Hazardous Air Pollutants applied, if any (Colorado Regulation No. 7, Part E, Section II.A.f.(i)(C)); and (D) A description of any corrective action taken (Colorado Regulation No. 7, Part E, Section II.A.7.f.(i)(D)). (E) If the owner or operator conducts the combustion process adjustment according to the manufacturer recommended procedures and schedule and the manufacturer specifies a combustion process adjustment on an operation time schedule, the hours of operation (Colorado Regulation No. 7, Part E, Section II.A.7.f.(i)(E)). (ii) The owner or operator must retain manufacturer recommended procedures, specifications, and maintenance schedule if utilized under Section II.A.6.c.(i). (Condition 2.9.2.2e(i)) for the life of the equipment (Colorado Regulation No. 7, Part E, Section II.A.7.f.(ii)). (iii) As an alternative to the requirements described in Section II.A.7.f.(i) (Condition (i) above), the owner or operator may comply with applicable recordkeeping requirements related to combustion process adjustments conducted according to a New Source Performance Standard in 40 CFR Part 60 or National Emission Standard for Hazardous Air Pollutants in 40 CFR Part 63 (Colorado Regulation No. 7, Part E, Section II.A.7.f.(iii)). Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 37 b. All sources qualifying for an exemption under Section II.A.2. (Condition 2.9.2.1) must maintain all records necessary to demonstrate that an exemption applies (Colorado Regulation No. 7, Part E, Section II.A.7.g.). 2.10 40 CFR Part 60 Subpart JJJJ NSPS This engine is subject to the New Source Performance Standards requirements of 40 CFR Part 60, Subpart JJJJ "Standards of Performance for Stationary Spark Ignition Internal Combustion Engines", including, but not limited to, the following: The requirements below reflect the current rule language as of the revisions to 40 CFR Part 60 Subpart JJJJ published in the Federal Register on 8/30/2016. However, if revisions to this Subpart are published at a later date, the owner or operator is subject to the requirements contained in the revised version of 40 CFR Part 60 Subpart JJJJ. These requirements have not been adopted into Colorado Regulation No. 6, Part A as of the date of this permit issuance March 1, 2021, and are therefore not state -enforceable. In the event that these requirements are adopted into Colorado Regulations, they will become state -enforceable. Emission Standards for Owners and Operators: 2.10.1 Each engine must comply with the specific emission limitations shown in the table below (Table 1 of Subpart JJJJ). Manufacture Date: July t, 201 Q Emission Standards ( p -hr) Emission Standards (ppmvd at 15% O2) NOx CO VOC NOx CO VOC 1.0 2.0 0.7 82 270 60 2.10.1.1 Owners and operators of new or reconstructed non -emergency lean burn SI stationary engines with a site rating of greater than or equal to 250 brake HP located at a major source that are meeting the requirements of 40 CFR part 63, subpart ZZZZ, Table 2a (Condition 2.13.3) do not have to comply with the CO emission standards of Table 1 of this subpart (Table 1 and Footnote b of Subpart JJJJ). 2.10.1.2 For purposes of this subpart, when calculating emissions of volatile organic compounds, emissions of formaldehyde should not be included (Table 1 and Footnote d of Subpart JJJJ). 2.10.1.3 For engines manufactured prior to January 1, 2011 that were certified to the certification emission standards in 40 CFR part 1048 applicable to engines that are not severe duty engines, if such stationary SI ICE was certified to a carbon monoxide (CO) standard above the standard in Condition 2.10.1 above, then the source may meet the CO certification (not field testing) standard for which the engine was certified (§60.4233(e)). Compliance Requirements for Owners and Operators: Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 38 2.10.2 This facility shall keep a maintenance plan and records of conducted maintenance and, to the extent practicable, maintain and operate the engine in a manner consistent with good air pollution control practice for minimizing emissions. In addition, this facility shall conduct an initial performance test and conduct subsequent performance testing every 8,760 hours or 3 years, whichever comes first, thereafter to demonstrate compliance (§60.4243(b)(2)(ii)). Testing Requirements for Owners and Operators: 2.10.3 Owners and operators of stationary SI ICE who conduct performance tests must follow the procedures in §60.4244(a) through (g) of this subpart (§60.4244). Notification, Reports and Records for Owners and Operators: 2.10.4 The facility must keep records of the following information: 2.10.4.1 All notifications submitted to comply with this subpart and all documentation supporting any notification (§60.4245(a)(1)). 2.10.4.2 Maintenance conducted on the engine (§60.4245(a)(2)). 2.10.4.3 If the engine is not a certified engine or is a certified engine operating in a non -certified manner and subject to §60.4243(a)(2), documentation that the engine meets the emission standards (§60.4245(a)(4)). 2.10.5 Engines that not been certified by an engine manufacturer to meet the emission standards in §60.4231 must submit an initial notification as required in §60.7(a)(1) (Condition 2.12.1). The notification must include the information in §60.4245(c)(1) through (c)(5) of this subpart (§60.4245(c)). 2.10.6 The source must submit a copy of each performance test as conducted in §60.4244 (Condition 2.10.3) within 60 days after the test has been completed (§60.4245(d)). 2.11 40 CFR Part 60 Subpart OOOO NSPS The compressor driven by this engine C-237 is subject to the New Source Performance Standard requirements of Colorado Regulation No. 6, Part A, Subpart OOOO (40 CFR Part 60, Subpart OOOO) "Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution for which Construction, Modification or Reconstruction Commenced After August 23, 2011, and on or before September 18, 2015" including, but not limited to, the following: The requirements below reflect the current rule language as of the revisions to 40 CFR Part 60 Subpart OOOO published in the Federal Register on 6/3/2016. However, if revisions to this Subpart are published at a later date, the owner or operator is subject to the requirements contained in the revised version of 40 CFR Part 60 Subpart OOOO. Standards for Reciprocating Compressor Affected Facilities Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 39 2.11.1 You must replace the reciprocating compressor rod packing according to either paragraph (a)(1) (Condition 2.11.1.1) or (2) (Condition 2.11.1.2) of this section or you must comply with paragraph (a)(3) (Condition 2.11.1.3) of this section (§60.5385(a)). 2.1 1,1.1 Before the compressor has operated for 26,000 hours. The number of hours of operation must be continuously monitored beginning upon initial startup of your reciprocating compressor affected facility, or October 15, 2012, or the date of the most recent reciprocating compressor rod packing replacement, whichever is later (§60.5385(a)(1)). 2.11.1.2 Prior to 36 months from the date of the most recent rod packing replacement, or 36 months from the date of startup for a new reciprocating compressor for which the rod packing has not yet been replaced (§60.5385(a)(2)). 2.11.1.3 Collect the emissions from the rod packing using a rod packing emissions collection system which operates under negative pressure and route the rod packing emissions to a process through a closed vent system that meets the requirements of §60.5411(a) (Conditions 2.11.6 through 2.11.8) (§60.5385(a)(3)). 2.11.2 You must demonstrate initial compliance with standards that apply to reciprocating compressor affected facilities as required by §60.5410 (Condition 2.11.5) (§60.5385(b)). 2.11.3 You must demonstrate continuous compliance with standards that apply to reciprocating compressor affected facilities as required by §60.5415 (Condition 2.11.9) (§60.5385(c)). 2.11.4 You must perform the required notification, recordkeeping, and reporting as required by §60.5420 (Conditions 2.11.13 through 2.11.14) (§60.5385(d)). Initial Compliance Requirements for Reciprocating Compressor Affected Facilities 2.11.5 You must determine initial compliance with the standards for each affected facility using the requirements in paragraph (c) (Condition 2.11.5.1) of this section. The initial compliance period begins on October 15, 2012, or upon initial startup, whichever is later, and ends no later than one year after the initial startup date for your affected facility or no later than one year after October 15, 2012. The initial compliance period may be less than one full year (§60.5410). 2.11.5.1 To achieve initial compliance with the standards for each reciprocating compressor affected facility you must comply with paragraphs (c)(1) (Condition a) through (4) (Condition d) of this section (§60.5410(c)). a. If complying with §60.5385(a)(1) (Condition 2.11.1.1) or (2) (Condition 2.11.1.2), during the initial compliance period, you must continuously monitor the number of hours of operation or track the number of months since the last rod packing replacement (§60.5410(c)(1)). b. If complying with §60.5385(a)(3) (Condition 2.11.1.3), you must operate the rod packing emissions collection system under negative pressure and route Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 40 emissions to a process through a closed vent system that meets the requirements of §60.5411(a) (Conditions 2.11.6 through 2.11.8) (§60.5410(c)(2)). c. You must submit the initial annual report for your reciprocating compressor as required in §60.5420(b) (Condition 2.11.13). (§60.5410(c)(3)). d. You must maintain the records as specified in §60.5420(c)(3) (Condition 2.11.14.1) for each reciprocating compressor affected facility (§60.5410(c)(4)). Additional Initial Compliance Requirements for Closed Vent Systems 2.11.6 You must design the closed vent system to route all gases, vapors, and fumes emitted from the material in the reciprocating compressor rod packing emissions collection system or the wet seal fluid degassing system to a control device or to a process that meets the requirements specified in §60.5412(a) through (c) of this Subpart (§60.5411(a)(1)). 2.11.7 You must design and operate the closed vent system with no detectable emissions as demonstrated by §60.5416(b) (Condition 2.11.11) (§60.5411(a)(2)). 2.11.8 You must meet the requirements specified in paragraphs (a)(3)(i) (Condition 2.11.8.1) and (ii) (Condition 2.11.8.2) of this section if the closed vent system contains one or more bypass devices that could be used to divert all or a portion of the gases, vapors, or fumes from entering the control device (§60.5411(a)(3)). 2.11.8.1 Except as provided in paragraph (a)(3)(ii) (Condition 2.11.8.2) of this section, you must comply with either paragraph (a)(3)(i)(A) (Condition a) or (B) (Condition b) of this section for each bypass device (§60.5411(a)(3)(i)). a. You must properly install, calibrate, maintain, and operate a flow indicator at the inlet to the bypass device that could divert the stream away from the control device or process to the atmosphere that is capable of taking periodic readings as specified in §60.5416(a)(4) (Condition 2.11.10.4) and either sounds an alarm, or initiates notification via remote alarm to the nearest field office, when the bypass device is open such that the stream is being, or could be, diverted away from the control device or process to the atmosphere. You must maintain records of each time the alarm is activated according to §60.5420(c)(8) (Condition 2.11.14.4) (§60.5411(a)(3)(i)(A)). b. You must secure the bypass device valve installed at the inlet to the bypass device in the non -diverting position using a car -seal or a lock -and -key type configuration (§60.5411(a)(3)(i)(B)). 2.11.8.2 Low leg drains, high point bleeds, analyzer vents, open-ended valves or lines, and safety devices are not subject to the requirements of paragraph (a)(3)(i) (Condition 2.11.8.1) of this section (§60.5411(a)(3)(ii)). Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 41 Continuous Compliance Demonstration Requirements for Reciprocating Compressor Affected Facilities 2.11.9 For each reciprocating compressor affected facility complying with §60.5385(a)(1) (Condition 2.11.1.1) or (2) (Condition 2.11.1.2), you must demonstrate continuous compliance according to paragraphs (c)(1) (Condition 2.11.9.1) through (3) (Condition 2.11.9.3) of this section. For each reciprocating compressor affected facility complying with §60.5385(a)(3) (Condition 2.11.1.3), you must demonstrate continuous compliance according to paragraph (c)(4) (Condition 2.11.9.4) of this section (§60.5415(c)). 2.11.9.1 You must continuously monitor the number of hours of operation for each reciprocating compressor affected facility or track the number of months since initial startup, or October 15, 2012, or the date of the most recent reciprocating compressor rod packing replacement, whichever is later (§60.5415(c)(1)). 2.11.9.2 You must submit the annual report as required in §60.5420(b) (Condition 2.11.13) and maintain records as required in §60.5420(c)(3) (Condition 2.11.14.1) (§60.5415(c)(2)). 2.11.9.3 You must replace the reciprocating compressor rod packing before the total number of hours of operation reaches 26,000 hours or the number of months since the most recent rod packing replacement reaches 36 months (§60.5415(c)(3)). 2.11.9.4 You must operate the rod packing emissions collection system under negative pressure and continuously comply with the closed vent requirements in §60.5416(a) (Condition 2.11.10) and (b) (Condition 2.11.11) (§60.5415(c)(4)). Initial and Continuous Cover and Closed Vent System Inspection and Monitoring Requirements 2.11.10 Except as provided in paragraphs §60.5416(b)(11) and (12) of this Subpart, you must inspect each closed vent system according to the procedures and schedule specified in paragraphs (a)(1) (Condition 2.11.10.1) and (2) (Condition 2.11.10.2) of this section, and inspect each bypass device according to the procedures of paragraph (a)(4) (Condition 2.11.10.4) of this section (§60.5416(a)). 2.11.10.1 For each closed vent system joint, seam, or other connection that is permanently or semi -permanently sealed (e.g., a welded joint between two sections of hard piping or a bolted and gasketed ducting flange), you must meet the requirements specified in paragraphs (a)(1)(i) (Condition a) and (ii) (Condition b) of this section (§60.5416(a)(1)). a. Conduct an initial inspection according to the test methods and procedures specified in paragraph (b) (Condition 2.11.11) of this section to demonstrate that the closed vent system operates with no detectable emissions. You must maintain records of the inspection results as specified in §60.5420(c)(6) (Condition 2.11.14.2) (§60.5416(a)(1)(i)). Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 42 b. Conduct annual visual inspections for defects that could result in air emissions. Defects include, but are not limited to, visible cracks, holes, or gaps in piping; loose connections; liquid leaks; or broken or missing caps or other closure devices. You must monitor a component or connection using the test methods and procedures in paragraph (b) (Condition 2.11.11) of this section to demonstrate that it operates with no detectable emissions following any time the component is repaired or replaced or the connection is unsealed. You must maintain records of the inspection results as specified in §60.5420(c)(6) (Condition 2.11.14.2) ((§60.5416(a)(1)(ii)). 2.11.10.2 For closed vent system components other than those specified in paragraph (a)(1) (Condition 2.11.10.1) of this section, you must meet the requirements of paragraphs (a)(2)(i) (Condition a) through (iii) (Condition c) of this section (§60.5416(a)(2)). a. Conduct an initial inspection according to the test methods and procedures specified in paragraph (b) (Condition 2.11.11) of this section to demonstrate that the closed vent system operates with no detectable emissions. You must maintain records of the inspection results as specified in §60.5420(c)(6) (Condition 2.11.14.2) (§60.5416(a)(2)(i)). b. Conduct annual inspections according to the test methods and procedures specified in paragraph (b) (Condition 2.11.11) of this section to demonstrate that the components or connections operate with no detectable emissions. You must maintain records of the inspection results as specified in §60.5420(c)(6) (Condition 2.11.14.2) (§60.5416(a)(2)(ii)). c. Conduct annual visual inspections for defects that could result in air emissions. Defects include, but are not limited to, visible cracks, holes, or gaps in ductwork; loose connections; liquid leaks; or broken or missing caps or other closure devices. You must maintain records of the inspection results as specified in §60.5420(c)(6) (Condition 2.11.14.2) (§60.5416(a)(2)(iii)). 2.11.10.3 For each cover, you must meet the requirements in paragraphs (a)(3)(i) (Condition a) and (ii) (Condition b) of this section (§60.5416(a)(3)). a. Conduct visual inspections for defects that could result in air emissions. Defects include, but are not limited to, visible cracks, holes, or gaps in the cover, or between the cover and the separator wall; broken, cracked, or otherwise damaged seals or gaskets on closure devices; and broken or missing hatches, access covers, caps, or other closure devices. In the case where the storage vessel is buried partially or entirely underground, you must inspect only those portions of the cover that extend to or above the ground surface, and those connections that are on such portions of the cover (e.g., fill ports, access hatches, gauge wells, etc.) and can be opened to the atmosphere (§ 60.5416(a)(3)(i)). Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 43 b. You must initially conduct the inspections specified in paragraph (a)(3)(i) (Condition a above) of this section following the installation of the cover. Thereafter, you must perform the inspection at least once every calendar year, except as provided in paragraphs (b)(11) and (12) of this section. You must maintain records of the inspection results as specified in §60.5420(c)(7) (Condition 2.11.14.3) (§60.5416(a)(3)(ii)). 2.11.10.4 For each bypass device, except as provided for in §60.5411 (Condition 2.11.8.2), you must meet the requirements of paragraphs (a)(4)(i) (Condition a) or (ii) (Condition b) of this section (§60.5416(a)(4)). a. Set the flow indicator to take a reading at least once every 15 minutes at the inlet to the bypass device that could divert the steam away from the control device to the atmosphere (§60.5416(a)(4)(i)). b. If the bypass device valve installed at the inlet to the bypass device is secured in the non -diverting position using a car -seal or a lock -and -key type configuration, visually inspect the seal or closure mechanism at least once every month to verify that the valve is maintained in the non -diverting position and the vent stream is not diverted through the bypass device. You must maintain records of the inspections according to §60.5420(c)(8) (Condition 2.11.14.4) (§60.5416(a)(4)(ii)). 2.11.11 No detectable emissions test methods and procedures. If you are required to conduct an inspection of a closed vent system or cover at your centrifugal compressor or reciprocating compressor affected facility as specified in paragraphs (a)(1) (Condition 2.11.10.1), (2) (Condition 2.11.10.2), or (3) (Condition 2.11.10.3) of this section, you must meet the requirements of paragraphs (b)(1) through (13) of this Subpart (§60.5416(b)). Notification, Recordkeeping and Reporting Requirements 2.11.12 If you own or operate a reciprocating compressor facility you are not required to submit the notifications required in §60.7(a)(1), (3), and (4) (§60.5420(a)(1)). 2.1 1.13 Reporting requirements. You must submit annual reports containing the information specified in paragraphs §60.5420(b)(1) and (b)(4) of this Subpart to the Administrator and performance test reports as specified in paragraph §60.5420(b)(7) or (8) of this Subpart. The initial annual report is due no later than 90 days after the end of the initial compliance period as determined according to §60.5410 (Condition 2.11.5). Subsequent annual reports are due no later than same date each year as the initial annual report. If you own or operate more than one affected facility, you may submit one report for multiple affected facilities provided the report contains all of the information required as specified in paragraphs §60.5420(b)(1) and (b)(4) of this section. Annual reports may coincide with title V reports as long as all the required elements of the annual report are included. You may arrange with the Administrator a common schedule on which reports required by this part may be submitted as long as the schedule does not extend the reporting period (§60.5420(b)). Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 44 2.11.14 Recordkeeping requirements. You must maintain the records identified as specified in §60.7(f) (Condition 2.12.1) and in paragraphs (c)(3) (Condition 2.11.14.1), (c)(6) (Condition 2.11.14.2), (c)(8) (Condition 2.11.14.4) and (c)(9) Condition 2.11.14.5) and (c)(14) (Condition 2.11.14.6) of this section. All records required by this subpart must be maintained either onsite or at the nearest local field office for at least 5 years (§60.5420(c)). 2.11.14.1 For each reciprocating compressors affected facility, you must maintain the records in paragraphs (c)(3)(i) through (iii) of this section (§60.5420(c)(3)). a. Records of the cumulative number of hours of operation or number of months since initial startup or October 15, 2012, or the previous replacement of the reciprocating compressor rod packing, whichever is later (§60.5420(c)(3)(i)). b. Records of the date and time of each reciprocating compressor rod packing replacement, or date of installation of a rod packing emissions collection system and closed vent system as specified in §60.5385(a)(3) (Condition 2.11.1.3) (§60.5420(c)(3)(ii)). c. Records of deviations in cases where the reciprocating compressor was not operated in compliance with the requirements specified in §60.5385 (Conditions 2.11.1 through 2.11.3) (§60.5420(c)(3)(iii)). 2.11.14.2 Records of the cumulative number of hours of operation or number of months since initial startup or October 15, 2012, or the previous replacement of the reciprocating compressor rod packing, whichever is later (§60.5420(c)(6)). 2.11.14.3 A record of each cover inspection required under §60.5416(a)(3) (Condition 2.11.10.3) for centrifugal or reciprocating compressors (§60.5420(c)(7)). 2.11.14.4 If you are subject to the bypass requirements of §60.5416(a)(4) (Condition 2.11.10.4) for reciprocating compressors or, a record of each inspection or a record each time the key is checked out or a record of each time the alarm is sounded (§60.5420(c)(8)). 2.11.14.5 If you are subject to the closed vent system no detectable emissions requirements of §60.5416(b) (Condition 2.11.11) for reciprocating compressors, a record of the monitoring conducted in accordance with §60.5416(b) (Condition 2.11.11) (§60.5420(c)(9)). 2.11.14.6 A log of records as specified in §60.5413(e)(4) of this Subpart for all inspection, repair and maintenance activities for each control device failing the visible emissions test (§60.5420(c)(14)). 2.12 40 CFR Part 60 Subpart A NSPS This engine is subject to the requirements in 40 CFR Part 60 Subpart A "General Provisions", as specified in 40 CFR Part 60 Subpart JJJJ §60.4246 and 40 CFR Part 60 Subpart OOOO §60.5425. These requirements include, but are not limited to the following: 2.12.1 Notification and recordkeeping (§60.7) Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 45 2,12.2 Performance tests (§60.8) 2.12,3 Compliance with standards and maintenance requirements (§60.11) 2.12.4 Circumvention (§60.12) 2.12.5 General notification and reporting requirements (§60.19) 2.13 40 CFR Part 63 Subpart ZZZZ MACT This engine is subject to the National Emissions Standards for Hazardous Air Pollutants requirements of Regulation No. 8, Part E, Subpart ZZZZ (40 CFR Part 63, Subpart ZZZZ) "National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines", including, but not limited to, the following: The requirements below reflect the current rule language as of the revisions to 40 CFR Part 63 Subpart ZZZZ published in the Federal Register on 2/27/2014. However, if revisions to this Subpart are published at a later date, the owner or operator is subject to the requirements contained in the revised version of 40 CFR Part 63 Subpart ZZZZ. Note that as of the date of revised permit issuance March 1, 2021, the requirements in 40 CFR Part 63 Subpart ZZZZ promulgated on March 3, 2010 and later have not been adopted into Colorado Regulation No. 8, Part E by the Division and are therefore not state -enforceable. In the event that the Division adopts these requirements, they will become both state and federally enforceable. General Requirements: 2.13.1 You must be in compliance with the emission limitations in Condition 2.13.3, operating limitations in Condition 2.13.4, and other requirements in this subpart that apply to you at all times. (§63.6605(a)). 2.13.2 At all times you must operate and maintain any affected source, including associated air pollution control equipment and monitoring equipment, in a manner consistent with safety and good air pollution control practices for minimizing emissions. The general duty to minimize emissions does not require you to make any further efforts to reduce emissions if levels required by this standard have been achieved. Determination of whether such operation and maintenance procedures are being used will be based on information available to the Administrator which may include, but is not limited to, monitoring results, review of operation and maintenance procedures, review of operation and maintenance records, and inspection of the source. (§63.6605(b)). Emission Limitations: 2.13.3 Owners or operators of a new or reconstructed 4SLB stationary RICE with a site rating of more than 500 brake HP located at major source of HAP emissions shall: Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 46 2.13.3.1 Reduce CO emissions by 93 percent or more (§63.6600(b), Table 2a, Item 2.a.), or 2.13.3.2 Limit concentration of formaldehyde in the stationary RICE exhaust to 14 ppmvd or less at 15 percent O2 (§63.6600(b), Table 2a, Item 2.b.). Operating Limitations: 2.13.4 Owners or operators of a new or reconstructed 4SLB stationary RICE with a site rating of more than 500 brake HP located at major source of HAP emissions shall: 2.13.4.1 Maintain your catalyst so that the pressure drop across the catalyst does not change by more than 2 inches of water at 100 percent load plus or minus 10 percent from the pressure drop across the catalyst that was measured during the initial performance test (§63.6600(b), Table 2b, Item1.a.); and 2.13.4,2 Maintain the temperature of your stationary RICE exhaust so that the catalyst inlet temperature is greater than or equal to 450°F and less than or equal to 1350°F (§63.6600(b), Table 2b, Item1.b.). Subsequent Performance Test Requirements: 2.13.5 Subsequent performance tests shall be conducted semi-annually (§63.6615, Table 3, Item 1). 2.13.6 After compliance has been demonstrated for two consecutive tests, the frequency of semi-annual tests may be reduced to annually. If the results of any subsequent annual performance test indicates the stationary RICE is not in compliance with the CO emission limitations, or you deviate from any of your operating limitations, you must resume semi-annual performance tests (§63.6615, Table 3, Footnote 1). Performance Tests and Other Procedures 2.13.7 Each performance test must be conducted according to the requirements that this subpart specifies in Table 4 to this subpart. The test must be conducted at any load condition within plus or minus 10 percent of 100 percent load (§63.6620(b)). Monitoring, Installation, Collection, Operation and Maintenance Requirements: 2.13.8 You must install, maintain and operate a continuous parametric monitoring system (CPMS) to continuously monitor catalyst inlet temperature according to the requirements of §63.6625(b)(1) through (6) of this subpart (§63.6625(b), Table 5, Item 1). 2,13,9 If you operate a new, reconstructed, or existing stationary engine, you must minimize the engine's time spent at idle during startup and minimize the engine's startup time to a period needed for appropriate and safe loading of the engine, not to exceed 30 minutes, after which time the emission standards applicable to all times other than startup in Condition 2.13.3 to this subpart apply (§63.6625(h)). Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 47 Monitoring and Collecting Data for Continuous Compliance: 2.13.10 Data must be monitored and collected in accordance with the following (§63.6635(a)): 2.13.10.1 Except for monitor malfunctions, associated repairs, required performance evaluations, and required quality assurance or control activities, you must monitor continuously at all times that the stationary RICE is operating. A monitoring malfunction is any sudden, infrequent, not reasonably preventable failure of the monitoring to provide valid data. Monitoring failures that are caused in part by poor maintenance or careless operation are not malfunctions. (§63.6635(b)). 2.13.10.2 You may not use data recorded during monitoring malfunctions, associated repairs, and required quality assurance or control activities in data averages and calculations used to report emission or operating levels. You must however, use all the valid data collected during all other periods (§63.6635(c)). Demonstrating Continuous Compliance with the Emission and Operating Limitations: 2.13.11 You must demonstrate continuous compliance with each emission and operating limitation in Conditions 2.13.3 and 2.13.4 as follows: 2.13.11.1 Conducting subsequent performance tests as specified in Condition 2.13.5 and demonstrating the required CO reduction in Condition 2.13.3.1 (§63.6640(a), Table 6, Item 1.i.). 2.13.11.2 Conducting semiannual performance tests for formaldehyde as specified in Condition 2.13.5 to demonstrate that your emissions remain at or below the formaldehyde concentration limit in Condition 2.13.3.2 (§63.6640(a), Table 6, Item 7.i.) 2.13.11.3 Collecting the catalyst inlet temperature data according to §63.6625(b) (Condition 2.13.8); (§63.6640(a), Table 6, Item 1.a.ii. or 7.a.ii.) and 2.13.11.4 Reducing these data to 4 -hour rolling averages; ((§63.6640(a), Table 6, Item 1.a.iii. or 7.a.iii.) and 2.13.11.5 Maintaining the 4 -hour rolling averages within the operating limitations for the catalyst inlet temperature (Condition 2.13.4.2); (§63.6640(a), Table 6, Item 1.a.iv. or 7.a.iv.) and 2.13.1 1.6 Measuring the pressure drop across the catalyst once per month and demonstrating that the pressure drop across the catalyst is within the operating limitation established during the performance test (§63.6640(a), Table 6, Item 1.v. and Item 7.v.). 2.13.11.7 After you have demonstrated compliance for two consecutive tests, you may reduce the frequency of subsequent performance tests to annually. If the results of any subsequent annual performance test indicate the stationary RICE is not in compliance with the CO or formaldehyde emission limitation, or you deviate from any of your operating limitations, you must resume semiannual performance tests (§63.6640(a), Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 48 Table 6, Footnote a). 2.13.12 You must report each instance in which you did not meet each emission limitation or operating limitation in Conditions 2.13.3 and 2.13.4. These instances are deviations from the emission and operating limitations in Conditions 2.13.3 and 2.13.4. These deviations must be reported according to the requirements in Conditions 2.13.18 through 2.13.22. If you change your catalyst, you must reestablish the values of the operating parameters measured during the initial performance test. When you reestablish the values of your operating parameters, you must also conduct a performance test to demonstrate that you are meeting the required emission limitation applicable to your stationary RICE (§63.6640(b)). 2.13.13 For new, reconstructed, and rebuilt stationary RICE, deviations from the emission (Condition 2.13.3) or operating limitations (Condition 2.13.4) that occur during the first 200 hours of operation from engine startup (engine burn -in period) are not violations. Rebuilt stationary RICE means a stationary RICE that has been rebuilt as that term is defined in 40 CFR § 94.11(a) (§63.6640(d)). 2.13.14 You must also report each instance in which you did not meet the requirements in Condition 2.14 of this permit (§63.6640(e)). What Notifications to Submit and When: 2.13.15 You must submit all of the notifications in §63.7(b) and (c), 63.8(e), (0(4) and (0(6), 63.9(b) through (e), and (g) and (h) that apply to you by the dates specified. (§63.6645(a)). 2.13.16 If you are required to conduct a performance test, you must submit a Notification of Intent to conduct a performance test at least 60 days before the performance test is scheduled to begin as required in § 63.7(b)(1) (Condition 2.14.3) (§63.6645(g)). 2.13.17 If you are required to conduct a performance test as specified in Condition 2.13.5, you must submit the Notification of Compliance Status according to §63.6645(h)(1) and (h)(2) of this subpart (§63.6645(h)). What Reports to Submit and When: 2.13.18 You must submit each report in Table 7 of this subpart that applies to you (§63.6650(a)). 2.13.19 Unless the Division has approved a different schedule for submission of reports under §63.10(a) (Condition 2.14.6), you must submit Compliance Reports in accordance with the requirements of §63.6650(b)(1) through (b)(9) of this subpart (§63.6650(b)). 2.13.20 The Compliance Reports must include the information in §63.6650(c)(1) through (c)(6) of this subpart (§63.6650(c)). Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 49 2.13.21 For each deviation from any emission or operating limitation that occurs for a stationary RICE where you are using a CPMS to comply with the emission and operating limitations in this subpart you must include information in §63.6650(c)(1) through (4) and (e)(1) through (12) of this subpart (§63.6650(e)). 2.13.22 Each affected source that has obtained a title V operating permit pursuant to 40 CFR part 70 or 71 must report all deviations as defined in this subpart in the semiannual monitoring report required by 40 CFR 70.6 (a)(3)(iii)(A) or 40 CFR 71.6(a)(3)(iii)(A). If an affected source submits a Compliance report pursuant to Condition 2.13.18 along with, or as part of, the semiannual monitoring report required by 40 CFR 70.6(a)(3)(iii)(A) or 40 CFR 71.6(a)(3)(iii)(A), and the Compliance report includes all required information concerning deviations from any emission or operating limitation in this subpart, submission of the Compliance report shall be deemed to satisfy any obligation to report the same deviations in the semiannual monitoring report. However, submission of a Compliance report shall not otherwise affect any obligation the affected source may have to report deviations from permit requirements to the permit authority §63.6650(f)). What Records to Keep: 2.1 3.23 A copy of each notification and report that you submitted to comply with this subpart, including all documentation supporting any Initial Notification or Notification of Compliance Status that you submitted, according to the requirement in §63.10(b)(2)(xiv) (Condition 2.14.6) (§63.6655(a)(1)). 2.13.24 Records of the occurrence and duration of each malfunction of operation (i.e., process equipment) or the air pollution control and monitoring equipment. (§63.6655(a)(2)). 2.13.25 Records of performance tests and performance evaluations as required in §63.10(b)(2)(viii) (Condition 2.14.6) (§63.6655(a)(3)). 2.13.26 Records of all required maintenance performed on the air pollution control and monitoring equipment. (§63.6655(a)(4)). 2.13.27 Records of actions taken during periods of malfunction to minimize emissions in accordance with Condition 2.13.2, including corrective actions to restore malfunctioning process and air pollution control and monitoring equipment to its normal or usual manner of operation (§63.6655(a)(5)). 2.13.28 For each CPMS you must keep the following records (§63.6655(b)): 2.13.28.1 Records described in §63.10(b)(2)(vi) through (xi) (Condition 2.14.6) (§63.6655(b)(1)). 2.13.28.2 Previous (i.e., superseded) versions of the performance evaluation plan as required in §63.8(d)(3) (Condition 2.14.4) (§63.6655(b)(2)). Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 50 2.13,28,3 Requests for alternatives to the relative accuracy test for CPMS as required in §63.8(f)(6)(i) (Condition 2.14.4), if applicable (§63.6655(b)(3)). 2.13,29 You must keep the records required in Condition 2.13.11 to show continuous compliance with each emission or operating limitation that applies to you (§63.6655(d)). Form and Length of Recordkeeping: 2.13.30 Your records must be in a form suitable and readily available for expeditious review according to §63.10(b)(1) (Condition 2.14.6) (§63.6660(a)). 2.13.31 As specified in §63.10(b)(1) (Condition 2.14.6), you must keep each record for 5 years following the date of each occurrence, measurement, maintenance, corrective action, report, or record (§63.6660(b)). 2.13.32 You must keep each record readily accessible in hard copy or electronic form for at least 5 years after the date of each occurrence, measurement, maintenance, corrective action, report, or record, according to §63.10(b)(1) (Condition 2.14.6 (§63.6660(c)). 2.14 40 CFR Part 63 Subpart A MACT This engine is subject to the requirements in 40 CFR part 63 Subpart A "General Provisions", as adopted by reference in Colorado Regulation No. 8, Part E, Section I as specified in 40 CFR Part 63 Subpart ZZZZ §63.6665. These requirements include, but are not limited to the following: 2.14.1 Prohibited activities and circumvention (§63.4) 2.14.2 Operation and maintenance requirements (§63.6(e)(1)) 2.14.3 Performance testing requirements (§63.7) 2.14.4 Monitoring requirements (§63.8) 2.14.5 Notification requirements (§63.9) 2.14.6 Recordkeeping and reporting requirements (§63.10) Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 3. D-2 — Forum Triethylene Glycol Dehydration Unit, AIRS ID: 068 DCP Operating Company, LP Enterprise Compressor Station Page 51 This TEG Dehydration Unit D-2 will be removed upon commencement of operation of TEG Dehydration Unit D-3 (Condition 4) Parameter Permit Condition Number Compliance Limits Compliance Emission Factor Monitoring Method Interval Emission & Throughput Limits VOC 3.1 D-2: 25.0 tons/year Pilot: 0.001 tons/year Assist: 1.9 tons/year D-2: GLYCaIc 4.0 or higher Pilot: 5.5 lb/MMscf Assist: Calculation Process Simulation and Twelve Month Rolling Total Calculation Monthly NOx 3.2 D-2: 0.4 tons/year Pilot: 0.02 tons/year Assist: 1.0 tons/year D-2 & Assist: 0.068 lb/MMBtu Pilot: 100 lb/MMscf CO D-2: 2.0 tons/year Pilot: 0.02 tons/year Assist: 4.4 tons/year D-2 & Assist: 0.31 lb/MMBtu Pilot: 84 lb/MMscf Dry Gas Throughput 3.3 Total: 40,150 MMscf/year VRU Downtime: Not to exceed 5% of total actual dry gas processed COMB -1 Downtime: Not to exceed 1% of total actual dry gas processed Meter and Twelve Month Rolling Total Calculation Monthly Combustion Gas Limitations Pilot Gas: 0.44 MMscf/year Assist Gas: 28.03 MMscf/year Lean Glycol Circulation Rate 3.4 20 gpm Meter and Recordkeeping Daily Other Requirements Extended Gas Analysis 3 5 ASTM Methods or Equivalent Annually y Parametric Monitoring 3.6 Recordkeeping Weekly Hours of Operation 3.7 Recordkeeping Daily Opacity 3.8 Not to exceed 30% for a period or periods aggregating more than six (6) minutes in any sixty (60) consecutive minutes See Condition 3.8 Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 52 Control Device Requirements 3.9 See Condition 3.9 Alternative Operating Scenario (AOS) 3.10 See Condition 3.10 Compliance Assurance Monitoring (CAM) 3.11 See Condition 3.11 Statewide Controls for Oil and Gas Operations 3.12 See Condition 3.12 40 CFR 63 Subpart HH MACT 3.13 See Condition 3.13 40 CFR 63 Subpart A General Provisions 3.14 See Condition 3.14 MACT 3.1 VOC Emission Limitations & Compliance Monitoring Emissions of Volatile Organic Compounds (VOC) for this dehydration unit shall not exceed the limitation listed in Summary Table 3 above (Colorado Construction Permit 00WE0470, as modified under the provisions of Section I, Condition 1.3, and Colorado Regulation No. 3, Part C, Section I.A.7 and Part C, Section III.B.7 based on requested emissions identified on the APEN submitted on 11/20/2018). Compliance with the emission limitations shall be monitored as follows: 3.1.1 Dehydration Unit VOC Emissions: Monthly determination of VOC emissions from the dehydration unit flash gas and still vent shall be conducted by the end of the subsequent month utilizing the Gas Research Institute's GLYCalc (Version 4.0 or higher). 3.1.1.1 The following parameters shall be input to the process model: a. The inlet wet gas composition obtained from the most recent extended gas analysis, as required by Condition 3.5.1. b. The average daily dry gas processed, as required by Condition 3.3.1.1. c. The average monthly value of the lean glycol circulation rate, as required by Condition 3.4, the inlet wet gas temperature and pressure and the flash tank operating temperature and pressure, as required by Condition 3.6. 3.1.1.2 Control Efficiencies a. A control efficiency (CE) of 95% shall apply to the enclosed combustion device (COMB -1) when it is operational and emissions from the dehydration unit are routed to it, provided the requirements of Conditions 3.9.2, 3.12.1.1 and 3.12.2.1 are met. 3.1.1.3 Operating Hours Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 53 a. Hours of vapor recovery unit (VRU) downtime, as required by Condition 3.7.3, shall be input to the equation below, along with the corresponding control efficiency (CE) of 95% for COMB -1, to determine actual emissions of VOC during periods of VRU downtime, in which the flash tank emissions are routed to COMB -1. b. Total hours of operation for this dehydration unit, as required by Condition 3.7.1, and hours of COMB -1 downtime, as required by Condition 3.7.4 shall be input to the equation below, along with the corresponding control efficiency (CE) of 95% for COMB -1, to determine actual emissions of VOC during periods of COMB -1 operation, in which still vent emissions are routed to COMB -1. c. Hours of COMB -1 downtime, as required by Condition 3.7.4, shall be input to the equation below, to determine actual still vent emissions of VOC during periods of COMB -1 downtime, in which still vent emissions are routed to atmosphere. 3.1.1.4 Monthly emissions of VOC from the dehydration unit flash gas and still vent shall be calculated using the following equations: FGVOC/HAP ( 16 hrsh x (1 CE(%)1 tons l (hr� x DTVR� mont100 J (month/ Unit Converstion (2000 lb\ ton 1 Flash Gas Emissions lb hrs tons l SVVOC/HAP (hr)x DTCOMB-i (m \ Still Vent Emissions (month/ 2000 Ib + Unit Converstion ( ton SVVOC/HAP ((lb hrs hrs CE(%)\ lhr) x [OHTEG (month hrs (month)] x k' 100 J Unit Converstion (2000 161 ton 1 Where: FGvoc/HAP = Uncontrolled Flash Gas Emissions of VOC or HAP, lb/hr SVvoc/HAP = Uncontrolled Still Vent Emissions of VOC or HAP, lb/hr OHTEG = Total Dehydration Unit Operating Hours, hrs/month DTvRu = VRU Downtime, hrs/month DTcoMe-i = COMB — 1 Downtime, hrs/month CE = Control Efficiency of COMB - 1,95% Total monthly VOC emissions shall be the sum total of emissions contributed by the dehydration unit flash gas and still vent. The total monthly VOC emissions obtained from this calculation Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 54 shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 3.1.2 Pilot Gas VOC Emissions: Monthly determination of VOC emissions from the combustion of pilot gas shall be conducted by the end of the subsequent month using the emission factor listed in Summary Table 3 above (from EPA's AP -42: Compilation of Emission Factors, Section 1.4 for Natural Gas Combustion, Final Section, dated 7/98) and the monthly pilot gas flowrate, as required by Condition 3.3.2.1, in the equation below: ( lb ) MMscf) tons ) EF MMscf x FRpiiot (month Pilot Gas Emissions (month) 2000 lb ) Unit Conversion ( ton Where: EF = Emission Factor, lb/MMscf FR pilot = Pilot Gas Flowrate, scf/month The monthly VOC emissions obtained from this calculation shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 3.1.3 Assist Gas VOC Emissions: Monthly determination of VOC emissions from the combustion of assist gas shall be conducted by the end of the subsequent month using the monthly assist gas flowrate, as required by Condition 3.3.2.2, the molecular weight and VOC content of the assist gas obtained from the most recent extended gas analysis, as required by Condition 3.5.2, and a control efficiency of 95% for COMB -1, provided the requirements of Conditions 3.9.2, 3.12.1.1 and 3.12.2.1 are met, in the equation below: sc l6 CE(% tons l FRAssisc (month) x MWAssisc (16mol� x XAssisc x (1 100 ) Assist Gas Emissions (month/ 2000 lb '379.5 scf Unit Conversion ( ton ) x Unit Conversion (37" ) Where: FRAssist = Assist Gas Flowrate, scf /month MWAssist = Assist Gas Molecular Weight, lb/lbmol xAssist = Assist Gas VOC or HAP content, mass fraction CE = Control Efficiency of COMB - 1,95% Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 55 The monthly VOC emissions obtained from this calculation shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 3.1.4 Emissions of Hazardous Air Pollutants (HAP) from the condensate storage tanks, produced water storage tanks and dehydration unit combined shall not exceed the facility -wide limitations listed in Summary Table 9 below. Monthly emissions of HAP shall be calculated by the end of the subsequent month using the same method as required for VOC emissions. Monthly HAP emissions shall be used in a twelve month total to monitor compliance with the facility -wide HAP emission limitation, as required by Condition 9.1. 3.2 NOx & CO Emission Limitations & Compliance Monitoring Emissions of Nitrogen Oxides (NOx) and Carbon Monoxide (CO) generated by the destruction of emissions from this dehydration unit shall not exceed the limitation listed in Summary Table 3 above (Colorado Construction Permit 00WE0470, as modified under the provisions of Section I, Condition 1.3, and Colorado Regulation No. 3, Part C, Section I.A.7 and Part C, Section III.B.7 based on requested emissions identified on the APEN submitted on 11/20/2018). Compliance with the emission limitations shall be monitored as follows: 3.2.1 Dehydration Unit NOx & CO Emissions: The NOx and CO emissions generated by dehydration unit flash gas and still vent combustion shall be calculated by the end of the subsequent month using the emission factors listed in Summary Table 3 above (from EPA's AP - 42: Compilation of Emission Factors, Section 13.5 for Industrial Flares, Final Section, dated 2/18), the hourly flash gas flowrate, the hourly still vent flowrate, the flash gas heat content and still vent heat content obtained from the most recent monthly process model run, as required by Condition 3.1.1, the total monthly hours of dehydration unit operation, as required by Condition 3.7.1, the total monthly hours of VRU downtime, as required by Condition 3.7.3, and the total monthly hours of COMB -1 downtime, as required by Condition 3.7.4, as inputs to the equation below. NOx or CO Emissions ( tons l month/ FG MMscf x HC MMBtu x EF (( lb hrs l ( ) Fc (MMsc ) (MMBtu) x DT VRU `month) Unit Conversion (2000 lb) ton 1 (MMscf ) x HCs�, (MMB f) x EF ( lb ) )(Pi TEG ( hrs+SV 1 DTcoMB—i ( hrs `l hJ `MMsc J MMBtu mtJ mJJ Unit Conversion (2000 lb) ton Where: FG = Uncontrolled Flash Gas Flowrate, MMscf/hr SV = Uncontrolled Still Vent Flowrate, MMscf/hr Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 HCFG = Heat Content of Flash Gas Emissions, MMBtu/MMscf HCsV = Heat Content of Still Vent Emissions, MMBtu/MMscf EF = Emission Factor, lb/MMBtu OHTEG = Total Dehydration Unit Operating Hours, hrs/month DTVRu = VRU Downtime, hrs/month DTcoMs-i = COMB — 1 Downtime, hrs/month DCP Operating Company, LP Enterprise Compressor Station Page 56 The monthly NOx and CO emissions obtained from this calculation shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 3.2.2 Pilot Gas NOx & CO Emissions: The NOx and CO emissions generated by pilot gas combustion shall be calculated by the end of the subsequent month using the emission factor listed in Summary Table 3 above (from EPA's AP -42: Compilation of Emission Factors, Section 1.4 for Natural Gas Combustion, Final Section, dated 7/98) and the monthly pilot gas flowrate, as required by Condition 3.3.2.1, in the equation below: lb l MMscf tons l EFMMscfx FRp,1 _ 't kmonth) NOx or CO Emissions (month) ) (2000 1b) Unit Conversion l ton Where: EF = Emission Factor, lb/MMscf FRFuat = Pilot Gas Flowrate, MMscf/month The monthly NOx and CO emissions obtained from this calculation shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 3.2.3 Assist Gas NOx & CO Emissions: The NOx and CO emissions generated by assist gas combustion shall be calculated by the end of the subsequent month using the emission factor listed in Summary Table 3 above (from EPA's AP -42: Compilation of Emission Factors, Section 13.5 for Industrial Flares, Final Section, Table 13.5-2, dated 2/18), the monthly assist gas flowrate, as required by Condition 3.3.2.2, and the heat content of the assist gas obtained from the most recent extended gas analysis, as required by Condition 3.5.2 in the equation below: (( lb scf Btu tons EF IMMBtu) x FRAssfst (month) x HCAssist (scf ) Assist Gas Emissions (month) 6 Unit Conversion (20 o0 lb) x Unit Conversionn (MMBtu) Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 Where: EF = Emission Factor, lb/MMBtu FRAsstst = Assist Gas Flowrate, scf/month HCAsstst = Assist Gas Heat Content, Btu/scf DCP Operating Company, LP Enterprise Compressor Station Page 57 The monthly NOx and CO emissions obtained from this calculation shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 3.3 Gas Throughput Limitations & Compliance Monitoring 3.3.1 Dehydration Unit Dry Gas Processing Limitations 3.3.1,1 Total Dry Gas Processed: The total amount of dry gas processed by this dehydration unit shall not exceed the limitations listed in Summary Table 3 above (Colorado Construction Permit 00WE0470, as modified under the provisions of Section I, Condition 1.3, and Colorado Regulation No. 3, Part C, Section I.A.7 and Part C, Section III.B.7 based on requested limitations identified on the APEN submitted on 11/20/2018). The dry gas processed by this dehydration unit shall be monitored and recorded monthly using the flowmeter located at the unit outlet. The monthly dry gas throughput shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. An average daily dry gas processed rate shall be used as an input to the monthly process model run, as required by Condition 3.1.1. This average daily gas processed rate shall be calculated by dividing the total monthly dry gas processed by the total unit hours of operation, as required by Condition 3.7.1, as follows: Total Monthly Dry Gas Processed (MMscf) Unit Conversion 24 hrs MMscf = (month) ( day )) Average Daily Dry Gas Processed day hrs Total Hours of Operation (-month) 3.3.1.2 Dry Gas Processed during VRU Downtime: The total amount of dry gas processed by this dehydration unit during periods of VRU downtime shall not exceed 5% of the total dry gas processed by this dehydration unit on a rolling twelve month basis (as provided for under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3, Part C, Section I.A.7 and Part C, Section III.B.7). VRU downtime is defined as periods when the dehydration unit is operating and flash tank emissions are routed to enclosed combustion device COMB -1. The dry gas processed by this dehydration unit during periods of VRU downtime shall be determined monthly as the total amount of Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 58 dry gas processed by this dehydration unit, as indicated by the outlet flowmeter (Condition 3.3.1.1), during periods for which flash tank emissions were routed to COMB -1, as indicated by the hours of VRU downtime (Condition 3.7.3). The monthly dry gas processed during VRU downtime shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 3.3.1.3 Dry Gas Processed during COMB -1 Downtime: The total amount of dry gas processed by this dehydration unit during periods of COMB -1 downtime shall not exceed 1% of the total dry gas processed by this dehydration unit on a rolling twelve month basis (as provided for under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3, Part C, Section I.A.7 and Part C, Section III.B.7). COMB - 1 downtime is defined as periods when the dehydration unit is operating and still vent emissions are routed to atmosphere. The dry gas processed by this dehydration unit during periods of COMB -1 downtime shall be determined monthly as the total amount of dry gas processed by this dehydration unit, as indicated by the outlet flowmeter (Condition 3.3.1.1), during periods for which still vent emissions were routed to atmosphere, as indicated by the hours of COMB -1 downtime (Condition 3.7.4). The monthly dry gas processed during COMB -1 downtime shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 3.3.2 Combustion Device Gas Throughput Limitations 3.3.2.1 Pilot Gas Throughput: The amount of pilot gas throughput to enclosed combustion device COMB -1 shall not exceed the limitations listed in Summary Table 3 above (as provided for under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3, Part C, Section I.A.7 and Part C, Section III.B.7). The pilot gas throughput to enclosed combustion device COMB -1 shall be assumed to have a constant value of 50 scfh. Monthly pilot gas throughput shall be determined by multiplying this hourly pilot gas throughput by enclosed combustion device COMB -1 monthly hours of operation, as required by Condition 3.7.2. Records of the monthly pilot gas throughput calculation and the manufacturer specification for the hourly pilot gas throughput shall be maintained and made available to the Division upon request. The monthly pilot gas throughput shall be used to monitor compliance the VOC, NOx and CO emission limitations, as required by Conditions 3.1.2 and 3.2.2. 3.3.2.2 Assist Gas Throughput: The amount of assist gas throughput to enclosed combustion device COMB -1 shall not exceed the limitations listed in Summary Table 3 above (as provided for under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3, Part C, Section I.A.7 and Part C, Section III.B.7). A flowmeter shall be located on the assist gas line routed to enclosed combustion device COMB -1 upon installation of such an assist gas line. The assist gas throughput to enclosed combustion device Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 59 COMB -1 shall be monitored and recorded monthly using the flowmeter located on the assist gas line routed to COMB -1. Records of the monthly assist gas throughput shall be maintained and made available to the Division upon request. The monthly assist gas throughput shall be used to monitor compliance the VOC, NOx and CO emission limitations, as required by Conditions 3.1.3 and 3.2.3. 3.4 Lean Glycol Circulation Rate Limitations & Compliance Monitoring The circulation rate of lean glycol for this dehydration unit shall not exceed the limitation listed in Summary Table 3 above (Colorado Construction Permit 00WE0470, as modified under the provisions of Section I, Condition 1.3, and Colorado Regulation No. 3, Part C, Section I.A.7 and Part C, Section III.B.7). The lean glycol flowrate shall be recorded daily using the existing glycol flowmeter. The recorded flowrate shall be the sum of the flowrate from each pump and all other glycol injection points (if applicable). For any period during which the lean glycol circulation rate cannot be obtained from the glycol flowmeter, the maximum permitted lean glycol circulation rate listed in Summary Table 3 above shall be used. Records of the daily lean glycol circulation rate shall be maintained and made available to the Division upon request. A monthly average of the lean glycol circulation rate shall be calculated from the daily recorded values from that month for this dehydration unit. This monthly average shall be used as an input to the monthly process model run, as required by Condition 3.1.1. 3.5 Extended Gas Analysis 3.5.1 An extended gas analysis of the inlet wet gas to this dehydration unit shall be performed annually according to appropriate ASTM methods, or equivalent, if approved in advance by the Division. At least eight (8) months shall separate sequential sampling events. The extended analysis shall identify the VOC and HAP constituents of the wet gas, including any BTEX components. Results of the wet gas analysis shall be maintained and made available to the Division upon request. The composition indicated by the most recent extended wet gas analysis shall be used as an input to the monthly process model run, as required by Condition 3.1.1. 3.5.2 An extended gas analysis of the assist gas shall be performed annually according to appropriate ASTM methods, or equivalent, if approved in advance by the Division (as provided for under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3, Part C, Section I.A.7 and Part C, Section III.B.7). At least eight (8) months shall separate sequential sampling events. The extended analysis shall identify the heat content and VOC and HAP constituents of the assist gas, including any BTEX components. Results of the extended gas analysis shall be maintained and made available to the Division upon request. The composition and heat content indicated by the most recent extended gas analysis shall be used to monitor compliance with the assist gas VOC, NOx and CO emission limitations, as required by Conditions 3.1.3 and 3.2.3. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 3.6 Parametric Monitoring DCP Operating Company, LP Enterprise Compressor Station Page 60 The following operating parameters for this dehydration unit shall be monitored and recorded at the intervals specified in the table below. Values of the parameters recorded shall be representative of the unit's operation for the duration of the monitoring period. Records of the values recorded shall be maintained and made available to the Division upon request. Parameter Monitoring Frequency Inlet Wet Gas Temperature Weekly Inlet Wet Gas Pressure Weekly Flash Tank Operating Temperature Weekly Flash Tank Operating Pressure Weekly Monthly averages of each parameter shall be obtained by averaging the operating values recorded for that month. These monthly averages shall be used as inputs to the monthly process model run, as required by Condition 3.1.1. 3.7 Hours of Operation 3.7.1 Total Hours of Operation: Hours of operation for this dehydration unit shall be monitored and recorded daily in a log to be made available to the Division upon request. Monthly hours of operation shall be used to monitor compliance with the VOC, NOx and CO emission limitations, as required by Conditions 3.1.1 and 3.2.1, and to determine the average daily dry gas processed, as required by Condition 3.3.1.1. 3.7.2 COMB -1 Hours of Operation: Hours of operation of enclosed combustion device COMB -1 shall be monitored and recorded daily in a log to be made available to the Division upon request (as provided for under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3, Part C, Section I.A.7 and Part C, Section III.B.7). Hours of operation shall be determined using the COMB -1 run status indication. Hours of COMB -1 operation shall be used to monitor compliance with the pilot gas throughput limitations, as required by Condition 3.3.2.1. 3.7.3 VRU Downtime: Hours of downtime during which the VRU was not operating and emissions from the dehydration unit flash tank were routed to COMB -1 shall be monitored and recorded daily in a log to be made available to the Division upon request (as provided for under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3, Part C, Section I.A.7 and Part C, Section III.B.7). Hours of downtime shall be determined using the VRU run status indication. Hours of VRU downtime shall be used to monitor compliance with the VOC, NOx and CO emission limitations, as required by Conditions 3.1.1 and 3.2.1, and to monitor compliance with the dry gas processed during VRU downtime limitation, as required by Condition 3.3.1.2. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 61 3.7.4 COMB -1 Downtime: Hours of downtime during which COMB -1 was not operating and emissions from the dehydration unit still vent were routed to atmosphere shall be monitored and recorded daily in a log to be made available to the Division upon request (as provided for under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3, Part C, Section I.A.7 and Part C, Section III.B.7). Hours of downtime shall be determined using the difference between the D-2 run status, as required by Condtion 3.7.1, and COMB -1 run status, as required by Condition 3.7.2. Hours of COMB -1 downtime shall be used to monitor compliance with the VOC, NOx and CO emission limitations, as required by Conditions 3.1.1 and 3.2.1, and to monitor compliance with the dry gas processed during COMB -1 downtime limitation, as required by Condition 3.3.1.3. 3.8 Opacity The following opacity requirements apply to enclosed combustion device COMB -1: 3.8.1 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. (Colorado Regulation No. 1, Section II.A.5). In the absence of credible evidence to the contrary, compliance with the opacity limit shall be presumed, provided the requirements of Conditions 3.9.2 and 10.5.4 are met. 3.9 Control Device Requirements 3.9.1 The following requirements apply to the Vapor Recovery Unit (VRU): 3.9.1.1 The owner or operator shall complete a daily visual inspection of the air pollution control equipment to ensure that the valves for the piping from the dehydration unit flash tank vent to the VRU are open, except during periods of permitted downtime. The results of this daily visual inspection shall be maintained and made available to the Division upon request. 3.9.2 The following requirements apply to enclosed combustion device COMB -1: 3.9.2.1 The owner or operator shall complete a daily visual inspection of the air pollution control equipment to ensure that the valves for the piping from the dehydration unit still vent (and, if the VRU is experiencing downtime, the flash tank vent) to the enclosed combustion device COMB -1 are open, except during periods of permitted downtime. The results of this daily visual inspection shall be maintained and made available to the Division upon request. 3.9.2.2 The enclosed combustion device COMB -1 shall be operated with a pilot light present at all times, except during periods of permitted downtime. A thermocouple or equivalent heat sensing device shall continuously monitor the presence of the pilot light. If a flame is not detected, an alarm will indicate the absence of the pilot light. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 62 Records of pilot light outage events, the duration of such events and an estimation of emissions shall be maintained and made available to the Division upon request. a. In the event the pilot light presence cannot be verified by the thermocouple or equivalent heat sensing device, visual inspection of the pilot light shall be completed daily to verify pilot light presence. A daily log with the results from the visual inspection shall be maintained and made available to the Division upon request. 3.9.2.3 Visible Emissions Observations a. A six (6) minute visual observation of enclosed combustion device COMB -1 shall be performed daily to monitor for the presence of smoke. The results of the daily visual observation shall be maintained in a log and made available to the Division upon request. b. In the event smoke is observed during the six (6) minute observation period required by Condition a above, an EPA Reference Method 22 observation shall be conducted to monitor compliance with the no visible emission requirement set forth in Condition 10.5.4 by determining if visible emissions are present for a period of at least one (1) minute in any fifteen (15) minute period of normal operation. The results of any Method 22 observations performed shall be maintained in a log and made available to the Division upon request. c. In the event visible emissions are observed pursuant to an EPA Reference Method 22 test required by Condition b above, an EPA Reference Method 9 opacity observation shall be performed to monitor compliance with the opacity limitations set forth in Condition 3.8. The results of any Method 9 observations performed shall be maintained in a log and made available to the Division upon request. (i) The EPA Reference Method 9 opacity observations shall be performed by an observer with a current and valid Method 9 certification. A clear and readable copy of the observer's certificate and any opacity observations shall be kept on file and made available to the Division for review upon request. (ii) Subject to the provisions of §25-7-123.1, C.R.S., and in the absence of credible evidence to the contrary, exceedance of the opacity limit (Condition 3.8) shall be considered to exist from the time a Method 9 reading is taken that shows an exceedance of the opacity limit until a Method 9 reading is taken that shows the opacity is less than the opacity limit. 3.10 Alternative Operating Scenario (AOS) The electric glycol circulation pumps may be replaced with another electric glycol circulation pump in accordance with the requirements of Regulation 3, Part A, Section IV.A and without applying for a Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 63 revision to this permit or obtaining a new construction permit, provided the following requirements are met: 3.10.1 A replacement pump shall operate at the same or lower glycol recirculation rate as required by Condition 3.4. 3.10.2 The owner or operator shall maintain a log on -site or at a local field office to contemporaneously record the start and stop dates of any pump replacement, the manufacturer, model number, serial number and capacity of the replacement pump. This log shall be made available to the Division upon request. 3.11 Compliance Assurance Monitoring (CAM) This dehydration unit is subject to the Compliance Assurance Monitoring (CAM) requirements with respect to the annual emission limitations in Condition 3.1 for VOC and Condition 9.1 for HAP. Compliance with the CAM requirements shall be monitored in accordance with the requirements in Condition 12 and the CAM Plan in Appendix G. 3.12 Statewide Controls for Oil and Gas Operations 3.12.1 Colorado Regulation No. 7, Part D, Section I.H. Requirements: This dehydration unit and associated air pollution control equipment are subject to the following "Emission Reductions from Glycol Natural Gas Dehydrators" of Colorado Regulation No. 7, Part D, Section I., "Volatile Organic Compound Emissions from Oil and Gas Operations": Conditions shown in italic text below represent monitoring, recordkeeping and recording provisions that are not included in Colorado Regulation No. 7 as of the issuance date of this permit, but are being included as per Colorado Regulation No. 3, Part C, Section V.C.5.b. Part D, Section I. General Requirements 3.12,1,1 This dehydration unit is subject to the General Provisions of Colorado Regulation No. 7, Part D, Section I.C., as required by Conditions 10.2.1 and 10.2.2. Part D, Section I.H. Control Requirements 3.12.1.2 Beginning May 1, 2005, still vents and vents from any flash separator or flash tank on a glycol natural gas dehydrator located at an oil and gas exploration and production operation, natural gas compressor station, drip station or gas -processing plant in the 8 - Hour Ozone Control Area and subject to control requirements pursuant to Section I.H.3. (Condition 3.12.1.3), shall reduce uncontrolled actual emissions of volatile organic compounds by at least 90 percent on a rolling twelve-month basis through the use of a condenser or air pollution control equipment (Colorado Regulation No. 7, Part D, Section I.H.1.). Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 64 [Compliance Monitoring: In absence of credible evidence to the contrary, compliance with the requirements VOC reduction requirements of Condition 3.12.1.2 shall be presumed as long as the control device requirements in Conditions 3.9 and 3.12.1.1 are met.] 3.12.1.3 The control requirements of Section I.H.1. (Condition 3.12.1.2) apply where: a. Actual uncontrolled emissions of volatile organic compounds from the glycol natural gas dehydrator are equal to or greater than one ton per year (Colorado Regulation No. 7, Part D, Section I.H.3.a.); and b. The sum of actual uncontrolled emissions of volatile organic compounds from any single glycol natural gas dehydrator or grouping of glycol natural gas dehydrators at a single stationary source is equal to or greater than 15 tons per year. To determine if a grouping of dehydrators meets or exceeds the 15 tons per year threshold, sum the total actual uncontrolled emissions of volatile organic compounds from all individual dehydrators at the stationary source, including those with emissions less than one ton per year (Colorado Regulation No. 7, Part D, Section I.H.3.b.). 3.12.1.4 For purposes of Section I.H. (Condition 3.12.1), emissions from still vents and vents from any flash separator or flash tank on a glycol natural gas dehydrator shall be calculated using a method approved in advance by the Division (Colorado Regulation No. 7, Part D, Section I.H.4.). Part D, Section I.H. Monitoring and Recordkeeping Requirements 3.12.1.5 [Additional Monitoring: The owner or operator shall maintain current records of uncontrolled actual emissions on a rolling twelve month basis for this glycol dehydration unit. Such records shall be used to determine whether the control requirements in Condition 3.12.1.2 apply. Such records shall be maintained and made available for the Division upon request. Dehydration units that are not subject to the control requirements in Condition 3.12.1.2 that increase uncontrolled actual emissions from the dehydrator and/or group of dehydrators at the facility above the thresholds listed in Conditions 3.12.1.3a and/or 3.12.1.3b shall comply with the control requirements of Condition 3.12.1.2 within 60 days of discovery of the emission increase.] 3.12.1.6 Monitoring and Recordkeeping (Colorado Regulation No. 7, Part D, Section I.H.5.) a. Beginning January 1, 2017, owners or operators of glycol natural gas dehydrators subject to the control requirements of Sections I.H.1. (Condition 3.12.1.2) must check on a weekly basis that any condenser or air pollution control equipment used to control emissions of volatile organic compounds is operating properly (Colorado Regulation No. 7, Part D, Section I.H.5.a.), and document: Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 65 (i) The date of each inspection (Colorado Regulation No. 7, Part D, Section I.H.5.a.(i)); (ii) A description of any problems observed during the inspection of the condenser or air pollution control equipment (Colorado Regulation No. 7, Part D, Section I.H.5.a.(ii)); and (iii) A description and date of any corrective actions taken to address problems observed during the inspection of the condenser or air pollution control equipment (Colorado Regulation No. 7, Part D, Section I.H.5.a.(iii)). b. The owner or operator must check and document on a weekly basis that the pilot light on a combustion device is lit, that the valves for piping of gas to the pilot light are open, and visually check for the presence or absence of smoke (Colorado Regulation No. 7, Part D, Section I.H.5.b.). c. The owner or operator must document the maintenance of the condenser or air pollution control equipment, consistent with manufacturer specifications or good engineering and maintenance practices (Colorado Regulation No. 7, Part D, Section I.H.5.c.). d. The owner or operator must retain records for a period of five years and make these records available to the Division upon request (Colorado Regulation No. 7, Part D, Section I.H.5.d.). Part D, Section I.H. Reporting Requirements 3.12.1.7 On or before November 30, 2017, and semi-annually by April 30 and November 30 of each year thereafter, the owner or operator must submit the following information for the preceding calendar year (April 30 report) and for May 1 through September 30 (November 30 report) using Division -approved format (Colorado Regulation No. 7, Part D, Section I.H.6.a.). a. A list of the glycol natural gas dehydrator(s) subject to Section I.H. (Colorado Regulation No. 7, Part D, Section I.H.6.a.(i)); b. A list of the condenser or air pollution control equipment used to control emissions of volatile organic compounds from the glycol natural gas dehydrator(s) (Colorado Regulation No. 7, Part D, Section I.H.6.a.(ii)); and c. The date(s) of inspection(s) where the condenser or air pollution control equipment was found not operating properly or where smoke was observed (Colorado Regulation No. 7, Part D, Section I.H.6.a.(iii)). 3.12.2 [State -Only Enforceable] Colorado Regulation No. 7, Part D, Section II.D. Requirements: Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 66 This dehydration unit and associated air pollution control equipment are subject to the following State -Only Enforceable "Emission Reductions from Glycol Natural Gas Dehydrators" of Colorado Regulation No. 7, Part D, Section II, "Statewide Controls for Oil and Gas Operations": Conditions shown in italic text below represent monitoring, recordkeeping and recording provisions that are not included in Colorado Regulation No. 7 as of the issuance date of this permit, but are being included as per Colorado Regulation No. 3, Part C, Section V.C.5.b. Part D, Section II. General Requirements 3.12.2.1 This dehydration unit is subject to the General Provisions of Colorado Regulation No. 7, Part D, Section II.B., as required by Conditions 10.5.1 through 10.5.5. Part D, Section II.D. Control Requirements 3.12.2.2 Beginning May 1, 2008, still vents and vents from any flash separator or flash tank on a glycol natural gas dehydrator located at an oil and gas exploration and production operation, natural gas compressor station, or gas -processing plant subject to control requirements pursuant to Section II.D.2. (Condition 3.12.2.3), shall reduce uncontrolled actual emissions of volatile organic compounds by at least 90 percent through the use of a condenser or air pollution control equipment (Colorado Regulation No. 7, Part D, Section II.D.1.). [Compliance Monitoring: In absence of credible evidence to the contrary, compliance with the requirements VOC reduction requirements of Condition 3.12.2.2 shall be presumed as long as the control device requirements in Conditions 3.9 and 3.12.2.1 are met.] 3.12.2.3 The control requirements in Section II.D.1. (Condition 3.12.2.2) apply where: a. Actual uncontrolled emissions of volatile organic compounds from the glycol natural gas dehydrator are equal to or greater than two tons per year; and (Colorado Regulation No. 7, Part D, Section II.D.2.a.) b. The sum of actual uncontrolled emissions of volatile organic compounds from any single glycol natural gas dehydrator or grouping of glycol natural gas dehydrators at a single stationary source is equal to or greater than 15 tons per year. To determine if a grouping of dehydrators meets or exceeds the 15 tons per year threshold, sum the total actual uncontrolled emissions of volatile organic compounds from all individual dehydrators at the stationary source, including those with emissions less than two tons per year (Colorado Regulation No. 7, Part D, Section II.D.2.b.). 3.12.2.4 Beginning May 1, 2015, still vents and vents from any flash separator or flash tank on a glycol natural gas dehydrator located at an oil and gas exploration and production operation, natural gas compressor station, or gas -processing plant subject to control requirements pursuant to Section II.D.4. (Condition 3.12.2.5), shall reduce Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 67 uncontrolled actual emissions of hydrocarbons by at least 95 percent on a rolling twelve-month basis through the use of a condenser or air pollution control equipment (Colorado Regulation No. 7, Part D, Section II.D.3.). [Compliance Monitoring: In absence of credible evidence to the contrary, compliance with the hydrocarbon reduction requirements of Condition 3.12.2.4 shall be presumed as long as the control device requirements in Conditions 3.9 and 3.12.2.1 are met.] If a combustion device is used (to meet the requirements of Condition 3.12.2.4), it shall have a design destruction efficiency of at least 98% for hydrocarbons except where: a. The combustion device has been authorized by permit prior to May 1, 2014 (Colorado Regulation No. 7, Part D, Section II.D.3.a.); and b. A building unit or designated outside activity area (as defined in Section II.D.4.c.) is not located within 1,320 feet of the facility at which the natural gas glycol dehydrator is located (Colorado Regulation No. 7, Part D, Section II.D.3.b.). [Compliance Monitoring: In absence of credible evidence to the contrary, compliance with the design destruction efficiency requirements of Condition 3.12.2.4 shall be presumed as long as the requirements in Conditions 3.12.2.7 and 3.12.2.8 are met.] 3.12.2.5 The control requirements in Section II.D.3. (Condition 3.12.2.4) apply where: a. Uncontrolled actual emissions of VOCs from a single glycol natural gas dehydrator constructed before May 1, 2015, are equal to or greater than (Colorado Regulation No. 7, Part D, Section II.D.4.b.): (i) six (6) tons per year, or (ii) two (2) tons per year if the glycol natural gas dehydrator is located within 1,320 feet of a building unit or designated outside activity area (as defined in Section II.D.4.c.). Part D, Section II.D. Recordkeeping Requirements 3.12.2.6 [Additional Monitoring: The owner or operator shall maintain current records of uncontrolled actual emissions on a rolling twelve month basis for each glycol dehydrator. Such records shall be used to determine whether the control requirements in either Conditions 3.12.2.2 or 3.12.2.4 apply. Such records shall be maintained and made available for the Division upon request. Dehydrators that are not subject to the control requirements in Conditions 3.12.2.2 or 3.12.2.4 that increase uncontrolled actual emissions from the dehydrator and/or Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 68 group of dehydrators at the facility above the thresholds listed in Conditions 3.12.2.3 and/or 3.12.2.5 shall comply with the control requirements of Conditions 3.12.2.2 and/or 3.12.2.4 within 60 days of discovery of the emission increase.] 3.12.2.7 [Additional Monitoring: If the owner or operator is claiming an exemption from the control requirements of Condition 3.12.2.4 based on the location of the facility, the owner or operator shall maintain records that document whether the facility is located within 1, 320 feet of a residential building unit or designated outside activity area. Such records shall be reviewed annually and updated if necessary, and made available to the Division upon request. Dehydrators that are not subject to the control requirements in Condition 3.12.2.4 that become subject based on additions of or changes to residential building units or designated outside activity areas shall comply with the control requirements of Condition 3.12.2.4 within 60 days of discovery of the changes.] 3.12,2,8 [Compliance Monitoring: The owner or operator shall maintain records that document the design efficiency of the combustion device used to meet the requirements of Condition 3.12.2.4. Such records shall be maintained and made available for Division review.] 3.13 40 CFR Part 63 Subpart HH MACT This dehydration unit is subject to the National Emission Standards for Hazardous Air Pollutants requirements of Colorado Regulation No. 8, Part E, Subpart HH (40 CFR Part 63, Subpart HH) "National Emission Standards for Hazardous Air Pollutants From Oil and Natural Gas Production Facilities", including, but not limited to, the following: The requirements below reflect the current rule language as of the revisions to 40 CFR Part 63 Subpart HH published in the Federal Register on 8/16/2012. However, if revisions to this Subpart are published at a later date, the owner or operator is subject to the requirements contained in the revised version of 40 CFR Part 63 Subpart HH. Affirmative Defense for Violations of Emission Standards during Malfunction 3,13.1 The provisions set forth in this subpart shall apply at all times (§63.762(a)). General Standards 3.13.2 Except as specified in paragraph (e)(1) (Condition 3.13.3) of this section, the owner or operator of an affected source located at an existing or new area source of HAP emissions shall comply with the applicable standards specified in paragraph (d) (Condition 3.13.2.1) of this section (§63.764(d)). 3.13.2.1 Each owner or operator of an area source not located in a UA plus offset and UC boundary (as defined in §63.761) shall comply with paragraphs (d)(2)(i) through (iii) (Conditions a through c, below) of this section (§63.764(d)(2)). Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 69 a. Determine the optimum glycol circulation rate using the following equation (§63.764(d)(2)(i)): ( gal TEG) F x (I — 0) Lopr = 1.15 x 3.0 lb H2O x 24 hr/day Where: LOFT = Optimal circulation rate, gal/hr F = Gas flowrate (MMSCF/D) I = Inlet water content (lb/MMSCF) 0 = Outlet water content (lb/MMSCF) 3.0 = The industry accepted rule of thumb for a TEG to water ratio (gal TEG/lb H20) 1.15 = Adjustment factor included for a margin of safety b. Operate the TEG dehydration unit such that the actual glycol circulation rate does not exceed the optimum glycol circulation rate determined in accordance with paragraph (d)(2)(i) (Condition a, above) of this section. If the TEG dehydration unit is unable to meet the sales gas specification for moisture content using the glycol circulation rate determined in accordance with paragraph (d)(2)(i) (Condition a, above), the owner or operator must calculate an alternate circulation rate using GRI-GLYCalcTM, Version 3.0 or higher. The owner or operator must document why the TEG dehydration unit must be operated using the alternate circulation rate and submit this documentation with the initial notification in accordance with §63.775(c)(7) of this subpart (§63.764(d)(2)(ii)). c. Maintain a record of the determination specified in paragraph (d)(2)(ii) (Condition b, above) in accordance with the requirements in §63.774(f) (Condition 3.13.8) and submit the Initial Notification in accordance with the requirements in §63.775(c)(7). If operating conditions change and a modification to the optimum glycol circulation rate is required, the owner or operator shall prepare a new determination in accordance with paragraph (d)(2)(i) (Condition a, above) or (ii) (Condition b, above) of this section and submit the information specified under §63.775(c)(7)(ii) through (v) of this subpart (§63.764(d)(2)(iii)). 3.13.3 The owner or operator of an area source is exempt from the requirements of paragraph (d) (Condition 3.13.2) of this section if the criteria listed in paragraph (e)(1)(i) (Condition 3.13.3.1, below) or (ii) (Condition 3.13.3.2, below) of this section are met, except that the records of the determination of these criteria must be maintained as required in §63.774(d)(1) (Condition 3.13.7) (§63.764(e)(1)). 3.13.3.1 The actual annual average flowrate of natural gas to the glycol dehydration unit is less than 85 thousand standard cubic meters per day, as determined by the procedures Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 70 specified in §63.772(b)(1) (Condition 3.13.5.1) of this subpart (§63.764(e)(1)(i)); or 3.13,3,2 The actual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere are less than 0.90 megagram per year, as determined by the procedures specified in §63.772(b)(2) (Condition 3.13.5.2) of this subpart (§63.764(e)(1)(ii)). 3.13.4 At all times the owner or operator must operate and maintain any affected source, including associated air pollution control equipment and monitoring equipment, in a manner consistent with safety and good air pollution control practices for minimizing emissions. Determination of whether such operation and maintenance procedures are being used will be based on information available to the Administrator which may include, but is not limited to, monitoring results, review of operation and maintenance procedures, review of operation and maintenance records, and inspection of the source (§63.764(j)). Test methods, compliance procedures, and compliance demonstrations 3,13.5 Determination of glycol dehydration unit flowrate, benzene emissions, or BTEX emissions. The procedures of this paragraph shall be used by an owner or operator to determine glycol dehydration unit natural gas flowrate, benzene emissions, or BTEX emissions (§63.772(b)). 3.13.5.1 The determination of actual flowrate of natural gas to a glycol dehydration unit shall be made using the procedures of paragraph (b)(1)(i) (Condition a, below) of this section (§63.772(b)(1)). a. The owner or operator shall install and operate a monitoring instrument that directly measures natural gas flowrate to the glycol dehydration unit with an accuracy of plus or minus 2 percent or better. The owner or operator shall convert annual natural gas flowrate to a daily average by dividing the annual flowrate by the number of days per year the glycol dehydration unit processed natural gas (§63.772(b)(1)(i)). 3.13.5.2 The determination of actual average benzene or BTEX emissions from a glycol dehydration unit shall be made using the procedures of paragraph (b)(2)(i) (Condition a, below) of this section. Emissions shall be determined either uncontrolled, or with federally enforceable controls in place (§63.772(b)(2)). a. The owner or operator shall determine actual average benzene or BTEX emissions using the model GRI-GLYCalcTM, Version 3.0 or higher, and the procedures presented in the associated GRI-GLYCalcTM Technical Reference Manual. Inputs to the model shall be representative of actual operating conditions of the glycol dehydration unit and may be determined using the procedures documented in the Gas Research Institute (GRI) report entitled "Atmospheric Rich/Lean Method for Determining Glycol Dehydrator Emissions" (GRI-95/0368.1) (§63.772(b)(2)(i)). Recordkeeping Requirements Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 71 3.13.6 Except as specified in paragraphs (d) (Condition 3.13.7) and (f) (Condition 3.13.8) of this section, each owner or operator of a facility subject to this subpart shall maintain the records specified in paragraphs (b)(1) (Condition 3.13.6.1) through (2) (Condition 3.13.6.2) of this section (§63.774(b)): 3.13.6.1 The owner or operator of an affected source subject to the provisions of this subpart shall maintain files of all information (including all reports and notifications) required by this subpart. The files shall be retained for at least 5 years following the date of each occurrence, measurement, maintenance, corrective action, report or period. (§63.774(b)(1)). a. All applicable records shall be maintained in such a manner that they can be readily accessed (§63.774(b)(1)(i)). b. The most recent 12 months of records shall be retained on site or shall be accessible from a central location by computer or other means that provides access within 2 hours after a request (§63.774(b)(1)(ii)). c. The remaining 4 years of records may be retained offsite (§63.774(b)(1)(iii)). d. Records may be maintained in hard copy or computer -readable form including, but not limited to, on paper, microfilm, computer, floppy disk, magnetic tape, or microfiche (§63.774(b)(1)(iv)). 3.13.6.2 Records specified in §63.10(b)(2) (Condition 3.14.4) (§63.774(b)(2)). 3.13,7 An owner or operator of a glycol dehydration unit that meets the exemption criteria in §63.764(e)(1)(i) (Condition 3.13.3.1) or §63.764(e)(1)(ii) (Condition 3.13.3.2) shall maintain the records specified in paragraph (d)(1)(i) (Condition 3.13.7.1) or paragraph (d)(1)(ii) (Condition 3.13.7.2) of this section, as appropriate, for that glycol dehydration unit (§63.774(d)(1)). 3.13.7.1 The actual annual average natural gas throughput (in terms of natural gas flowrate to the glycol dehydration unit per day) as determined in accordance with §63.772(b)(1) (Condition 3.13.5.1) (§63.774(d)(1)(i)), or 3.13.7.2 The actual average benzene emissions (in terms of benzene emissions per year) as determined in accordance with §63.772(b)(2) (Condition 3.13.5.2) (§63.774(d)(1)(ii)). 3.13.8 The owner or operator of an area source not located within a UA plus offset and UC boundary must keep a record of the calculation used to determine the optimum glycol circulation rate in accordance with §63.764(d)(2)(i) (Condition 3.13.2.1 a) or §63.764(d)(2)(ii) (Condition 3.13.2.1 b), as applicable (§63.774(f)). 3.14 40 CFR Part 63 Subpart A MACT Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 72 This dehydration unit is subject to the requirements in 40 CFR Part 63 Subpart A "General Provisions", as adopted by reference in Colorado Regulation No. 8, Part E, Section I as specified in 40 CFR Part 63 Subpart HH §63.764(a). These requirements include, but are not limited to the following: 3.14.1 Prohibited activities and circumvention (§63.4) 3.14.2 Compliance with standards and maintenance requirements (§63.6(e)(1)) 3.14.3 Notification requirements (§63.9(j)) 3.14.4 Recordkeeping and reporting requirements (§63.10) Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 4. D-3 —Triethylene Glycol Dehydration Unit, AIRS ID: 077 DCP Operating Company, LP Enterprise Compressor Station Page 73 Parameter Permit Condition Number Compliance Limits Compliance Emission Factor Monitoring Monthly Annual Method Interval Emission & Throughput Limits VOC 4.1 D-3: 3,751 lb/month Pilot: 0.2 lb/month Assist: 316 lb/month D-3: 22.1 tons/year Pilot: 0.001 tons/year Assist: 1.9 tons/year D-3: GLYCaIc 4.0 or higher Pilot: 5.5 lb/MMscf Assist: Calculation Process Simulation, Recordkeeping and Twelve Month Rolling Total Calculation Monthly NOx 4.2 D-3: 85 lb/month Pilot: 4 lb/month Assist: 165 lb/month D-3: 0.5 tons/year Pilot: 0.02 tons/year Assist: 1.0 ton/year D-3 & Assist: 0.068 lb/MMBtu Pilot: 100 lb/MMscf CO D-3: 386 lb/month Pilot: 4 lb/month Assist: 753 lb/month D-3: 2.3 tons/year Pilot: 0.02 tons/year Assist: 4.4 tons/year D-3 & Assist: 0.31 lb/MMBtu Pilot: 84 lb/MMscf Gas Throughput 4,3 Dry Gas Limitations Meter and Twelve Month Rolling Total Calculation Monthly Total: 4,495 MMscf/month Total: 52,925 MMscf/year VRU Downtime: Not to exceed 5% of total actual dry gas processed COMB -1 Downtime: Not to exceed 1% of total actual dry gas processed Combustion Gas Limitations Pilot Gas: 0.04 MMscf/month Assist Gas: 2.38 MMscf/month Pilot Gas: 0.44 MMscf/year Assist Gas: 28.03 MMscf/year Lean Glycol Circulation Rate 4.4 25 gpm Meter and Recordkeeping Daily Other Requirements Extended Gas Analysis 4.5 ASTM Methods or Equivalent Annually Parametric Monitoring 4.6 Recordkeeping Weekly Hours of Operation 4.7 Recordkeeping Daily Operating Permit Number: 95OPWE 103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 74 Opacity 4.8 Not to exceed 30% for a period or periods aggregating more than six (6) minutes in any sixty (60) consecutive minutes See Condition 4.8 Control Device Requirements 4.9 See Condition 4.9 Final Approval Requirements 4.10 See Condition 4.10 Alternative Operating Scenario (AOS) 4.11 See Condition 4.11 Compliance Assurance Monitoring (CAM) 4.12 See Condition 4.12 Statewide Controls for Oil and Gas Operations 4.13 See Condition 4.13 40 CFR 63 Subpart HH MACT 4.14 See Condition 4.14 40 CFR 63 Subpart A General Provisions MACT 4.15 See Condition 4.15 4.1 VOC Emission Limitations & Compliance Monitoring Emissions of Volatile Organic Compounds (VOC) for this dehydration unit shall not exceed the limitations listed in Summary Table 4 above (Colorado Construction Permit 19WE0492). During the first twelve months of operation, compliance with both the monthly and annual limitations are required. After the first twelve months of operation, compliance with only the annual limitation is required. Compliance with the emission limitation shall be monitored as follows: 4.1.1 Dehydration Unit VOC Emissions: Monthly determination of VOC emissions from the dehydration unit flash gas and still vent shall be conducted by the end of the subsequent month utilizing the Gas Research Institute's GLYCalc (Version 4.0 or higher). 4.1.1.1 The following parameters shall be input to the process model: a. The inlet wet gas composition obtained from the most recent extended gas analysis, as required by Condition 4.5.1. b. The average daily dry gas processed, as required by Condition 4.3.1.1. c. The average monthly value of the lean glycol circulation rate, as required by Condition 4.4, and the inlet wet gas temperature and pressure, the flash tank operating temperature and pressure, as required by Condition 4.6. 4.1.1.2 Control Efficiencies Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 75 a. A control efficiency (CE) of 95% shall apply to the enclosed combustion device (COMB -1) when it is operational and emissions from the dehydration unit are routed to it, provided the requirements of Conditions 4.9.2, 4.13.1.1 and 4.13.2.1 are met. 4.1.1.3 Operating Hours a. Hours of vapor recovery unit (VRU) downtime, as required by Condition 4.7.3, shall be input to the equation below, along with the corresponding control efficiency (CE) of 95% for COMB -1, to determine actual emissions of VOC during periods of VRU downtime, in which the flash tank emissions are routed to COMB -1. b. Total hours of operation for this dehydration unit, as required by Condition 4.7.1, and hours of COMB -1 downtime, as required by Condition 4.7.4, shall be input to the equation below, along with the corresponding control efficiency (CE) of 95% for COMB -1, to determine actual emissions of VOC during periods of COMB -1 operation, in which still vent emissions are routed to COMB -1. c. Hours of COMB -1 downtime, as required by Condition 4.7.4, shall be input to the equation below, to determine actual still vent emissions of VOC during periods of COMB -1 downtime, in which still vent emissions are routed to atmosphere. 4.1.1.4 Monthly emissions of VOC from the dehydration unit flash gas and still vent shall be calculated using the following equations: 66 hrs ( CE(%)1 tons l FGVOC/NAP hr) x DTVRU (month X 1 100) Flash Gas Emissions (month/ (2000 lbl Unit Conversion l ton 1 lb hrs tons SVVOC/NAP (hr) X DTCOMB-1 (month) Still Vent Emissions (month)— 2000 lb + Unit Converstion ( ton ) lb hrs hrs l ( CE(%)1 SVVoc/HAP (hr) x [OHrec (month) DTCOMR-i (month)) X 1 100 ) Unit Converstion (2000 lb) ton Where: FGVoc/HAP = Uncontrolled Flash Gas Emissions of VOC or HAP, lb/hr SVvoc/HAP = Uncontrolled Still Vent Emissions of VOC or HAP, lb/hr OHTEG = Total Dehydration Unit Operating Hours, hrs/month Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DTVRU = VRU Downtime, hrs/month DTCOMB-1 = COMB — 1 Downtime, hrs/month CE = Control Efficiency of COMB - 1,95% DCP Operating Company, LP Enterprise Compressor Station Page 76 Total monthly VOC emissions shall be the sum total of emissions contributed by the dehydration unit flash gas and still vent. The total monthly VOC emissions obtained from this calculation shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 4.1.2 Pilot Gas VOC Emissions: Monthly determination of VOC emissions from the combustion of pilot gas shall be conducted by the end of the subsequent month using the emission factor listed in Summary Table 4 above (from EPA's AP -42: Compilation of Emission Factors, Section 1.4 for Natural Gas Combustion, Final Section, dated 7/98) and the monthly pilot gas flowrate, as required by Condition 4.3.2.1, in the equation below: tons Pilot Gas Emissions ( ) EF lb ' „ FR ._ot (MMscf\ vti month Unit Conversion (2000 lb) ton 1 Where: EF = Emission Factor, lb/MMscf FRpiiot = Pilot Gas Flowrate, scf /month The monthly VOC emissions obtained from this calculation shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 4.1.3 Assist Gas VOC Emissions: Monthly determination of VOC emissions from the combustion of assist gas shall be conducted by the end of the subsequent month using the monthly assist gas flowrate, as required by Condition 4.3.2.2, the molecular weight and VOC content of the assist gas obtained from the most recent extended gas analysis, as required by Condition 4.5.2, and a control efficiency of 95% for COMB -1, provided the requirements of Conditions 4.9.2, 4.13.1.1 and 4.13.2.1 are met, in the equation below: scf lb CE(%) tons FRAssist (month) x MWAssist (lbmol) x Xassist X (1 100 ) Assist Gas Emissions (month) 2000 lb (379.5 scf) Unit Conversion ( ton � x Unit Conversion lbmol Where: Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 FRAssist = Assist Gas Flowrate, scf/month MWAssist = Assist Gas Molecular Weight, lb/lbmol xAssist = Assist Gas VOC or HAP content, mass fraction CE = Control Efficiency of COMB — 1,95% DCP Operating Company, LP Enterprise Compressor Station Page 77 The monthly VOC emissions obtained from this calculation shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 4.1.4 Emissions of Hazardous Air Pollutants (HAP) from the condensate storage tanks, produced water storage tanks and dehydration unit combined shall not exceed the facility -wide limitations listed in Summary Table 9 below. Monthly emissions of HAP shall be calculated by the end of the subsequent month using the same method as required for VOC emissions. Monthly HAP emissions shall be used in a twelve month total to monitor compliance with the facility -wide HAP emission limitation, as required by Condition 9.2. 4.2 NOx & CO Emission Limitations & Compliance Monitoring Emissions of Nitrogen Oxides (NOx) and Carbon Monoxide (CO) generated by the destruction of emissions from this dehydration unit shall be determined monthly and used to monitor compliance with the limitations listed in Summary Table 4 above (Colorado Construction Permit 19WE0492). During the first twelve months of operation, compliance with both the monthly and annual limitations are required. After the first twelve months of operation, compliance with only the annual limitation is required. 4.2.1 Dehydration Unit NOx & CO Emissions: The NOx and CO emissions generated by dehydration unit flash gas and still vent combustion shall be calculated by the end of the subsequent month using the emission factors listed in Summary Table 4 above (from EPA's AP - 42: Compilation of Emission Factors, Section 13.5 for Industrial Flares, Final Section, Table 13.5-2, dated 2/18), the hourly flash gas flowrate, the hourly still vent flowrate, the flash gas heat content and still vent heat content obtained from the most recent monthly process model run, as required by Condition 4.1.1, the total monthly hours of dehydration unit operation, as required by Condition 4.7.1, the total monthly hours of VRU downtime, as required by Condition 4.7.3, and the total monthly hours of COMB -1 downtime, as required by Condition 4.7.4, as inputs to the equation below: tons NOx or CO Emissions month) + 2000 lb Unit Conversion ( ton FG (MMscfl X HCFc (M) x EF ( lb ) x DT veu ( hrs ) MMsc MMBtu montEi Unit Conversion (2000 lb) ton 1 l sv (MMrscf)x HC., (MMB f, x EF (mow) ) x [OHrsc (month hrs ) DT coMa—i ( hrs )] qtMMsc J mont Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 78 Where: FG = Uncontrolled Flash Gas Flowrate, MMscf/hr SV = Uncontrolled Still Vent Flowrate, MMscf/hr HCFG = Heat Content of Flash Gas Emissions, MMBtu/MMscf HCsv = Heat Content of Still Vent Emissions, MMBtu/MMscf EF = Emission Factor, lb/MMBtu OHTEG = Total Dehydration Unit Operating Hours, hrs/month DTvRU = VRU Downtime, hrs/month DTcoMR-i = COMB — 1 Downtime, hrs/month The monthly NOx and CO emissions obtained from this calculation shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 4.2.2 Pilot Gas NOx & CO Emissions: The NOx and CO emissions generated by pilot gas combustion shall be calculated by the end of the subsequent month using the emission factor listed in Summary Table 4 above (from EPA's AP -42: Compilation of Emission Factors, Section 1.4 for Natural Gas Combustion, Final Section, dated 7/98) and the monthly pilot gas flowrate, as required by Condition 4.3.2.1, in the equation below: lb MMscf tons EF (MMscf) x FRpLIOt (month) NOx and CO Emissions (month )= (2000 lb Unit Conversion l ton Where: EF = Emission Factor, lb/MMscf FR pilot = Pilot Gas Flowrate, MMscf /month The monthly NOx and CO emissions obtained from this calculation shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 4.2.3 Assist Gas NOx & CO Emissions: The NOx and CO emissions generated by assist gas combustion shall be calculated by the end of the subsequent month using the emission factor listed in Summary Table 4 above (from EPA's AP -42: Compilation of Emission Factors, Section 13.5 for Industrial Flares, Final Section, Table 13.5-2, dated 2/18), the monthly assist gas flowrate, as required by Condition 4.3.2.2, and the heat content of the assist gas obtained from the most recent extended gas analysis, as required by Condition 4.5.2 in the equation below: Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 79 Ib scf Btu tons ) _ EF �MMBtu� x FRass�sr (month) x HCass`Sr (scf ) Assist Gas Emissions (month/ (2000 lb(106 Btu\ ton ) x Unit Conversion IMMBtu) ( Unit Conversion Where: EF = Emission Factor, lb/MMBtu FRAssist = Assist Gas Flowrate,scf/month HCAssist = Assist Gas Heat Content, Btu/sc f The monthly NOx and CO emissions obtained from this calculation shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 4.3 Gas Throughput Limitations & Compliance Monitoring 4.3.1 Dehydration Unit Dry Gas Processing Limitations 4.3,1.1 Total Dry Gas Processed: The total amount of dry gas processed by this dehydration unit shall not exceed the limitations listed in Summary Table 4 above (Colorado Construction Permit 19WE0492). During the first twelve months of operation, compliance with both the monthly and annual limitations are required. After the first twelve months of operation, compliance with only the annual limitation is required. The dry gas processed by this dehydration unit shall be monitored and recorded each month using the flowmeter located at the unit outlet. The monthly dry gas processed shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. An average daily dry gas processed rate shall be used as an input to the monthly process model run, as required by Condition 4.1.1. This average daily gas processed rate shall be calculated by dividing the total monthly dry gas processed by the total unit hours of operation, as required by Condition 4.7.1, as follows: Average Daily Dry Gas Processed 2 Total Monthly Dry Gas Processed (month) �x Unit Conversion days) ( day MMscf ) ) Total Hours of Operation mhrs \ � 4.3.1.2 Dry Gas Processed during VRU Downtime: The total amount of dry gas processed by this dehydration unit during periods of VRU downtime shall not exceed 5% of the total dry gas processed by this dehydration unit on a rolling twelve month basis (Colorado Construction Permit I9WE0492). VRU downtime is defined as periods Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 80 when the dehydration unit is operating and flash tank emissions are routed to enclosed combustion device COMB -1. The dry gas processed by this dehydration unit during periods of VRU downtime shall be determined monthly as the total amount of dry gas processed by this dehydration unit, as indicated by the outlet flowmeter (Condition 4.3.1.1), during periods for which flash tank emissions were routed to COMB -1, as indicated by the hours of VRU downtime (Condition 4.7.3). The monthly dry gas processed during VRU downtime shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 4.3.1.3 Dry Gas Processed during COMB -1 Downtime: The total amount of dry gas processed by this dehydration unit during periods of COMB -1 downtime shall not exceed 1% of the total dry gas processed by this dehydration unit on a rolling twelve month basis (Colorado Construction Permit 19WE0492). COMB -1 downtime is defined as periods when the dehydration unit is operating and still vent emissions are routed to atmosphere. The dry gas processed by this dehydration unit during periods of COMB -1 downtime shall be determined monthly as the total amount of dry gas processed by this dehydration unit, as indicated by the outlet flowmeter (Condition 4.3.1.1), during periods for which still vent emissions were routed to atmosphere, as indicated by the hours of COMB -1 downtime (Condition 4.7.4). The monthly dry gas processed during COMB -1 downtime shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 4.3.2 Combustion Device Gas Throughput Limitations 4.3.2.1 Pilot Gas Throughput: The amount of pilot gas throughput to enclosed combustion device COMB -1 shall not exceed the limitations listed in Summary Table 4 above. During the first twelve months of operation, compliance with both the monthly and annual limitations are required. After the first twelve months of operation, compliance with only the annual limitation is required. The pilot gas throughput to enclosed combustion device COMB -1 shall be assumed to have a constant value of 50 scfh. Monthly pilot gas throughput shall be determined by multiplying this hourly pilot gas throughput by enclosed combustion device COMB -1 monthly hours of operation, as required by Condition 4.7.2. Records of the monthly pilot gas throughput calculation and the manufacturer specification for the hourly pilot gas throughput shall be maintained and made available to the Division upon request. The monthly pilot gas throughput shall be used to monitor compliance the VOC, NOx and CO emission limitations, as required by Conditions 4.1.2 and 4.2.2. 4,3.2,2 Assist Gas Throughput: The amount of assist gas throughput to enclosed combustion device COMB -1 shall not exceed the limitations listed in Summary Table 4 above. During the first twelve months of operation, compliance with both the monthly and Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 81 annual limitations are required. After the first twelve months of operation, compliance with only the annual limitation is required. A flowmeter shall be located on the assist gas line routed to enclosed combustion device COMB -1 upon installation of such an assist gas line. The assist gas throughput to enclosed combustion device COMB -1 shall be monitored and recorded monthly using the flowmeter located on the assist gas line routed to COMB -1. Records of the monthly assist gas throughput shall be maintained and made available to the Division upon request. The monthly assist gas throughput shall be used to monitor compliance the VOC, NOx and CO emission limitations, as required by Conditions 4.1.3 and 4.2.3. 4.4 Lean Glycol Circulation Rate Limitations & Compliance Monitoring The circulation rate of lean glycol for this dehydration unit shall not exceed the limitation listed in Summary Table 4 above (Colorado Construction Permit 19WE0492). The lean glycol flowrate shall be recorded daily using a glycol flowmeter. The recorded flowrate shall be the sum of the flowrate from each pump and all other glycol injection points (if applicable). For any period during which the lean glycol circulation rate cannot be obtained from the glycol flowmeter, the maximum permitted lean glycol circulation rate listed in Summary Table 4 above shall be used. Records of the daily lean glycol circulation rate shall be maintained and made available to the Division upon request. A monthly average of the lean glycol circulation rate shall be calculated from the daily recorded values from that month for this dehydration unit. This monthly average shall be used as an input to the monthly process model run, as required by Condition 4.1.1. 4.5 Extended Gas Analysis 4.5.1 An extended gas analysis of the inlet wet gas to this dehydration unit shall be performed annually according to appropriate ASTM methods, or equivalent, if approved in advance by the Division (Colorado Construction Permit 19WE0492). At least eight (8) months shall separate sequential sampling events. The extended analysis shall identify the VOC and HAP constituents of the wet gas, including any BTEX components. Results of the wet gas analysis shall be maintained and made available to the Division upon request. The composition indicated by the most recent extended wet gas analysis shall be used as an input to the monthly process model run, as required by Condition 4.1.1. 4.5.2 An extended gas analysis of the assist gas shall be performed annually according to appropriate ASTM methods, or equivalent, if approved in advance by the Division (Colorado Construction Permit 19WE0492). At least eight (8) months shall separate sequential sampling events. The extended analysis shall identify the heat content and VOC and HAP constituents of the assist gas, including any BTEX components. Results of the extended gas analysis shall be maintained and made available to the Division upon request. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 82 The composition and heat content indicated by the most recent extended gas analysis shall be used to monitor compliance with the assist gas VOC, NOx and CO emission limitations, as required by Conditions 4.1.3 and 4.2.3. 4.6 Parametric Monitoring The following operating parameters for this dehydration unit shall be monitored and recorded at the intervals specified in the table below. Values of the parameters recorded shall be representative of the unit's operation for the duration of the monitoring period. Records of the values recorded shall be maintained and made available to the Division upon request. Parameter Monitoring Frequency Inlet Wet Gas Temperature Weekly Inlet Wet Gas Pressure Weekly Flash Tank Operating Temperature Weekly Flash Tank Operating Pressure Weekly Monthly averages of each parameter shall be obtained by averaging the operating values recorded for that month. These monthly averages shall be used as inputs to the monthly process model run, as required by Condition 4.1.1. 4.7 Hours of Operation 4.7.1 Total Hours of Operation: Hours of operation for this dehydration unit shall be monitored and recorded daily in a log to be made available to the Division upon request. Monthly hours of operation shall be used to monitor compliance with the dehydration unit VOC, NOx and CO emission limitations, as required by Conditions 4.1.1 and 4.2.1, and to determine the average daily dry gas processed, as required by Condition 4.3.1.1. 4.7.2 COMB -1 Hours of Operation: Hours of operation of enclosed combustion device COMB -1 shall be monitored and recorded daily in a log to be made available to the Division upon request. Hours of operation shall be determined using the COMB -1 run status indication. Hours of COMB -1 operation shall be used to monitor compliance with the pilot gas throughput limitations, as required by Conditions 4.3.2.1. 4.7.3 VRU Downtime: Hours of downtime during which the VRU was not operating and emissions from the dehydration unit flash tank were routed to COMB -1 shall be monitored and recorded daily in a log to be made available to the Division upon request (Colorado Construction Permit 19WE0492). Hours of downtime shall be determined using the VRU run status indication. Hours of VRU downtime shall be used to monitor compliance with the VOC, NOx and CO emission limitations, as required by Conditions 4.1.1 and 4.2.1, and to monitor compliance with the dry gas processed during VRU downtime limitation, as required by Condition 4.3.1.2. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 83 4.7.4 COMB -1 Downtime: Hours of downtime during which COMB -1 was not operating and emissions from the dehydration unit still vent were routed to atmosphere shall be monitored and recorded daily in a log to be made available to the Division upon request (Colorado Construction Permit 19WE0492). Hours of downtime shall be determined using the difference between the D- 3 run status, as required by Condition 4.7.1, and COMB -1 run status, as required by Condition 4.7.2. Hours of COMB -1 downtime shall be used to monitor compliance with the VOC, NOx and CO emission limitations, as required by Conditions 4.1.1 and 4.2.1, and to monitor compliance with the dry gas processed during COMB -1 downtime limitation, as required by Condition 4.3.1.3. 4.8 Opacity The following opacity requirements apply to enclosed combustion device COMB -1: 4.8.1 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. (Colorado Regulation No. 1, Section II.A.5). In the absence of credible evidence to the contrary, compliance with the opacity limit shall be presumed, provided the requirements of Conditions 4.9.2 and 10.5.4 are met. 4.9 Control Device Requirements 4.9.1 The following requirements apply to the Vapor Recovery Unit (VRU): 4.9.1.1 The owner or operator shall complete a daily visual inspection of the air pollution control equipment to ensure that the valves for the piping from the dehydration unit flash tank vent to the VRU are open, except during periods of permitted downtime. The results of this daily visual inspection shall be maintained and made available to the Division upon request. 4.9.2 The following requirements apply to enclosed combustion device COMB -1: 4.9.2.1 The owner or operator shall complete a daily visual inspection of the air pollution control equipment to ensure that the valves for the piping from the dehydration unit still vent (and, if the VRU is experiencing downtime, the flash tank vent) to the enclosed combustion device COMB -I are open, except during periods of permitted downtime. The results of this daily visual inspection shall be maintained and made available to the Division upon request. 4.9.2.2 The enclosed combustion device COMB -1 shall be operated with a pilot light present at all times, except during periods of permitted downtime. A thermocouple or equivalent heat sensing device shall continuously monitor the presence of the pilot light. If a flame is not detected, an alarm will indicate the absence of the pilot light. Records of pilot light outage events, the duration of such events and an estimation of Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 84 emissions shall be maintained and made available to the Division upon request. a. In the event the pilot light presence cannot be verified by the thermocouple or equivalent heat sensing device, visual inspection of the pilot light shall be completed daily to verify pilot light presence. A daily log with the results from the visual inspection shall be maintained and made available to the Division upon request. 4.9.2.3 Visible Emissions Observations a. A six (6) minute visual observation of enclosed combustion device COMB -1 shall be performed daily to monitor for the presence of smoke. The results of the daily visual observation shall be maintained in a log and made available to the Division upon request. b. In the event smoke is observed during the six (6) minute observation period required by Condition a above, an EPA Reference Method 22 observation shall be conducted to monitor compliance with the no visible emission requirement set forth in Condition 10.5.4 by determining if visible emissions are present for a period of at least one (1) minute in any fifteen (15) minute period of normal operation. The results of any Method 22 observations performed shall be maintained in a log and made available to the Division upon request. c. In the event visible emissions are observed pursuant to an EPA Reference Method 22 test required by Condition b above, an EPA Reference Method 9 opacity observation shall be performed to monitor compliance with the opacity limitations set forth in Condition 4.8. The results of any Method 9 observations performed shall be maintained in a log and made available to the Division upon request. (i) The EPA Reference Method 9 opacity observations shall be performed by an observer with a current and valid Method 9 certification. A clear and readable copy of the observer's certificate and any opacity observations shall be kept on file and made available to the Division for review upon request. (ii) Subject to the provisions of §25-7-123.1, C.R.S., and in the absence of credible evidence to the contrary, exceedance of the opacity limit (Condition 4.8) shall be considered to exist from the time a Method 9 reading is taken that shows an exceedance of the opacity limit until a Method 9 reading is taken that shows the opacity is less than the opacity limit. 4.10 Final Approval Requirements 4.10.1 [State -Only Enforceable] The permit number and ten digit AIRS ID assigned by the Division shall be marked on this dehydration unit for ease of identification (Colorado Construction Permit 19WE0492). Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 85 4.10.2 The Division shall be notified no later than fifteen days of the commencement of operation, by submitting a Notice of Startup form for the dehydration unit covered by this Condition 4. The Notice of Startup form may be downloaded online at www.colorado.gov/cdphe/air/manage- permit. (Colorado Construction Permit 19WE0492). 4.10.3 The following information shall be provided to the Division within fifteen (15) days of commencement of operation (Colorado Construction Permit 19WE0492): 4.10.3.1 The manufacturer name, model number and serial number of the dehydration unit 4.10.3.2 The manufacturer name and model number of the glycol circulation pumps This information shall be included with the Notice of Startup (Condition 4.10.1) submitted for this dehydration unit. 4.10.4 The operator shall complete the following initial compliance testing and sampling (Colorado Construction Permit 19WE0492): 4.10.4.1 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 within one hundred and eighty days (180) of commencement of operation of this dehydration unit. 4.10.4.2 The owner or operator shall complete the initial extended gas analysis of the inlet wet gas within one hundred and eighty days (180) of commencement of operation of this dehydration unit. 4.10.4.3 The owner or operator shall complete the initial extended gas analysis of the fuel gas used for assist gas within one hundred and eighty days (180) of commencement of operation of this dehydration unit. Results of all initial testing required by this condition shall be submitted with the first semi- annual report due after the initial testing was conducted. 4.10.5 This Condition 4 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 Colorado Construction Permit 19WE0492 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 (Colorado Regulation Number 3, Part B, Section III.F.4.). 4.11 Alternative Operating Scenario (AOS) The electric glycol circulation pumps may be replaced with another electric glycol circulation pump in accordance with the requirements of Regulation 3, Part A, Section IV.A and without applying for a Operating Permit Number: 950PWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 86 revision to this permit or obtaining a new construction permit, provided the following requirements are met: 4.11.1 A replacement pump shall operate at the same or lower glycol recirculation rate as required by Condition 4.4. 4.11.2 The owner or operator shall maintain a log on -site or at a local field office to contemporaneously record the start and stop dates of any pump replacement, the manufacturer, model number, serial number and capacity of the replacement pump. This log shall be made available to the Division upon request. 4.12 Compliance Assurance Monitoring (CAM) This dehydration unit is subject to the Compliance Assurance Monitoring (CAM) requirements with respect to the annual emission limitations in Condition 4.1 for VOC and Condition 9.2 for HAP. Compliance with the CAM requirements shall be monitored in accordance with the requirements in Condition 12 and the CAM Plan in Appendix G. 4.13 Statewide Controls for Oil and Gas Operations 4.13.1 Colorado Regulation No. 7, Part D, Section I.H. Requirements: This dehydration unit and associated air pollution control equipment is subject to the following "Emission Reductions from Glycol Natural Gas Dehydrators" of Colorado Regulation No. 7, Part D, Section I., "Volatile Organic Compound Emissions from Oil and Gas Operations": Conditions shown in italic text below represent monitoring, recordkeeping and recording provisions that are not included in Colorado Regulation No. 7 as of the issuance date of this permit, but are being included as per Colorado Regulation No. 3, Part C, Section V.C.5.b. Part D, Section I. General Requirements 4.13.1.1 This dehydration unit is subject to the General Provisions of Colorado Regulation No. 7, Part D, Section I.C., as required by Conditions 10.2.1 and 10.2.2. Part D, Section I.H. Control Requirements 4.13.1.2 Beginning May 1, 2005, still vents and vents from any flash separator or flash tank on a glycol natural gas dehydrator located at an oil and gas exploration and production operation, natural gas compressor station, drip station or gas -processing plant in the 8 - Hour Ozone Control Area and subject to control requirements pursuant to Section I.H.3. (Condition 4.13.1.3), shall reduce uncontrolled actual emissions of volatile organic compounds by at least 90 percent on a rolling twelve-month basis through the use of a condenser or air pollution control equipment (Colorado Regulation No. 7, Part D, Section I.H.1.). Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 87 [Compliance Monitoring: In absence of credible evidence to the contrary, compliance with the requirements VOC reduction requirements of Condition 4.13.1.2 shall be presumed as long as the control device requirements in Conditions 4.9 and 4.13.1.1 are met.] 4.13.1.3 The control requirements of Sections I.H.1. (Condition 4.13.1.2) apply where: a. Actual uncontrolled emissions of volatile organic compounds from the glycol natural gas dehydrator are equal to or greater than one ton per year (Colorado Regulation No. 7, Part D, Section I.H.3.a.); and b. The sum of actual uncontrolled emissions of volatile organic compounds from any single glycol natural gas dehydrator or grouping of glycol natural gas dehydrators at a single stationary source is equal to or greater than 15 tons per year. To determine if a grouping of dehydrators meets or exceeds the 15 tons per year threshold, sum the total actual uncontrolled emissions of volatile organic compounds from all individual dehydrators at the stationary source, including those with emissions less than one ton per year (Colorado Regulation No. 7, Part D, Section I.H.3.b.). 4.13.1.4 For purposes of Section I.H. (Condition 4.13.1), emissions from still vents and vents from any flash separator or flash tank on a glycol natural gas dehydrator shall be calculated using a method approved in advance by the Division (Colorado Regulation No. 7, Part D, Section I.H.4.). Part D, Section I.H. Monitoring and Recordkeeping Requirements 4.13.1.5 [Additional Monitoring: The owner or operator shall maintain current records of uncontrolled actual emissions on a rolling twelve month basis for this glycol dehydration unit. Such records shall be used to determine whether the control requirements in Condition 4.13.1.2 apply. Such records shall be maintained and made available for the Division upon request. Dehydration units that are not subject to the control requirements in Condition 4.13.1.2 that increase uncontrolled actual emissions from the dehydrator and/or group of dehydrators at the facility above the thresholds listed in Conditions 4.13.1.3a and/or 4.13.1.3b shall comply with the control requirements of Condition 4.13.1.2 within 60 days of discovery of the emission increase.] 4.13.1.6 Monitoring and Recordkeeping (Colorado Regulation No. 7, Part D, Section I.H.5.) a. Beginning January 1, 2017, owners or operators of glycol natural gas dehydrators subject to the control requirements of Sections I.H.1. (Condition 4.13.1.2) must check on a weekly basis that any condenser or air pollution control equipment used to control emissions of volatile organic compounds is operating properly (Colorado Regulation No. 7, Part D, Section I.H.5.a.), and document: Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 88 (i) The date of each inspection (Colorado Regulation No. 7, Part D, Section I.H.5.a.(i)); (ii) A description of any problems observed during the inspection of the condenser or air pollution control equipment (Colorado Regulation No. 7, Part D, Section I.H.5.a.(ii)); and (iii) A description and date of any corrective actions taken to address problems observed during the inspection of the condenser or air pollution control equipment (Colorado Regulation No. 7, Part D, Section I.H.5.a.(iii)). b. The owner or operator must check and document on a weekly basis that the pilot light on a combustion device is lit, that the valves for piping of gas to the pilot light are open, and visually check for the presence or absence of smoke (Colorado Regulation No. 7, Part D, Section I.H.5.b.). c. The owner or operator must document the maintenance of the condenser or air pollution control equipment, consistent with manufacturer specifications or good engineering and maintenance practices (Colorado Regulation No. 7, Part D, Section I.H.5.c.). d. The owner or operator must retain records for a period of five years and make these records available to the Division upon request (Colorado Regulation No. 7, Part D, Section I.H.5.d.). Part D, Section I.H. Reporting Requirements 4.13.1.7 On or before November 30, 2017, and semi-annually by April 30 and November 30 of each year thereafter, the owner or operator must submit the following information for the preceding calendar year (April 30 report) and for May 1 through September 30 (November 30 report) using Division -approved format (Colorado Regulation No. 7, Part D, Section I.H.6.a.). a. A list of the glycol natural gas dehydrator(s) subject to Section I.H. (Colorado Regulation No. 7, Part D, Section I.H.6.a.(i)); b. A list of the condenser or air pollution control equipment used to control emissions of volatile organic compounds from the glycol natural gas dehydrator(s) (Colorado Regulation No. 7, Part D, Section I.H.6.a.(ii)); and c. The date(s) of inspection(s) where the condenser or air pollution control equipment was found not operating properly or where smoke was observed (Colorado Regulation No. 7, Part D, Section I.H.6.a.(iii)). 4.13.2 [State -Only Enforceable] Colorado Regulation No. 7, Part D, Section II.D. Requirements: Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 89 This dehydration unit and associated air pollution control equipment are subject to the following State -Only Enforceable "Emission Reductions from Glycol Natural Gas Dehydrators" of Colorado Regulation No. 7,Part D, Section II, "Statewide Controls for Oil and Gas Operations": Conditions shown in italic text below represent monitoring, recordkeeping and recording provisions that are not included in Colorado Regulation No. 7 as of the issuance date of this permit, but are being included as per Colorado Regulation No. 3, Part C, Section V.C.5.b. Part D, Section II. General Requirements 4.13.2.1 This dehydration unit is subject to the General Provisions of Colorado Regulation No. 7, Part D, Section II.B., as required by Conditions 10.5.1 through 10.5.5. Part D, Section II.D. Control Requirements 4.13.2.2 Beginning May 1, 2008, still vents and vents from any flash separator or flash tank on a glycol natural gas dehydrator located at an oil and gas exploration and production operation, natural gas compressor station, or gas -processing plant subject to control requirements pursuant to Section II.D.2. (Condition 4.13.2.3), shall reduce uncontrolled actual emissions of volatile organic compounds by at least 90 percent through the use of a condenser or air pollution control equipment (Colorado Regulation No. 7, Part D, Section II.D.1.). [Compliance Monitoring: In absence of credible evidence to the contrary, compliance with the requirements VOC reduction requirements of Condition 4.13.2.2 shall be presumed as long as the control device requirements in Conditions 4.9 and 4.13.2.1 are met.] 4.13.2.3 The control requirements in Section II.D.1. (Condition 4.13.2.2) apply where: a. Actual uncontrolled emissions of volatile organic compounds from the glycol natural gas dehydrator are equal to or greater than two tons per year; and (Colorado Regulation No. 7, Part D, Section II.D.2.a.) b. The sum of actual uncontrolled emissions of volatile organic compounds from any single glycol natural gas dehydrator or grouping of glycol natural gas dehydrators at a single stationary source is equal to or greater than 15 tons per year. To determine if a grouping of dehydrators meets or exceeds the 15 tons per year threshold, sum the total actual uncontrolled emissions of volatile organic compounds from all individual dehydrators at the stationary source, including those with emissions less than two tons per year (Colorado Regulation No. 7, Part D, Section II.D.2.b.). 4.13.2.4 Beginning May 1, 2015, still vents and vents from any flash separator or flash tank on a glycol natural gas dehydrator located at an oil and gas exploration and production operation, natural gas compressor station, or gas -processing plant subject to control requirements pursuant to Section II.D.4. (Condition 4.13.2.5), shall reduce Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 90 uncontrolled actual emissions of hydrocarbons by at least 95 percent on a rolling twelve-month basis through the use of a condenser or air pollution control equipment (Colorado Regulation No. 7, Part D, Section II.D.3.). [Compliance Monitoring: In absence of credible evidence to the contrary, compliance with the hydrocarbon reduction requirements of Condition 4.13.2.4 shall be presumed as long as the control device requirements in Conditions 4.9 and 4.13.2.1 are met.] If a combustion device is used (to meet the requirements of Condition 4.13.2.4), it shall have a design destruction efficiency of at least 98% for hydrocarbons except where: a. The combustion device has been authorized by permit prior to May 1, 2014 (Colorado Regulation No. 7, Part D, Section II.D.3.a.); and b. A building unit or designated outside activity area (as defined in Section II.D.4.c.) is not located within 1,320 feet of the facility at which the natural gas glycol dehydrator is located (Colorado Regulation No. 7, Part D, Section II.D.3.b.). [Compliance Monitoring: In absence of credible evidence to the contrary, compliance with the design destruction efficiency requirements of Condition 4.13.2.4 shall be presumed as long as the requirements in Conditions 4.13.2.7 and 4.13.2.8 are met.] 4.13.2.5 The control requirements in Section II.D.3. (Condition 4.13.2.4) apply where: a. Uncontrolled actual emissions of VOCs from a glycol natural gas dehydrator constructed on or after May 1, 2015, are equal to or greater than two (2) tons per year. Such glycol natural gas dehydrators must be in compliance with Section II.D.3. (Condition 4.13.2.4) by the date that the glycol natural gas dehydrator commences operation (Colorado Regulation No. 7, Part D, Section II.D.4.a.). Part D, Section II.D. Recordkeeping Requirements 4.13.2.6 [Additional Monitoring: The owner or operator shall maintain current records of uncontrolled actual emissions on a rolling twelve month basis for each glycol dehydrator. Such records shall be used to determine whether the control requirements in either Conditions 4.13.2.2 or 4.13.2.4 apply. Such records shall be maintained and made available for the Division upon request. Dehydrators that are not subject to the control requirements in Conditions 4.13.2.2 or 4.13.2.4 that increase uncontrolled actual emissions from the dehydrator and/or group of dehydrators at the facility above the thresholds listed in Conditions 4.13.2.3 and/or 4.13.2.5 shall comply with the control requirements of Conditions 4.13.2.2 Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 91 and/or 4.13.2.4 within 60 days of discovery of the emission increase.] 4.13.2.7 [Additional Monitoring: If the owner or operator is claiming an exemption from the control requirements of Condition 4.13.2.4 based on the location of the facility, the owner or operator shall maintain records that document whether the facility is located within 1, 320 feet of a residential building unit or designated outside activity area. Such records shall be reviewed annually and updated if necessary, and made available to the Division upon request. Dehydrators that are not subject to the control requirements in Condition 4.13.2.4 that become subject based on additions of or changes to residential building units or designated outside activity areas shall comply with the control requirements of Condition 4.13.2.4 within 60 days of discovery of the changes.] 4.13.2.8 [Compliance Monitoring: The owner or operator shall maintain records that document the design efficiency of the combustion device used to meet the requirements of Condition 4.13.2.4. Such records shall be maintained and made available for Division review.] 4.14 40 CFR Part 63 Subpart HH MACT This dehydration unit is subject to the National Emission Standards for Hazardous Air Pollutants requirements of Colorado Regulation No. 8, Part E, Subpart HH (40 CFR Part 63, Subpart HH) "National Emission Standards for Hazardous Air Pollutants From Oil and Natural Gas Production Facilities", including, but not limited to, the following: The requirements below reflect the current rule language as of the revisions to 40 CFR Part 63 Subpart HH published in the Federal Register on 8/16/2012. However, if revisions to this Subpart are published at a later date, the owner or operator is subject to the requirements contained in the revised version of 40 CFR Part 63 Subpart HH. Applicability and Designation of Affected Source 4.14.1 The owner or operator of an affected area source that is not located in an Urban -1 county, as defined in §63.761, the construction or reconstruction of which commences on or after July 8, 2005, shall achieve compliance with the provisions of this subpart immediately upon initial startup or January 3, 2007, whichever date is later (§63.760(f)(6)). Affirmative Defense for Violations of Emission Standards during Malfunction 4.14.2 The provisions set forth in this subpart shall apply at all times (§63.762(a)). General Standards 4.14.3 Except as specified in paragraph (e)(1) (Condition 4.14.4) of this section, the owner or operator of an affected source located at an existing or new area source of HAP emissions shall comply Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 92 with the applicable standards specified in paragraph (d) (Condition 4.14.3.1) of this section (§63.764(d)). 4.14.3.1 Each owner or operator of an area source not located in a UA plus offset and UC boundary (as defined in §63.761) shall comply with paragraphs (d)(2)(i) through (iii) (Conditions a through c, below) of this section (§63.764(d)(2)). a. Determine the optimum glycol circulation rate using the following equation (§63.764(d)(2)(i)): ( gal TEG' F x (1 — 0) Loin,= 1.15 x 3.0 lb H2O J x 24 hr/day Where: LOPT = Optimal circulation rate, gal/hr F = Gas flowrate (MMSCF/D) I = Inlet water content (lb/MMSCF) 0 = Outlet water content (lb/MMSCF) 3.0 = The industry accepted rule of thumb for a TEG to water ratio (gal TEG/lb 1120) 1.15 = Adjustment factor included for a margin of safety b. Operate the TEG dehydration unit such that the actual glycol circulation rate does not exceed the optimum glycol circulation rate determined in accordance with paragraph (d)(2)(i) (Condition a, above) of this section. If the TEG dehydration unit is unable to meet the sales gas specification for moisture content using the glycol circulation rate determined in accordance with paragraph (d)(2)(i) (Condition a, above), the owner or operator must calculate an alternate circulation rate using GRI-GLYCa1cTM, Version 3.0 or higher. The owner or operator must document why the TEG dehydration unit must be operated using the alternate circulation rate and submit this documentation with the initial notification in accordance with §63.775(c)(7) (Condition 4.14.10.2) of this subpart (§63.764(d)(2)(ii)). c. Maintain a record of the determination specified in paragraph (d)(2)(ii) (Condition b, above) in accordance with the requirements in §63.774(f) (Condition 4.14.9) and submit the Initial Notification in accordance with the requirements in §63.775(c)(7) (Condition 4.14.10.2). If operating conditions change and a modification to the optimum glycol circulation rate is required, the owner or operator shall prepare a new determination in accordance with paragraph (d)(2)(i) (Condition a, above) or (ii) (Condition b, above) of this section and submit the information specified under §63.775(c)(7)(ii) through (v) (Conditions 4.14.10.2b through 4.14.10.2e) of this subpart (§63.764(d)(2)(iii)). Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 93 4.14.4 The owner or operator of an area source is exempt from the requirements of paragraph (d) (Condition 4.14.3) of this section if the criteria listed in paragraph (e)(1)(i) (Condition 4.14.4.1, below) or (ii) (Condition 4.14.4.2, below) of this section are met, except that the records of the determination of these criteria must be maintained as required in §63.774(d)(1) (Condition 4.14.8) (§63.764(e)(1)). 4.14.4.1 The actual annual average flowrate of natural gas to the glycol dehydration unit is less than 85 thousand standard cubic meters per day, as determined by the procedures specified in §63.772(b)(1) (Condition 4.14.6.1) of this subpart (§63.764(e)(1)(i)); or 4.14.4.2 The actual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere are less than 0.90 megagram per year, as determined by the procedures specified in §63.772(b)(2) (Condition 4.14.6.2) of this subpart (§63.764(e)(1)(ii)). 4.14.5 At all times the owner or operator must operate and maintain any affected source, including associated air pollution control equipment and monitoring equipment, in a manner consistent with safety and good air pollution control practices for minimizing emissions. Determination of whether such operation and maintenance procedures are being used will be based on information available to the Administrator which may include, but is not limited to, monitoring results, review of operation and maintenance procedures, review of operation and maintenance records, and inspection of the source (§63.764(j)). Test methods, compliance procedures, and compliance demonstrations 4.14.6 Determination of glycol dehydration unit flowrate, benzene emissions, or BTEX emissions. The procedures of this paragraph shall be used by an owner or operator to determine glycol dehydration unit natural gas flowrate, benzene emissions, or BTEX emissions (§63.772(b)). 4.14.6.1 The determination of actual flowrate of natural gas to a glycol dehydration unit shall be made using the procedures of paragraph (b)(1)(i) (Condition a, below) of this section (§63.772(b)(1)). a. The owner or operator shall install and operate a monitoring instrument that directly measures natural gas flowrate to the glycol dehydration unit with an accuracy of plus or minus 2 percent or better. The owner or operator shall convert annual natural gas flowrate to a daily average by dividing the annual flowrate by the number of days per year the glycol dehydration unit processed natural gas (§63.772(b)(1)(i)). 4.14.6.2 The determination of actual average benzene or BTEX emissions from a glycol dehydration unit shall be made using the procedures of paragraph (b)(2)(i) (Condition a, below) of this section. Emissions shall be determined either uncontrolled, or with federally enforceable controls in place (§63.772(b)(2)). a. The owner or operator shall determine actual average benzene or BTEX emissions using the model GRI-GLYCalcTM, Version 3.0 or higher, and the Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 94 procedures presented in the associated GRI-GLYCalcTM Technical Reference Manual. Inputs to the model shall be representative of actual operating conditions of the glycol dehydration unit and may be determined using the procedures documented in the Gas Research Institute (GRI) report entitled "Atmospheric Rich/Lean Method for Determining Glycol Dehydrator Emissions" (GRI-95/0368.1) (§63.772(b)(2)(i)). Recordkeeping Requirements 4.14.7 §63.774(b) Except as specified in paragraphs (d) (Condition 4.14.8) and (f) (Condition 4.14.9) of this section, each owner or operator of a facility subject to this subpart shall maintain the records specified in paragraphs (b)(1) (Condition 4.14.7.1) through (2) (Condition 4.14.7.2) of this section: 4.14.7.1 The owner or operator of an affected source subject to the provisions of this subpart shall maintain files of all information (including all reports and notifications) required by this subpart. The files shall be retained for at least 5 years following the date of each occurrence, measurement, maintenance, corrective action, report or period. (§63.774(b)(1)). a. All applicable records shall be maintained in such a manner that they can be readily accessed (§63.774(b)(1)(i)). b. The most recent 12 months of records shall be retained on site or shall be accessible from a central location by computer or other means that provides access within 2 hours after a request (§63.774(b)(1)(ii)). c. The remaining 4 years of records may be retained offsite (§63.774(b)(1)(iii)). d. Records may be maintained in hard copy or computer -readable form including, but not limited to, on paper, microfilm, computer, floppy disk, magnetic tape, or microfiche (§63.774(b)(1)(iv)). 4.14.7.2 Records specified in §63.10(b)(2) (Condition 4.15.4) (§63.774(b)(2)). 4.14.8 An owner or operator of a glycol dehydration unit that meets the exemption criteria in §63.764(e)(1)(i) (Condition 4.14.4.1) or §63.764(e)(1)(ii) (Condition 4.14.4.2) shall maintain the records specified in paragraph (d)(1)(i) (Condition 4.14.8.1) or paragraph (d)(1)(ii) (Condition 4.14.8.2) of this section, as appropriate, for that glycol dehydration unit (§63.774(d)(1)). 4.14.8.1 The actual annual average natural gas throughput (in terms of natural gas flowrate to the glycol dehydration unit per day) as determined in accordance with §63.772(b)(1) (Condition 4.14.6.1) (§63.774(d)(1)(i)), or 4.14.8.2 The actual average benzene emissions (in terms of benzene emissions per year) as determined in accordance with §63.772(b)(2) (Condition 4.14.6.2) (§63.774(d)(1)(ii)). 4.14.9 The owner or operator of an area source not located within a UA plus offset and UC boundary must keep a record of the calculation used to determine the optimum glycol circulation rate in Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 95 accordance with §63.764(d)(2)(i) (Condition 4.14.3.1a) or §63.764(d)(2)(ii) (Condition 4.14.3.1 b), as applicable (§63.774(f)). 4.14.10 Except as provided in paragraph (c)(8) (Condition 4.14.10.3), each owner or operator of an area source subject to this subpart shall submit the information listed in paragraph (c)(1) (Condition 4.14.10.1) of this section. If the source is located within a UA plus offset and UC boundary, the owner or operator shall also submit the information listed in paragraphs (c)(2) through (6) of this section. If the source is not located within any UA plus offset and UC boundaries, the owner or operator shall also submit the information listed within paragraph (c)(7) (Condition 4.14.10.2) (§63.775(c)). 4.14.10.1 The initial notifications required under §63.9(b)(2) (Condition 4.15.3) not later than January 3, 2008. In addition to submitting your initial notification to the addressees specified under §63.9(a) (Condition 4.15.3), you must also submit a copy of the initial notification to the EPA's Office of Air Quality Planning and Standards. Send your notification via email to Oil and Gas Sector@epa.gov or via U.S. mail or other mail delivery service to U.S. EPA, Sector Policies and Programs Division/Fuels and Incineration Group (E143-01), Attn: Oil and Gas Project Leader, Research Triangle Park, NC 27711 (§63.775(c)(1)). 4.14.10.2 The information listed in paragraphs (c)(7)(i) through (v) (Conditions a through e) of this section. This information shall be submitted with the initial notification (§63.775(c)(7)). a. Documentation of the source's location relative to the nearest UA plus offset and UC boundaries. This information shall include the latitude and longitude of the affected source; whether the source is located in an urban cluster with 10,000 people or more; the distance in miles to the nearest urbanized area boundary if the source is not located in an urban cluster with 10,000 people or more; and the name of the nearest urban cluster with 10,000 people or more and nearest urbanized area (§63.775(c)(7)(i)). b. Calculation of the optimum glycol circulation rate determined in accordance with §63.764(d)(2)(i) (Condition 4.14.3.1a) (§63.775(c)(7)(ii)). c. If applicable, documentation of the alternate glycol circulation rate calculated using GRI-GLYCalcTM, Version 3.0 or higher and documentation stating why the TEG dehydration unit must operate using the alternate glycol circulation rate (§63.775(c)(7)(iii)). d. The name of the manufacturer and the model number of the glycol circulation pump(s) in operation (§63.775(c)(7)(iv)). e. Statement by a responsible official, with that official's name, title, and signature, certifying that the facility will always operate the glycol dehydration unit using the optimum circulation rate determined in accordance with Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 96 §63.764(d)(2)(i) (Condition 4.14.3.1a) or §63.764(d)(2)(ii) (Condition 4.14.3.1b), as applicable (§63.775(c)(7)(v)). 4.14.10.3 An owner or operator of a TEG dehydration unit located at an area source that meets the criteria in §63.764(e)(1)(i) (Condition 4.14.4.1) or §63.764(e)(1)(ii) (Condition 4.14.4.2) is exempt from the reporting requirements for area sources in paragraphs (c)(1) through (7) (Conditions 4.14.10.1 and 4.14.10.2) of this section, for that unit (§63.775(c)(8)). 4.15 40 CFR Part 63 Subpart A MACT This dehydration unit is subject to the requirements in 40 CFR Part 63 Subpart A "General Provisions", as adopted by reference in Colorado Regulation No. 8, Part E, Section I as specified in 40 CFR Part 63 Subpart HH §63.764(a). These requirements include, but are not limited to the following: 4.15.1 Prohibited activities and circumvention (§63.4) 4.15.2 Compliance with standards and maintenance requirements (§63.6(e)(1)) 4.15.3 Notification requirements (§63.9(a), (b)(2) & (j)) 4.15.4 Recordkeeping and reporting requirements (§63.10) Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 97 5. P016 — Stabilized Condensate Atmospheric Truck Loadout Rack, AIRS ID: 066 Parameter Permit Condition Number Compliance Limits Compliance Emission Factor Monitoring Method Interval Emission & Throughput Limits VOC 5.1 0.94 tons/year 0.186 lb/bbl Recordkeeping and Twelve Month Rolling Total Calculation Monthly Condensate Throughput 5.2 202,848 bbl/year Other Requirements Liquids Analysis 5 3 ASTM Methods or Equivalent OnExtended r Every c5 years Opacity 5.4 Not to exceed 30% for a period or periods aggregating more than six (6) minutes in any sixty (60) consecutive minutes See Condition 5.4 Operational Requirements 5.5 See Condition 5.5 Control Device Requirements 5.6 See Condition 5.6 Reasonably Available Control Technology (RACT) 5.7 Submerged Fill Recordkeeping Statewide Controls for Oil and Gas Operations 5.8 See Condition 5.8 5.1 VOC Emission Limitations & Compliance Monitoring Emissions of Volatile Organic Compounds (VOC) from stabilized condensate truck loading operations shall not exceed the limitation listed in Summary Table 5 above (Colorado Construction Permit 19WE0492). Compliance with the emission limitations shall be monitored as follows: 5.1.1 Monthly determination of VOC emissions shall be calculated by the end of the subsequent month using the following methodology: 5.1.1.1 The following parameters shall be input to the equation below: a. The emission factor listed in Summary Table 5 above. b. The monthly condensate throughput to the loadout rack, as required by Condition 5.2. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 98 c. A control efficiency (CE) of 95% shall apply to the enclosed combustion device when it is operational and emissions from the condensate truck loading rack are routed to it, provided the requirements of Condition 5.6 are met. 3 EF ( 36 x F (10 gal) x (1. — CE(%)) tons ll _ 10 gal) `month VOC or HAP Emissions (monthl 2000 ib Unit Conversion ( ton Where: EF = Loading Loss Emission Factor, lb/103 gal F = Condensate Throughput, 103 gal/month CE = Enclosed Combustion Device Control Efficiency, 95% Monthly VOC emissions shall be used in a twelve month rolling total to monitor compliance with the annual limitation. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 5.1.2 Annual emissions of Hazardous Air Pollutants (HAP), for the purposes of APEN reporting and the payment of annual fees, shall be calculated using HAP emissions derived from the same method as required for VOC emissions, except that the following emission factors shall be input to the equation above: HAP Species Emission Factor (lb/bbl) n -Hexane 3.62 x 10-3 Benzene 5.16 x 10-4 Toluene 6.34 x 10"4 Ethylbenzene 1.78 x 10-5 Xylene 9.62 x 10-5 i 5.1.3 A verification analysis of the emission factor listed in Summary Table 5 above shall be performed once every five (5) years to ensure any variation in process conditions does not result in an underestimation of emissions. The initial verification analysis shall be conducted within one (1) year of permit issuance. At least four (4) years shall separate sequential verification analyses. This emission factor was derived using Equation 1 of AP -42, Chapter 5.2, Transportation and Marketing of Petroleum Liquids (07/2008): lb SxP(psia)xM(( 16 42 al L l 12.46 x llbmol� x Unit Conversion g c (bbl/ T (°R) x 1000 gal ( bbl / Where: Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 99 LL = Loading Loss Emission Factor, 0.186 lb/bbl S = Saturation Factor for Submerged Loading, 0.6 P = True Vapor Pressure of Loaded Liquid, 4.65 psia M = Molecular Weight of Vapors, 66 lb/lbmol T = Temperature of Bulk Liquid, 519.67°R To verify this emission factor, the physical properties indicated by the most recent extended liquids analysis, as required by Condition 5.3, shall be input to the equation above to obtain an emission factor in terms of lb VOC/bbl condensate. If the emission factor obtained from this verification analysis is greater than the emission factor listed in Summary Table 5 above, the owner or operator shall apply for a permit modification within sixty (60) days of the verification analysis. Results of this verification analysis shall be maintained and made available to the Division upon request. 5.2 Condensate Throughput Limitations & Compliance Monitoring The quantity of condensate loaded into trucks shall not exceed the limitation listed in Summary Table 5 above (Colorado Construction Permit 19WE0492). Sales or haul tickets from each loading operation shall be used to monitor the volume of condensate transferred. The monthly condensate throughput shall be the sum of the volume transferred, as indicated on each sales or haul ticket for all loading operations that took place during that month. The monthly condensate throughput shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. The monthly condensate throughput shall be used to monitor compliance with the VOC emission limitation, as required by Condition 5.1. 5.3 Extended Liquids Analysis An extended liquids analysis of the condensate loaded shall be performed once every five (5) years, according to appropriate ASTM methods or equivalent, if approved in advance by the Division. The initial analysis shall be performed within one (1) year of permit issuance. At least four (4) years shall separate sequential sampling events. Results of each analysis shall be maintained and made available to the Division upon request. The physical parameters as indicated by the most recent analysis shall be monitored to ensure the static emission factor set forth in this permit does not require modification, pursuant to Condition 5.1.3. 5.4 Opacity The following opacity requirements apply to the enclosed combustion device: Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 100 5.4.1 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. (Colorado Regulation No. 1, Section II.A.5). In the absence of credible evidence to the contrary, compliance with the opacity limit shall be presumed, provided the requirements of Condition 5.6.2 are met. 5.5 Operational Requirements 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 (Colorado Construction Permit 19WE0492). The following loading procedures shall be utilized to minimize the leakage of VOCs to the atmosphere including, but not limited to: 5.5.1 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. 5.5.2 Thief hatch seals shall be inspected annually for integrity and replaced as necessary. Thief hatch covers shall be weighted and properly seated. 5.5.3 Pressure relief devices (PRD) shall be inspected annually for proper operation and replaced as necessary. PRDs shall be set to release at a pressure that will ensure flashing, working and breathing losses are not vented through the PRD under normal operating conditions. 5.5.4 The equipment design requirements, loading procedures and monthly onsite loading equipment inspections set forth in Condition 5.8.1.2c for controlled loading operations shall be utilized to minimize the leakage of VOC to atmosphere. This requirement shall apply at all times, regardless of actual loadout throughput. Records of standard loadout operating procedures and equipment design documentation validating the loadout is designed to minimize leakage of VOC, as well as records of each inspection of onsite loading equipment, compartment hatch operation, thief hatches, and pressure relief devices shall be maintained and made available to the Division upon request. These records must include an indication of equipment status, a description of any problems found, any replacements made and their resolution. 5.6 Control Device Requirements 5.6.1 The enclosed combustion device shall be operated with a pilot light present at all times. A thermocouple or equivalent heat sensing device shall continuously monitor the presence of the pilot light. If a flame is not detected, an alarm will indicate the absence of the pilot light. Records of pilot light outage events, the duration of such events and an estimation of emissions shall be maintained and made available to the Division upon request. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 101 5.6.1.1 In the event the pilot light presence cannot be verified by the thermocouple or equivalent heat sensing device, visual inspection of the pilot light shall be completed daily to verify pilot light presence. A daily log with the results from the visual inspection shall be maintained and made available to the Division upon request. 5.6,2 Visible Emissions Observations 5.6.2.1 A six (6) minute visual observation of the enclosed combustion device shall be performed daily to monitor for the presence of smoke. The results of the daily visual observation shall be maintained in a log and made available to the Division upon request. 5.6.2.2 In the event smoke is observed during the six (6) minute observation period required by Condition 5.6.2.1 above, an EPA Reference Method 22 observation shall be conducted to monitor compliance with the no visible emission requirement set forth in Condition 10.5.4 by determining if visible emissions are present for a period of at least one (1) minute in any fifteen (15) minute period of normal operation. The results of any Method 22 observations performed shall be maintained in a log and made available to the Division upon request. 5.6.2.3 In the event visible emissions are observed pursuant to an EPA Reference Method 22 test required by Condition 5.6.2.2 above, an EPA Reference Method 9 opacity observation shall be performed to monitor compliance with the opacity limitations set forth in Condition 5.4. The results of any Method 9 observations performed shall be maintained in a log and made available to the Division upon request. a. The EPA Reference Method 9 opacity observations shall be performed by an observer with a current and valid Method 9 certification. A clear and readable copy of the observer's certificate and any opacity observations shall be kept on file and made available to the Division for review upon request. b. Subject to the provisions of §25-7-123.1, C.R.S., and in the absence of credible evidence to the contrary, exceedance of the opacity limit (Condition 5.4) shall be considered to exist from the time a Method 9 reading is taken that shows an exceedance of the opacity limit until a Method 9 reading is taken that shows the opacity is less than the opacity limit. 5.7 Reasonably Available Control Technology (RACT) The condensate truck loadout point is subject to Reasonably Available Control Technology (RACT) (Colorado Regulation No. 3, Part B, Section III.D.2.a.). RACT for this point has been determined to be loading the tank trucks using submerged fill, as required by Condition 5.8.1.2. This requirement shall apply at all times, regardless of actual loadout throughput. Records of standard loadout operating procedures and equipment design documentation validating the loadout is designed for submerged fill and operated as such shall be maintained and made available to the Division upon request. 5.8 Statewide Controls for Oil and Gas Operations Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 102 5.8.1 [State -Only Enforceable] Colorado Regulation No. 7, Part D, Section II.C.5. Requirements: This hydrocarbon liquid loadout and associated air pollution control equipment are subject to the following State -Only Enforceable "Storage Tank Hydrocarbon Liquids Loadout Requirements at Well Production Facilities, Natural Gas Compressor Stations and Natural Gas Processing Plants" of Colorado Regulation No. 7, Part D, Section II., "Statewide Controls for Oil and Gas Operations": Conditions shown in italic text below represent monitoring, recordkeeping and recording provisions that are not included in Colorado Regulation No. 7 as of the issuance date of this permit, but are being included as per Colorado Regulation No. 3, Part C, Section V.C.5.b. Part D, Section II. General Requirements 5.8.1.1 This hydrocarbon liquid loadout is subject to the General Provisions of Colorado Regulation No. 7, Part D, Section II.B., as required by Conditions 10.5.1 through 10.5.5. Part D, Section II.C.5. Operation and Control Requirements 5.8.1.2 Owners or operators of well production facilities, natural gas compressor stations, and natural gas processing plants with a hydrocarbon liquids loadout to transport vehicles throughput of greater than or equal to 5,000 barrels per year on a rolling 12 -month basis must control emissions from the loadout of hydrocarbon liquids from controlled storage tanks to transport vehicles by using (a) submerged fill and (b) a vapor collection and return system and/or air pollution control equipment (Colorado Regulation No. 7, Part D, Section II.C.5.a.). a. Compliance with Section II.C.5. (Condition 5.8.1) must be achieved in accordance with the following schedule (Colorado Regulation No. 7, Part D, Section II.C.5.a.(i)): (i) Facilities constructed before May 1, 2020, must be in compliance by May 1, 2021 (Colorado Regulation No. 7, Part D, Section II.C.5.a.(i)(B)). (ii) Facilities not subject to Section II.C.5.a.(i)(B) (Condition (i) above) that exceed the hydrocarbon liquids loadout to transport vehicles throughput of greater than or equal to 5,000 barrels per year on a rolling 12 -month basis must control emissions from loadout upon exceeding the loadout threshold. [Compliance Monitoring: In the absence of credible evidence to the contrary, compliance with the requirements of this Condition shall be presumed as long as the recordkeeping requirements of Condition e(vi) and e(vii) below indicate that the liquid loading equipment is capable of submerged fill and the vapor Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 103 collection and return system and/or air pollution control equipment is installed and operating.] b. Storage tanks must operate without venting at all times during loadout (Colorado Regulation No. 7, Part D, Section II.C.5.a.(ii)). [Clarification: Venting, for the purposes of this Condition b, is as defined in Colorado Regulation No. 7, Part D, Section II. C.2. a. (i) (Condition 6.6.2.9a).] [Compliance Monitoring: In the absence of credible evidence to the contrary, compliance with the requirements of this Condition shall be presumed as long as observations are being conducted pursuant to Conditions d(i) and d(ii) and the associated recordkeeping requirements of Conditions e(ii) and e(iii) below indicate that venting did not occur during loadout.] c. The owner or operator must, as applicable (Colorado Regulation No. 7, Part D, Section II.C.5.a.(iii)): (1) Install and operate the vapor collection and return equipment to collect vapors during the loadout of hydrocarbon liquids to tank compartments of outbound transport vehicles and to route the vapors to the storage tank or air pollution control equipment (Colorado Regulation No. 7, Part D, Section II.C.5.a.(iii)(A)). (ii) Include devices to prevent the release of vapor from vapor recovery hoses not in use (Colorado Regulation No. 7, Part D, Section II.C .5 .a.(iii)(B)). (iii) Use operating procedures to ensure that hydrocarbon liquids cannot be transferred to transport vehicles unless the vapor collection and return system is in use (Colorado Regulation No. 7, Part D, Section II.C.5.a.(iii)(C)). (iv) Operate all recovery and disposal equipment at a back -pressure less than the pressure relief valve setting of transport vehicles (Colorado Regulation No. 7, Part D, Section II.C.5.a.(iii)(D)). (v) The owner or operator must inspect onsite loading equipment to ensure that hoses, couplings, and valves are maintained to prevent dripping, leaking, or other liquid or vapor loss during loadout. These inspections must occur at least monthly (Colorado Regulation No. 7, Part D, Section II.C.5.a.(iii)(E)). d. Loadout observations and operator training (Colorado Regulation No. 7, Part D, Section II.C.5.a.(iv)): (i) The owner or operator must observe loadout to confirm that all storage tanks operate without venting when loadout operations are active. These inspections must occur at least monthly, unless loadout occurs Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 104 less frequently, then as often as loadout is occurring (Colorado Regulation No. 7, Part D, Section II.C.5.a.(iv)(A)), (ii) If observation of loadout is not feasible, the owner or operator must document the annual loadout frequency and the reason why observation is not feasible and inspect the facility within 24 hours after loadout to confirm that all storage tank thief hatches (or other access point to the tank) are closed and latched (Colorado Regulation No. 7, Part D, Section II.C.5.a.(iv)(B)). (iii) The owner or operator must install signage at or near the loadout control system that indicates which loadout control method(s) is used and the appropriate and necessary operating procedures for that system (Colorado Regulation No. 7, Part D, Section II.C.5.a.(iv)(C)). [Clarification: Signage may include, but is not limited to, 1) an indication that the thief hatches, pressure relief devices and/or other access points should not be opened to load out hydrocarbon liquids, 2) identification of the location for the appropriate equipment to be used during loadout and 3) location of additional detailed information on the use of equipment to control emissions during loadout.] (iv) The owner or operator must develop and implement an annual training program for employees and/or third parties conducting loadout activities subject to Section II.C.5. (Condition 5.8.1) that includes, at a minimum, operating procedures for each type of loadout control system (Colorado Regulation No. 7, Part D, Section II.C.5.a.(iv)(D)). [Compliance Monitoring: In the absence of credible evidence to the contrary, compliance with this condition may be presumed, provided records are kept of the training program as required by Condition e (v).1 e. Owners or operators must retain records and make such records available to the Division upon request (Colorado Regulation No. 7, Part D, Section II.C.5.a.(v)). (i) Records of the annual facility hydrocarbon liquids loadout to transport vehicles throughput (Colorado Regulation No. 7, Part D, Section II.C.5.a.(v)(A)). (ii) Inspections, including a description of any problems found and their resolution, required under Sections II.C.5.a.(iii) and II.C.5.a.(iv) (Conditions c and d above) must be documented in a log (Colorado Regulation No. 7, Part D, Section II.C.5.a.(v)(B)). (iii) Records of the infeasibility of observation of loadout (Colorado Regulation No. 7, Part D, Section II.C.5.a.(v)(C)). Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 105 (iv) Records of the frequency of loadout (Colorado Regulation No. 7, Part D, Section II.C.5.a.(v)(D)). (v) Records of the annual training program, including the date and names of persons trained (Colorado Regulation No. 7, Part D, Section II.C .5 .a.(v)(E)). (vi) [Additional Recordkeeping: A description of the loading equipment used to conduct submerged fill.] (vii) [Additional Recordkeeping: A description of the vapor collection and return equipment and any devices used to prevent release of vapor from vapor recovery hoses not in use.] [Clarification: Note that in accordance with the requirements in Section IV, Conditions 22. b and 22. c records shall be kept for a period of five years.] f. Air pollution control equipment used to comply with this Section II.C.5. (Condition 5.8.1) must comply with Section II.B. (Condition 5.8.1.1), be inspected in accordance with Sections II.C.1.d.(ii) through (v) (Conditions 6.6.2.7b through 6.6.2.7e), and achieve a hydrocarbon control efficiency of 95% (Colorado Regulation No. 7, Part D, Section II.C.5.a.(iv)). Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 106 6. P013 — Eight (8) 300 bbl Stabilized Condensate Storage Tanks, AIRS ID: 063 Parameter Permit Condition Number Compliance Limits Emission Factor Monitoring Method Interval Emission & Throughput Limits VOC 6.1 1.7 tons/year 0.33 lb/bbl Recordkeeping and Twelve Month Rolling Total Calculation Monthly Condensate Throughput 6.2 202,848 bbl/year Other Requirements Extended Liquids Analysis 6 3 ASTM Methods or Equivalent EOe Once ry years Opacity 6.4 Not to exceed 30% for a period or periods aggregating more than six (6) minutes in any sixty (60) consecutive minutes See Condition 6.4 Control Device Requirements 6.5 See Condition 6.5 Statewide Controls for Oil and Gas Operations 6.6 See Condition 6.6 6.1 VOC Emission Limitations & Compliance Monitoring Emissions of Volatile Organic Compounds (VOC) from the stabilized condensate storage tanks shall not exceed the limitation listed in Summary Table 6 above (Colorado Construction Permit 19WE0492). Compliance with the emission limitation shall be monitored as follows: 6.1.1 Monthly determination of VOC emissions shall be calculated by the end of the subsequent month using the following methodology: 6.1.1.1 The following parameters shall be input to the equation below: a. The emission factor listed in Summary Table 6 above. b. The monthly condensate throughput to the condensate tanks, as required by Condition 6.2. c. A control efficiency (CE) of 95% shall apply to the enclosed combustion device when it is operational and emissions from the condensate tanks are routed to it, provided the requirements of Condition 6.5 are met. tons ll _ EF (bbl x F lmonthbbl ) x (1 — CE(%)) VOC or HAP Emissions( 2000 lb Unit Conversion ( ) ton Where: Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 107 EF = Emission Factor, lb/bbl F = Condensate Throughput, bbl/month CE = Enclosed Combustion Device Control Efficiency, 95% Monthly VOC emissions shall be used in a twelve month rolling total to monitor compliance with the annual limitation. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 6.1.2 Emissions of Hazardous Air Pollutants (HAP) from the condensate storage tanks, produced water storage tanks and dehydration unit combined shall not exceed the facility -wide limitations listed in Summary Table 9 below. Monthly emissions of HAP shall be calculated by the end of the subsequent month using the same method as required for VOC emissions, except that the following emission factors shall be input to the equation above: HAP Species Emission Factor (lb/bbl) I n -Hexane 3.2 x 10-2 Benzene 4.0 x 10-3 Toluene 1.5 x 10-2 Ethylbenzene 1.0 x 10-4 Xylene 1.1 x 10-2 Monthly HAP emissions shall be used in a twelve month total to monitor compliance with the facility -wide HAP emission limitation, as required by Condition 9.1. 6.1.3 A verification analysis of the emission factor listed in Summary Table 6 above shall be performed once every five (5) years to ensure any variation in process conditions does not result in an underestimation of emissions. The initial verification analysis shall be conducted within one (1) year of permit issuance. At least four (4) years shall separate sequential verification analyses. The most recent rolling twelve month condensate throughput total, as required by Condition 6.2 and the physical properties indicated by the most recent extended liquids analysis, as required by Condition 6.3, shall be used in conjunction with the methods set forth in EPA's AP -42: Compilation of Emission Factors, Chapter 7 for Liquid Storage Tanks to obtain an emission factor in terms of lb VOC/bbl condensate. If the emission factor obtained from this verification analysis is greater than the emission factor listed in Summary Table 6 above, the owner or operator shall apply for a permit modification within sixty (60) days of the verification analysis. Results of this verification analysis shall be maintained and made available to the Division upon request. 6.2 Condensate Throughput Limitations & Compliance Monitoring The quantity of condensate throughput to the tank battery shall not exceed the limitation listed in Summary Table 6 above. Sales or haul tickets from each loading operation shall be used to monitor the volume of Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 108 condensate transferred. The monthly condensate throughput shall be the sum of the volume transferred, as indicated on each sales or haul ticket for all loading operations that took place during that month. The monthly condensate throughput shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. The monthly condensate throughput shall be used to monitor compliance with the VOC emission limitation, as required by Condition 6.1, and to ensure the static emission factor set forth in this permit does not require modification, pursuant to Condition 6.1.3. 6.3 Extended Liquids Analysis An extended liquids analysis of the condensate stored in this tank battery shall be performed once every five (5) years, according to appropriate ASTM methods or equivalent, if approved in advance by the Division. The initial analysis shall be performed within one (1) year of permit issuance. At least four (4) years shall separate sequential sampling events. Results of each analysis shall be maintained and made available to the Division upon request. The condensate composition and physical properties indicated by the most recent analysis shall be used to ensure the static emission factor set forth in this permit does not require modification, pursuant to Condition 6.1.3. 6.4 Opacity The following opacity requirements apply to the enclosed combustion device: 6.4.1 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. (Colorado Regulation No. 1, Section II.A.5). In the absence of credible evidence to the contrary, compliance with the opacity limit shall be presumed, provided the requirements of Conditions 6.5.2 and 10.5.4 are met. 6.5 Control Device Requirements 6.5.1 The enclosed combustion device shall be operated with a pilot light present at all times. A thermocouple or equivalent heat sensing device shall continuously monitor the presence of the pilot light. If a flame is not detected, an alarm will indicate the absence of the pilot light. Records of pilot light outage events, the duration of such events and an estimation of emissions shall be maintained and made available to the Division upon request. 6.5.1.1 In the event the pilot light presence cannot be verified by the thermocouple or equivalent heat sensing device, visual inspection of the pilot light shall be completed daily to verify pilot light presence. A daily log with the results from the visual Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 109 inspection shall be maintained and made available to the Division upon request. 6.5.2 Visible Emissions Observations 6.5.2.1 A six (6) minute visual observation of the enclosed combustion device shall be performed daily to monitor for the presence of smoke. The results of the daily visual observation shall be maintained in a log and made available to the Division upon request. 6.5.2.2 In the event smoke is observed during the six (6) minute observation period required by Condition 6.5.2.1 above, an EPA Reference Method 22 observation shall be conducted to monitor compliance with the no visible emission requirement set forth in Condition 10.5.4 by determining if visible emissions are present for a period of at least one (1) minute in any fifteen (15) minute period of normal operation. The results of any Method 22 observations performed shall be maintained in a log and made available to the Division upon request. 6.5.2.3 EPA Reference Method 9 opacity observations are required as follows: a. In the event visible emissions are observed pursuant to an EPA Reference Method 22 test required by Condition 6.5.2.2 above, an EPA Reference Method 9 opacity observation shall be performed to monitor compliance with the opacity limitations set forth in Condition 6.4. The results of any Method 9 observations performed shall be maintained in a log and made available to the Division upon request. b. An EPA Reference Method 9 opacity observation shall be performed annually to monitor compliance with the opacity limitation set forth in Colorado Regulation No. 7, Part D, Section I.I.4.b. (Condition 6.6.1.1 d(ii)). This observation must be performed during normal operations only. The results of this annual Method 9 observation performed shall be maintained in a log and made available to the Division upon request. c. The EPA Reference Method 9 opacity observations shall be performed by an observer with a current and valid Method 9 certification. A clear and readable copy of the observer's certificate and any opacity observations shall be kept on file and made available to the Division for review upon request. d. Subject to the provisions of §25-7-123.1, C.R.S., and in the absence of credible evidence to the contrary, exceedance of the opacity limit (Condition 6.4 or 6.6.1.1d(ii)) shall be considered to exist from the time a Method 9 reading is taken that shows an exceedance of the opacity limit until a Method 9 reading is taken that shows the opacity is less than the opacity limit. 6.6 Statewide Controls for Oil and Gas Operations 6.6.1 Colorado Regulation No. 7, Part D, Section I.I. Requirements: Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 110 This tank battery is subject to the following requirements of Colorado Regulation No. 7, Part D, Section I, "Volatile Organic Compound Emissions from Oil and Gas Operations": Conditions shown in italic text below represent monitoring, recordkeeping and recording provisions that are not included in Colorado Regulation No. 7 as of the issuance date of this permit, but are being included as per Colorado Regulation No. 3, Part C, Section V.C.5.b. 6.6.1.1 The requirements of Sections I.D. through I.F. do not apply to the owner or operator of any natural gas compressor station or natural gas drip station located in an Ozone Nonattainment or Attainment/Maintenance Area if (Colorado Regulation No. 7, Part D, Section I.I.): a. Air pollution control equipment is installed and properly operated to reduce emissions of volatile organic compounds from all atmospheric condensate storage tanks (or tank batteries) that have uncontrolled actual emissions of greater than or equal to two tons per year (Colorado Regulation No. 7, Part D, Section I.I.1.); b. The air pollution control equipment is designed to achieve a VOC control efficiency of at least 95% on a rolling 12 -month basis and meets the requirements of Sections I.C.I.a. (Condition 10.2.1) and I.C.1.b (Condition 10.2.2) (Colorado Regulation No. 7, Part D, Section I.I.2.); c. The owner or operator of such natural gas compressor station or natural gas drip station does not own or operate any exploration and production facilities in the Ozone Nonattainment or Attainment -maintenance Area (Colorado Regulation No. 7, Part D, Section 1.I.3.); and d. The owner or operator of such natural gas compressor station or natural gas drip station does the following and maintains associated records and reports for a period of five years (Colorado Regulation No. 7, Part D, Section 1.I.4.): (1) Documents the maintenance of the air pollution control equipment according to manufacturer specifications (Colorado Regulation No. 7, Part D, Section I.I.4.a.); (ii) Conducts an annual opacity observation once each year on the air pollution control equipment to verify opacity does not exceed 20% during normal operations (Colorado Regulation No. 7, Part D, Section I.I.4.b.); [Compliance Monitoring: Compliance with this opacity limitation shall be demonstrated using EPA Reference Method 9, as required by Condition 6.5.2.3b.] (iii) Maintains records of the monthly stabilized condensate throughput and monthly actual VOC emissions (Colorado Regulation No. 7, Part D, Section I.I.4.c.); Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 111 (iv) [Additional Recordkeeping: Maintains documentation verifying the owner or operator does not own or operate any exploration and production facilities in the Ozone Nonattainment or Attainment - maintenance Area, if claiming this exemption pursuant to Part D, Section 11.3. (Condition 6.6.1.1c);] (v) [Additional Recordkeeping: Maintains manufacturer documentation of the design destruction efficiency if a combustion device is used; and] (vi) Reports compliance with these requirements (Conditions (i) through (v) above) to the Division annually (Colorado Regulation No. 7, Part D, Section I.I.4.d.). 6.6.2 [State -Only Enforceable] Colorado Regulation No. 7, Part D, Section II.C. Requirements: This tank battery is subject to the following State -Only Enforceable "Emission Reduction from Storage Tanks at Oil and Gas Exploration and Production Operations, Well Production Facilities, Natural Gas Compressor Stations and Natural Gas Processing Plants" requirements of Colorado Regulation No. 7, Part D, Section II, "Statewide Controls for Oil and Gas Operations": Conditions shown in italic text below represent monitoring, recordkeeping and recording provisions that are not included in Colorado Regulation No. 7 as of the issuance date of this permit, but are being included as per Colorado Regulation No 3, Part C, Section V.C.5.b. Part D, Section II. General Requirements 6.6.2.1 This tank battery is subject to the General Provisions of Colorado Regulation No. 7, Part D, Section II.B., as required by Conditions 10.5.1 through 10.5.5. Part D, Section II.C. Control Requirements: 6.6.2.2 Beginning May 1, 2008, owners or operators of all storage tanks storing condensate with uncontrolled actual emissions of VOCs equal to or greater than twenty (20) tons per year based on a rolling twelve-month total must collect and control emissions from each storage tank by routing emissions to and operating air pollution control equipment that has a control efficiency of at least 95% for VOCs (Colorado Regulation No. 7, Part D, Section II.C.1.a.). [Compliance Monitoring: In the absence of credible evidence to the contrary, compliance with the 95% VOC control efficiency requirement shall be presumed as long as the requirements in Conditions 6.5 and 6.6.2.1 are met.] 6.6.2.3 Owners or operators of storage tanks with uncontrolled actual emissions of VOCs equal to or greater than six (6) tons per year based on a rolling twelve-month total must collect and control emissions from each storage tank by routing emissions to and operating air pollution control equipment that achieves a hydrocarbon control efficiency of 95% (Colorado Regulation No. 7, Part D, Section II.C.I .b.). Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 112 [Compliance Monitoring: In the absence of credible evidence to the contrary, compliance with the 95% hydrocarbon control efficiency requirement shall be presumed as long as the requirements in Conditions 6.5 and 6.6.2.1 are met] 6.6.2.4 Control requirements of Section II.C.1.b. (Condition 6.6.2.3) must be achieved in accordance with the following schedule (Colorado Regulation No. 7, Part D, Section II.C.1.b.(i)): a. A storage tank constructed before May 1, 2014, must be in compliance by May 1, 2015 (Colorado Regulation No. 7, Part D, Section II.C.1.b.(i)(B)). b. A storage tank not otherwise subject to Section II.C.1.b.(i)(B) (Condition a above) that increases uncontrolled actual emissions to six (6) tons per year VOC or more on a rolling twelve month basis after May 1, 2014, must be in compliance within sixty (60) days of discovery of the emissions increase (Colorado Regulation No. 7, Part D, Section II.C.1.b.(i)(C)). 6.6.2.5 Owners or operators of storage tanks with uncontrolled actual emissions of VOCs equal to or greater than two (2) tons per year based on a rolling twelve-month total must collect and control emissions from each storage tank by routing emissions to and operating air pollution control equipment that achieves a hydrocarbon control efficiency of 95% (Colorado Regulation No. 7, Part D, Section II.C.1.c.). [Compliance Monitoring: In the absence of credible evidence to the contrary, compliance with the 95% hydrocarbon control efficiency requirement shall be presumed as long as the requirements in Conditions 6.5 and 6.6.2.1 are met.] 6.6.2.6 Control requirements of Section II.C.1.c. (Condition 6.6.2.5) must be achieved in accordance with the following schedule (Colorado Regulation No. 7, Part D, Section II.C.1.c.(i)): a. A storage tank constructed before March 1, 2020, that is not already controlled under Sections I.D. or II.C.1.b. (Condition 6.6.2.3) must be in compliance by May 1, 2021 (Colorado Regulation No. 7, Part D, Section II.C.1.c.(i)(B)). b. A storage tank not otherwise subject to Section II.C.1.c.(i)(B) (Condition a above) that increases uncontrolled actual emissions above the applicable threshold in Section II.C.1.c.(i)(B) (Condition a above) after the applicable date in Section II.C.1.c.(i)(B) (Condition a above) must be in compliance within sixty (60) days of the first day of the month after which the storage tank emissions exceeded the applicable threshold based on a rolling twelve-month basis (Colorado Regulation No. 7, Part D, Section II.C.1.c.(i)(C)). Part D, Section II.C. Visual Inspection Requirements: 6.6.2.7 Beginning May 1, 2014, or the applicable compliance date in Section II.C.1.b.(i) (Condition 6.6.2.4) or II.C.1.c.(i) (Condition 6.6.2.6), whichever comes later, owners or operators of storage tanks subject to Section II.C.1. (Conditions 6.6.2.2, 6.6.2.3 and 6.6.2.5) must conduct audio, visual, olfactory ("AVO") and additional visual Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 g. Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 113 inspections of the storage tank and any associated equipment (e.g. separator, air pollution control equipment, or other pressure reducing equipment) at the same frequency as liquids are loaded out from the storage tank. These inspections are not required more frequently than every seven (7) days but must be conducted at least every thirty one (31) days, unless otherwise specified below. Monitoring is not required for storage tanks or associated equipment that are unsafe, difficult, or inaccessible to monitor, as defined in Section II.C.1.e. (Condition 6.6.2.8). The additional visual inspections must include, at a minimum (Colorado Regulation No. 7, Part D, Section II.C.1.d.): a. Visual inspection of any thief hatch, pressure relief valve, or other access point to ensure that they are closed and properly sealed (Colorado Regulation No. 7, Part D, Section II.C.1.d.(i)); b. Visual inspection or monitoring of the air pollution control equipment to ensure that it is operating, including that the pilot light is lit on combustion devices used as air pollution control equipment (Colorado Regulation No. 7, Part D, Section II.C.1.d.(ii)); c. Visual inspection of the autoigniter and valves for piping of gas to the pilot light to ensure they are functioning properly (Colorado Regulation No. 7, Part D, Section II.C.1.d.(iii)); d. Visual inspection of the air pollution control equipment to ensure that the valves for the piping from the storage tank to the air pollution control equipment are open (Colorado Regulation No. 7, Part D, Section II.C.1.d.(iv)) e. Daily inspection of the device for the presence or absence of smoke, as required by Condition 6.5.2 (Colorado Regulation No. 7, Part D, Section II.C.1.d.(v)); f. Beginning May 1, 2020, or the applicable compliance date in Section II.C.1.c.(i) (Condition 6.6.2.6), whichever comes later, visual observation of the dump valve(s) of the last separator(s) before the storage tank(s) to ensure the dump valve is free of debris and not stuck open. The owner or operator is not required to observe the actuation of the dump valve during this inspection; however, if a dump event occurs during the inspection, the owner or operator must confirm proper operation of the valve (Colorado Regulation No. 7, Part D, Section II.C.1.d.(vi)). Beginning May 1, 2020, or the applicable compliance date in Section II.C.1.c.(i) (Condition 6.6.2.6), whichever comes later, a check for the presence of liquids in liquid knockout vessels that do not drain automatically, underground lines, and aboveground piping (Colorado Regulation No. 7, Part D, Section II.C.1.d.(vii)). (i) For liquid knockout vessels for which a procedure exists to check liquid level, check for the presence of liquids. If liquids are present above the Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 114 low level indication point, drain liquids (Colorado Regulation No. 7, Part D, Section II.C.1.d.(vii)(A)). (ii) For liquid knockout vessels for which no procedure exists to check liquid level, drain liquids (Colorado Regulation No. 7, Part D, Section II.C.1.d.(vii)(B)). (iii) For underground lines and aboveground piping that is not sloped to a liquid knockout or tank and for which a procedure exists to check for the presence of liquids accumulation, check for the presence of liquids and drain liquids as needed (Colorado Regulation No. 7, Part D, Section II.C.1.d.(vii)(C)). (iv) For underground lines and aboveground piping that is not sloped to a liquid knockout vessel or tank and for which no written procedure exists to check for the presence of liquids accumulation, drain liquids quarterly (Colorado Regulation No. 7, Part D, Section II.C.1.d.(vii)(D)). 6.6.2.8 If storage tanks or associated equipment is unsafe, difficult, or inaccessible to monitor, the owner or operator is not required to monitor such equipment until it becomes feasible to do so (Colorado Regulation No. 7, Part D, Section II.C.I.e.). Part D, Section II.C. Capture Requirements: 6.6.2.9 Capture requirements for storage tanks that are fitted with air pollution control equipment as required by Section II.C.1. (Conditions 6.6.2.2, 6.6.2.3 and 6.6.2.5): Owners or operators of storage tanks must route all hydrocarbon emissions to air pollution control equipment, and must operate without venting hydrocarbon emissions from the thief hatch (or other access point to the tank) or pressure relief device during normal operation, unless venting is reasonably required for maintenance, gauging (unless the use of a storage tank measurement system is required pursuant to and the operator compiles with Section II.C.4.; Condition 6.6.2.11), or safety of personnel and equipment. Compliance must be achieved in accordance with the schedule in Section II.C.2.b.(ii) (Condition d). (Colorado Regulation No. 7, Part D, Section II.C.2.a.). a. Venting is emissions from a controlled storage tank thief hatch, pressure relief device, or other access point to the storage tank, which (Colorado Regulation No. 7, Part D, Section II.C.2.a.(i)): (i) Are primarily the result of over -pressurization, whether related to design, operation, or maintenance (Colorado Regulation No. 7, Part D, Section II.C.2.a.(i)(A)); or (ii) Are the result of an open, unlatched, or visibly unseated pressure relief device (e.g., thief hatch or pressure relief valve), an open vent line, or an unintended opening in the storage tank (e.g., crack or hole) (Colorado Regulation No. 7, Part D, Section II.C.2.a.(i)(B)). Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 115 b. When emissions from a controlled storage tank are observed, the Division may require the owner or operator to submit sufficient information demonstrating whether or not the emissions were primarily the result of over -pressurization. Absent a demonstration that such emissions were not primarily the result of over -pressurization, such emissions will be considered venting for purposes of Section II.C.2.a. (Condition 6.6.2.9) (Colorado Regulation No. 7, Part D, Section II.C.2.a.(ii)). c. When venting is observed, the owner or operator must confirm within twenty- four (24) hours of taking action to return the storage tank to operation without venting that the action(s) taken was effective. If the venting was observed using an approved instrument monitoring method, the confirmation must be made using an approved instrument monitoring method (Colorado Regulation No. 7, Part D, Section II.C.2.a.(iii)). [Clarification: For the purposes of this condition, approved instrument monitoring method means an infra -red camera or EPA Method 21.] [Compliance Monitoring: In the absence of credible evidence to the contrary, compliance with the requirements of this Condition shall be presumed as long as the recordkeeping requirements of Conditions 6.6.2.10b and 6.6.2.10f indicate that hydrocarbon emissions venting did not occur during normal operation unless venting is reasonably required for maintenance, gauging, or safety of personnel and equipment.] d. Owners or operators must achieve the requirements of Section II.C.2.a. (Condition 6.6.2.9) and begin implementing the required approved instrument monitoring method in accordance with the following schedule (Colorado Regulation No. 7, Part D, Section II.C.2.b.(ii)): [Clarification: For the purposes of this condition, approved instrument monitoring method means an infra -red camera or EPA Method 21.] Part D, Section II.C. Initial Compliance Dates for Capture Requirements and AIMM Inspections (i) A storage tank subject to Sections II.C.I.a. (Condition 6.6.2.2) or II.C.1.b. (Condition 6.6.2.3) and constructed before May 1, 2014, must comply with the requirements of Section II.C.2.a. (Condition 6.6.2.9) by May 1, 2015 (Colorado Regulation No. 7, Part D, Section II.C.2.b.(ii)(B)). (ii) A storage tank subject to Section II.C.1.c. (Condition 6.6.2.5) and constructed before March 1, 2020, that is not subject to the control requirements of the system -wide control strategy in Section I.D.1. must comply with the requirements of Section II.C.2.a. (Condition 6.6.2.9) by May 1, 2021. Approved instrument monitoring method inspections Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 116 of the storage tank must begin in 2021 (Colorado Regulation No. 7, Part D, Section II.C.2.b.(ii)(E)). (iii) A storage tank with uncontrolled actual emissions of VOCs equal to or greater than six (6) and less than or equal to twelve (12) tons per year must begin semi-annual approved instrument monitoring method inspections in 2020 (Colorado Regulation No. 7, Part D, Section II.C.2.b.(ii)(F)). (iv) A storage tank not otherwise subject to Section II.C.2.b.(ii)(B) ((i) above) that increases uncontrolled actual emissions to six (6) tons per year VOC or more on a rolling twelve month basis after May 1, 2014, must comply with the requirements of Sections II.C.2.a. (Condition 6.6.2.9) and implement the required approved instrument monitoring method inspections within sixty (60) days of discovery of the emissions increase (Colorado Regulation No. 7, Part D, Section II.C.2.b.(ii)(G)). (v) A storage tank not otherwise subject to Sections II.C.2.b.(ii)(A) through II.C.2.b.(ii)(F) (Conditions (i) through (iii) above) that increases uncontrolled actual emissions above the applicable threshold in Section II.C.1.c.(i)(B) (Condition 6.6.2.6a) after the applicable date in Section II.C.I.c.(i)(B) (Condition 6.6.2.6a), must comply with the requirements of Section II.C.2.a. (Condition 6.6.2.9) and implement the required approved instrument monitoring method inspections within sixty (60) days of the first day of the month after which the storage tank VOC emissions exceeded the applicable threshold based on a rolling twelve-month basis (Colorado Regulation No. 7, Part D, Section II.C.2.b.(ii)(H)). Part D, Section II.C. AIMM Inspection Frequency (vi) Following the first approved instrument monitoring method inspection, owners or operators must continue conducting approved instrument monitoring method inspections in accordance with the inspection frequency in Table 1 (Colorado Regulation No. 7, Part D, Section II.C.2.b.(ii)(I)) >2and<12 Semi -Annually >12and<50 Quarterly Monthly >50 Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 117 [Additional Monitoring: For the purposes of this Condition (vi), uncontrolled actual emissions shall be evaluated on a rolling twelve month basis. When rolling twelve month actual uncontrolled emissions increase such that a storage tank becomes subject to a higher inspection frequency, the owner or operator shall conduct the next inspection within 30 days of the discovery of the emission increase, or at the time that next inspection was scheduled as per the previous inspection frequency, whichever occurs first.] e. Owners or operators are not required to monitor storage tanks and associated equipment that are unsafe, difficult, or inaccessible to monitor, as defined in Section II.C.1.e. (Condition 6.6.2.8) (Colorado Regulation No. 7, Part D, Section II.C.2.b.(iii)). Part D, Section II.C. Recordkeeping 6.6.2.10 The owner or operator must maintain records of any required monitoring and make them available to the Division upon request, including (Colorado Regulation No. 7, Part D, Section II.C.3.): a. The AIRS ID for the storage tank (Colorado Regulation No. 7, Part D, Section II.C.3.a.). b. The date and duration of any period where the thief hatch, pressure relief device, or other access point are found to be venting hydrocarbon emissions, except for venting that is reasonably required for maintenance, gauging (unless use of a storage tank measurement system is required pursuant to and the operator complies with Section II.C.4.; Condition 6.6.2.11), or safety of personnel and equipment (Colorado Regulation No. 7, Part D, Section II.C.3.b.). c. The date and duration of any period where the air pollution control equipment is not operating (Colorado Regulation No. 7, Part D, Section II.C.3.c.). d. Records of the inspections required in Sections II.C.1.d. (Condition 6.6.2.7) and II.C.2.b.(ii) (Condition 6.6.2.9d), including the time and date of each inspection and a description of any problems observed, description and date of any corrective action(s) taken, and name of employee or third party performing corrective action(s) (Colorado Regulation No. 7, Part D, Section II.C.3.d.). e. Where a combustion device is being used, the date and result of any EPA Method 22 test or investigation pursuant to Section II.C.1.d.(v) (Condition 6.6.2.7e) (Colorado Regulation No. 7, Part D, Section II.C.3.e.). f. The timing of and efforts made to eliminate venting, restore operation of air pollution control equipment, and mitigate visible emissions, including the dates and results of action(s) taken and the monitoring used to confirm the Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 g. DCP Operating Company, LP Enterprise Compressor Station Page 118 action(s) were successful (Colorado Regulation No. 7, Part D, Section II.C.3.f.). A list of equipment associated with the storage tank that is designated as unsafe, difficult, or inaccessible to monitor, as described in Section II.C.1.e. (Condition 6.6.2.8), an explanation stating why the equipment is so designated, and the plan for monitoring such equipment (Colorado Regulation No. 7, Part D, Section II.C.3.g.). [Clarification: Note that in accordance with the requirements in Section IV, Conditions 22. b and 22. c records shall be kept for a period of five years.] Part D, Section II.C. Storage Tank Measurement System Requirements 6.6.2.11 Storage tank measurement system requirements at well production facilities, natural gas compressor stations, and natural gas processing plants (Colorado Regulation No. 7, Part D, Section II.C.4.). a. The owners or operators of controlled storage tanks at well production facilities, natural gas compressor stations, or natural gas processing plants constructed on or after May 1, 2020, and at any facilities that are modified on or after May 1, 2020, such that an additional controlled storage vessel is constructed to receive an anticipated increase in throughput of hydrocarbon liquids or produced water, must use a storage tank measurement system to determine the quantity of liquids in the storage tank(s) (Colorado Regulation No. 7, Part D, Section II.C.4.a.(i)). [Compliance Monitoring: In the absence of credible evidence to the contrary, compliance with this condition is presumed, provided records are kept of the date of construction of the storage vessels, as required by Conditions g(i), and a description of the storage tank measurement system, as required by Condition g(ii).] b. The owners or operators of controlled storage tanks at well production facilities, natural gas compressor stations, or natural gas processing plants constructed on or after January 1, 2021, and at any facilities that are modified on or after January 1, 2021, such that an additional controlled storage vessel is constructed to receive an anticipated increase in throughput of hydrocarbon liquids or produced water, must use a storage tank measurement system to determine the quality and quantity of liquids in the storage tank(s) (Colorado Regulation No. 7, Part D, Section II.C.4.a.(ii)). [Compliance Monitoring: In the absence of credible evidence to the contrary, compliance with this condition is presumed, provided records are kept of the date of construction of the storage vessels, as required by Conditions g(i), and a description of the storage tank measurement system, as required by Condition g(ii).] Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 g. Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 119 c. Owner or operators subject to the storage tank measurement system requirements in Section II.C.4.a. (Conditions a and b above), must keep thief hatches (or other access points to the tank) and pressure relief devices on storage tanks closed and latched during activities to determine the quality and/or quantity of liquids in the storage tank(s) (Colorado Regulation No. 7, Part D, Section II.C.4.b.). [Compliance Monitoring: The owner or operator shall record the date and time of all qualitative and/or quantitative measurement events in a log to be made available to the Division upon request. The log shall include an indication of whether the thief hatch, other access points and any pressure relief devices were open or closed during these events.] d. Operators may inspect, test, and/or calibrate the storage tank measurement system semi-annually, or as directed by the Bureau of Land Management (see 43 CFR Section 3174.6(b)(5)(ii)(B) (November 17, 2016)) or system manufacturer. Opening the thief hatch if required to inspect, test, or calibrate the system is not a violation of Section II.C.4.b. (Condition c above) (Colorado Regulation No. 7, Part D, Section II.C.4.c.). e. The owner or operator must install signage at or near the storage tank that indicates which equipment and method(s) is used and the appropriate and necessary operating procedures for that system (Colorado Regulation No. 7, Part D, Section II.C.4.d.). [Clarification: Signage may include, but is not limited to, 1) an indication that the thief hatches, pressure relief devices and/or other access points should not be opened to obtain data on the quality or quantity of hydrocarbon liquids, 2) identification of the location for obtaining the quality and quantity data and 3) location of additional detailed information on the storage tank measurement system and expectations for truck loading.] f. The owner or operator must develop and implement an annual training program for employees and/or third parties conducting activities subject to Section II.C.4. (Conditions a and b above) that includes, at a minimum, operating procedures for each type of system (Colorado Regulation No. 7, Part D, Section II.C.4.e.). [Compliance Monitoring: In the absence of credible evidence to the contrary, compliance with this condition may be presumed, provided records are kept of the training program as required by Condition g(v).] Owner or operators must retain records and make such records available to the Division upon request, including (Colorado Regulation No. 7, Part D, Section II.C.4.f.): (i) Date of construction of the storage vessel or facility (Colorado Regulation No. 7, Part D, Section II.C.4.f.(i)). Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 120 (ii) Description of the storage tank measurement system used to comply with Section II.C.4.a. (Conditions a and b above) (Colorado Regulation No. 7, Part D, Section II.C.4.f.(ii)). (iii) Date(s) of storage tank measurement system inspections, testing, and/or calibrations pursuant to Section II.C.4.c. (Condition d above) (Colorado Regulation No. 7, Part D, Section II.C.4.f.(iii)). (iv) Manufacturer specifications regarding storage tank measurement system inspections, and/or calibrations, if followed pursuant to Section II.C.4.c. (Condition d above) (Colorado Regulation No. 7, Part D, Section II.C.4.f.(iv)). (v) Records of the annual training program, including the date and names of persons trained (Colorado Regulation No. 7, Part D, Section II.C.4.f.(v)). [Clarification: Note that in accordance with the requirements in Section IV, Conditions 22. b and 22. c records shall be kept for a period of five years.] Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 121 7. SUMP -1/2 — Two (2) 90 bbl Produced Water Storage Tanks, AIRS ID: 075 Parameter Permit Condition Number Compliance Limits Compliance Emission Factor Monitoring Method Interval Emission & Throughput Limits VOC 7.1 1.9 tons/year 0.28 lb/bbl Recordkeeping and Twelve Month Rolling Total Calculation Monthly Produced Water Throughput 7.2 13,299 bbl/year Recordkeeping and Twelve Month Rolling Total Calculation Monthly Other Requirements Flash Liberation Analysis 7.3 See Condition 7.4 ASTM Methods or Equivalent Annually Statewide Controls for Oil and Gas Operations 7.4 7.1 VOC Emission Limitations & Compliance Monitoring Emissions of Volatile Organic Compounds (VOC) from the produced water storage tanks shall not exceed the limitations listed in Summary Table 7 above (as provided for under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3, Part C, Section I.A.7 and Part C, Section III.B.7., based on requested emissions identified on the APEN submitted on 6/1/2020). Compliance with the emission limitation shall be monitored as follows: 7.1.1 Monthly determination of VOC and HAP emissions shall be calculated by the end of the subsequent month using the following methodology: 7.1.1.1 The following parameters shall be input to the equation below: a. The emission factor listed in Summary Table 7 above. b. The monthly produced water throughput to the produced water tanks, as required by Condition 7.2. (lb bbl tons _ EF(1b) x F \month VOC or HAP Emissions month Unit Conversion (2000 lb) \ ton Where: EF = Emission Factor, lb/bbl F = Produced Water Throughput, bbl/month Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 122 Monthly VOC emissions shall be used in a twelve month rolling total to monitor compliance with the annual limitation. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 7.1.2 Emissions of Hazardous Air Pollutants (HAP) from the condensate storage tanks, produced water storage tanks and dehydration unit combined shall not exceed the facility -wide limitations listed in Summary Table 9 below. Monthly emissions of HAP shall be calculated by the end of the subsequent month using the same method as required for VOC emissions, except that the following emission factors shall be input to the equation above: HAP Species Emission Factor (1b/bbl_ n -Hexane 0.026 Monthly HAP emissions shall be used in a twelve month total to monitor compliance with the facility -wide HAP emission limitation, as required by Condition 9.1. 7.1.3 A verification analysis of the emission factor listed in Summary Table 7 above shall be performed annually to ensure any variation in process conditions does not result in an underestimation of emissions. At least eight (8) months shall separate sequential verification analyses. The most recent rolling twelve month produced water throughput total, as required by Condition 7.2 and the physical properties indicated by the most recent flash liberation analysis, as required by Condition 7.3, shall be used in conjunction with the methods set forth in EPA's AP -42: Compilation of Emission Factors, Chapter 7 for Liquid Storage Tanks to obtain an emission factor in terms of lb VOC/bbl produced water. If the emission factor obtained from this verification analysis is greater than the emission factor listed in Summary Table 7 above, the owner or operator shall apply for a permit modification within sixty (60) days of the verification analysis. Results of this annual verification analysis shall be maintained and made available to the Division upon request. 7.2 Produced Water Throughput Limitations & Compliance Monitoring The quantity of produced water throughput to the produced water storage tanks shall not exceed the limitation listed in Summary Table 7 above. Sales or haul tickets from each loading operation shall be used to monitor the volume of produced water transferred. The monthly produced water throughput shall be the sum of the volume transferred, as indicated on each sales or haul ticket for all loading operations that took place during that month. The monthly produced water throughput shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. The monthly produced water throughput shall be used to monitor compliance with the VOC emission limitation, as required by Condition 7.1. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 123 7.3 Flash Liberation Analysis A flash liberation analysis of the pressurized produced water routed to these produced water storage tanks shall be performed annually, according to appropriate ASTM methods or equivalent, if approved in advance by the Division. At least eight (8) months shall separate sequential sampling events. Results of each analysis shall be maintained and made available to the Division upon request. The flash gas composition and physical properties indicated by the most recent analysis shall be used to ensure the static emission factor set forth in this permit does not require modification, pursuant to Condition 7.1.3. 7.4 Statewide Controls for Oil and Gas Operations 7.4.1 [State -Only Enforceable] Colorado Regulation No. 7, Part D, Section II.C. Requirements: These produced water storage tanks are subject to the following State -Only Enforceable "Emission Reduction from Storage Tanks at Oil and Gas Exploration and Production Operations, Well Production Facilities, Natural Gas Compressor Stations and Natural Gas Processing Plants" requirements of Colorado Regulation No. 7, Part D, Section II, "Statewide Controls for Oil and Gas Operations": Conditions shown in italic text below represent monitoring, recordkeeping and recording provisions that are not included in Colorado Regulation No. 7 as of the issuance date of this permit, but are being included as per Colorado Regulation No 3, Part C, Section V.C.5.b. Part D, Section II. General Requirements 7.4.1.1 These produced water storage tanks are subject to the General Provisions of Colorado Regulation No. 7, Part D, Section II.B., as required by Conditions 10.5.1 and 10.5.2. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 8. COMP -BD — Reciprocating Compressor Blowdowns, AIRS ID: 076 DCP Operating Company, LP Enterprise Compressor Station Page 124 Parameter Permit Condition Number Compliance Limits Compliance Emission Factor Monitoring Method Interval Emission & Throughput Limits VOC' 8.1 9.8 tons/year C-234, C-235, C-236, C-238: 2,883 scf/event Recordkeeping and Twelve Month Rolling Total Calculation Monthly C-237: 5,674 sef/event Blowdown Events 8.2 Each Compressor: 63 events/year Recordkeeping and Twelve Month Rolling Total Calculation Monthly Other Requirements Extended Gm Analysis 8 3 ASTM or Other Division Approved Method wall y Reasonably Available Control Technology (RACT) 8.4 Operating Practices Recordkeeping Final Approval Requirements 8.5 See Condition 8.5 'This emission limitation applies to all blowdown events combined. 8.1 VOC Emission Limitations & Compliance Monitoring Emissions of Volatile Organic Compounds (VOC) from reciprocating compressor blowdowns shall not exceed the limitations listed in Summary Table 8 above (Colorado Construction Permit 19WE0094, as provided for under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3, Part C, Section I.A.7 and Part C, Section III.B.7., based on requested emissions identified on the APEN submitted on 10/30/2020). Compliance with the emission limitation shall be monitored as follows: 8.1.1 Monthly determination of VOC and HAP emissions shall be calculated by the end of the subsequent month using the following methodology: 8.1.1.1 The following parameters shall be input to the equation below: a. The emission factor listed in Summary Table 8 above. b. The number of blowdown events, totaled monthly, as required by Condition 8.2. c. The molecular weight and VOC content obtained from the most recent extended gas analysis, as required by Condition 8.3. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 125 8.1.1.2 Monthly emissions of VOC and HAP from the reciprocating compressor blowdowns shall be calculated using the following equation: scf events lb tons l — EF (event) x E (month) x MW �lbmol� x x� VOC or HAP Emissions (month) 2000 Ib 379.5 scf Each Compressor Unit Conversion ( ton ) x ( lbmol ) Where: EF = Compressor Blowdown Event Emission Factor, scf/event E = Compressor Slowdown Events, events/month MW = Slowdown Gas Molecular Weight, lb/Ibmol xG = Slowdown Gas VOC or HAP Content, mass fraction Monthly VOC emissions shall be used in a twelve month rolling total to monitor compliance with the annual limitation. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 8.1.2 Annual emissions of Hazardous Air Pollutants (HAP), for the purposes of APEN reporting and the payment of annual fees, shall be calculated using HAP emissions derived from the same method as required for VOC emissions, except that the HAP content obtained from the most recent extended gas analysis, as required by Condition 8.3, shall be input to the equation above. 8.2 Blowdown Event Limitations & Compliance Monitoring The number of blowdowns from each compressor shall not exceed the limitation listed in Summary Table 8 above (Colorado Construction Permit 19WE0094, as provided for under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3, Part C, Section I.A.7 and Part C, Section III.B.7., based on requested limitations identified on the APEN submitted on 10/30/2020). The compressor facility identifier and the date of each blowdown event for that compressor shall be recorded in a log to be made available to the Division upon request. The monthly blowdown events for each compressor shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. The monthly blowdown events for each compressor shall be used to monitor compliance with the VOC emission limitation, as required by Condition 8.1. 8.3 Extended Gas Analysis An extended gas analysis of a gas representative of the blowdown emissions shall be performed annually, according to appropriate ASTM methods or equivalent, if approved in advance by the Division (Colorado Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 126 Construction Permit 19WE0094). At least eight (8) months shall separate sequential sampling events. Results of each analysis shall be maintained and made available to the Division upon request. The VOC content and molecular weight indicated by the most recent analysis shall be used to monitor compliance with the VOC emission limitation, as required by Condition 8.1. 8.4 Reasonably Available Control Technology (RACT) The reciprocating compressor blowdown point is subject to Reasonably Available Control Technology (RACT) (Colorado Regulation No. 3, Part B, Section III.D.2.a.). RACT for these reciprocating compressor blowdowns has been determined to be good work practices. Good work practices shall be performed during each blowdown event to minimize emissions, unless it is determined to be unsafe to perform such a work practice (Colorado Construction Permit 19WE0094, as modified under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3, Part C, Section I.A.7 and Part C, Section III.B.7). Records of the good work practices used during each blowdown event, as well as an explanation of infeasibility if good work practices were not used, shall be maintained and made available to the Division upon request. 8.5 Final Approval Requirements The operator shall complete the following initial compliance testing and sampling (Colorado Construction Permit 19WE0094): 8.5.1 The owner or operator shall complete the initial extended gas analysis of the natural gas vented from this emissions unit within one hundred and eighty days (180) of permit issuance. Results of all initial testing required by this condition shall be submitted with the first semi-annual report due after the initial testing was conducted. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 127 9. HAP Emission Limitations for the Stabilized Condensate Storage Tanks, AIRS ID: 063, Produced Water Storage Tanks, AIRS ID: 075 and TEG Dehydration Unit, AIRS ID: 068 or 077 Parameter Permit Condition Number Limitations Compliance Emission Factor Monitoring Monthly Annual Method Interval For AIRS 063, 075 & 068 only: HAP 9.1 Individual: 1,359 lb/month Total: 3,398 lb/month Individual: 8 tons/year Total: 20 tons/year For AIRS 063, 075 & 077 only: HAP 9.2 Individual: 8 tons/year Total: 20 tons/year Recordkeeping and Twelve Month Rolling Total Calculation Monthly 9.1 HAP Emission Limitations & Compliance Monitoring for AIRS 063, AIRS 075 & AIRS 068 Emissions of Hazardous Air Pollutants (HAP) from the Stabilized Condensate Storage Tanks (AIRS 063), Produced Water Storage Tanks (AIRS 075) and TEG Dehydration Unit D-2 (AIRS 068) shall not exceed the annual limitations listed in Summary Table 9 above. Compliance with the emission limitations shall be monitored as follows: 9.1.1 Monthly emission calculations shall be completed for each HAP with uncontrolled actual emissions above the de minimis reporting level (per individual emission unit), as defined in Colorado Regulation No. 3 Appendix A. Calculations for the dehydration unit, condensate storage tanks and produced water storage tanks shall be conducted using the methodology required by Conditions 3.1, 6.1 and 7.1. 9.1.2 Facility -wide emissions for an individual HAP shall be the sum total emissions of that HAP from the dehydration unit, condensate storage tanks and produced water storage tanks combined for which uncontrolled actual emissions of that HAP are above the de minimis reporting threshold. Monthly emissions of each HAP shall be used in a twelve month rolling total to monitor compliance with the individual HAP annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 9.1.3 Facility -wide emissions for total HAP shall be the sum total of all HAP emitted from the dehydration unit, condensate storage tanks and produced water storage tanks combined for which uncontrolled actual emissions are above the de minimis reporting threshold. Monthly emissions of total HAP shall be used in a twelve month rolling total to monitor compliance with the total HAP annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 128 This Condition 9.1 only shall apply to the Stabilized Condensate Storage Tanks (AIRS 063), Produced Water Storage Tanks (AIRS 075) and TEG Dehydration Unit D-2 (AIRS 068) until TEG Dehydration Unit D-3 (AIRS 077) commences operation, after which compliance with this Condition 9.1 is no longer required and Condition 9.2 only shall apply. 9.2 HAP Emission Limitations & Compliance Monitoring for AIRS 063, AIRS 075 & AIRS 077 Emissions of Hazardous Air Pollutants (HAP) from the Stabilized Condensate Storage Tanks (AIRS 063), Produced Water Storage Tanks (AIRS 075) and TEG Dehydration Unit D-3 (AIRS 077) shall not exceed the annual limitations listed in Summary Table 9 above. During the first twelve months of TEG dehydration unit D-3 operation, compliance with both the monthly and annual limitations are required. After the first twelve months of operation, compliance with only the annual limitation is required. Compliance with the emission limitations shall be monitored as follows: 9.2.1 Monthly emission calculations shall be completed for each HAP with uncontrolled actual emissions above the de minimis reporting level (per each individual emission unit), as defined in Colorado Regulation No. 3 Appendix A. Calculations for the dehydration unit, condensate storage tanks and produced water storage tanks shall be conducted using the methodology required by Conditions 4.1, 6.1, and 7.1. 9.2.2 Facility -wide emissions for an individual HAP shall be the sum total emissions of that HAP from the dehydration unit, condensate storage tanks and produced water storage tanks combined for which uncontrolled actual emissions of that HAP are above the de minimis reporting threshold. Monthly emissions of each HAP shall be used in a twelve month rolling total to monitor compliance with the individual HAP limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 9.2.3 Facility -wide emissions for total HAP shall be the sum total of all HAP emitted from the dehydration unit, condensate storage tanks and produced water storage tanks combined for which uncontrolled actual emissions are above the de minimis reporting threshold. Monthly emissions of total HAP shall be used in a twelve month rolling total to monitor compliance with the total HAP limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. This Condition 9.2 only shall apply to the Stabilized Condensate Storage Tanks (AIRS 063), Produced Water Storage Tanks (AIRS 075) and TEG Dehydration Unit D-3 (AIRS 077) upon commencement of operation of TEG Dehydration Unit D-3 (AIRS 077). Compliance with this Condition 9.2 is not required until TEG Dehydration Unit D-3 (AIRS 077) commences operation, after which Condition 9.1 shall no longer apply. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 129 10. Facility -Wide Requirements 10.1 The project permitted under Colorado Construction Permit 19WE0492, Issuance 1 avoided major New Source Review (NSR) permitting requirements and is potentially subject to the relaxation provisions of Colorado Regulation No. 3, Part D, Section V.A.7.b. The emission units associated with this project include the stabilized condensate storage tanks (AIRS 063), stabilized condensate loadout (AIRS 066), produced water storage tanks (AIRS 075), TEG dehydration unit D-3 (AIRS 077), and the reboiler associated with TEG dehydration unit D-3 (insignificant activity). Major NSR applicability details for this project are included in the Technical Review Document (TRD) associated with the March 1, 2021 issuance of this permit (Colorado Construction Permit 19WE0492). 10.2 Colorado Regulation No. 7, Part D, Section I.C. Requirements: This facility is subject to the following "General Provisions" of Colorado Regulation No. 7, Part D, Section I, "Volatile Organic Compound Emissions from Oil and Gas Operations": Conditions shown in italic text below represent monitoring, recordkeeping and recording provisions that are not included in Colorado Regulation No. 7 as of the issuance date of this permit, but are being included as per Colorado Regulation No 3, Part C, Section V.C.5.b. 10.2.1 All air pollution control equipment used to demonstrate compliance with this Section I. must be operated and maintained consistent with manufacturer specifications and good engineering and maintenance practices. The owner or operator must keep manufacturer specifications on file. In addition, all such air pollution control equipment must be adequately designed and sized to achieve the control efficiency rates required by this Section I. and to handle reasonably foreseeable fluctuations in emissions of volatile organic compounds. Fluctuations in emissions that occur when the separator dumps into the tank are reasonably foreseeable (Colorado Regulation No. 7, Part D, Section I.C.I.a.). 10.2.2 All hydrocarbon liquids and produced water collection, storage, processing, and handling operations, regardless of size, must be designed, operated, and maintained so as to minimize emission of volatile organic compounds to the atmosphere to the maximum extent practicable (Colorado Regulation No. 7, Part D, Section I.C.1.b.). 10.3 Colorado Regulation No. 7, Part D, Section I.J. Requirements: Each compressor is subject to the following "Compressor Requirements" of Colorado Regulation No. 7, Part D, Section I, "Volatile Organic Compound Emissions from Oil and Gas Operations": Conditions shown in italic text below represent monitoring, recordkeeping and recording provisions that are not included in Colorado Regulation No. 7 as of the issuance date of this permit, but are being included as per Colorado Regulation No 3, Part C, Section V.C.5.b. Part D, Section I.J. Emission Control Requirements Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 130 10.3.1 Beginning January 1, 2018, the rod packing on reciprocating compressors located between the wellhead and the point of custody transfer to the natural gas transmission and storage segment must be replaced every 26,000 hours of operation or every thirty six (36) months (Colorado Regulation No. 7, Part D, Section I.J.2.a.). Part D, Section I.J. Recordkeeping Requirements 10.3.2 Owners or operators must maintain the following records for at least five (5) years and make records available to the Division upon request (Colorado Regulation No. 7, Part D, Section I.J.2.c.(i)): 10.3.2.1 Identification of each reciprocating compressor (Colorado Regulation No. 7, Part D, Section I.J.2.c.(i)(A)). 10.3,2.2 The hours of operation or the number of months since the previous rod packing replacement (Colorado Regulation No. 7, Part D, Section I.J.2.c.(i)(B)). 10.3.2.3 The date of each rod packing replacement, or date of installation of a rod packing emissions collection system and closed vent system (Colorado Regulation No. 7, Part D, Section I.J.2.c.(i)(C)). Part D, Section I.J. Alternate Compliance Option 10.3.3 As an alternative to the emission control, inspection, repair, and recordkeeping provisions described in Sections I.J.2.a. (Condition 10.3.1) through I.J.2.c. (Condition 10.3.2), the owner or operator may comply with reciprocating compressor emission control, monitoring, recordkeeping, and reporting requirements of a New Source Performance Standard in 40 CFR Part 60 (Colorado Regulation No. 7, Part D, Section I.J.2.e.). 10.4 Colorado Regulation No. 7, Part D, Section I.L. Requirements: This facility is subject to the following "Leak detection and repair program for well production facilities and natural gas compressor stations located in the 8 -hour Ozone Control Area" of Colorado Regulation No. 7, Part D, Section I, "Volatile Organic Compound Emissions from Oil and Gas Operations": Conditions shown in italic text below represent monitoring, recordkeeping and recording provisions that are not included in Colorado Regulation No. 7 as of the issuance date of this permit, but are being included as per Colorado Regulation No 3, Part C, Section V.C.5.b. 10.4.1 Beginning June 30, 2018, owners or operators of natural gas compressor stations must inspect components for leaks using an approved instrument monitoring method at least quarterly (Colorado Regulation No. 7, Part D, Section I.L.1.a). 10.4.2 If a component is unsafe, difficult, or inaccessible to monitor, the owner or operator is not required to monitor the component until it becomes feasible to do so (Colorado Regulation No. 7, Part D, Section I.L.3.). Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 131 10.4.2.1 Difficult to monitor components are those that cannot be monitored without elevating the monitoring personnel more than two (2) meters above a supported surface or are unable to be reached via a wheeled scissor -lift or hydraulic type scaffold that allows access to components up to 7.6 meters (25 feet) above the ground (Colorado Regulation No. 7, Part D, Section I.L.3.a.). 10.4.2.2 Unsafe to monitor components are those that cannot be monitored without exposing monitoring personnel to an immediate danger as a consequence of completing the monitoring (Colorado Regulation No. 7, Part D, Section I.L.3.b.). 10.4.2.3 Inaccessible to monitor components are those that are buried, insulated, or obstructed by equipment or piping that prevents access to the components by monitoring personnel (Colorado Regulation No. 7, Part D, Section I.L.3.c.). 10.4.3 Leaks requiring repair: Only leaks from components exceeding the thresholds in this Section I.L.4. require repair under Section I.L.5 (Condition 10.4.4) (Colorado Regulation No. 7, Part D, Section I.L.4.). 10.4.3.1 For EPA Method 21 monitoring, repair is required for leaks with any concentration of hydrocarbon above 500 ppm not associated with normal equipment operation, such as pneumatic device actuation and crank case ventilation (Colorado Regulation No. 7, Part D, Section I.L.4.a.). 10.4.3.2 For infra -red camera monitoring, repair is required for leaks with any detectable emissions not associated with normal equipment operation, such as pneumatic device actuation and crank case ventilation (Colorado Regulation No. 7, Part D, Section I.L.4.b.). 10.4.3.3 For other approved instrument monitoring methods or programs, leak identification requiring repair will be established as set forth in an approval under Section I.L.8 (Condition 10.4.7) (Colorado Regulation No. 7, Part D, Section I.L.4.c.). 10.4.3.4 For leaks identified using an approved non -quantitative instrument monitoring method, owners or operators have the option of either repairing the leak in accordance with the repair schedule set forth in Section I.L.5. (Condition 10.4.4) or conducting follow-up monitoring using EPA Method 21 within five (5) working days of the leak detection. If the follow-up EPA Method 21 monitoring shows that the emission is a leak requiring repair as set forth in Section I.L.4.a. (Condition 10.4.3.1) the leak must be repaired and remonitored in accordance with Section I.L.5 (Condition 10.4.4) (Colorado Regulation No. 7, Part D, Section I.L.4.d.). 10.4.3.5 Owners or operators must maintain and operate approved nonquantitative instrument monitoring methods according to manufacturer recommendations (Colorado Regulation No. 7, Part D, Section I.L.4.e.). 10.4.4 Repair and remonitoring (Colorado Regulation No. 7, Part D, Section I.L.5.) 10.4.4.1 First attempt to repair a leak must be made no later than five (5) working days after Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 132 discovery and completed no later than thirty (30) working days after discovery, unless parts are unavailable, the equipment requires shutdown to complete repair, or other good cause exists (Colorado Regulation No. 7, Part D, Section I.L.5.a.). a. If parts are unavailable, they must be ordered promptly and the repair must be made within fifteen (15) working days of receipt of the parts (Colorado Regulation No. 7, Part D, Section I.L.5.a.(i)). b. If shutdown is required, a repair attempt must be made during the next scheduled shutdown and final repair completed within two (2) years after discovery (Colorado Regulation No. 7, Part D, Section I.L.5.a.(ii)). c. If delay is attributable to other good cause, repairs must be completed within fifteen (15) working days after the cause of delay ceases to exist (Colorado Regulation No. 7, Part D, Section I.L.5.a.(iii)). 10.4.4.2 Within fifteen (15) working days of completion of a repair the leak must be remonitored using an approved instrument monitoring method to verify that the repair was effective (Colorado Regulation No. 7, Part D, Section I.L.5.b.). 10.4.4.3 Leaks discovered pursuant to the leak detection methods of Section I.L.4. (Condition 10.4.3) are not subject to enforcement by the Division unless the owner or operator fails to perform the required repairs in accordance with Section I.L.5. (Condition 10.4.4) or keep required records in accordance with Section I.L.6 (Condition 10.4.5) (Colorado Regulation No. 7, Part D, Section I.L.5.c.). 10.4.5 Recordkeeping (Colorado Regulation No. 7, Part D, Section I.L.6.) 10.4.5.1 Documentation of the initial approved instrument monitoring method inspection for well production facilities and natural gas compressor stations (Colorado Regulation No. 7, Part D, Section I.L.6.a.); 10.4.5.2 The date, facility name, and facility AIRS ID or facility location if the facility does not have an AIRS ID for each inspection (Colorado Regulation No. 7, Part D, Section I.L.6.b.); 10.4.5.3 A list of the leaks requiring repair and the monitoring method(s) used to determine the presence of the leak (Colorado Regulation No. 7, Part D, Section I.L.6.c.); 10.4.5.4 The date of first attempt to repair the leak and, if necessary, any additional attempt to repair (Colorado Regulation No. 7, Part D, Section I.L.6.d.); 10.4.5.5 The date the leak was repaired and type of repair method applied (Colorado Regulation No. 7, Part D, Section I.L.6.e.); 10.4.5.6 The delayed repair list, including the date and duration of any period where the repair of a leak was delayed due to unavailable parts, required shutdown, or delay for other good cause, the basis for the delay, and the schedule for repairing the leak. Delay of repair beyond thirty (30) days after initial discovery due to unavailable parts must be reviewed, and a record kept of that review, by a representative of the owner or operator Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 133 with responsibility for leak detection and repair compliance functions. This review will not be made by the individual making the initial determination to place a part on the delayed repair list (Colorado Regulation No. 7, Part D, Section I.L.6.f.); 10.4.5.7 The date the leak was remonitored and the results of the remonitoring (Colorado Regulation No. 7, Part D, Section I.L.6.g.); and 10.4.5.8 A list of components that are designated as unsafe, difficult, or inaccessible to monitor, as described in Section I.L.3. (Condition 10.4.2), an explanation stating why the component is so designated, and the schedule for monitoring such component(s) (Colorado Regulation No. 7, Part D, Section I.L.6.h.). 10.4,5.9 Records must be maintained for a minimum of five years and made available to the Division upon request (Colorado Regulation No. 7, Part D, Section I.L.6.i.). 10.4.5.10 [Additional Monitoring: The owner or operator shall maintain records that document the categories of equipment operation that may result in emissions but are not considered to be leaks under Colorado Regulation No. 7, Part D, Section I.L.4. (Condition 10.4.3) because they qualify as "normal equipment operation ". This requirement shall not apply to pneumatic device actuation and crankcase ventilation, which are already explicitly defined in the rule as normal equipment operation. The records shall include a description of each category or type of "normal equipment operation" and a description of the component or equipment type associated with that category.] 10.4.6 Reporting: The owner or operator of each facility subject to the leak detection and repair requirements in Section I.L. (Condition 10.4) must submit a single annual report on or before May 31st of each year (beginning May 31st, 2019) that includes, at a minimum, the following information regarding leak detection and repair activities at their subject facilities conducted the previous calendar year (Colorado Regulation No. 7, Part D, Section I.L.7.): 10.4.6.1 The total number of well production facilities and total number of natural gas compressor stations inspected (Colorado Regulation No. 7, Part D, Section I.L.7.a.); 10.4.6.2 The total number of inspections performed per inspection frequency tier of well production facilities and the total number of inspections performed at natural gas compressor stations (Colorado Regulation No. 7, Part D, Section I.L.7.b.); 10.4.6.3 The total number of identified leaks requiring repair broken out by component type, monitoring method, and inspection frequency tier of well production facility as reported in Section I.L.7.b. (Condition 10.4.6.2) and the total number of identified leaks requiring repair at natural gas compressor stations broken out by component type and monitoring method (Colorado Regulation No. 7, Part D, Section I.L.7.c.); 10.4.6.4 The total number of leaks repaired for each inspection frequency tier of well production facilities as reported in Section I.L.7.b. (Condition 10.4.6.2) and the total number of leaks repaired for natural gas compressor stations (Colorado Regulation No. 7, Part D, Section I.L.7.d.); Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 134 10.4.6.5 The total number of leaks on the delayed repair list as of December 31st broken out by component type, inspection frequency tier of well production facility as reported in Section I.L.7.b. (Condition 10.4.6.2) or natural gas compressor station, and the basis for each delay of repair (Colorado Regulation No. 7, Part D, Section I.L.7.e.); 10.4.6.6 The record of all reviews conducted for delayed repairs due to unavailable parts extending beyond 30 days for the previous calendar year (Colorado Regulation No. 7, Part D, Section I.L.7.f.); and 10.4.6.7 Each report shall be accompanied by a certification by a responsible official that, based on information and belief formed after reasonable inquiry, the statements and information in the document are true, accurate, and complete (Colorado Regulation No. 7, Part D, Section I.L.7.g.). 10.4.7 Alternative approved instrument monitoring methods may be used in lieu of, or in combination with an infra -red camera, EPA Method 21, or other approved instrument monitoring method to inspect for leaks as required by Section I.L. (Condition 10.4), if the following conditions are met (Colorado Regulation No. 7, Part D, Section I.L.8.): 10.4.7.1 The proponent of the alternative approved instrument monitoring method applies for a determination of an alternative approved instrument monitoring method or program. The application must include, at a minimum, the following (Colorado Regulation No. 7, Part D, Section I.L.8.a.): a. The proposed alternative approved instrument monitoring method manufacturer information (Colorado Regulation No. 7, Part D, Section I.L.8.a.(i)); b. A description of the proposed alternative approved instrument monitoring method including, but not limited to (Colorado Regulation No. 7, Part D, Section I.L.8.a.(ii)): (i) Whether the proposed alternative approved instrument monitoring method is a quantitative detection method, and how emissions are quantified, or qualitative leak detection method (Colorado Regulation No. 7, Part D, Section I.L.8.a.(ii)(A)); (ii) Whether the proposed alternative approved instrument monitoring method is commercially available (Colorado Regulation No. 7, Part D, Section I.L.8.a.(ii)(B)); (iii) Whether the proposed alternative approved instrument monitoring method is approved by other regulatory authorities and for what application (e.g., pipeline monitoring, emissions detected) (Colorado Regulation No. 7, Part D, Section I.L.8.a.(ii)(C)); (iv) The leak detection capabilities, reliability, and limitations of the proposed alternative approved instrument monitoring method, including, but not limited to, the ability to identify specific leaks or Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 135 locations, detection limits, and any restrictions on use, as well as supporting data (Colorado Regulation No. 7, Part D, Section I.L.8.a.(ii)(D)); (v) The frequency of measurements and data logging capabilities of the proposed alternative approved instrument monitoring method (Colorado Regulation No. 7, Part D, Section I.L.8.a.(ii)(E)); (vi) Data quality indicators for precision and bias of the proposed alternative approved instrument monitoring method (Colorado Regulation No. 7, Part D, Section I.L.8.a.(ii)(F)); (vii) Quality control and quality assurance procedures necessary to ensure proper operation of the proposed alternative approved instrument monitoring method (Colorado Regulation No. 7, Part D, Section I.L.8.a.(ii)(G)); (viii) A description of where, when, and how the proposed alternative approved instrument monitoring method will be used (Colorado Regulation No. 7, Part D, Section I.L.8.a.(ii)(H)); and (ix) Documentation (e.g., field or test data, modeling) adequate to demonstrate the proposed alternative approved instrument monitoring method or program is capable of achieving emission reductions that are at least as effective as the emission reductions achieved by the leak detection and repair provisions in Section I.L. (Condition 10.4) (Colorado Regulation No. 7, Part D, Section I.L.8.a.(ii)(I)) c. The Division will transmit a copy of the complete application and any other materials provided by the applicant to EPA (Colorado Regulation No. 7, Part D, Section I.L.8.a.(iii)). d. Public notice of the application is provided pursuant to Regulation Number 3, Part B, Section III.C.4 (Colorado Regulation No. 7, Part D, Section I.L.8.a.(iv)). e. The Division and the EPA approves the proposal. The Division will transmit a copy of the application and any other materials provided by the applicant, all public comments, all Division responses and the Division's approval to EPA Region 8. If EPA fails to approve or disapprove the proposal within six (6) months of receipt of these materials, EPA will be deemed to have approved the proposal (Colorado Regulation No. 7, Part D, Section I.L.8.a.(v)). 10.5 [State -Only Enforceable] Colorado Regulation No. 7, Part D, Section II.B. Requirements This facility is subject to the following State -Only Enforceable "General Provisions" of Colorado Regulation No. 7, Part D, Section II, "Statewide Controls for Oil and Gas Operations": Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 136 Conditions shown in italic text below represent monitoring, recordkeeping and recording provisions that are not included in Colorado Regulation No. 7 as of the issuance date of this permit, but are being included as per Colorado Regulation No 3, Part C, Section V.C.5.b. Part D, Section II.B. General Requirements 10.5.1 All hydrocarbon liquids and produced water collection, storage, processing, and handling operations, regardless of size, must be designed, operated, and maintained so as to minimize emission of VOCs and other hydrocarbons to the atmosphere to the extent reasonably practicable (Colorado Regulation No. 7, Part D, Section II.B.1.a.). 10.5.2 At all times, including periods of start-up and shutdown, the facility and air pollution control equipment must be maintained and operated in a manner consistent with good air pollution control practices for minimizing emissions. Determination of whether or not acceptable operation and maintenance procedures are being used will be based on information available to the Division, which may include, but is not limited to, monitoring results, opacity observations, review of operation and maintenance procedures, and inspection of the source (Colorado Regulation No. 7, Part D, Section II.B.1.b.). Part D, Section II.B. General Requirements for Air Pollution Control Equipment 10.5.3 All air pollution control equipment must be operated and maintained pursuant to the manufacturing specifications or equivalent to the extent practicable, and consistent with technological limitations and good engineering and maintenance practices. The owner or operator must keep manufacturer specifications or equivalent on file. In addition, all such air pollution control equipment must be adequately designed and sized to achieve the control efficiency rates and to handle reasonably foreseeable fluctuations in emissions of VOCs and other hydrocarbons during normal operations. Fluctuations in emissions that occur when the separator dumps into the tank are reasonably foreseeable (Colorado Regulation No. 7, Part D, Section II.B.2.a.). 10.5.4 If a combustion device is used to control emissions of VOCs and other hydrocarbons, it must be enclosed, have no visible emissions during normal operation, and be designed so that an observer can, by means of visual observation from the outside of the enclosed combustion device, or by other means approved by the Division, determine whether it is operating properly (Colorado Regulation No. 7, Part D, Section II.B.2.b.). 10.5.5 Auto -igniters: All combustion devices used to control emissions of hydrocarbons must be equipped with and operate an auto -igniter as follows (Colorado Regulation No. 7, Part D, Section II.B.2.d.): 10.5.5.1 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 (Colorado Regulation No. 7, Part D, Section Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 137 II.B.2.d.(ii)). Part D, Section II.B.3. Requirements for Compressor Seals and Open -Ended Valves or Lines 10.5.6 Beginning January 1, 2015, each open-ended valve or line at well production facilities and natural gas compressor stations must be equipped with a cap, blind flange, plug, or a second valve that seals the open end at all times except during operations requiring process fluid flow through the open-ended valve or line. Open-ended valves or lines in an emergency shutdown system which are designed to open automatically in the event of a process upset are exempt from the requirement to seal the open end of the valve or line. Alternatively, an open-ended valve or line may be treated as if it is a "component" as defined in Section II.A.6., and may be monitored under the provisions of Section II.E (Condition 10.6) (Colorado Regulation No. 7, Part D, Section II.B.3.a.). [Compliance Monitoring: The owner or operator of affected operations shall maintain records documenting the location of each open-ended valve or line and whether each is: (1) capped, blind flanged, plugged or equipped with a second valve, (2) exempt due to location in an emergency shutdown system, or (3) treated as a "component" and subject to the Leak Detection and Repair Program requirements in Condition 10.6. These records shall be updated on an annual basis. Such records shall be maintained and made available for Division review.] 10.5.7 Beginning January 1, 2015, the rod packing on any reciprocating compressor located at a natural gas compressor station must be replaced every 26,000 hours of operation or every thirty six (36) months, unless the reciprocating compressor is subject to 40 CFR Part 60, Subpart OOOO on that date or thereafter. The measurement of accumulated hours of operation (26,000) or months elapsed (36) begins on January 1, 2015 (Colorado Regulation No. 7, Part D, Section II.B.3.c.). [Compliance Monitoring: The owner or operator shall record: 10.5.7.1 The number of hours of operation for each reciprocating compressor on a monthly basis and maintain a total of hours of operation for each reciprocating compressor since initial startup, January 1, 2015, or the date of the most recent reciprocating compressor rod packing replacement, whichever is later; OR 10.5.7.2 The number of months since initial startup, January 1, 2015, or the date of the most recent reciprocating compressor rod packing replacement, whichever is later. The records required in Conditions 10.5.7.1 and 10.5.7.2 above shall be maintained and made available to the Division upon request.] 10.6 [State -Only Enforceable] Colorado Regulation No. 7, Part D, Section II.E. Requirements: Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 138 This facility is subject to the following "Leak Detection and Repair Program for Well Production Facilities and Natural Gas Compressor Stations" of Colorado Regulation No. 7, Part D, Section II "Statewide Controls for Oil and Gas Operations": Conditions shown in italic text below represent monitoring, recordkeeping and recording provisions that are not included in Colorado Regulation No. 7 as of the issuance date ofthis permit, but are being included as per Colorado Regulation No 3, Part C, Section V.C.5.b. 10.6.1 Owners or operators of well production facilities or natural gas compressor stations that monitor components as part of Section II.E. (Condition 10.6) may estimate uncontrolled actual emissions from components for the purpose of evaluating the applicability of component fugitive emissions to Regulation Number 3 by utilizing the emission factors defined as less than 10,000 ppmv of Table 2-8 of the 1995 EPA Protocol for Equipment Leak Emission Estimates (Document EPA - 453/R -95-017). (Colorado Regulation No. 7, Part D, Section II.E.2.). 10.6.2 Beginning January 1, 2015, owners or operators of natural gas compressor stations must inspect components for leaks using an approved instrument monitoring method, in accordance with the following schedule (Colorado Regulation No. 7, Part D, Section II.E.3.): [Clarification: For the purposes of this condition, approved instrument monitoring method means an infra -red camera or EPA Method 21.] 10.6.2.1 Approved instrument monitoring method inspections must begin within ninety (90) days after January 1, 2015, or the date the natural gas compressor station commences operation if such date is after January 1, 2015, for natural gas compressor stations with fugitive VOC emissions greater than zero (0) but less than or equal to fifty (50) tons per year, based on a rolling twelve-month total (Colorado Regulation No. 7, Part D, Section II.E.3.a.). a. Annual approved instrument monitoring method inspections at natural gas compressor stations with fugitive VOC emissions greater than zero (0) but less than or equal to twelve (12) tons per year, based on a rolling twelve-month total, must begin within ninety (90) days after January 1, 2015, or the date the natural gas compressor station commences operation if such date is after January 1, 2015. Annual inspections must be conducted through calendar year 2019 (Colorado Regulation No. 7, Part D, Section II.E.3.a.(i)). b. Beginning calendar year 2020, owners or operators of natural gas compressor stations with fugitive VOC emissions greater than zero (0) but less than or equal to twelve (12) tons per year, based on a rolling twelve-month total, must conduct semi-annual approved instrument monitoring method inspections (Colorado Regulation No. 7, Part D, Section II.E.3.a.(ii)). 10.6.2,2 Following the first approved instrument monitoring method inspection, owners or operators must continue conducting approved instrument monitoring method inspections in accordance with the Inspection Frequency in Table 2 (Colorado Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 139 Regulation No. 7, Part D, Section II.E.3.c.): Table 2 — Natural Gas Compressor Station Component Inspections Fugitive VOC Emissions (rolling twelve-month tpy) Inspection Frequency > 0 and < 12 Semi -Annually > 12 and < 50 Quarterly > 50 Monthly 10.6.2.3 For purposes of Section II.E.3. (Condition 10.6.2), fugitive emissions must be calculated using the emission factors of Table 2-4 of the 1995 EPA Protocol for Equipment Leak Emission Estimates (Document EPA -453/R-95-017), or other Division approved method (Colorado Regulation No. 7, Part D, Section II.E.3.d.). 10.6.3 If a component is unsafe, difficult, or inaccessible to monitor, the owner or operator is not required to monitor the component until it becomes feasible to do so (Colorado Regulation No. 7, Part D, Section II.E.5.). 10.6.3.1 Difficult to monitor components are those that cannot be monitored without elevating the monitoring personnel more than two (2) meters above a supported surface or are unable to be reached via a wheeled scissor -lift or hydraulic type scaffold that allows access to components up to 7.6 meters (25 feet) above the ground (Colorado Regulation No. 7, Part D, Section II.E.5.a.). 10.6.3.2 Unsafe to monitor components are those that cannot be monitored without exposing monitoring personnel to an immediate danger as a consequence of completing the monitoring (Colorado Regulation No. 7, Part D, Section II.E.5.b.). 10.6.3.3 Inaccessible to monitor components are those that are buried, insulated, or obstructed by equipment or piping that prevents access to the components by monitoring personnel (Colorado Regulation No. 7, Part D, Section II.E.5.c.). 10.6.4 Leaks requiring repair: Leaks must be identified utilizing the methods listed in Section II.E.6. (Conditions 10.6.4.1 through 10.6.4.3 below). Only leaks from components exceeding the thresholds in Section II.E.6. (Conditions 10.6.4.1 through 10.6.4.3 below) require repair under Section II.E.7. (Condition 10.6.5) (Colorado Regulation No. 7, Part D, Section II.E.6.). 10.6.4.1 For EPA Method 21 monitoring, at facilities constructed before May 1, 2014, repair is required for leaks with any concentration of hydrocarbon above 2,000 parts per million (ppm) not associated with normal equipment operation, such as pneumatic device actuation and crank case ventilation (Colorado Regulation No. 7, Part D, Section II.E.6.a., except for requirements that apply only to well production facilities). 10.6.4.2 For infra -red camera monitoring, repair is required for leaks with any detectable emissions not associated with normal equipment operation, such as pneumatic device Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 140 actuation and crank case ventilation (Colorado Regulation No. 7, Part D, Section II.E.6.c., except for requirements associated with AVO monitoring, which only apply to well production facilities). 10.6.4.3 For leaks identified using an approved non -quantitative instrument monitoring method, owners or operators have the option of either repairing the leak in accordance with the repair schedule set forth in Section II.E.7. (Condition 10.6.5) or conducting follow-up monitoring using EPA Method 21 within five (5) working days of the leak detection. If the follow-up EPA Method 21 monitoring shows that the emission is a leak requiring repair as set forth in Section II.E.6. (this Condition 10.6.4), the leak must be repaired and remonitored in accordance with Section II.E.7. (Condition 10.6.5). (Colorado Regulation No. 7, Part D, Section II.E.6.e., except for requirements that apply only to well production facilities). 10.6.5 Repair and remonitoring (Colorado Regulation No. 7, Part D, Section II.E.7.): 10.6.5.1 First attempt to repair a leak must be made no later than five (5) working days after discovery and repair of a leak discovered on or after January 1, 2018, completed no later than thirty (30) working days after discovery, unless parts are unavailable, the equipment requires shutdown to complete repair, or other good cause exists (Colorado Regulation No. 7, Part D, Section II.E.7.a.). a. If parts are unavailable, they must be ordered promptly and the repair must be made within fifteen (15) working days of receipt of the parts (Colorado Regulation No. 7, Part D, Section II.E.7.a.(i)). b. If shutdown is required, a repair attempt must be made during the next scheduled shutdown and final repair completed within two (2) years after discovery (Colorado Regulation No. 7, Part D, Section II.E.7.a.(ii)). c. If delay is attributable to other good cause, repairs must be completed within fifteen (15) working days after the cause of delay ceases to exist (Colorado Regulation No. 7, Part D, Section II.E.7.a.(iii)). 10.6.5.2 Within fifteen (15) working days of completion of a repair, the leak must be remonitored using an approved instrument monitoring method to verify that the repair was effective (Colorado Regulation No. 7, Part D, Section II.E.7.b.). 10.6.5.3 Leaks discovered pursuant to the leak detection methods of Section II.E.6. (Condition 10.6.4) are not subject to enforcement by the Division unless the owner or operator fails to perform the required repairs in accordance with Section II.E.7. (this Condition 10.6.5) or keep required records in accordance with Section II.E.8. (Condition 10.6.6). (Colorado Regulation No. 7, Part D, Section II.E.7.c.). 10.6.6 Recordkeeping: The owner or operator of each facility subject to the leak detection and repair requirements in Section II.E. (Condition 10.6) must maintain the following records and make them available to the Division upon request (Colorado Regulation No. 7, Part D, Section II.E.8.): Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 141 [Clarification: Note that in accordance with the requirements in Section IV, Conditions 22.b and 22. c records shall be kept for a period of five years.] 10.6.6.1 The date, facility name, and facility AIRS ID or facility location if the facility does not have an AIRS ID for each inspection (Colorado Regulation No. 7, Part D, Section II.E.8.b.); 10.6.6.2 A list of the leaking components requiring repair and the monitoring method(s) used to determine the presence of the leak (Colorado Regulation No. 7, Part D, Section II.E.8.c.); 10.6.6.3 The date of first attempt to repair the leak and, if necessary, any additional attempt to repair the leak (Colorado Regulation No. 7, Part D, Section II.E.8.d.); 10.6.6.4 The date the leak was repaired and for leaks discovered and repaired on or after January 1, 2018, the type of repair method applied (Colorado Regulation No. 7, Part D, Section II.E.8.e.); 10.6.6.5 The delayed repair list, including the basis for placing leaks on the list (Colorado Regulation No. 7, Part D, Section II.E.8.f.); 10.6.6.6 For leaks discovered on or after January 1, 2018, the delayed repair list must include the date and duration of any period where the repair of a leak was delayed due to unavailable parts, required shutdown, or delay for other good cause, the basis for the delay, and the schedule for repairing the leak. Delay of repair beyond thirty (30) days after initial discovery due to unavailable parts must be reviewed, and a record kept of that review, by a representative of the owner or operator with responsibility for leak detection and repair compliance functions. This review will not be made by the individual making the initial determination to place a part on the delayed repair list; (Colorado Regulation No. 7, Part D, Section II.E.8.g.); 10.6.6.7 The date the leak was remonitored and the results of the remonitoring (Colorado Regulation No. 7, Part D, Section II.E.8.h.); and 10.6.6.8 A list of components that are designated as unsafe, difficult, or inaccessible to monitor, as described in Section II.E.5. (Condition 10.6.3), an explanation stating why the component is so designated, and the schedule for monitoring such component(s) (Colorado Regulation No. 7, Part D, Section II.E.8.i.). 10.6.7 [Additional Monitoring: The owner or operator shall maintain records that document the categories of equipment operation that may result in emissions but are not considered to be leaks under Colorado Regulation No. 7, Part D, Section II.E. 6. (Condition 10.6.4) because they qualify as "normal equipment operation ". This requirement shall not apply to pneumatic device actuation and crankcase ventilation, which are already explicitly defined in the rule as normal equipment operation. The records shall include a description of each category or type of "normal equipment operation" and a description of the component or equipment type associated with that category.] Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 142 10.6.8 Reporting: The owner or operator of each facility subject to the leak detection and repair requirements in Section II.E. (Condition 10.6) must submit a single annual report on or before May 31st of each year (beginning May 31st, 2019) that includes, at a minimum, the following information regarding leak detection and repair activities at their subject facilities conducted the previous calendar year (Colorado Regulation No. 7, Part D, Section II.E.9.): 10.6.8.1 The total number of well production facilities and total number of natural gas compressor stations inspected (Colorado Regulation No. 7, Part D, Section II.E.9.a.); 10.6.8,2 The total number of inspections performed per inspection frequency tier of well production facilities and inspection frequency tier of natural gas compressor stations (Colorado Regulation No. 7, Part D, Section II.E.9.b.); 10.6.8.3 The total number of identified leaks requiring repair, broken out by component type, monitoring method, and inspection frequency tier of well production facilities, as reported in Section II.E.9.b. (Condition 10.6.8.2), or inspection frequency tier of natural gas compressor stations (Colorado Regulation No. 7, Part D, Section II.E.9.c.); 10.6.8.4 The total number of leaks repaired for each inspection frequency tier of well production facilities, as reported in Section II.E.9.b. (Condition 10.6.8.2), or inspection frequency tier of natural gas compressor stations (Colorado Regulation No. 7, Part D, Section II.E.9.d.); 10.6.8.5 The total number of leaks on the delayed repair list as of December 31st broken out by component type, inspection frequency tier of well production facilities, as reported in Section II.E.9.b. (Condition 10.6.8.2), or inspection frequency tier of natural gas compressor stations, and the basis for each delay of repair (Colorado Regulation No. 7, Part D, Section II.E.9.e.); 10.6.8.6 The record of all reviews conducted for delayed repairs due to unavailable parts extending beyond 30 days for the previous calendar year (Colorado Regulation No. 7, Part D, Section II.E.9.f.); and 10.6.8.7 Each report must be accompanied by a certification by a responsible official that, based on information and belief formed after reasonable inquiry, the statements and information in the document are true, accurate, and complete (Colorado Regulation No. 7, Part D, Section II.E.9.g.). 10.7 [State -Only Enforceable] Colorado Regulation No. 7, Part D, Section V. Requirements: This facility is subject to the following "Oil and Natural Gas Operations Inventory" requirements of Colorado Regulation No. 7, Part D, Section V.: Conditions shown in italic text below represent monitoring, recordkeeping and recording provisions that are not included in Colorado Regulation No. 7 as of the issuance date of this permit, but are being included as per Colorado Regulation No 3, Part C, Section V.C.5.b. Operating Permit Number: 95OPWE 103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 143 10.7.1 On or before June 30th, 2021 (and on June 30th each year thereafter), the owner or operator of oil and natural gas operations and equipment at or upstream of a natural gas processing plant in Colorado must submit a single annual report that includes actual emissions and specified information in the Division -approved report format (Colorado Regulation No. 7, Part D, Section V.A.). 10.7.2 General reporting requirements (Colorado Regulation No. 7, Part D, Section V.B.). 10.7.2.1 The following information must be reported in accordance with Section V.A (Condition 10.7.1) (Colorado Regulation No. 7, Part D, Section V.B.1.). a. Company name, physical street address, and name and contact information of the company representative, for reporting purposes (Colorado Regulation No. 7, Part D, Section V.B.1.a.). b. The date of submittal and the year covered by the report (Colorado Regulation No. 7, Part D, Section V.B.1.b.). c. A list of the activities or equipment, as specified in Section V.C. (Condition 10.7.3), for which emissions are reported (Colorado Regulation No. 7, Part D, Section V.B.1.c.). d. The company's monthly actual emissions of volatile organic compounds (VOC), oxides of nitrogen (NOx), carbon monoxide (CO), methane, and ethane for each month of May through September (Colorado Regulation No. 7, Part D, Section V.B.1.d.). e. The company's annual actual emissions of VOCs, NOx, CO, methane, and ethane for the entire calendar year (Colorado Regulation No. 7, Part D, Section V.B.1.e.). f. The actual emissions of VOCs, NOx, CO, methane, and ethane for each activity or equipment listed in Section V.C. (Condition 10.7.3) per facility, or per pipeline between facilities where the pipeline is not located at a stationary source (Colorado Regulation No. 7, Part D, Section V.B.I.f.). (i) The report must include the actual emissions from each activity or equipment per month for each month of May through September (Colorado Regulation No. 7, Part D, Section V.B.1.f.(i)). (ii) The report must include the actual emissions from each activity or equipment for the entire calendar year (Colorado Regulation No. 7, Part D, Section V.B. 1 .f.(ii)). A certification by the company representative that supervised the development and submission of the inventory report that, based on information and belief formed after reasonable inquiry, the statements and information in the document are true, accurate, and complete (Colorado Regulation No. 7, Part D, Section V.B.1.g.). g. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 144 10.7.2.2 The owner or operator must submit a revised annual report after discovering that an annual report submitted within the previous two (2) years contained one or more substantive errors. A substantive error is a mass of emissions of any individual pollutant subject to reporting under Section V. (Condition 10.7) that is at least 10% higher or lower than the mass of emissions of the pollutant reported across the owner or operator's activity or equipment, as listed in Section V.C. (Condition 10.7.3), in Colorado. A refinement of or improvement to an emissions estimation technique or emission factor is not a substantive error but must be noted in the subsequent annual report after the refinement or improvement. Revised annual reports must be submitted by August 31 if the substantive error is discovered between January 1 and June 30, and by February 28 if the substantive error is discovered between July 1 and December 31 of the preceding calendar year (Colorado Regulation No. 7, Part D, Section V.B.2.). 10,7.3 Beginning July 1, 2020, and each calendar year thereafter, owners or operators must maintain the following information for inclusion in the annual report (Colorado Regulation No. 7, Part D, Section V.C.). 10.7.3.1 AIRS number of the activity or equipment and associated facility or pipeline (if a pipeline between facilities) location, including latitude and longitude coordinates. If the activity or equipment does not have an AIRS number, a description of the activity or equipment (Colorado Regulation No. 7, Part D, Section V.C.1.). 10.7.3.2 Actual emissions from each activity or equipment listed in this Section V.C.2., unless otherwise specified in the Division -approved report format, and the emission factor(s), assumptions, and calculation methodology used to calculate the emissions (Colorado Regulation No. 7, Part D, Section V.C.2.). Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 145 11. Portable Monitoring (ver. 6/26/2014) Emission measurements of nitrogen oxides (NOx) and carbon monoxide (CO) shall be conducted quarterly using a portable flue gas analyzer. At least one calendar month shall separate the quarterly tests. Note that if the engine is operated for less than 100 hrs in any quarterly period, then the portable monitoring requirements do not apply. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol (ver March 2006 or newer) as found on the Division's website at: https://cdphe.colorado.gov/compliance-and-enforcement Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual or short term emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year (whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year (8760), whichever applies. If the portable analyzer results indicate compliance with both the NOx and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOx and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOx or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOx and CO emission limitations or until the engine is taken offline. For comparison with the emission rates/factors, the emission rates/factors determined by the portable analyzer tests and approved by the Division shall be converted to the same units as the emission rates/factors in the permit. If the portable analyzer tests shows that either the NOx or CO emission rates/factors are greater than the relevant ones set forth in the permit, and in the absence of subsequent testing results to the contrary (as approved by the Division), the permittee shall apply for a modification to this permit to reflect, at a minimum, the higher emission rate/factor within 60 days of the completion of the test. Results of all tests conducted shall be kept on site and made available to the Division upon request. 11.1 The outlet oxygen content of the exhaust stream shall be measured during portable monitoring when measurement of the outlet CO content is being conducted. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 12. Compliance Assurance Monitoring (ver. 4/16/2009) DCP Operating Company, LP Enterprise Compressor Station Page 146 12.1 The Compliance Assurance Monitoring (CAM) requirements in 40 CFR Part 64, as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV, apply to the following units: 12.1.1 C-238, C-235, C-236 and C-234 — Four (4) Caterpillar Model G3612 Engines (3,550 hp) with respect to the VOC limitations identified in Condition 1.2. 12.1.1.1 Excursions, for the purposes of reporting, are defined as any catalyst inlet temperature reading that is less than 450°F or greater than 1350°F. 12.1.2 C-237 — One (1) Caterpillar Model G3616 Engine (4,735 hp) with respect to the CO emission limitation identified in Condition 2.1 and the VOC emission limitation identified in Condition 2.2. 12.1.2.1 Excursions, for the purposes of reporting, are defined as any catalyst inlet temperature reading that is less than 450°F or greater than 1350°F. 12.1.3 D-2 — One (1) Forum TEG Dehydration Unit (110 MMscfd) with respect to the VOC limitation identified in Condition 3.1 and the HAP limitation identified in Condition 9.1. 12.1.3.1 Excursions, for the purposes of reporting, are defined as any absence of the enclosed combustion device pilot flame, except during periods of permitted downtime. 12.1.4 D-3 — One (1) Custom TEG Dehydration Unit (145 MMscfd) with respect to the VOC limitation identified in Condition 4.1 and the HAP limitation identified in Condition 9.2. 12.1.4,1 Excursions, for the purposes of reporting, are defined as any absence of the enclosed combustion device pilot flame, except during periods of permitted downtime. The permittee shall follow the CAM Plan provided in Appendix G of this permit. Excursions shall be reported as required by Section IV, Conditions 21 and 22.d of this permit. 12.1.5 Operation of Approved Monitoring 12.1.5,1 At all times, the owner or operator shall maintain the monitoring, including but not limited to, maintaining necessary parts for routine repairs of the monitoring equipment (40 CFR Part 64 § 64.7(b), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 12.1.5.2 Except for, as applicable, monitoring malfunctions, associated repairs, and required quality assurance or control activities (including, as applicable, calibration checks and required zero and span adjustments), the owner or operator shall conduct all monitoring in continuous operation (or shall collect data at all required intervals) at all times that the pollutant -specific emissions unit is operating. Data recorded during monitoring malfunctions, associated repairs, and required quality assurance or control activities shall not be used for purposes of these CAM requirements, including data averages and calculations, or fulfilling a minimum data availability requirement, if Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 147 applicable. The owner or operator shall use all the data collected during all other periods in assessing the operation of the control device and associated control system. A monitoring malfunction is any sudden, infrequent, not reasonably preventable failure of the monitoring to provide valid data. Monitoring failures that are caused in part by poor maintenance or careless operation are not malfunctions (40 CFR Part 64 § 64.7(c), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 12.1.5.3 Response to excursions or exceedances a. Upon detecting an excursion or exceedance, the owner or operator shall restore operation of the pollutant -specific emissions unit (including the control device and associated capture system) to its normal or usual manner of operation as expeditiously as practicable in accordance with good air pollution control practices for minimizing emissions. The response shall include minimizing the period of any startup, shutdown or malfunction and taking any necessary corrective actions to restore normal operation and prevent the likely recurrence of the cause of an excursion or exceedance (other than those caused by excused startup or shutdown conditions). Such actions may include initial inspection and evaluation, recording that operations returned to normal without operator action (such as through response by a computerized distribution control system), or any necessary follow-up actions to return operation to within the indicator range, designated condition, or below the applicable emission limitation or standard, as applicable (40 CFR Part 64 § 64.7(d)(1), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). b. Determination of whether the owner of operator has used acceptable procedures in response to an excursion or exceedance will be based on information available, which may include but is not limited to, monitoring results, review of operation and maintenance procedures and records, and inspection of the control device, associated capture system, and the process (40 CFR Part 64 § 64.7(d)(2), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 12.1.5.4 After approval of the monitoring required under the CAM requirements, if the owner or operator identifies a failure to achieve compliance with an emission limitation or standard for which the approved monitoring did not provide an indication of an excursion or exceedance while providing valid data, or the results of compliance or performance testing document a need to modify the existing indicator ranges or designated conditions, the owner or operator shall promptly notify the Division and, if necessary submit a proposed modification for this permit to address the necessary monitoring changes. Such a modification may include, but is not limited to, reestablishing indicator ranges or designated conditions, modifying the frequency of conducting monitoring and collecting data, or the monitoring of additional parameters (40 CFR Part 64 § 64.7(e), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 148 12.1.6 Quality Improvement Plan (QIP) Requirements 12.1.6.1 Based on the results of a determination made under the provisions of Condition 12.1.5.3b, the Division may require the owner or operator to develop and implement a QIP (40 CFR Part 64 § 64.8(a), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 12.1.6.2 The owner or operator shall maintain a written QIP, if required, and have it available for inspection (40 CFR Part 64 § 64.8(b)(1), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 12.1.6.3 The QIP initially shall include procedures for evaluating the control performance problems and, based on the results of the evaluation procedures, the owner or operator shall modify the plan to include procedures for conducting one or more of the following actions, as appropriate: a. Improved preventative maintenance practices (40 CFR Part 64 § 64.8(b)(2)(i), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). b. Process operation changes (40 CFR Part 64 § 64.8(b)(2)(ii), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). c. Appropriate improvements to control methods (40 CFR Part 64 § 64.8(b)(2)(iii), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). d. Other steps appropriate to correct control performance (40 CFR Part 64 § 64.8(b)(2)(iv), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). e. More frequent or improved monitoring (only in conjunction with one or more steps under Conditions a through d above) (40 CFR Part 64 § 64.8(b)(2)(v), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 12.1.6.4 If a QIP is required, the owner or operator shall develop and implement a QIP as expeditiously as practicable and shall notify the Division if the period for completing the improvements contained in the QIP exceeds 180 days from the date on which the need to implement the QIP was determined (40 CFR Part 64 § 64.8(c), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 12.1.6.5 Following implementation of a QIP, upon any subsequent determination pursuant to Condition 12.1.5.3b, the Division or the U.S. EPA may require that an owner or operator make reasonable changes to the QIP if the QIP is found to have: a. Failed to address the cause of the control device performance problems (40 CFR Part 64 § 64.8(d)(1), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV); or b. Failed to provide adequate procedures for correcting control device performance problems as expeditiously as practicable in accordance with good Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 149 air pollution control practices for minimizing emissions (40 CFR Part 64 § 64.8(d)(2), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 12.1.6.6 Implementation of a QIP shall not excuse the owner or operator of a source from compliance with any existing emission limitation or standard, or any existing monitoring, testing, reporting or recordkeeping requirement that may apply under federal, state, or local law, or any other applicable requirements under the federal clean air act (40 CFR Part 64 § 64.8(e), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 12.1.7 Reporting and Recordkeeping Requirements 12.1.7.1 Reporting Requirements: The reports required by Section IV, Condition 22.d shall contain the information specified in Appendix B of the permit and the following information, as applicable: a. Summary information on the number, duration and cause (including unknown cause, if applicable), for monitor downtime incidents (other than downtime associated with zero and span or other daily calibration checks, if applicable) ((40 CFR Part 64 § 64.9(a)(2)(ii), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV); and b. The owner or operator shall submit, if necessary, a description of the actions taken to implement a QIP during the reporting period as specified in Condition 12.1.6 of this permit. Upon completion of a QIP, the owner or operator shall include in the next summary report documentation that the implementation of the plan has been completed and reduced the likelihood of similar levels of excursions or exceedances occurring (40 CFR Part 64 § 64.9(a)(2)(iii), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 12.1.7.2 General Recordkeeping Requirements: In addition to the recordkeeping requirements in Section IV, Condition 22.a through 22.c. a. The owner or operator shall maintain records of any written QIP required pursuant to Condition 12.1.6 and any activities undertaken to implement a QIP, and any supporting information required to be maintained under these CAM requirements (such as data used to document the adequacy of monitoring, or records of monitoring maintenance or corrective actions) (40 CFR Part 64 § 64.9(b)(1), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). b. Instead of paper records, the owner or operator may maintain records on alternative media, such as microfilm, computer files, magnetic tape disks, or microfiche, provided that the use of such alternative media allows for expeditious inspection and review, and does not conflict with other applicable Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 150 recordkeeping requirements (40 CFR Part 64 § 64.9(b)(2), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 12.1.8 Savings Provisions 12.1.8.1 Nothing in these CAM requirements shall excuse the owner or operator of a source from compliance with any existing emission limitation or standard, or any existing monitoring, testing, reporting or recordkeeping requirement that may apply under federal, state, or local law, or any other applicable requirements under the federal clean air act. These CAM requirements shall not be used to justify the approval of monitoring less stringent than the monitoring which is required under separate legal authority and are not intended to establish minimum requirements for the purposes of determining the monitoring to be imposed under separate authority under the federal clean air act, including monitoring in permits issued pursuant to title I of the federal clean air act. The purpose of the CAM requirements is to require, as part of the issuance of this Title V operating permit, improved or new monitoring at those emissions units where monitoring requirements do not exist or are inadequate to meet the requirements of CAM (40 CFR Part 64 § 64.10(a)(1), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 12.1.8.2 Nothing in these CAM requirements shall restrict or abrogate the authority of the U.S. EPA or the Division to impose additional or more stringent monitoring, recordkeeping, testing or reporting requirements on any owner or operator of a source under any provision of the federal clean air act, including but not limited to sections 114(a)(1) and 504(b), or state law, as applicable (40 CFR Part 64 § 64.10(a)(2), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 12.1.8.3 Nothing in these CAM requirements shall restrict or abrogate the authority of the U.S. EPA or the Division to take any enforcement action under the federal clean air act for any violation of an applicable requirement or of any person to take action under section 304 of the federal clean air act (40 CFR Part 64 § 64.10(a)(2), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 151 SECTION III - Permit Shield Regulation No. 3, 5 CCR 1001-5, Part C, §§ I.A.4, V.D. & XIII.B; § 25-7-114.4(3)(a), C.R.S. 1. Specific Non -Applicable Requirements Based upon the information available to the Division and supplied by the applicant, the following parameters and requirements have been specifically identified as non -applicable to the facility to which this permit has been issued. This shield does not protect the source from any violations that occurred prior to or at the time of permit issuance. In addition, this shield does not protect the source from any violations that occur as a result of any modification or reconstruction on which construction commenced prior to permit issuance. Emission Unit Description & Number Applicable Requirement Justification C-238 Caterpillar G3612 3,550 hp Colorado Regulation No. 1, Section III.A.1.b. - Particulate emissions from fuel -burning equipment Internal combustion engines are not considered fuel burning equipment for the purposes of the Colorado Regulation No. 1 Particulate Matter Standards. C-235 Caterpillar G3612 3,550 hp C-236 Caterpillar G3612 3,550 hp C-234 Caterpillar G3612 3,550 hp C-237 Caterpillar G3616 4,735 hp Facility -wide Colorado Regulation No. 7, Part B, Sections IV.B.1 and IV.B.2 - Storage of Petroleum Distillates These regulations are intended to apply to gasoline storage and loading facilities and are therefore not applicable to condensate at a natural gas compressor station. Colorado Regulation No. 7, Part B, Section V.C - Crude Oil Storage This regulation requires crude oil storage tanks over 40,000 gallons to comply with selected requirements from Colorado Regulation No. 7, Part B, Section IV. This natural gas compressor station does not store crude oil, and is therefore not required to comply with this requirement. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 2. General Conditions DCP Operating Company, LP Enterprise Compressor Station Page 152 Compliance with this Operating Permit shall be deemed compliance with all applicable requirements specifically identified in the permit and other requirements specifically identified in the permit as not applicable to the source. This permit shield shall not alter or affect the following: 2.1 The provisions of §§ 25-7-112 and 25-7-113, C.R.S., or § 303 of the federal act, concerning enforcement in cases of emergency; 2.2 The liability of an owner or operator of a source for any violation of applicable requirements prior to or at the time of permit issuance. 2.3 The applicable requirements of the federal Acid Rain Program, consistent with § 408(a) of the federal act; 2.4 The ability of the Air Pollution Control Division to obtain information from a source pursuant to § 25-7- 111(2)(I), C.R.S., or the ability of the Administrator to obtain information pursuant to § 114 of the federal act; 2.5 The ability of the Air Pollution Control Division to reopen the Operating Permit for cause pursuant to Regulation No. 3, Part C, § XIII. 2.6 Sources are not shielded from terms and conditions that become applicable to the source subsequent to permit issuance. 3. Streamlined Conditions 3.1 The following applicable requirements have been subsumed within this operating permit using the pertinent streamlining procedures approved by the U.S. EPA. For purposes of the permit shield, compliance with the listed permit conditions will also serve as a compliance demonstration for purposes of the associated subsumed requirements. Permit Condition Streamlined (Subsumed) Requirements SECTION II - 5.8.1.2c(v) Colorado Regulation No. 7, Part D, Section II.C.5.a.(iii)(E) [only with respect to inspection frequency] — State -Only Requirement SECTION II - 6.6.2.7e Colorado Regulation No. 7, Part D, Section II.C.1.d.(v) [only with respect to inspection frequency] — State -Only Requirement SECTION II - 10.6.2 SECTION II - 10.6.4 Colorado Regulation No. 7, Part D, Section II.A.2. [definition of Approved Instrument Monitoring Method — only with respect to other Division -approved alternatives] — State - Only Requirement General Conditions SECTION IV - 22.b SECTION IV - 22.c Colorado Regulation No. 7, Part D, Section II.C.3. [only the requirement to maintain records for two years] — State -Only Requirement Colorado Regulation No. 7, Part D, Section II.C.4.f. [only the requirement to maintain records for two years] — State -Only Requirement Colorado Regulation No. 7, Part D, Section II.C.5.a.(v) [only the requirement to maintain records for two years] — State -Only Requirement Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 153 Permit Condition I Streamlined (Subsumed) Requirements Colorado Regulation No. 7, Part D, Section II.E.8. [only the requirement to maintain records for two years] — State -Only Requirement Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 154 SECTION IV - General Permit Conditions (ver. 1/21/2020) 1. Administrative Changes Regulation No. 3, 5 CCR 1001-5, Part A, § III. The permittee shall submit an application for an administrative permit amendment to the Division for those permit changes that are described in Regulation No. 3, Part A, § I.B.1. The permittee may immediately make the change upon submission of the application to the Division. 2. Certification Requirements Regulation No. 3, 5 CCR 1001-5, Part C, &S III.B.9., V.C.16.a.& e. and V.C.17. a. Any application, report, document and compliance certification submitted to the Air Pollution Control Division pursuant to Regulation No. 3 or the Operating Permit shall contain a certification by a responsible official of the truth, accuracy and completeness of such form, report or certification stating that, based on information and belief formed after reasonable inquiry, the statements and information in the document are true, accurate and complete. b. All compliance certifications for terms and conditions in the Operating Permit shall be submitted to the Air Pollution Control Division at least annually unless a more frequent period is specified in the applicable requirement or by the Division in the Operating Permit. c. Compliance certifications shall contain: (i) the identification of each permit term and condition that is the basis of the certification; (ii) the compliance status of the source; (iii) whether compliance was continuous or intermittent; (iv) method(s) used for determining the compliance status of the source, currently and over the reporting period; and (v) such other facts as the Air Pollution Control Division may require to determine the compliance status of the source. d. All compliance certifications shall be submitted to the Air Pollution Control Division and to the Environmental Protection Agency at the addresses listed in Appendix D of this Permit. e. If the permittee is required to develop and register a risk management plan pursuant to § 112(r) of the federal act, the permittee shall certify its compliance with that requirement; the Operating Permit shall not incorporate the contents of the risk management plan as a permit term or condition. 3. Common Provisions Common Provisions Regulation, 5 CCR 1001-2 &$ II.A., II.B., II.C., II.E., II.F., II.I, and II.J a. To Control Emissions Leaving Colorado When emissions generated from sources in Colorado cross the State boundary line, such emissions shall not cause the air quality standards of the receiving State to be exceeded, provided reciprocal action is taken by the receiving State. b. Emission Monitoring Requirements Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 155 The Division may require owners or operators of stationary air pollution sources to install, maintain, and use instrumentation to monitor and record emission data as a basis for periodic reports to the Division. c. Performance Testing The owner or operator of any air pollution source shall, upon request of the Division, conduct performance test(s) and furnish the Division a written report of the results of such test(s) in order to determine compliance with applicable emission control regulations. Performance test(s) shall be conducted and the data reduced in accordance with the applicable reference test methods unless the Division: (i) specifies or approves, in specific cases, the use of a test method with minor changes in methodology; (ii) approves the use of an equivalent method; (iii) approves the use of an alternative method the results of which the Division has determined to be adequate for indicating where a specific source is in compliance; or (iv) waives the requirement for performance test(s) because the owner or operator of a source has demonstrated by other means to the Division's satisfaction that the affected facility is in compliance with the standard. Nothing in this paragraph shall be construed to abrogate the Commission's or Division's authority to require testing under the Colorado Revised Statutes, Title 25, Article 7, and pursuant to regulations promulgated by the Commission. Compliance test(s) shall be conducted under such conditions as the Division shall specify to the plant operator based on representative performance of the affected facility. The owner or operator shall make available to the Division such records as may be necessary to determine the conditions of the performance test(s). Operations during period of startup, shutdown, and malfunction shall not constitute representative conditions of performance test(s) unless otherwise specified in the applicable standard. The owner or operator of an affected facility shall provide the Division thirty days prior notice of the performance test to afford the Division the opportunity to have an observer present. The Division may waive the thirty day notice requirement provided that arrangements satisfactory to the Division are made for earlier testing. The owner or operator of an affected facility shall provide, or cause to be provided, performance testing facilities as follows: (i) Sampling ports adequate for test methods applicable to such facility; (ii) Safe sampling platform(s); (iii) Safe access to sampling platform(s); and (iv) Utilities for sampling and testing equipment. Each performance test shall consist of at least three separate runs using the applicable test method. Each run shall be conducted for the time and under the conditions specified in the applicable standard. For the purpose of determining compliance with an applicable standard, the arithmetic mean of results of at least three runs shall apply. In the event that a sample is accidentally lost or conditions occur in which one of the runs must be discontinued because of forced shutdown, failure of an irreplaceable portion of the sample train, extreme meteorological conditions, or other circumstances beyond the owner or operator's control, compliance may, upon the Division's approval, be determined using the arithmetic mean of the results of the two other runs. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 156 Nothing in this section shall abrogate the Division's authority to conduct its own performance test(s) if so warranted. d. Affirmative Defense Provision for Excess Emissions during Malfunctions An affirmative defense to a claim of violation under these regulations is provided to owners and operators for civil penalty actions for excess emissions during periods of malfunction. To establish the affirmative defense and to be relieved of a civil penalty in any action to enforce an applicable requirement, the owner or operator of the facility must meet the notification requirements below in a timely manner and prove by a preponderance of evidence that: (i) The excess emissions were caused by a sudden, unavoidable breakdown of equipment, or a sudden, unavoidable failure of a process to operate in the normal or usual manner, beyond the reasonable control of the owner or operator; (ii) The excess emissions did not stem from any activity or event that could have reasonably been foreseen and avoided, or planned for, and could not have been avoided by better operation and maintenance practices; (iii) Repairs were made as expeditiously as possible when the applicable emission limitations were being exceeded; (iv) The amount and duration of the excess emissions (including any bypass) were minimized to the maximum extent practicable during periods of such emissions; (v) All reasonably possible steps were taken to minimize the impact of the excess emissions on ambient air quality; (vi) All emissions monitoring systems were kept in operation (if at all possible); (vii) The owner or operator's actions during the period of excess emissions were documented by properly signed, contemporaneous operating logs or other relevant evidence; (viii) The excess emissions were not part of a recurring pattern indicative of inadequate design, operation, or maintenance; (ix) At all times, the facility was operated in a manner consistent with good practices for minimizing emissions. This section is intended solely to be a factor in determining whether an affirmative defense is available to an owner or operator, and shall not constitute an additional applicable requirement; and (x) During the period of excess emissions, there were no exceedances of the relevant ambient air quality standards established in the Commissions' Regulations that could be attributed to the emitting source. The owner or operator of the facility experiencing excess emissions during a malfunction shall notify the division verbally as soon as possible, but no later than noon of the Division's next working day, and shall submit written notification following the initial occurrence of the excess emissions by the end of the source's next reporting period. The notification shall address the criteria set forth above. The Affirmative Defense Provision contained in this section shall not be available to claims for injunctive relief. The Affirmative Defense Provision does not apply to failures to meet federally promulgated performance standards or emission limits, including, but not limited to, new source performance standards and national emission standards for hazardous air pollutants. The affirmative defense provision does not apply to state implementation plan (sip) limits or permit limits that have been set taking into account potential emissions during malfunctions, including, but not necessarily limited to, certain limits with 30 -day or longer averaging times, limits that indicate they apply during malfunctions, and limits that indicate they apply at all times or without exception. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 157 e. Circumvention Clause A person shall not build, erect, install, or use any article, machine, equipment, condition, or any contrivance, the use of which, without resulting in a reduction in the total release of air pollutants to the atmosphere, reduces or conceals an emission which would otherwise constitute a violation of this regulation. No person shall circumvent this regulation by using more openings than is considered normal practice by the industry or activity in question. f. Compliance Certifications g. For the purpose of submitting compliance certifications or establishing whether or not a person has violated or is in violation of any standard in the Colorado State Implementation Plan, nothing in the Colorado State Implementation Plan shall preclude the use, including the exclusive use, of any credible evidence or information, relevant to whether a source would have been in compliance with applicable requirements if the appropriate performance or compliance test or procedure had been performed. Evidence that has the effect of making any relevant standard or permit term more stringent shall not be credible for proving a violation of the standard or permit term. When compliance or non-compliance is demonstrated by a test or procedure provided by permit or other applicable requirement, the owner or operator shall be presumed to be in compliance or non-compliance unless other relevant credible evidence overcomes that presumption. Affirmative Defense Provision for Excess Emissions During Startup and Shutdown An affirmative defense is provided to owners and operators for civil penalty actions for excess emissions during periods of startup and shutdown. To establish the affirmative defense and to be relieved of a civil penalty in any action to enforce an applicable requirement, the owner or operator of the facility must meet the notification requirements below in a timely manner and prove by a preponderance of the evidence that: (i) The periods of excess emissions that occurred during startup and shutdown were short and infrequent and could not have been prevented through careful planning and design; (ii) The excess emissions were not part of a recurring pattern indicative of inadequate design, operation or maintenance; (iii) If the excess emissions were caused by a bypass (an intentional diversion of control equipment), then the bypass was unavoidable to prevent loss of life, personal injury, or severe property damage; (iv) The frequency and duration of operation in startup and shutdown periods were minimized to the maximum extent practicable; (v) All possible steps were taken to minimize the impact of excess emissions on ambient air quality; (vi) All emissions monitoring systems were kept in operation (if at all possible); (vii) The owner or operator's actions during the period of excess emissions were documented by properly signed, contemporaneous operating logs or other relevant evidence; and, (viii) At all times, the facility was operated in a manner consistent with good practices for minimizing emissions. This subparagraph is intended solely to be a factor in determining whether an affirmative defense is available to an owner or operator, and shall not constitute an additional applicable requirement. The owner or operator of the facility experiencing excess emissions during startup and shutdown shall notify the Division verbally as soon as possible, but no later than two (2) hours after the start of the next working day, and shall submit written quarterly notification following the initial occurrence of the excess emissions. The notification shall address the criteria set forth above. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 158 The Affirmative Defense Provision contained in this section shall not be available to claims for injunctive relief. The Affirmative Defense Provision does not apply to State Implementation Plan provisions or other requirements that derive from new source performance standards or national emissions standards for hazardous air pollutants, or any other federally enforceable performance standard or emission limit with an averaging time greater than twenty-four hours. In addition, an affirmative defense cannot be used by a single source or small group of sources where the excess emissions have the potential to cause an exceedance of the ambient air quality standards or Prevention of Significant Deterioration (PSD) increments. In making any determination whether a source established an affirmative defense, the Division shall consider the information within the notification required above and any other information the Division deems necessary, which may include, but is not limited to, physical inspection of the facility and review of documentation pertaining to the maintenance and operation of process and air pollution control equipment. 4. Compliance Requirements Regulation No. 3, 5 CCR 1001-5, Part C, §§ III.C.9., V.C.11. & 16.d. and § 25-7-122.1(2), C.R.S. a. The permittee must comply with all conditions of the Operating Permit. Any permit noncompliance relating to federally -enforceable terms or conditions constitutes a violation of the federal act, as well as the state act and Regulation No. 3. Any permit noncompliance relating to state -only terms or conditions constitutes a violation of the state act and Regulation No. 3, shall be enforceable pursuant to state law, and shall not be enforceable by citizens under § 304 of the federal act. Any such violation of the federal act, the state act or regulations implementing either statute is grounds for enforcement action, for permit termination, revocation and reissuance or modification or for denial of a permit renewal application. b. It shall not be a defense for a permittee in an enforcement action or a consideration in favor of a permittee in a permit termination, revocation or modification action or action denying a permit renewal application that it would have been necessary to halt or reduce the permitted activity in order to maintain compliance with the conditions of the permit. c. The permit may be modified, revoked, reopened, and reissued, or terminated for cause. The filing of any request by the permittee for a permit modification, revocation and reissuance, or termination, or any notification of planned changes or anticipated noncompliance does not stay any permit condition, except as provided in §§ X. and XI. of Regulation No. 3, Part C. d. The permittee shall furnish to the Air Pollution Control Division, within a reasonable time as specified by the Division, any information that the Division may request in writing to determine whether cause exists for modifying, revoking and reissuing, or terminating the permit or to determine compliance with the permit. Upon request, the permittee shall also furnish to the Division copies of records required to be kept by the permittee, including information claimed to be confidential. Any information subject to a claim of confidentiality shall be specifically identified and submitted separately from information not subject to the claim. e. Any schedule for compliance for applicable requirements with which the source is not in compliance at the time of permit issuance shall be supplemental, and shall not sanction noncompliance with, the applicable requirements on which it is based. f. For any compliance schedule for applicable requirements with which the source is not in compliance at the time of permit issuance, the permittee shall submit, at least every 6 months unless a more frequent period is specified in the applicable requirement or by the Air Pollution Control Division, progress reports which contain the following: (i) dates for achieving the activities, milestones, or compliance required in the schedule for compliance, and dates when such activities, milestones, or compliance were achieved; and Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 g. DCP Operating Company, LP Enterprise Compressor Station Page 159 (ii) an explanation of why any dates in the schedule of compliance were not or will not be met, and any preventive or corrective measures adopted. The permittee shall not knowingly falsify, tamper with, or render inaccurate any monitoring device or method required to be maintained or followed under the terms and conditions of the Operating Permit. 5. Emergency Provisions Regulation No. 3, 5 CCR 1001-5, Part C, & VII An emergency means any situation arising from sudden and reasonably unforeseeable events beyond the control of the source, including acts of God, which situation requires immediate corrective action to restore normal operation, and that causes the source to exceed the technology -based emission limitation under the permit due to unavoidable increases in emissions attributable to the emergency. "Emergency" does not include noncompliance to the extent caused by improperly designed equipment, lack of preventative maintenance, careless or improper operation, or operator error. An emergency constitutes an affirmative defense to an enforcement action brought for noncompliance with a technology -based emission limitation if the permittee demonstrates, through properly signed, contemporaneous operating logs, or other relevant evidence that: a. an emergency occurred and that the permittee can identify the cause(s) of the emergency; b. the permitted facility was at the time being properly operated; c. during the period of the emergency the permittee took all reasonable steps to minimize levels of emissions that exceeded the emission standards, or other requirements in the permit; and d. the permittee submitted oral notice of the emergency to the Air Pollution Control Division no later than noon of the next working day following the emergency, and followed by written notice within one month of the time when emissions limitations were exceeded due to the emergency. This notice must contain a description of the emergency, any steps taken to mitigate emissions, and corrective actions taken. This emergency provision is in addition to any emergency or malfunction provision contained in any applicable requirement. 6. Emission Controls for Asbestos Regulation No. 8, 5 CCR 1001-10, Part B The permittee shall not conduct any asbestos abatement activities except in accordance with the provisions of Regulation No. 8, Part B, "asbestos control." 7. Emissions Trading, Marketable Permits, Economic Incentives Regulation No. 3, 5 CCR 1001-5, Part C, V.C.13. No permit revision shall be required under any approved economic incentives, marketable permits, emissions trading and other similar programs or processes for changes that are specifically provided for in the permit. 8. Fee Payment C.R.S S& 25-7-114.1(6) and 25-7-114.7 a. The permittee shall pay an annual emissions fee in accordance with the provisions of C.R.S. § 25-7-114.7. A 1% per month late payment fee shall be assessed against any invoice amounts not paid in full on the 91st day after the date of invoice, unless a permittee has filed a timely protest to the invoice amount. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 160 b. The permittee shall pay a permit processing fee in accordance with the provisions of C.R.S. § 25-7-114.7. If the Division estimates that processing of the permit will take more than 30 hours, it will notify the permittee of its estimate of what the actual charges may be prior to commencing any work exceeding the 30 hour limit. c. The permittee shall pay an APEN fee in accordance with the provisions of C.R.S. § 25-7-114.1(6) for each APEN or revised APEN filed. 9. Fugitive Particulate Emissions Regulation No. 1, 5 CCR 1001-3, t? III.D.1. The permittee shall employ such control measures and operating procedures as are necessary to minimize fugitive particulate emissions into the atmosphere, in accordance with the provisions of Regulation No. 1, § III.D.1. 10. Inspection and Entry Regulation No. 3, 5 CCR 1001-5, Part C, V.C.16.b. Upon presentation of credentials and other documents as may be required by law, the permittee shall allow the Air Pollution Control Division, or any authorized representative, to perform the following: a. enter upon the permittee's premises where an Operating Permit source is located, or emissions -related activity is conducted, or where records must be kept under the terms of the permit; b. have access to, and copy, at reasonable times, any records that must be kept under the conditions of the permit; c. inspect at reasonable times any facilities, equipment (including monitoring and air pollution control equipment), practices, or operations regulated or required under the Operating Permit; d. sample or monitor at reasonable times, for the purposes of assuring compliance with the Operating Permit or applicable requirements, any substances or parameters. 11. Minor Permit Modifications Regulation No. 3, 5 CCR 1001-5, Part C, .0 X. & XI. The permittee shall submit an application for a minor permit modification before making the change requested in the application. The permit shield shall not extend to minor permit modifications. 12. New Source Review Regulation No. 3, 5 CCR 1001-5, Parts B & D The permittee shall not commence construction or modification of a source required to be reviewed under the New Source Review provisions of Regulation No. 3, Parts B and/or D, as applicable, without first receiving a construction permit. 13. No Property Rights Conveyed Regulation No. 3, 5 CCR 1001-5, Part C, & V.C.11.d. This permit does not convey any property rights of any sort, or any exclusive privilege. 14. Odor Regulation No. 2, 5 CCR 1001-4, Part A Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 161 As a matter of state law only, the permittee shall comply with the provisions of Regulation No. 2 concerning odorous emissions. 15. Off -Permit Changes to the Source Regulation No. 3, 5 CCR 1001-5, Part C, § XII.B. The permittee shall record any off -permit change to the source that causes the emissions of a regulated pollutant subject to an applicable requirement, but not otherwise regulated under the permit, and the emissions resulting from the change, including any other data necessary to show compliance with applicable ambient air quality standards. The permittee shall provide contemporaneous notification to the Air Pollution Control Division and to the Environmental Protection Agency at the addresses listed in Appendix D of this Permit. The permit shield shall not apply to any off -permit change. 16. Opacity Regulation No. 1, 5 CCR 1001-3, §§ I., II. The permittee shall comply with the opacity emissions limitation set forth in Regulation No. 1, §§ I.- II. 17. Open Burning Regulation No. 9, 5 CCR 1001-11 The permittee shall obtain a permit from the Division for any regulated open burning activities in accordance with provisions of Regulation No. 9. 18. Ozone Depleting Compounds Regulation No. 15, 5 CCR 1001-19 The permittee shall comply with the provisions of Regulation No. 15 concerning emissions of ozone depleting compounds. Sections I., II.C., II.D., III. IV., and V. of Regulation No. 15 shall be enforced as a matter of state law only. 19. Permit Expiration and Renewal Regulation No. 3, 5 CCR 1001-5, Part C, §§ III.B.6., IV.C., V.C.2. a. The permit term shall be five (5) years. The permit shall expire at the end of its term. Permit expiration terminates the permittee's right to operate unless a timely and complete renewal application is submitted. b. Applications for renewal shall be submitted at least twelve months, but not more than 18 months, prior to the expiration of the Operating Permit. An application for permit renewal may address only those portions of the permit that require revision, supplementing, or deletion, incorporating the remaining permit terms by reference from the previous permit. A copy of any materials incorporated by reference must be included with the application. 20. Portable Sources Regulation No. 3, 5 CCR 1001-5, Part C, § II.D. Portable Source permittees shall notify the Air Pollution Control Division at least 10 days in advance of each change in location. 21. Prompt Deviation Reporting Regulation No. 3, 5 CCR 1001-5, Part C, § V.C.7.b. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 162 The permittee shall promptly report any deviation from permit requirements, including those attributable to malfunction conditions as defined in the permit, the probable cause of such deviations, and any corrective actions or preventive measures taken. "Prompt" is defined as follows: a. Any definition of "prompt" or a specific timeframe for reporting deviations provided in an underlying applicable requirement as identified in this permit; or b. Where the underlying applicable requirement fails to address the time frame for reporting deviations, reports of deviations will be submitted based on the following schedule: (i) For emissions of a hazardous air pollutant or a toxic air pollutant (as identified in the applicable regulation) that continue for more than an hour in excess of permit requirements, the report shall be made within 24 hours of the occurrence; (ii) For emissions of any regulated air pollutant, excluding a hazardous air pollutant or a toxic air pollutant that continue for more than two hours in excess of permit requirements, the report shall be made within 48 hours; and (iii) For all other deviations from permit requirements, the report shall be submitted every six (6) months, except as otherwise specified by the Division in the permit in accordance with paragraph 22.d. below. c. If any of the conditions in paragraphs b.i or b.ii above are met, the source shall notify the Division by telephone (303- 692-3155) or facsimile (303-782-0278) based on the timetables listed above. [Explanatory note: Notification by telephone or facsimile must speck that this notification is a deviation report for an Operating Permit.] A written notice, certified consistent with General Condition 2.a. above (Certification Requirements), shall be submitted within 10 working days of the occurrence. All deviations reported under this section shall also be identified in the 6 -month report required above. "Prompt reporting" does not constitute an exception to the requirements of "Emergency Provisions" for the purpose of avoiding enforcement actions. 22. Record Keeping and Reporting Requirements Regulation No. 3, 5 CCR 1001-5, Part A, II.; Part C, 44 V.C.6., V.C.7. a. Unless otherwise provided in the source specific conditions of this Operating Permit, the permittee shall maintain compliance monitoring records that include the following information: (i) date, place as defined in the Operating Permit, and time of sampling or measurements; (ii) date(s) on which analyses were performed; (iii) the company or entity that performed the analysis; (iv) the analytical techniques or methods used; (v) the results of such analysis; and (vi) the operating conditions at the time of sampling or measurement. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 163 b. The permittee shall retain records of all required monitoring data and support information for a period of at least five (5) years from the date of the monitoring sample, measurement, report or application. Support information, for this purpose, includes all calibration and maintenance records and all original strip -chart recordings for continuous monitoring instrumentation, and copies of all reports required by the Operating Permit. With prior approval of the Air Pollution Control Division, the permittee may maintain any of the above records in a computerized form. c. Permittees must retain records of all required monitoring data and support information for the most recent twelve (12) month period, as well as compliance certifications for the past five (5) years on -site at all times. A permittee shall make available for the Air Pollution Control Division's review all other records of required monitoring data and support information required to be retained by the permittee upon 48 hours advance notice by the Division. d. The permittee shall submit to the Air Pollution Control Division all reports of any required monitoring at least every six (6) months, unless an applicable requirement, the compliance assurance monitoring rule, or the Division requires submission on a more frequent basis. All instances of deviations from any permit requirements must be clearly identified in such reports. e. The permittee shall file an Air Pollutant Emissions Notice ("APEN") prior to constructing, modifying, or altering any facility, process, activity which constitutes a stationary source from which air pollutants are or are to be emitted, unless such source is exempt from the APEN filing requirements of Regulation No. 3, Part A, § II.D or as provided for in Regulation No. 3, Part A, § II.A.2 for oil and gas well production facilities. A revised APEN shall be filed annually whenever a significant change in emissions, as defined in Regulation No. 3, Part A, § II.C.2., occurs; whenever there is a change in owner or operator of any facility, process, or activity; whenever new control equipment is installed; whenever a different type of control equipment replaces an existing type of control equipment; whenever a permit limitation must be modified; or before the APEN expires. An APEN is valid for a period of five years. The five-year period recommences when a revised APEN is received by the Air Pollution Control Division. Revised APENs shall be submitted no later than 30 days before the five-year term expires. Permittees submitting revised APENs to inform the Division of a change in actual emission rates must do so by April 30 of the following year. Where a permit revision is required, the revised APEN must be filed along with a request for permit revision. APENs for changes in control equipment must be submitted before the change occurs, except an APEN shall be filed once per year for control equipment at condensate storage tanks located at oil and gas exploration and production facilities subject to Regulation No. 7, Part D § I. Annual fees are based on the most recent APEN on file with the Division. 23. Reopenings for Cause Regulation No. 3, 5 CCR 1001-5, Part C, $ XIII. a. The Air Pollution Control Division shall reopen, revise, and reissue Operating Permits; permit reopenings and reissuance shall be processed using the procedures set forth in Regulation No. 3, Part C, § III., except that proceedings to reopen and reissue permits affect only those parts of the permit for which cause to reopen exists. b. The Division shall reopen a permit whenever additional applicable requirements become applicable to a major source with a remaining permit term of three or more years, unless the effective date of the requirements is later than the date on which the permit expires, or unless a general permit is obtained to address the new requirements; whenever additional requirements (including excess emissions requirements) become applicable to an affected source under the acid rain program; whenever the Division determines the permit contains a material mistake or that inaccurate statements were made in establishing the emissions standards or other terms or conditions of the permit; or whenever the Division determines that the permit must be revised or revoked to assure compliance with an applicable requirement. c. The Division shall provide 30 days' advance notice to the permittee of its intent to reopen the permit, except that a shorter notice may be provided in the case of an emergency. d. The permit shield shall extend to those parts of the permit that have been changed pursuant to the reopening and reissuance procedure. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 24. Requirements for Major Stationary Sources DCP Operating Company, LP Enterprise Compressor Station Page 164 Regulation No. 3, 5 CCR 1001-5, Part D, §§ V.A.7.c & d, VI.B.5 & VI.B.6 The following provisions apply to projects at existing emissions units at a major stationary source (other than projects at a source with a PAL) that are not part of a major modification and where the owner or operator relies on projected actual emissions. The definitions of baseline actual emissions, major modification, major stationary source, PAL, projected actual emissions, regulated NSR pollutant and significant can be found in Regulation No. 3, Part D, § II.A. a. Before beginning actual construction of the project, the owner or operator shall document and maintain a record of the following information: (i) (ii) identification of the emissions unit(s) whose emissions of a regulated NSR pollutant could be affected by the project; and a description of the project; (iii) a description of the applicability test used to determine the project is not a major modification for any regulated NSR pollutants, including the baseline actual emissions, the projected actual emissions, the amount of emissions excluded and an explanation for why such amount was excluded, and any netting calculations, if applicable. b. The owner or operator shall monitor emissions of any regulated NSR pollutant that could increase as a result of the project from any emissions units identified in paragraph a(ii) and calculate and maintain a record of the annual emissions, in tons per year on a calendar year basis, for a period of five (5) years following resumption of regular operation after the change, or for a period of ten (10) years following resumption of regular operation after the change if the project increases the design capacity or potential to emit of that regulated NSR pollutant at such emissions unit. c. For existing electric utility steam generating units the following requirements apply: (i) Before beginning actual construction, the owner or operator shall provide a copy of the information required by paragraph a above to the Division. The owner or operator is not required to obtain a determination from the Division prior to beginning actual construction. (ii) The owner or operate shall submit a report to the Division within sixty days after the end of each year during which records must be generated under paragraph b above setting out the unit's annual emissions during the calendar year that preceded submission of the report. d. For existing emissions units that are not electric utility steam generating units, the owner or operator shall submit a report to the Division if the annual emissions from the project, in tons per year, exceed the baseline actual emissions (documented and maintained per paragraph a(iii)) by a significant amount for that regulated NSR pollutant, and if such emissions differ from the preconstruction projection (documented and maintained per paragraph a(iii)). Such report shall be submitted to the Division within sixty days after the end of such year. The report shall contain the following: (i) The name, address and telephone number of the owner or operator; (ii) The annual emissions as calculated per paragraph b; and (iii) Any other information that the owner or operator wishes to include in the report. e. The owner of operation of the source shall make the information in paragraph a available for review upon request to the Division or the general public. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 25. Section 502(b)(10) Changes DCP Operating Company, LP Enterprise Compressor Station Page 165 Regulation No. 3, 5 CCR 1001-5, Part C, XII.A. The permittee shall provide a minimum 7 -day advance notification to the Air Pollution Control Division and to the Environmental Protection Agency at the addresses listed in Appendix D of this Permit. The permittee shall attach a copy of each such notice given to its Operating Permit. 26. Severability Clause Regulation No. 3, 5 CCR 1001-5, Part C, V.C.10. In the event of a challenge to any portion of the permit, all emissions limits, specific and general conditions, monitoring, record keeping and reporting requirements of the permit, except those being challenged, remain valid and enforceable. 27. Significant Permit Modifications Regulation No. 3, 5 CCR 1001-5, Part C, $ III.B.2. The permittee shall not make a significant modification required to be reviewed under Regulation No. 3, Part B ("Construction Permit" requirements) without first receiving a construction permit. The permittee shall submit a complete Operating Permit application or application for an Operating Permit revision for any new or modified source within twelve months of commencing operation, to the address listed in Item 1 in Appendix D of this permit. If the permittee chooses to use the "Combined Construction/Operating Permit" application procedures of Regulation No. 3, Part C, then the Operating Permit must be received prior to commencing construction of the new or modified source. 28. Special Provisions Concerning the Acid Rain Program Regulation No. 3, 5 CCR 1001-5, Part C, $$ V.C.1.b. & 8 a. Where an applicable requirement of the federal act is more stringent than an applicable requirement of regulations promulgated under Title IV of the federal act, 40 Code of Federal Regulations (CFR) Part 72, both provisions shall be incorporated into the permit and shall be federally enforceable. b. Emissions exceeding any allowances that the source lawfully holds under Title IV of the federal act or the regulations promulgated thereunder, 40 CFR Part 72, are expressly prohibited. 29. Transfer or Assignment of Ownership Regulation No. 3, 5 CCR 1001-5, Part C, II.C. No transfer or assignment of ownership of the Operating Permit source will be effective unless the prospective owner or operator applies to the Air Pollution Control Division on Division -supplied Administrative Permit Amendment forms, for reissuance of the existing Operating Permit. No administrative permit shall be complete until a written agreement containing a specific date for transfer of permit, responsibility, coverage, and liability between the permittee and the prospective owner or operator has been submitted to the Division. 30. Volatile Organic Compounds Regulation No. 7, 5 CCR 1001-9, Part B, $$ I & III. The requirements in paragraphs a, b and e apply to sources located in the Denver 1 -hour ozone attainment/maintenance area, any nonattainment area for the 1 -hour ozone standard and to the 8 -hour Ozone Control Area and on a state -only basis to sources located in any ozone nonattainment area, which includes areas designated nonattainment for either the 1 -hour or 8 -hour ozone standard, unless otherwise specified in Regulation No. 7, Part A, Section I.A.1.c. The requirements in paragraphs c and d apply statewide. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit # 95OPWE103 DCP Operating Company, LP Enterprise Compressor Station Page 166 a. All storage tank gauging devices, anti -rotation devices, accesses, seals, hatches, roof drainage systems, support structures, and pressure relief valves shall be maintained and operated to prevent detectable vapor loss except when opened, actuated, or used for necessary and proper activities (e.g. maintenance). Such opening, actuation, or use shall be limited so as to minimize vapor loss. Detectable vapor loss shall be determined visually, by touch, by presence of odor, or using a portable hydrocarbon analyzer. When an analyzer is used, detectable vapor loss means a VOC concentration exceeding 10,000 ppm. Testing shall be conducted as in Regulation No. 7, Part B, Section VI.C.3. b. Except as otherwise provided by Regulation No. 7, all volatile organic compounds, excluding petroleum liquids, transferred to any tank, container, or vehicle compartment with a capacity exceeding 212 liters (56 gallons), shall be transferred using submerged or bottom filling equipment. For top loading, the fill tube shall reach within six inches of the bottom of the tank compartment. For bottom -fill operations, the inlet shall be flush with the tank bottom. c. No person shall dispose of volatile organic compounds by evaporation or spillage unless Reasonably Available Control Technology (RACT) is utilized. d. No owner or operator of a bulk gasoline terminal, bulk gasoline plant, or gasoline dispensing facility as defined in Colorado Regulation No. 7, Part B, Sections IV.C.2., IV.C.3. and VII.A.3., shall permit gasoline to be intentionally spilled, discarded in sewers, stored in open containers, or disposed of in any other manner that would result in evaporation. e. Beer production and associated beer container storage and transfer operations involving volatile organic compounds with a true vapor pressure of less than 1.5 psia actual conditions are exempt from the provisions of paragraph b, above. 31. Wood Stoves and Wood burning Appliances Regulation No. 4, 5 CCR 1001-6 The permittee shall comply with the provisions of Regulation No. 4 concerning the advertisement, sale, installation, and use of wood stoves and wood burning appliances. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Appendices OPERATING PERMIT APPENDICES A - INSPECTION INFORMATION B - MONITORING AND PERMIT DEVIATION REPORT C - COMPLIANCE CERTIFICATION REPORT D - NOTIFICATION ADDRESSES E - PERMIT ACRONYMS F - PERMIT MODIFICATIONS G - COMPLIANCE ASSURANCE MONITORING H - AOS APPLICABILITY REPORTS DISCLAIMER: None of the information found in these Appendices shall be considered to be State or Federally enforceable, except as otherwise provided in this permit, and is presented to assist the source, permitting authority, inspectors, and citizens. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Inspection Information APPENDIX A Inspection Information 1. Directions to Facility: Appendix A Page 1 The station is in the Southwest quarter of the Southwest quarter Section of Section 30, Township 3 North, Range 63 West in Weld County. The station is one (1) mile North of US Highway 76 on the Gutterson Road between the towns of Keenesburg and Roggen. 2. Safety Equipment Required: • Hard Hat • Safety Shoes (Steel -Toed Boots) • Hearing Protection • Eye Protection • Fire Retardant Clothing 3. Facility Plot Plan: The attached figure below shows the plot plan as submitted in the May 17, 2019 construction permit application for 19WE0492. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Inspection Information I i4gthq Li ! o 1 1 'a 1 '- ' ::, !lllE: �. .- nna AI It Q _ 7"'�.t 1 Q ', . , .-PVII I rs..' Q _;..,' ttttx.ltt..11 if 111 --... ° <IFO 14" Miti& ai: ll SI III11llllt!!!Wa a:�: 0 , B 1 ;:: ,.,..' '. i t'.4t �ji81l1 =I ritut xii:�° 1x!1!4: ! �. ii; 1 . I 11. 1 � 11! r [ I IQ1i 1 r 1 j.1 1 1 ` IiiIIII�Ii« I..n i.sr.as..cruc i in#ll#lpit i us _1Er'•- En $ k i S s 3 ! i�4 a s**yR_rt r 11"1 � o � -`=� .fi IF lnn4r.{ °PI ifEP V n ! d Ili 2— m=_ �J a i of eat a g! • it .iii H►'? d d d di .,� • L�1ii1.7.i y o e vs,• 1 !=e I Ir s Appendix A Page 2 Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Inspection Information 4. List of Insignificant Activities: Appendix A Page 3 The following list of insignificant activities was provided by the source to assist in the understanding of the facility layout. Since there is no requirement to update such a list, activities may have changed since the last filing. The asterisk (*) denotes an insignificant activity source category based on the size of the activity, emissions levels from the activity or the production rate of the activity. The owner or operator of individual emission points in insignificant activity source categories marked with an asterisk (*) must maintain sufficient record keeping verifying that the exemption applies. Such records shall be made available for Division review upon request (Colorado Regulation No. 3, Part C, Section II.E). *Colorado Regulation No. 3, Part C, Section II.E.3.a: Individual emission points in nonattainment areas having uncontrolled actual emissions of any criteria pollutant (as defined in Section I.B.17. of Part A of this Regulation Number 3) of less than one ton per year and individual emission points in attainment or attainment/maintenance areas having uncontrolled actual emissions of any criteria pollutant of less than two tons per year, and each individual emission point with uncontrolled actual emissions of lead less than one hundred pounds per year, regardless of where the source is located. • One (1) 16" Marla Pig Receiver Blowdown • One (1) 20" Inlet Pig Receiver Blowdown • One (1) 12" Inlet Pig Receiver Blowdown • One (1) 20" Pig Launcher Blowdown • One (1) 16" Pig Launcher Blowdown • One (1) 16" Roggen Pig Launcher Blowdown • Pressurized Condensate Loadout Rack • Two (2) 30,000 gal Pressurized Bullet Tanks (P014A, P014B) • Two (2) 80 bbl Sump Tanks (Sump 3, Sump 5) • One (1) 475 gal Sump Tank (Sump 4) • One (1) 80 bbl TEG/Cond Collection (Sump 6) • One (1) 80 bbl TEG Stormwater Collection (Sump 7) • Two (2) 10 acfm Remediation Skimmers/Bubblers *Colorado Regulation No. 3, Part C, Section II.E.3.k: Each individual piece of fuel burning equipment, other than smokehouse generators and internal combustion engines, that uses gaseous fuel, and that has a design rate less than or equal to five million British thermal units per hour. • One (1) 2.5 MMBtu/hr D-2 Dehy Reboiler Burner • One (1) 1.5 MMBtu/hr D-3 Dehy Reboiler Burner • One (1) 0.75 MMBtu/hr NG Fired Separator Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Inspection Information • One (1) 0.006 MMBtu/hr 212950 Meter Shed Heater • One (1) 0.006 MMBtu/hr 214551 Meter Shed Heater Appendix A Page 4 Colorado Regulation No. 3, Part C, Section II.E.3.aaa: Storage tanks of capacity less than forty thousand gallons of lubricating oils or waste lubricating oils. • One (1) 210 bbl Lube Oil Tank • One (1) 68 bbl Used Oil Tank • Two (2) 475 gal Used Oil Tanks • Two (2) 300 gal Lube Oil Day Tanks • One (1) 80 bbl Slop Oil Sump (Sump 8) Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Monitoring and Permit Deviation Report APPENDIX B Reporting Requirements and Definitions with codes ver 8/20/2014 Please note that, pursuant to 113(c)(2) of the federal Clean Air Act, any person who knowingly: Appendix B Page 5 (A) makes any false material statement, representation, or certification in, or omits material information from, or knowingly alters, conceals, or fails to file or maintain any notice, application, record, report, plan, or other document required pursuant to the Act to be either filed or maintained (whether with respect to the requirements imposed by the Administrator or by a State); (B) fails to notify or report as required under the Act; or (C) falsifies, tampers with, renders inaccurate, or fails to install any monitoring device or method required to be maintained or followed under the Act shall, upon conviction, be punished by a fine pursuant to title 18 of the United States Code, or by imprisonment for not more than 2 years, or both. If a conviction of any person under this paragraph is for a violation committed after a first conviction of such person under this paragraph, the maximum punishment shall be doubled with respect to both the fine and imprisonment. The permittee must comply with all conditions of this operating permit. Any permit noncompliance constitutes a violation of the Act and is grounds for enforcement action; for permit termination, revocation and reissuance, or modification; or for denial of a permit renewal application. The Part 70 Operating Permit program requires three types of reports to be filed for all permits. All required reports must be certified by a responsible official. Report #1: Monitoring Deviation Report (due at least every six months) For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by data from any monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Monitoring and Permit Deviation Report Report #2: Permit Deviation Report (must be reported "promptly") Appendix B Page 6 In addition to the monitoring requirements set forth in the permits as discussed above, each and every requirement of the permit is subject to deviation reporting. The reports must address deviations from permit requirements, including those attributable to malfunctions as defined in this Appendix, the probable cause of such deviations, and any corrective actions or preventive measures taken. All deviations from any term or condition of the permit are required to be summarized or referenced in the annual compliance certification. For purposes of this operating permit, "malfunction" shall refer to both emergency conditions and malfunctions. Additional discussion on these conditions is provided later in this Appendix. For purposes of this operating permit, the Division is requiring that the permit deviation reports are due as set forth in General Condition 21. Where the underlying applicable requirement contains a definition of prompt or otherwise specifies a time frame for reporting deviations, that definition or time frame shall govern. For example, quarterly Excess Emission Reports required by an NSPS or Regulation No. 1, Section IV. In addition to the monitoring deviations discussed above, included in the meaning of deviation for the purposes of this operating permit are any of the following: (1) A situation where emissions exceed an emission limitation or standard contained in the permit; (2) A situation where process or control device parameter values demonstrate that an emission limitation or standard contained in the permit has not been met; (3) A situation in which observations or data collected demonstrates noncompliance with an emission limitation or standard or any work practice or operating condition required by the permit; or, (4) A situation in which an excursion or exceedance as defined in 40CFR Part 64 (the Compliance Assurance Monitoring (CAM) Rule) has occurred. (only if the emission point is subject to CAM) For reporting purposes, the Division has combined the Monitoring Deviation Report with the Permit Deviation Report. All deviations shall be reported using the following codes: 1 = Standard: 2 = Process: 3 = Monitor: 4 = Test: 5 = Maintenance: 6 = Record: 7 = Report: When the requirement is an emission limit or standard When the requirement is a production/process limit When the requirement is monitoring When the requirement is testing When required maintenance is not performed When the requirement is recordkeeping When the requirement is reporting Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Monitoring and Permit Deviation Report 8=CAM: 9 = Other: Appendix B Page 7 A situation in which an excursion or exceedance as defined in 40CFR Part 64 (the Compliance Assurance Monitoring (CAM) Rule) has occurred. When the deviation is not covered by any of the above categories Report #3: Compliance Certification (annually, as defined in the permit) Submission of compliance certifications with terms and conditions in the permit, including emission limitations, standards, or work practices, is required not less than annually. Compliance Certifications are intended to state the compliance status of each requirement of the permit over the certification period. They must be based, at a minimum, on the testing and monitoring methods specified in the permit that were conducted during the relevant time period. In addition, if the owner or operator knows of other material information (i.e. information beyond required monitoring that has been specifically assessed in relation to how the information potentially affects compliance status), that information must be identified and addressed in the compliance certification. The compliance certification must include the following: • The identification of each term or condition of the permit that is the basis of the certification; • Whether or not the method(s) used by the owner or operator for determining the compliance status with each permit term and condition during the certification period was the method(s) specified in the permit. Such methods and other means shall include, at a minimum, the methods and means required in the permit. If necessary, the owner or operator also shall identify any other material information that must be included in the certification to comply with section 113(c)(2) of the Federal Clean Air Act, which prohibits knowingly making a false certification or omitting material information; • The status of compliance with the terms and conditions of the permit, and whether compliance was continuous or intermittent. The certification shall identify each deviation and take it into account in the compliance certification. Note that not all deviations are considered violations.' • Such other facts as the Division may require, consistent with the applicable requirements to which the source is subject, to determine the compliance status of the source. 1 For example, given the various emissions limitations and monitoring requirements to which a source may be subject, a deviation from one requirement may not be a deviation under another requirement which recognizes an exception and/or special circumstances relating to that same event. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Monitoring and Permit Deviation Report Appendix B Page 8 The Certification shall also identify as possible exceptions to compliance any periods during which compliance is required and in which an excursion or exceedance as defined under 40 CFR Part 64 (the Compliance Assurance Monitoring (CAM) Rule) has occurred. (only for emission points subject to CAM) Note the requirement that the certification shall identify each deviation and take it into account in the compliance certification. Previously submitted deviation reports, including the deviation report submitted at the time of the annual certification, may be referenced in the compliance certification. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Monitoring and Permit Deviation Report Startup, Shutdown, Malfunctions and Emergencies, Appendix B Page 9 Understanding the application of Startup, Shutdown, Malfunctions and Emergency Provisions, is very important in both the deviation reports and the annual compliance certifications. Startup, Shutdown, and Malfunctions Please note that exceedances of some New Source Performance Standards (NSPS) and Maximum Achievable Control Technology (MACT) standards that occur during Startup, Shutdown or Malfunctions may not be considered to be non-compliance since emission limits or standards often do not apply unless specifically stated in the NSPS. Such exceedances must, however, be reported as excess emissions per the NSPS/MACT rules and would still be noted in the deviation report. In regard to compliance certifications, the permittee should be confident of the information related to those deviations when making compliance determinations since they are subject to Division review. The concepts of Startup, Shutdown and Malfunctions also exist for Best Available Control Technology (BACT) sources, but are not applied in the same fashion as for NSPS and MACT sources. Emergency Provisions Under the Emergency provisions of Part 70 certain operational conditions may act as an affirmative defense against enforcement action if they are properly reported. DEFINITIONS Malfunction (NSPS) means any sudden, infrequent, and not reasonably preventable failure of air pollution control equipment, process equipment, or a process to operate in a normal or usual manner. Failures that are caused in part by poor maintenance or careless operation are not malfunctions. Malfunction (SIP) means any sudden and unavoidable failure of air pollution control equipment or process equipment or unintended failure of a process to operate in a normal or usual manner. Failures that are primarily caused by poor maintenance, careless operation, or any other preventable upset condition or preventable equipment breakdown shall not be considered malfunctions. Emergency means any situation arising from sudden and reasonably unforeseeable events beyond the control of the source, including acts of God, which situation requires immediate corrective action to restore normal operation, and that causes the source to exceed a technology -based emission limitation under the permit, due to unavoidable increases in emissions attributable to the emergency. An emergency shall not include noncompliance to the extent caused by improperly designed equipment, lack of preventative maintenance, careless or improper operation, or operator error. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Monitoring and Permit Deviation Report APPENDIX B: Monitoring and Permit Deviation Report - Part I Appendix B Page 10 1. Following is the required format for the Monitoring and Permit Deviation report to be submitted to the Division as set forth in General Condition 21. The Table below must be completed for all equipment or processes for which specific Operating Permit terms exist. 2. Part II of this Appendix B shows the format and information the Division will require for describing periods of monitoring and permit deviations, or malfunction or emergency conditions as indicated in the Table below. One Part II Form must be completed for each Deviation. Previously submitted reports (e.g. EER's or malfunctions) may be referenced and the form need not be filled out in its entirety. FACILITY NAME: DCP Operating Company, LP — Enterprise Compressor Station OPERATING PERMIT NO: 95OP WE 103 REPORTING PERIOD: (see first page of the permit for specific reporting period and dates) Operating Permit Unit ID Unit Description Deviations noted During Period?' Deviation Code 2 Malfunction/Emergency Condition Reported During Period? YES NO 4YES NO 053 Caterpillar Model G3612 Turbocharged Natural Gas Fired Reciprocating Internal Combustion Engine, Site Rated at 3,550 hp 055 Caterpillar Model G3612 Turbocharged Natural Gas Fired Reciprocating Internal Combustion Engine, Site Rated at 3,550 hp 056 Caterpillar Model G3612 Turbocharged Natural Gas Fired Reciprocating Internal Combustion Engine, Site Rated at 3,550 hp 063 Eight (8) 300 bbl Stabilized Condensate Atmospheric Storage Tanks 066 Stabilized Condensate Atmospheric Truck Loadout 068 Forum Energy Technologies Custom TEG Dehydration Unit, Rated at 110 MMscfd Leed Fabrication Model L30-0018-00 Enclosed Combustion Device 070 Caterpillar Model G3612 Turbocharged Natural Gas Fired Reciprocating Internal Combustion Engine, Site Rated at 3,550 hp 071 Caterpillar Model G3616 Turbocharged Natural Gas Fired Reciprocating Internal Combustion Engine, Site Rated at 4,735 hp Operating Permit Number: 95OPWE 103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Monitoring and Permit Deviation Report Appendix B Page 11 Operating Permit Unit ID Unit Description Deviations noted During Period?1 Deviation Code 2 Malfunction/Emergency Condition Reported During Period? YES NO YES NO 075 Two (2) 90 bbl Produced Water Atmospheric Storage Tanks 076 Natural gas venting from reciprocating compressor blowdowns 077 TEG Dehydration Unit, Rated at 145 MMscfd Leed Fabrication Model L30-0018-00 Enclosed Combustion Device General Conditions Insignificant Activities 1 See previous discussion regarding what is considered to be a deviation. Determination of whether or not a deviation has occurred shall be based on a reasonable inquiry using readily available information. 2 Use the following entries, as appropriate 1= Standard: 2 = Process: 3 = Monitor: 4 = Test: 5 = Maintenance: 6 = Record: 7 = Report: 8 = CAM: 9 = Other: When the requirement is an emission limit or standard When the requirement is a production/process limit When the requirement is monitoring When the requirement is testing When required maintenance is not performed When the requirement is recordkeeping When the requirement is reporting A situation in which an excursion or exceedance as defined in 40CFR Part 64 (the Compliance Assurance Monitoring (CAM) Rule) has occurred. When the deviation is not covered by any of the above categories Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Monitoring and Permit Deviation Report APPENDIX B: Monitoring and Permit Deviation Report - Part II FACILITY NAME: DCP Operating Company, LP — Enterprise Compressor Station OPERATING PERMIT NO: 95OPWE 103 REPORTING PERIOD: Appendix B Page 12 Is the deviation being claimed as an: Emergency Malfunction N/A (For NSPS/MACT) Did the deviation occur during: Startup Shutdown Malfunction Normal Operation OPERATING PERMIT UNIT IDENTIFICATION: Operating Permit Condition Number Citation Explanation of Period of Deviation Duration (start/stop date & time) Action Taken to Correct the Problem Measures Taken to Prevent a Reoccurrence of the Problem Dates of Malfunctions/Emergencies Reported (if applicable) Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Monitoring and Permit Deviation Report Appendix B Page 13 Deviation Code Division Code QA: SEE EXAMPLE ON THE NEXT PAGE Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Monitoring and Permit Deviation Report EXAMPLE FACILITY NAME: Acme Corp. OPERATING PERMIT NO: 96OPZZXXX REPORTING PERIOD: 1/1/04 - 6/30/06 Is the deviation being claimed as an: (For NSPS/MACT) Did the deviation occur during: Emergency Appendix B Page 14 Malfunction XX N/A Startup Shutdown Malfunction Normal Operation OPERATING PERMIT UNIT IDENTIFICATION: Asphalt Plant with a Scrubber for Particulate Control - Unit XXX Operating Permit Condition Number Citation Section II, Condition 3.1 - Opacity Limitation Explanation of Period of Deviation Slurry Line Feed Plugged Duration START- 1730 4/10/06 END- 1800 4/10/06 Action Taken to Correct the Problem Line Blown Out Measures Taken to Prevent Reoccurrence of the Problem Replaced Line Filter Dates of Malfunction/Emergencies Reported (if applicable) Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Monitoring and Permit Deviation Report 5/30/06 to A. Einstein, APCD Deviation Code Division Code QA: Appendix B Page 15 Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Monitoring and Permit Deviation Report Appendix B Page 16 APPENDIX B: Monitoring and Permit Deviation Report - Part III REPORT CERTIFICATION SOURCE NAME: DCP Operating Company, LP — Enterprise Compressor Station FACILITY IDENTIFICATION NUMBER: 123-0277 PERMIT NUMBER: 95OPWE103 REPORTING PERIOD: (see first page of the permit for specific reporting period and dates) All information for the Title V Semi -Annual Deviation Reports must be certified by a responsible official as defined in Colorado Regulation No. 3, Part A, Section I.B. This signed certification document must be packaged with the documents being submitted. STATEMENT OF COMPLETENESS I have reviewed the information being submitted in its entirety and, based on information and belief formed after reasonable inquiry, I certify that the statements and information contained in this submittal are true, accurate and complete. Please note that the Colorado Statutes state that any person who knowingly, as defined in Sub -Section 18- 1-501(6), C.R.S., makes any false material statement, representation, or certification in this document is guilty of a misdemeanor and may be punished in accordance with the provisions of Sub -Section 25-7122.1, C.R.S. Printed or Typed Name Title Signature of Responsible Official Date Signed Note: Deviation reports shall be submitted to the Division at the address given in Appendix D of this permit. No copies need be sent to the U.S. EPA. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Compliance Certification Report APPENDIX C Required Format for Annual Compliance Certification Report (ver 8/20/2014) Appendix C Page 17 Following is the format for the Compliance Certification report to be submitted to the Division and the U.S. EPA annually based on the effective date of the permit. The Table below must be completed for all equipment or processes for which specific Operating Permit terms exist. FACILITY NAME: DCP Operating Company, LP - Enterprise Compressor Station OPERATING PERMIT NO: 95OP W E 103 REPORTING PERIOD: I. Facility Status During the entire reporting period, this source was in compliance with ALL terms and conditions contained in the Permit, each term and condition of which is identified and included by this reference. The method(s) used to determine compliance is/are the method(s) specified in the Permit. With the possible exception of the deviations identified in the table below, this source was in compliance with all terms and conditions contained in the Permit, each term and condition of which is identified and included by this reference, during the entire reporting period. The method used to determine compliance for each term and condition is the method specified in the Permit, unless otherwise indicated and described in the deviation report(s). Note that not all deviations are considered violations. Operating Permit Unit ID Unit Description Deviations Reported I Monitoring Method per Permit. Was compliance continuous or intermittent?3 Previous Current YES NO Continuous Intermittent 053 Caterpillar Model G3612 Turbocharged Natural Gas Fired Reciprocating Internal Combustion Engine, Site Rated at 3,550 hp 055 Caterpillar Model G3612 Turbocharged Natural Gas Fired Reciprocating Internal Combustion Engine, Site Rated at 3,550 hp 056 Caterpillar Model G3612 Turbocharged Natural Gas Fired Reciprocating Internal Combustion Engine, Site Rated at 3,550 hp 063 Eight (8) 300 bbl Stabilized Condensate Atmospheric Storage Tanks 066 Stabilized Condensate Atmospheric Truck Loadout Operating Permit Number: 95OPWE 103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Compliance Certification Report Appendix C Page 18 Operating Permit Unit ID Unit Description Deviations Reported I Monitoring Method per Permit?' Was compliance continuous or intermittent?' Previous I Current YES I NO Continuous I Intermittent 068 Forum Energy Technologies Custom TEG Dehydration Unit, Rated at 110 MMscfd Leed Fabrication Model L30-0018-00 Enclosed Combustion Device 070 Caterpillar Model G3612 Turbocharged Natural Gas Fired Reciprocating Internal Combustion Engine, Site Rated at 3,550 hp 071 Caterpillar Model G3616 Turbocharged Natural Gas Fired Reciprocating Internal Combustion Engine, Site Rated at 4,735 hp 075 Two (2) 90 bbl Produced Water Atmospheric Storage Tanks 076 Natural gas venting from reciprocating compressor blowdowns 077 TEG Dehydration Unit, Rated at 145 MMscfd Leed Fabrication Model L30-0018-00 Enclosed Combustion Device General Conditions Insignificant Activities ° If deviations were noted in a previous deviation report , put an "X" under "previous". If deviations were noted in the current deviation report (i.e. for the last six months of the annual reporting period), put an "X" under "current". Mark both columns if both apply. 2 Note whether the method(s) used to determine the compliance status with each term and condition was the method(s) specified in the permit. If it was not, mark "no" and attach additional information/explanation. 3 Note whether the compliance status with of each term and condition provided was continuous or intermittent. "Intermittent Compliance" can mean either that noncompliance has occurred or that the owner or operator has data sufficient to certify compliance only on an intermittent basis. Certification of intermittent compliance therefore does not necessarily mean that any noncompliance has occurred. NOTE: The Periodic Monitoring requirements of the Operating Permit program rule are intended to provide assurance that even in the absence of a continuous system of monitoring the Title V source can demonstrate whether it has operated in continuous compliance for the duration of the reporting period. Therefore, if a source 1) conducts all of the monitoring and recordkeeping required in its permit, even if such activities are done periodically and not continuously, and if 2) such monitoring and recordkeeping does not indicate non- compliance, and if 3) the Responsible Official is not aware of any credible evidence that indicates non-compliance, then the Responsible Official can certify that the emission point(s) in question were in continuous compliance during the applicable time period. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Compliance Certification Report 4 Compliance status for these sources shall be based on a reasonable inquiry using readily available information. II. Status for Accidental Release Prevention Program: Appendix C Page 19 A. This facility is subject is not subject to the provisions of the Accidental Release Prevention Program (Section 112(r) of the Federal Clean Air Act) B. If subject: The facility requirements of section 112(r). is is not in compliance with all the 1. A Risk Management Plan will be has been submitted to the appropriate authority and/or the designated central location by the required date. III. Certification All information for the Annual Compliance Certification must be certified by a responsible official as defined in Colorado Regulation No. 3, Part A, Section I.B. This signed certification document must be packaged with the documents being submitted. I have reviewed this certification in its entirety and, based on information and belief formed after reasonable inquiry, I certify that the statements and information contained in this certification are true, accurate and complete. Please note that the Colorado Statutes state that any person who knowingly, as defined in § 18-1-501(6), C.R.S., makes any false material statement, representation, or certification in this document is guilty of a misdemeanor and may be punished in accordance with the provisions of § 25-7 122.1, C.R.S. Printed or Typed Name Title Signature Date Signed NOTE: All compliance certifications shall be submitted to the Air Pollution Control Division and to the Environmental Protection Agency at the addresses listed in Appendix D of this Permit. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Notification Addresses APPENDIX D Notification Addresses (ver. 1/27/2020) 1. Air Pollution Control Division Colorado Department of Public Health and Environment Air Pollution Control Division Operating Permits Unit APCD-SS-B 1 4300 Cherry Creek Drive S. Denver, CO 80246-1530 ATTN: Title V Unit Supervisor 2. United States Environmental Protection Agency Compliance Notifications: Enforcement and Compliance Assurance Division Air and Toxics Enforcement Branch Mail Code 8ENF-AT U.S. Environmental Protection Agency, Region VIII 1595 Wynkoop Street Denver, CO 80202-1129 502(b)(10) Changes, Off Permit Changes: Air and Radiation Division Air Permitting and Monitoring Branch Mail Code 8ARD-PM U.S. Environmental Protection Agency, Region VIII 1595 Wynkoop Street Denver, CO 80202-1129 Appendix D Page 20 Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit Acronyms Appendix E Page 21 APPENDIX E Permit Acronyms Listed Alphabetically: AIRS Aerometric Information Retrieval System AP -42 EPA Document Compiling Air Pollutant Emission Factors APEN Air Pollution Emission Notice (State of Colorado) APCD Air Pollution Control Division (State of Colorado) ASTM - American Society for Testing and Materials BACT Best Available Control Technology BTU - British Thermal Unit CAA - Clean Air Act (CAAA = Clean Air Act Amendments) CCR Colorado Code of Regulations CEM Continuous Emissions Monitor CF - Cubic Feet (scf = Standard Cubic Feet) CFR Code of Federal Regulations CO Carbon Monoxide COM Continuous Opacity Monitor CRS - Colorado Revised Statute EPA Environmental Protection Agency FR Federal Register G Grams Gal Gallon HAPs Hazardous Air Pollutants HP - Horsepower HP -HR - Horsepower Hour (G/HP-HR = Grams per Horsepower Hour) LAER Lowest Achievable Emission Rate LBS Pounds M Thousand MM Million MMscf Million Standard Cubic Feet MMscfd Million Standard Cubic Feet per Day N/A or NA Not Applicable NOx Nitrogen Oxides NESHAP National Emission Standards for Hazardous Air Pollutants NSPS New Source Performance Standards PM10 Particulate Matter Under 10 Microns PSD Potential for Significant Deterioration PTE Potential To Emit Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit Acronyms RACT Reasonably Available Control Technology SCC Source Classification Code SIC Standard Industrial Code SO2 Sulfur Dioxide TPY - Tons Per Year TSP - Total Suspended Particulate VOC Volatile Organic Compounds Appendix E Page 22 Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Permit Modifications APPENDIX F Permit Modifications Appendix F Page 23 DATE OF REVISION SECTION NUMBER, CONDITION NUMBER DESCRIPTION OF REVISION Operating Permit Number: 95OPWE 103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Compliance Assurance Monitoring Plan Appendix G Page 24 APPENDIX G Compliance Assurance Monitoring Plans Compliance Assurance Monitoring Plan - Engines I. Background a. Emission Unit Description: AIRS ID 053 (C-238) Reciprocating Internal Combustion Engine (3,550 hp) for VOC AIRS ID 055 (C-235) Reciprocating Internal Combustion Engine (3,550 hp) for VOC AIRS ID 056 (C-236) Reciprocating Internal Combustion Engine (3,550 hp) for VOC AIRS ID 070 (C-234) Reciprocating Internal Combustion Engine (3,550 hp) for VOC AIRS ID 071 (C-237) Reciprocating Internal Combustion Engine (4,735 hp) for CO and VOC b. Applicable Regulation, Emission Limit, Monitoring Requirements: Engines C-238, C-235, C-236, and C-234: Regulations: Operating Permit Condition 1.2 Emission Limitations: Monitoring Requirements: Engine C-237: Regulations: Emission Limitations: VOC 24.0 tons/year Catalyst inlet temperature Operating Permit Conditions 2.1 and 2.2 CO 36.6 tons/year VOC 32.0 tons/year Monitoring Requirements: Catalyst inlet temperature c. Control Technology: Each engine is equipped with an oxidation catalyst to control CO and VOC emissions. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Compliance Assurance Monitoring Plan II. Monitoring Approach Appendix G Page 25 Indicator No. 1 I. Indicator Catalyst Inlet Temperature a. Measurement Approach The temperature of the exhaust gas into the catalyst will be measured using an inline thermocouple. II. Indicator Range Excursions, for the purposes of reporting, are defined as an inlet catalyst temperature below 450°F or above 1350°F. Excursions trigger the owner or operator to investigate the engine performance and make any repairs or adjustments necessary. Any adjustments or repairs shall be recorded in a log to be made available to the Division upon request. III. Performance Criteria a. Data Representativeness Temperature is measured at the inlet to the catalyst. The minimum accuracy is +/- 5°F. b. Verification of Operational Status N/A. c. QA/QC Practices and Criteria Thermocouples shall be calibrated annually and maintained and replaced in accordance with manufacturers recommendations. d. Monitoring Frequency Continuous. e. Data Collection Procedures The catalyst inlet temperature shall be recorded daily in a log to be made available to the Division upon request. f. Averaging Period None, unless more than one reading is taken, and then a daily average. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Compliance Assurance Monitoring Plan Compliance Assurance Monitoring Plan TEG Dehydration Unit I. Background a. Emission Unit Description: AIRS ID 068 (D-2) TEG Dehydration Unit (110 MMscfd) for VOC and HAP b. Applicable Regulation, Emission Limit, Monitoring Requirements: TEG Dehydration Unit D-2: Regulations: Emission Limitations: c. Control Technology: Operating Permit Conditions 3.1 and 9.1 VOC 25.0 tons/year Individual HAP 8 tons/year Total HAP 20 tons/year Appendix G Page 26 Enclosed combustion device (COMB -1) for still vent emission control, and flash tank emission control during VRU downtime. Still vent emissions are routed to the enclosed combustion device (COMB -1) with a DRE of 95%. This enclosed combustion device is permitted 1% annual downtime for maintenance and malfunctions, during which time the D-2 still vent is routed to atmosphere. Flash gas emissions are routed to the enclosed combustion device during periods of VRU downtime. The VRU is permitted 5% annual downtime for maintenance and malfunctions, during which time the D-2 flash gas is routed to this enclosed combustion device. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Compliance Assurance Monitoring Plan II. Monitoring Approach Appendix G Page 27 Indicator No. 1 I. Indicator Pilot Light Presence a. Measurement Approach The presence of a pilot light is continuously monitored with a thermocouple or equivalent heat sensing device, installed on the enclosed combustion device (COMB -1). II. Indicator Range Excursions, for the purposes of reporting, are defined as any absence of a pilot light, except during periods of permitted downtime. Excursions shall trigger an investigation and corrective action shall be performed as necessary. Any adjustments or repairs made shall be recorded in a log to be made available to the Division upon request. III. Performance Criteria a. Data Representativeness The presence of a pilot flame is required to initiate the destruction of emissions via combustion. The absence of a flame indicates that emissions are uncontrolled. b. Verification of Operational Status N/A. c. QA/QC Practices/Criteria The thermocouple or equivalent heat sensing device shall be calibrated, maintained and replaced per manufacturer specifications. In the event of a pilot light outage, an alarm is sent to the control room. d. Monitoring Frequency Continuous. e. Data Collection Procedures The presence of the pilot light shall be monitored continuously using a thermocouple or equivalent heat sensing device. In the event of a pilot light outage, an alarm is sent to the control room. All instances of pilot light absence and the duration of absence, except during periods of permitted downtime, shall be recorded in a log to be made available to the Division upon request. f. Averaging Time None. II. Justification a. Background: The pollutant specific emission unit is a TEG dehydration unit, which functions to remove water from the natural gas stream prior to pipeline transfer. Flash emissions from the dehydration unit are recycled via a vapor recovery unit (VRU), which is permitted 5% annual downtime. During periods of downtime, the flash emissions are routed to an enclosed combustion device (COMB -1). Still vent emissions are routed to this same enclosed combustion device or, during periods of enclosed combustion device downtime, to atmosphere. This CAM plan applies to the operation of the enclosed combustion device. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Compliance Assurance Monitoring Plan Appendix G Page 28 b. Rationale for Selection of Performance Indicators and Indicator Ranges: The enclosed combustion device (COMB -1) has a manufacturer's guaranteed VOC destruction efficiency of 98%, when operational. The Division has accepted a VOC destruction efficiency of 95% for enclosed combustion devices with a 98% manufacturer's guarantee. In order to achieve this destruction efficiency, the enclosed combustion device must have a pilot light that is continuously lit to ensure the still vent vapors from TEG dehydration unit D-2 are ignited. Verification of pilot light presence is accomplished by continuously monitoring the pilot light with a thermocouple or equivalent heat sensing device. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Compliance Assurance Monitoring Plan Compliance Assurance Monitoring Plan TEG Dehydration Unit I. Background a. Emission Unit Description: AIRS ID 077 (D-3) TEG Dehydration Unit (145 MMscfd) for VOC and HAP b. Applicable Regulation, Emission Limit, Monitoring Requirements: TEG Dehydration Unit D-3: Regulations: Emission Limitations: c. Control Technology, Operating Permit Conditions 4.1 and 9.2 VOC 22.1 tons/year Individual HAP 8 tons/year Total HAP 20 tons/year Appendix G Page 29 Enclosed combustion device (COMB -1) for still vent emission control, and flash tank emission control during VRU downtime. Still vent emissions are routed to the enclosed combustion device (COMB -1) with a DRE of 95%. This enclosed combustion device is permitted 1% annual downtime for maintenance and malfunctions, during which time the D-3 still vent is routed to atmosphere. Flash gas emissions are routed to the enclosed combustion device during periods of VRU downtime. The VRU is permitted 5% annual downtime for maintenance and malfunctions, during which time the D-3 flash gas is routed to this enclosed combustion device. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Compliance Assurance Monitoring Plan II. Monitoring Approach Appendix G Page 30 Indicator No. 1 I. Indicator Pilot Light Presence a. Measurement Approach The presence of a pilot light is continuously monitored with a thermocouple or equivalent heat sensing device, installed on the enclosed combustion device (COMB -1). II. Indicator Range Excursions, for the purposes of reporting, are defined as any absence of a pilot light, except during periods of permitted downtime. Excursions shall trigger an investigation and corrective action shall be performed as necessary. Any adjustments or repairs made shall be recorded in a log to be made available to the Division upon request. III. Performance Criteria a. Data Representativeness The presence of a pilot flame is required to initiate the destruction of emissions via combustion. The absence of a flame indicates that emissions are uncontrolled. b. Verification of Operational Status The thermocouple shall be installed per manufacturer recommendations. Upon startup of TEG dehydration unit D-3, pilot light presence shall be verified visually to confirm the thermocouple or equivalent heat sensing device output reading. Records of this verification shall be made available to the Division upon request. c. QA/QC Practices/Criteria The thermocouple or equivalent heat sensing device shall be calibrated, maintained and replaced per manufacturer specifications. In the event of a pilot light outage, an alarm is sent to the control room. d. Monitoring Frequency Continuous. e. Data Collection Procedures The presence of the pilot light shall be monitored continuously using a thermocouple or equivalent heat sensing device. In the event of a pilot light outage, an alarm is sent to the control room. All instances of pilot light absence and the duration of absence, except during periods of permitted downtime, shall be recorded in a log to be made available to the Division upon request. f. Averaging Time None. II. Justification a. Background: The pollutant specific emission unit is a TEG dehydration unit, which functions to remove water from the natural gas stream prior to pipeline transfer. Flash emissions from the dehydration unit are recycled via a vapor recovery unit (VRU), which is permitted 5% annual downtime. During periods of downtime, the flash emissions are routed to an enclosed combustion device (COMB -1). Still vent emissions are routed to this same enclosed combustion device or, during periods of enclosed combustion device downtime, to atmosphere. This CAM plan applies to the operation of the enclosed combustion device. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit Compliance Assurance Monitoring Plan Appendix G Page 31 b. Rationale for Selection of Performance Indicators and Indicator Ranges: The enclosed combustion device (COMB -1) has a manufacturer's guaranteed VOC destruction efficiency of 98%, when operational. The Division has accepted a VOC destruction efficiency of 95% for enclosed combustion devices with a 98% manufacturer's guarantee. In order to achieve this destruction efficiency, the enclosed combustion device must have a pilot light that is continuously lit to ensure the still vent vapors from TEG dehydration unit D-3 are ignited. Verification of pilot light presence is accomplished by continuously monitoring the pilot light with a thermocouple or equivalent heat sensing device. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit AOS Applicability Reports APPENDIX H Applicability Reports ver. 10/12/2012 (with updated web links and Reg 3 citations as of 8/20/2014) Note: A MS Word version of this Appendix can be found at: Appendix H Page 32 https://www.colorado.gov/pacific/cdphe/alternate-operating-scenario-aos-reporting-forms DISCLAIMER: These are only example reports and do not cover all possible requirements. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit AOS Applicability Reports Engine AOS Applicability Report Certification Language Appendix H Page 33 All information for the Applicability Reports must be certified by either 1) for Operating Permits, a Responsible Official as defined in Colorado Regulation No. 3, Part A, Section I.B.40) for Construction and General Permits, the person legally authorized to act on behalf of the source. This signed certification document must be packaged with the documents being submitted. I have reviewed this certification in its entirety and, based on information and belief formed after reasonable inquiry, I certify that the statements and information contained in this certification are true, accurate and complete. Further, I agree that by signing and submitting these documents I agree that any new requirements identified in the Applicability Report(s) shall be considered to be Applicable Requirements as defined in Colorado Regulation No. 3, Part A, Section I.B.9., and that such requirements shall be enforceable by the Division and its agents and shall be considered to be revisions to the underlying permit(s) referenced in the Report(s) until such time as the Permit is revised to reflect the new requirements. Please note that the Colorado Statutes state that any person who knowingly, as defined in § 18-1-501(6), C.R.S., makes any false material statement, representation, or certification in this document is guilty of a misdemeanor and may be punished in accordance with the provisions of § 25-7 122.1, C.R.S. Printed or Typed Name Title Signature Date Signed Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit AOS Applicability Reports Colorado Regulation No. 7 Sections XVI and XVILE Appendix H Page 34 DISCLAIMER: This is only an example report and does not cover all possible Reg 7 requirements. Company: Acme Gas Processing Source ID: 9991234 Permit #: 93OPXX999 Date: October 1, 2008 Determination of compliance and reporting requirements for a Manufacturer: BestEngineCompany Model: 777 LowNox Nameplate HP: 1340 Construction date: July 1, 2007 Note: If the engine is exempt from a requirement due to construction date or was relocated from within Colorado, supporting documentation must be provided. Determination of Regulation No. 7 requirements: Regulation No. 7, § XVI n Does not apply to this engine. Engine is not located in the ozone nonattainment area or does not have a manufacturer's design rate greater than 500 horsepower or did not commence operation on or after June 1, 2004. n Does apply to this engine and applicable emissions controls have been installed. Regulation No. 7, § XVILE n Does not apply to this engine. Engine does not have a maximum horsepower greater than 100 or the construction or relocation date precedes the applicability dates. n Does apply to this engine. The following emission limits apply to the engine: NOx (g/hp-hr): CO (g/hp-hr): VOC (g/hp-hr): 2.0 4.0 1.0 Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit AOS Applicability Reports Max Engine HP Construction or Relocation Date Emission Standards in g/hp-hr NOx CO VOC 100<Hp<500 January 1, 2008 2.0 4.0 1.0 January 1, 2011 1.0 2.0 0.7 500<Hp July 1, 2007 2.0 4.0 1.0 July 1, 2010 1.0 2.0 0.7 Appendix H Page 35 Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit AOS Applicability Reports NSPS JJJJ Example Report Format Appendix H Page 36 DISCLAIMER: This is only an example report and does not cover all possible JJJJ requirements. Note that as of August 20, 2015 that the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS JJJJ will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, § I.C, upon adoption of NSPS JJJJ into Regulation No. 6, Part A, an internal combustion engine relocated from outside the State of Colorado into the Date of Colorado shall meet the most recent emission standard required in NSPS JJJJ. Engines with a manufacturer's rated horsepower of less than 500 and with a relocation date no later than 5 years after the manufacture date are exempt from this requirement per Regulation No. 6, Part B, Section I.C.2.a. Relocation is defined in Section I.C.1.a. NSPS Subpart JJJJ: Standards of Performance for Stationary Spark Ignition Internal Combustion Engines Company: Acme Gas Processing Source ID: 9991234 Permit #: 93OPXX999 Date: October 1, 2008 Manufacturer: BestEngineCompany Model: 777 LowNox Nameplate HP: 1340 Engine Type: 2 Stroke Lean Burn Manufacture Date: July 1, 2007 Date Engine Ordered: April 1, 2007 Note: If the engine is exempt from a requirement due to construction/manufacture date, supporting documentation must be provided. Upon adoption of NSPS Subpart JJJJ into Colorado Regulation No. 6, Part A, if the engine is exempt because the engine was relocated within the state of Colorado, supporting documentation must be provided. ❑ NSPS JJJJ does not apply to this engine. ❑ NSPS JJJJ does apply to this engine. Note: Using the format below, the source must submit to the Division an analysis of all of the NSPS JJJJ applicable requirements that apply to this specific engine. The analysis below is an example only, based on a hypothetical engine that is a rich burn engine, greater than 500 HP, with a manufacture date after July 1, 2007. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit AOS Applicability Reports Determination of NSPS JJJJ requirements: 60.4230 Applicability Appendix H Page 37 (a)(4)(i) Applies to this engine since it is a rich burn engine, greater than 500 HP, with a manufacture date after July 1, 2007. 60.4233 Emission Standards for Owners and Operators (e) Owners and operators of stationary SI ICE with a maximum engine power greater than 100 HP must comply with the standards in Table 1. Non -Emergency SI, Natural Gas, HP>500, Manufactured after 7/1/2007 NO„ 2.0 g/HP-hr or 160 ppmvd@15% O2 CO 4.0 g/HP-hr or 540 ppmvd@15% O2 VOC 1.0 g/HP-hr or 86 ppmvd@15% O2 Other Requirements for Owners and Operators 60.4234 Emission standards must be met for the lifetime of the engine. 60.4235 N/A - Sulfur content of gasoline. 60.4236 N/A (for now) - After July 1, 2009 owners and operators may not install engines with a power rating > 500HP that do not meet the emissions standards in 60.4233. 60.4237 N/A - Emergency Engines. 60.4238 - 60.4242 Compliance Requirements for Manufacturers — (Not Applicable) 60.4243 Compliance Requirements for Owners and Operators (b)(2)(ii) To maintain compliance with the emission limits in 60.4233, owners of SI ICE > 500HP must: • Keep a maintenance plan; • Keep records of conducted maintenance; • Maintain and operate the engine in a manner consistent with good air pollution control practice for minimizing emissions; • Conduct an initial performance test; and • Conduct subsequent performance tests every 8,760 hours or every three years, which ever comes first, in order to demonstrate compliance with the emission limits. (g) Air to fuel ratio controllers (AFRCs) must be maintained and operated appropriately in order to ensure proper operation of the engine and control device to minimize emissions at all times. 60.4244 Testing Requirements for Owners and Operators Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit AOS Applicability Reports Appendix H Page 38 (a) Each performance test must be conducted within 10% of the highest achievable load and must comply with the testing requirements listed in 60.8 and Table 2 of NSPS JJJJ. (b) Performance tests may not be conducted during periods of startup, shutdown, or malfunction, as specified in 60.8(c). If the engine is non -operational when a performance test is due, the engine does not need to be started up just to test it, but will need to be tested immediately upon startup. (c) Three separate test runs must be conducted for each performance test as specified by 60.8(f j. Each run must be within 10% of max load and be at least 1 hour in duration. (d) To determine compliance with the NOR, CO, and VOC mass per unit output emission limitations, the measured concentration must be converted using the equations outlined in this section of NSPS JJJJ. 60.4245 Notification, Reports, and Records for Owners and Operators (a) Owners of all stationary SI ICE must keep records of the following: (1) All notifications submitted to comply with this subpart; (2) Maintenance conducted on the engine; (3) N/A - Manufacturer information for certified engines, and (4) Documentation that shows non -certified engines are in compliance with the emission standards. (b) N/A — For emergency engines only. (c) Owners of non -certified engines > 500HP must submit an initial notification as required in 60.7(a)(1) which includes the following information: (1) Name and address of the owner or operator; (2) The address of the affected source; (3) Engine information including make, model, engine family, serial number, model year, maximum engine power, and engine displacement; (4) Emission control equipment; and (5) Fuel used. CONCLUSION OF FINDINGS (EXAMPLE ONLY) In general, Acme's 1,235HP, Waukesha 7042 GSI engine is subject to the emissions limitations summarized in Table 1 of NSPS JJJJ. ACME will meet these emission limitations using an AFRC and a non -selective catalytic converter (NSCR). These emission rates will be met throughout the life of the engine. A maintenance plan will be kept and all maintenance activities will be recorded. Compliance with the emission limits will be confirmed by the initial performance tests, which shall be conducted following the procedures outlined in 60.4244. Copies of performance test results will be submitted within 60 days of the completion of each test. Since this is an uncertified engine, an initial notification will be submitted including all of the requested information in 40.4245 within 30 days of startup. ACME will keep records of all compliance related materials. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit AOS Applicability Reports Appendix H Page 39 MACT ZZZZ Example Report Format DISCLAIMER: This is only an example report and does not cover all possible ZZZZ requirements. MACT Subpart ZZZZ: National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines Company: Acme Gas Processing Source ID: 9991234 Permit #: 93OPXX999 Date: October 1, 2008 Manufacturer: BestEngineCompany Model: 777 LowNox Nameplate HP: 1340 Engine Type: 2 Stroke Lean Burn Manufacture Date: July 1, 2007 Date Engine Ordered: April 1, 2007 Note: If the engine is exempt from a requirement due to construction/reconstruction date, supporting documentation must be provided. ❑ MACT ZZZZ does not apply to this engine. ❑ MACT ZZZZ does apply to this engine. Note: Using the format below, the source must submit to the Division an analysis of all of the MACT ZZZZ applicable requirements that apply to this specific engine. The analysis below is an example only, based on a hypothetical new engine located at an area source of HAP emissions. Determination of MACT ZZZZ requirements: 63.6585 Applicability This subpart is applicable to Acme's engine since they are going to be operating a new stationary reciprocating internal combustion engine (RICE) at a major source of HAP emissions. 63.6590 What Parts of My Plant Does This Subpart Cover? This subpart covers Acme's new stationary reciprocating internal combustion engine. 63.6595 When do I have to comply with this Subpart? Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit AOS Applicability Reports Appendix H Page 40 (a)(5) The engine must comply with the applicable emission limitations and operating limitations upon startup. 63.6600 Emission and operating limitations for RICE site rated at more than 500 hp (a) The engine is subject to the emission limits in table la and the operating limits in table lb. ACME will meet the emission limitations by reducing formaldehyde emissions by 76 percent and will maintain the catalyst such that the pressure drop does not change by more than 2 inches of H2O at 100 % load plus or minus 10 percent from the pressure drop measured during the initial performance test and will maintain the temperature of the engine exhaust so that the catalyst inlet temperature is greater than or equal to 750 ° F and less than or equal to 1250 ° F. The engine will be equipped with non -selective catalytic reduction and an air fuel controller to meet the emission limitations. 63.6601 & 63.6611 Requirements for 4SLB engines between 250 and 500 hp These requirements do not apply. 63.6605 General Requirements (a) The engine will comply with the emission and operating limitations at all times, except during periods of startup, shutdown and malfunction (SSM) (b) The engine, including air pollution control and monitoring equipment shall be operating in a manner consistent with good air pollution control practices for minimizing emissions at all times, including during SSM. 63.6610 Initial performance test (a) The performance tests specified in Table 4 (select sampling port and measure O2, moisture and formaldehyde at inlet and outlet of the control device) shall be conducted within 180 days of startup. (b) & (c) Not applicable. Construction did not commence between 12/19/02 and 6/15/04. (d) Previous performance tests have not been conducted on this unit within two years, therefore, this provision does not apply. 63.6615 Subsequent performance tests Subsequent tests will be conducted as specified in Table 3. No additional testing is required for 4SRB engines meeting the formaldehyde percent reduction requirements. 63.6620 Performance test procedures (b) Tests must be conducted at 100 % load plus or minus 10% Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit AOS Applicability Reports Appendix H Page 41 (c) Tests may not be conducted during periods of SSM. (d) Must conduct three 1 -hr test runs (e) Equation (e)(1) shall be used to determine compliance with the percent reduction requirement. (f), (g) & (h) Not applicable (i) Engine load during test shall be determined as specified in this paragraph. 63.6625 Monitoring, installation, operation and maintenance requirements (a), (c) & (d) Not applicable (b) A continuous parameter monitoring system (CPMS) shall be installed to measure the catalyst inlet temperature. The CPMS will meet the requirements in § 63.8 63.6630 Demonstrating initial compliance (a) Initial compliance shall be determined in accordance with Table 5 (initial performance test must indicate formaldehyde reduction of 76 percent or more, a CPMS must be installed to measure inlet temperature of the catalyst and the pressure drop and catalyst inlet temperature must be recorded during the initial performance test). (b) Pressure differential will be established during the initial performance test. (c) Notification of compliance status will be submitted and will contain the results of the initial compliance demonstration. 63.6635 Monitoring to demonstrate continuous compliance (b) Except for monitor malfunctions, associated repairs, and required QA/QC activities monitoring must be continuous at all time the engine is operating. (c) Data recorded during monitoring malfunctions, associated repairs and required QA/QC activities must not be used in data averages and calculations to report operating levels, however, all the valid data collected during other periods shall be used. 63.6640 Demonstrating continuous compliance (a) (b) 63.6645 Notifications Continuous compliance will be demonstrated as specified in Table 6 (collect catalyst inlet temperature data, reduce that data to 4 -hr rolling average and maintain the 4 -hr rolling averages to within the operating limitation and measuring the pressure drop across the catalyst once per month and demonstrating that the pressure drop meets the operating limitation). Deviations from the emission and operating limitations must be reported per § 63.6550. If catalyst is changed the operating parameters established during the initial performance test must be re-established. When operating parameters re-established a performance test must also be conducted. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit AOS Applicability Reports Appendix H Page 42 (a) Submit notifications in §§ 63.7(b) & (c), 63.8(e), (f)(4) and (t)(6), 63.9(b) thru (e) & (g) & (h) that apply by dates specified. (b) Not applicable. Acme unit started after effective dated for Subpart ZZZZ. (c) Submit initial notification within 120 days after becoming subject to Subpart ZZZZ. (d) thru (0 Not applicable. Acme engine greater than 500 hp and subject to requirements in Subpart ZZZZ. (g) & (h) Submit notification of intent to conduct performance test and notification of compliance status. 63.6650 Reports (a) Submit reports required by Table 7 (compliance report and SSM reports (if actions inconsistent with SSM plan) (b) Not applicable, an alternate schedule for report submittal has been approved. Reports will be submitted with Title V reports (c) Compliance reports to contain the following information: company name and address, statement by responsible official certifying accuracy, date of report and beginning and end of reporting period, if SSM the information in 63.10(d)(5)(i), if no deviations a statement saying that, if no periods when CPMS out of control a statement saying that. (d) Not applicable, using CPMS (e) For each deviation the information in (e)(1) thru (e)(12) shall be provided. (f) Applicable. Compliance reports are submitted with title v reports. Compliance reports under Subpart ZZZZ include all necessary info for title v deviation report with respect to Subpart ZZZZ requirements. (g) Not applicable. Acme engine not firing landfill or digester gas. 63.6655 Recordkeeping (a) Retain records as follows: copy of each notification and report (including all documentation supporting any initial notification or notification of compliance status), records in 63.6(e)(iii) thru (v) related to SSM, and records of performance tests and evaluations. (b) CPMS records including records in 63.10(b)(2)(vi) thru (xi), previous versions of the performance evaluation plan required by 63.8(d)(3) and requests for alternatives to the relative accuracy test for CPMS as required by 63.8(f)(6)(i). (c) Not applicable. Acme engine not firing landfill or digester gas. (d) Will keep records required in Table 6 (monthly pressure drop readings, 4 -hr averages of catalyst inlet temperature) to show continuous compliance with emission and operating limits. 63.6660 Form and length of records (a) Records must be in a form suitable and readily available for expeditions review. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Air Pollution Control Division Colorado Operating Permit AOS Applicability Reports Appendix H Page 43 (b) Records must be retained for five years. (c) Records must be retained on -site for first 2 years, may be retained off -site for the remaining 3 years. 63.6665 General Provisions This engine must comply with the general provisions as indicated in Table 8. CONCLUSION OF FINDINGS (EXAMPLE ONLY) Since this engine is subject to the requirements of MACT Subpart ZZZZ. The engine will be installed with a non -selective catalyst to meet the formaldehyde reduction requirement of 76% or more. An initial performance test will be conducted within 180 days of startup to demonstrate compliance with the formaldehyde percent reduction requirement. During the initial performance test, the pressure drop across the catalyst will be measured. A CPMS will be installed to measure the catalyst inlet temperature. Continuous compliance will be demonstrated by keeping the 4 -hr rolling averages of catalyst inlet temperature within the operating limitations and recording the pressure drop across the catalyst monthly and demonstrating that the pressure drop is within the operating limitation. Records, notifications and reports will be submitted as required. To that end required reports and notifications include initial notification, notice of intent to conduct performance test, notification of compliance status, SSM reports (if required) and semi-annual compliance reports. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: March 1, 2021 Hello