The URL can be used to link to this page

Browse Search

Home My WebLink About20190055EXHIBIT INVENTORY CONTROL SHEET Case USR18-0106 - GARY HOWARD, JOHN AND DIANA HOWARD AND D & C FARMS, LLLP, C/O ROCKY MOUNTAIN MIDSTREAM, LLC Exhibit Submitted By Description A. Planning Commission Resolution of Recommendation B. Planning Commission Summary of Hearing (Minutes dated 12/18/2018) C. Planning Services PowerPoint Presentation D. Bill Wycoff Email and attachments (received 01/08/2019) E. Bill Wycoff Email and chart attachment (dated 12/27/2018) F. Applicant PowerPoint Presentation (received 01/09/2019) Outlined Testimony and Signed Petition (received G. Bill Wycoff 01/09/2019) H. Planning Services Email explaining name change (dated 11/02/2018) I. Bill Wycoff Email and Attachments (dated 01/28/2019) J. Matt Norton Email response to Mr. Wycoff (dated 01/30/2019) Email with power suggestion and response (dated K. Bill Wycoff & Matt Norton 02/01/2019) Email correspondence and attachments (dated L. Bill Wycoff 02/05/2019) Email regarding the noise and lighting standard (dated M. Hazel Frank 02/05/2019) N. Bill Wycoff Email with Denver Post attachments (dated 02/06/2019) Email regarding the continuance request (dated O. Matt Norton 02/10/2019) P. Matt Norton PowerPoint Presentation (received 02/22/2019) Testimony and images of similar uses (received Q. Bill Wycoff 02/25/2019) Email regarding buffer and property constraints (dated R. Matt Norton 02/26/2019) PowerPoint Presentation for 03/11/2019 (received S. Matt Norton 03/08/2019) Noise Modeling Report and Ambient Sound Level T. Matt Norton Reports for 06/28/18 and 01/31/19 2019-0055 WELD COUNTY ADMINISTRATION SUILDrNG r Fcarafit It u ' • . ht n. • rite sn I_ r ore wii P II as f 0 °IL ▪ . l k a e *t. re 0 ® ir iii � : P. "9 :.� �� d V illVie, r r .. R' .. c'a VIEW TO EAST FROM CR 17 p 4 Ap 1.1 i Y Sa 11 ,n Va tea, P ha h a S I �:I A i a 1 P- .' ■ S a.'Al i s "std NI� ■e•� 1199 9A• '' xis a r • 11 a 1. • r I y • .� a. S 1 a • • a ea Lai ■ r o o • 4 ay , Re: �.A A , • • • • e s1 .• • [ 'a II• I: S VIEW T SOUTHEAST. 3.... ryu ::0 L n q a • ea i Fla • '• S-- ai t ea • G mir a Ai Its d .. - r A �� T 4 4'1 ell shn a .� • a - 1 4• o at Iii iii • oo a`- • P ` q aia A mil • T. 11 ayq a. J�' 4.-1! aril a4 a A t .•,3� 6flS. ti a. • d .• dr" a' s • MIL se n ai _it: c • as it 4 51.4 r, a as • s .A es's as • * = r a ti I . uNaI a p n .741 ,y - A.. a U., ay ( - f' a r ZL.a �, .l F r• •� Qr". ze • l 5%"19• iq i 6 , `. ▪ r • a a a 0 _s I • iT Ta' 1 i'a s= a r'] _ - a i • ■ F Ai jjirg MIW: tea r hin- Pr• . JI tit t r VIEW TO SOUTH DOWN CR 17x r iii �� n %art, cc: .� # lig R L II nmt, °o- aR lb Selena Baltierra To: Subject: Esther Gesick RE: Material for Jan. 9 Board of Commissioners meeting on USR-18-0106 From: wwycoffbn7@aol.com <wwycoffbn7@aol.com> Sent: Monday, January 7, 2019 5:48 PM To: Esther Gesick <egesick@weldgov.com> Subject: Material for Jan. 9 Board of Commissioners meeting on USR-18-0106 t i t 100: This email originated from outside of Weld County Government. Do not click links or open attachments unless you recognize the sender and know the content is safe. MS. Gesick, While not quite sure how this works, I am sending to you documents for inclusion in the January 9, 2019 Board meeting. If this does not work well, I intend to bring the files to the meeting on a thumb drive. However, if they can be available for the Commissioners to view during the meeting that might be of benefit. Please let me know if there is anything I need to do. Thank you. Best Regards, Bill Wycoff 303.659.7259 1 All Stationary Sources of Air Pollution near the source: 123-9F71 DISCOVERY DJ SERVICES - WEST BRIGHTON CS The table can be copied and pasted into Excel or Word. Longitude Latitude AIRS -ID Facility Owner Facility Name Nitrogen Oxides O3 NAA? 9.4 -104.84655 39.94428 001-2101 WARD PETROLEUM CORPORATION GREAT WESTERN - SHARP 24-3-11HC 0.36779Y 8 -104.90788 39.94978 001-2111 NEW CINGULAR WIRELESS PCS LLC dba AT&T MOBILITY NEW CINGULAR DBA AT&T - USID 10262 GENRTR 0.04012 Y 7.3 -104.88856 39.95527 001 1572 GREAT WESTERN OPERATING COMPANY GREAT WESTERN - KORTUM BATTERY 7.31694 Y 9 -104.82349 39.95991 001-2130 WARD PETROLEUM CORPORATION GREAT WESTERN - ANDERSON 19-1-10HC 9.55114 Y 6.9 -104.86219 39.96365 001-2126 GREAT WESTERN OPERATING COMPANY GREAT WESTERN RIVERDALE 14-4-12HC 0.69046 Y 6.1 -104.90361 39.96666 001-1426 PDC ENERGY, INC. PDC ENERGY MCELWAI3 3: 41, 42-7 1.65674 Y 8.5 -104.81968 39.96948 001-0195 INTERTAPE POLYMER CORP (IPG) INTERTAPE POLYMER CORD (IPG) 2.6195 Y 6,1 -104.92481 39.97138 001 2105 GREAT WESTERN OPERATING COMPANY GREAT WESTERN OPERATING - WILLOW BEND 18 3.00572 Y 7.8 -104.95974 39.97158 001 1975 SYNERGY RESOURCES CORP SYNERGY RESOURCES - WRIGHT 1-14 1.70491Y 5.4 -104.93382 39.98283 001 2194 GREAT WESTERN OPERATING COMPANY GREAT WESTERN OPERATING - B -FARM LD PAD 1.95762 Y 4.5 -104.9137 39.98308 001 2180 GREAT WESTERN OPERATING COMPANY GREAT WESTERN OPERATING - OCHO LD PAD 19.05937 Y 3.8 -104.89402 39.98709 001-1664 PETROSHARE CORPORATION PETROSHARE - Zarlengo 23, 24-4 Cy 5.1 -104.93879 39.98984 001-1665 PETROSHARE CORPORATION PETROSHARE BREDEHOFT 13-6 0.00041Y 7.9 -104.97929 39.99201 001-1917 EXTRACTION OIL & GAS, INC. EXTRACTION O&G - LARKRIDGE MA03-09D, l0D 0.07254 Y 4.1 -104.85256 40.00169 123-6118 PDC ENERGY, INC. PDC Schmidt 33, 44-35 0.00083 Y 5.3 -104.95118 40.00221 123-993O KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE - 36112272 0.78795 Y 2.8 -104.86907 40.00398 123-9E5D GREAT WESTERN OPERATING COMPANY GREAT WESTERN OPERATING - MARCUS LD PAD 9.49321Y 8.6 -104.79495 40.00447 123-9E27 SYNERGY RESOURCES CORP SYNERGY RES - SRC EBERLE TANK BATTERY 0.70902 Y 6.3 -104.82229 40.00669 123 99ED METRO WASTEWATER RECLAMATION DISTRICT METRO WASTEWATER - NORTHERN TREATMENT 4.99994 Y 2.6 -104.91889 40.00707 123-9F2F PDC ENERGY, INC. PDC ENERGY JACOBUCCI 32 SEC PAD 3 1.65588 Y 2.5 -104.91739 40.0071 123-9F2A PDC ENERGY, INC. PDC ENERGY JACOBUCCI 32 SEC PAD 1 & 2 2.4847 Y 1.5 -104.8914 40.00758 123 6041 K.P. KAUFFMAN COMPANY, INC. KP KAUFFMAN CO - AMOCO- CHARTER-SCHNEIDER 0.10001 Y 8.6 -104.79302 40.01101 123-9CBA SYNERGY RESOURCES CORP SYNERGY RESOURCES- PHELPS TANK FARM BATT 2.8267 Y 7.8 -104.80189 40.01192 123 9F43 GREAT WESTERN OPERATING COMPANY GREAT WESTERN OPERATING - DITTMER KE PAD 16.45321 Y 5.1 -104.83396 40.01343 123 1636 K.P. KAUFFMAN COMPANY, INC. KP KAUFFMAN CO - BAURER / EIBERGER 1.1 Y 1.3 -104.8821 40.01374 123 9O14 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE OIL & GAS ONSHORE - 36166295 1.78003 Y 1.1 -104.88455 40.01421 123-0141 PUBLIC SERVICE COMPANY OF COLORADO -YOSEMITE NATURAL GAS PUBLIC SERVICE - AIR BLEND PLANT 50.9115Y 2.4 -104.9213 40.0147 123-6037 K.P. KAUFFMAN COMPANY, INC. K.P. KAUFFMAN CO- FINDLAY BATTERY 0.016Y 9.4 -104.7833 40.0147 123 5698 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE OIL & GAS - 36159241 0.2059Y 0.8 -104.89985 40.01502 123-9CED KERR-MCGEE OIL & GAS ONSHORE LP Kerr-McGee Oil and Gas Onshore- 36164761 0.6841Y 3.4 -104.93401 40.0152 123-0221 DCP OPERATING COMPANY, LP DCP OPERATING CO MARTHA KIRKMEYER C.S. 17.15 Y 9.7 -104.77924 40.0153 123 9AEB KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE O&G ONSHORE LP - 36104758 7,83966 Y 0.8 -104.8887 40.0154 123-0075 DCP OPERATING COMPANY, LP DCP OPERATING CO SURREY C.S. 25.8 Y 4.7 -104.94908 40.01693 123-6591 KERR-MCGEE OIL & OAS ONSHORE LP KERR-MCGEE - 35005819 0.04486 Y 9.5 -105.00694 40.01694 123-5279 EXTRACTION OIL & GAS, INC. EXTRACTION O&G - MEIKLE 28-1, 2 0.01749 Y 4.7 -104.94965 40.02038 123-6656 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE - 35005824 0.02286 Y 7.5 -104.80526 40.02412 123 7282 VESTAS BLADES AMERICA, INC VESTAS BLADES AMERICA- BRIGHTON BLADE FA 2.12 Y 9.9 -104.77735 40.02495 123-5255 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE 62159 5.22 Y 1.3 -104.90801 40.02518 123-8687 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE - 36156425 0.00464 Y 6.1 -104.96559 40.02646 001-1608 BLUE CHIP OIL, INC. BLUE CHIP OIL, INC.- ROBERTS #2 0.02844 Y 5.7 -104.96114 40.02653 123-6655 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE -35006000 0.03128 Y 7 -104.97703 40.02668 123-1388 CRESTONE PEAK RESOURCES OPERATING, LLC CRESTONE PEAK - ALAUX #F1,26 3&5 1.49175 Y 9.5 -105.00599 40.02862 123 7487 EXTRACTION OIL & GAS, INC. EXTRACTION O&G - DUMP UU 28-2, 3 0.04182 Y 1 -104.88891 40.02888 123 9D11 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE O&G ONSHORE- 36165657 1.30978 Y 9.6 -105.007 40.03 123 9F52 KERR-MCGEE GATHERING, LLC KERR MCGEE GATHERING - ERIE COMP STATION 39.15428 Y 9.4 -105.00422 40.03068 123-9BCB CRESTONE PEAK RESOURCES OPERATING, LLC CRESTONE PEAK - LIQUIDS HANDLING HUB 11.914 Y 8.9 -104.78919 40.03141 123-9FOB GREAT WESTERN OPERATING COMPANY GREAT WESTERN SACK 24-0.74947Y 1-12HC 1,4 -104.89972 40.03278 123-1911 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE OIL & GAS - 36163972 1.26001Y 5.4 -104.95602 40.03291 123-6265 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE - 36156450 0.0219Y 7.1 -104.97704 40.03335 014-1337 CRESTONE PEAK RESOURCES OPERATING, LLC CRESTONE PEAK - HELEN E UNIT 1 0.16579 Y 4.8 -104.84206 40.03896 123-1981 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE 62483 0.03561 Y 5.4 -104.83529 40.0396 123-1993 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE 62482 0.28151Y 6.4 -104.96458 40.04121 014-1360 CRESTONE PEAK RESOURCES OPERATING, LLC CRESTONE PEAK - BURY CRANDELL C UNIT #1 0.15763 Y 5.9 -104.95851 40.04226 123-6273 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE - 36156451 0.01554 Y 5.3 -104.94818 40.04492 123-8362 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE 13019 0.03067 Y 4.3 -104.85461 40.04544 123-2341 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE 62102 0.09603 Y 2.9 -104.'8909 40.0474 123-6966 NOBLE ENERGY, INC. NOBLE ENERGY, INC. - ENG-11364500 1.78 Y 3.6 -104.86939 40.04741 123-4744 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE 62651 -BRINK 15-15A 0.09859 Y 8 -104.806 40.049 123 9F57 KERR-MCGEE GATHERING, LLC KERR MCGEE GATHERING - POWARS COMP STA 38.63611 Y 9 -104.99027 40.05513 123-7883 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE OIL & GAS - 36156423 0.03462 Y 5.5 -104.84739 40.05596 123 9985 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE 36110644 / 36110619 0.94225Y 4.5 -104.92174 40.05608 123 9C8F KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE OIL & GAS - 36146148 1.06 Y 4.1 -104.88372 40.05678 123-0184 KERR-MCGEE GATHERING, LLC KERR-MCGEE GATHERING - FREDERICK CS 156.79138 Y 6.6 -104.83186 40.05718 123 9845 KERR-MCGEE OIL & GAS ONSHORE LP KERR MCGEE O&G ONSHORE LP - 34002628 0.64503 Y 6 -104.94579 40.05765 123-0295 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE - 34002966 / 65862 1 91291 Y 5 -104.925 40.06 123-9F6F KERR-MCGEE GATHERING, LLC KERR MCGEE - DACONO COMPRESSOR STATION 37.47611 Y 6.9 -104.83323 40.06271 123-2073 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE 62293 0.03282 Y 6,7 -104.83916 40.06482 123-9050 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE 36009209 0.14272 Y 5.2 -104.91715 40.06495 123-7842 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE 62399 0.01538 Y 5.3 -104.90965 40.06693 123-8916 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE 36002694 0.14601 Y $ -104.82216 40.06749 123-9696 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE 36054785 0.99646 Y 7 -104.94789 40.06957 123-9047 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE 62184 0.1341 Y 8.6 -104.96859 40.07444 123 2230 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE OIL & GAS - 34002866 3.82833 Y 6.2 -104.9105 40.07528 123 6045 K.P. KAUFFMAN COMPANY, INC. K.P. KAUFFMAN CO -CARL MILLER BATTERY 0.04952 Y 7.3 -104.84457 40.07531 123-1988 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE - 36130863 0.667 Y 9.5 -104.80763 40.07579 123-2335 KERR-MCGEE OIL ONSHORE LP KERR-MCGEE - 34002699 0.0421 Y 6.2 -104.91097 40.07588 123-4706 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE - 62313 0.14316 Y 6.3 -104.88914 40.07788 123-4329 K.P. KAUFFMAN COMPANY, INC. K.P. KAUFFMAN CO SPINDLE CONS FAC #5 0.2405 Y 9.4 -104.97316 40.08125 123-7815 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE O&G ONSHORE 34002319 0.46658 Y 7,7 -104.8485 40.0816 123-9O18 K.P. KAUFFMAN COMPANY, INC. FACILITY #8 1.36 Y 7.9 -104.84639 40.08192 123 4332 K.P. KAUFFMAN COMPANY, INC. KP KAUFFMAN - FACILITY #8 0.17 Y 8 -104.8461 40.08281 123-1987 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE - 62364 - PEHR POOLING UNIT #2 0.47649 Y 7.4 -104.86466 40.08391 123-7800 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE OIL & GAS - 34002679 0.55749 Y 8 -104.84913 40.08489 123-9BD4 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE - 36129606 0.40935 Y 7.1 -104.889 40.0852 123-6300 K.P. KAUFFMAN COMPANY, INC. KP KAUFFMAN - HEIN 2 & 4 0.081Y 7.3 -104.87796 40.08533 123-4330 K.P. KAUFFMAN COMPANY, INC. KP KAUFFMAN CO - FACILITY #6 0.12774 Y 7.6 -104.90927 40.08845 123 9E7A EXTRACTION OIL & GAS, INC. EXTRACTION OIL&GAS - TROUDT PROD FACILITY 0.6186 Y 7.6 -104.88472 40.08888 123-0015 DCP OPERATING COMPANY, LP DCP OPERATING CO - SPINDLE GAS PLANT 197.57003 Y 9.2 -104.8323 40.08912 123 8268 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE OIL & GAS - 34002698 0.01989 Y 7.7 -104.88 40.09 123 9FC7 KERR-MCGEE GATHERING, LLC KERR MCGEE GATHERING - COAL RIDGE CS 38.43428 Y 9.7 -104.82504 40.09058 123 2246 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE - 34002848 62763 4.06889Y 7.9 -104.88814 40.09176 123-5468 SPINDLE HILL ENERGY, LLC SPINDLE HILL ENERGY, LLC 39.29222 Y 9.2 -104.8378 40.09235 123 7736 COLOR STAR GROWERS, INC COLOR STAR GROWERS - OLD FT LUPTON FACIL 23 Y 9.3 -104.94869 40.09418 123 7514 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE 35014977 - STATE 2/DACONO... 0.16766Y 9.4 -104.94888 40.09434 123-3861 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE 61462 0.26387 Y 9.3 -104.87476 40.10381 123-6183 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE - 36156418 0.03716 Y 9.8 -104.85573 40.10435 123-3458 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE 62790 0.04217 Y 9.8 -104.87 40.10746 123-6188 KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE - 36156471 0.01779 Y APEN Reported Actual NOx Emissions Total: 810.25 TPY 98 sources of NOx total 810.25 tpy w/in 10 km of 40.02118 N, 104.89408 W (Geographic, WGS 1984) Tabular facility data (updated daily) provided by the Stationary Sources Program Inventory and Support Unit. More info at https://www.colorado.gov/airquality/permits.aspx. APEN emissions data valid as of 1/6/2019. Query Sources of Air Pollution January 7, 2019 1:72,224 24 sources of NOx total 291.64 tpy w/in 5 km of 40.02118 N, 104.89408 W (Geographic, WGS 1984) 0 0.5 1 0 1 2 2mi I I 4 km Sources: Esri, HERE, Garmin, USGS, Intermap, INCREMENT P, NRCan, Esri Japan, METI, Esri China (Hong Kong), Esri Korea, Esri (Thailand), NGCC, O OpenStreetMap contributors, and the GIS User Community, Source: Esri, DigitalGlobe, GeoEye, Earthstar Source(s) of interest labeled within the specified buffer using the web Map created by the Modeling, Meteorology and Emissions Inventory Unit, Technical Services Program, Air Pollution Control Division, Colorado Department of Public Health and Environment. Form APC6.1D2 remporr, File.= R calk, Mawla 4lbecd, f Sown Naar: larahU Culruw Swim, Allen 14th Calends DePaomol.i P.Hk Ik.IW na1Ieriroareer All PPIPWa (Petrel Dialaion Facility Wide Emissions Inventory Form ve, APr mis Pei.Fl�Fe•r 131. PM Hp [seamen. Fes. II J .1S1i p.pA+w rl Ian 1.0* Iw! Ir.Ame. 00 05 01 00 o an ILI 1651 60 16,1 00 1,1 el 14.rra lama• 1 a Ye IP Ib 12,4 15.115101 1,221 OA Mrs 761 0 SO ! 1 ie 11111 51.5.10 HAP to AMY r{II awl 163 IR1v 154% 11 444i *al 4+A 0. moo 00 no r+¢t�ia�T o Po W 55 Iai 11.2 e.r.il Pel.eYrcar"PTV 1A� MUNI is s}ro S 1 Ile Pe IN 1 iwR+ Amnia 1J11 f fla arm,- 616 %fa r4a mai *Li I el 1,4 11 ale 1144 Ann icerm.. Men uel rea.nl. • Plmlear.!dam. it +P; aka.. treW 01 ‘15.101111211119.splinia 1.1-•1,60.11050105.1041265 Pi1rl. 1..5114141 nrf 4,54 ea* Fee 1112 1116 005 001 0 05 oar 4. Odd 1,10 PAN 114 oo 5.5 02 12 New o lamp, 001 w+e ewa.a oo or 1612 06 -r.0.ee_4w..re 6 64 -aa-r4rt.44 luwe,e. CFI -kiampeas 01 2.1001.5•50 00 or or • 10 o. alpa.rer�.l� a4 06 Pm 15 • o 152 sa 55 5.4 14 Leer NMI OIL Lad a4 ELY Mel +ar wle�e..I Lr I L I If I al 1 I.A 1 PNA I M.+0.12B_LLIMLL_LISLIA.144 Ly1P4 WM I Mri IJR+41 V. 1 IM I LA I Li I LI L 1 1 44.4 I Lr I Mil I Ra I Ir+ 11111 IDOL 19 I C I Lora L ra t e..+e4...eAn art -1 IR+ I IA I Ii I ILl 1 w I 9A I L. 1 rA I u, 1 rr.r.r1 era A.lur. n m �f'�l Peter., I. Am Tura dreli !or arlleled b s4de Ida ..w.F u..a as d PF`Tre.i ern w e,41141 ar w m4y =mum rem !. Mi. animas raua..w im n.,•••• occ, Nee he Pena Ne. r ARS 11 .1444 mkar 1 KV rMcirPwr garb* a - Bma. 1UFTLP= ==4TImakpt.e""` Tom- Tdxer Art- i.an.hr+ u • Ulayinorars 141- !rice .a.4-,.4o_e PearMAlYr Mall - klNr4 4 APC4lsmrrt.ri.i Sa.s.ku4b 4.4.1ed .44n aarerletl. 1rrwrriawn ••••• 1 1.1,4 1+ 1 14 1 la I u I a1 i LI I aI I RI I AF I LI c�a1 r.arw.lxFrl 41"In Emission Source Type of Equipment CO NOx SOx PM,5 PM2.5 VOC HAP (APEN Exempt) Compressor Venting 0.45 0.02 Total Emission Permitted Sources 21.9 39.6 0.13 2.3 2.3 55.7 7.7 GP02 Emission Limitations 90 90 90 20 Major Source Thresholds 100 100 100 100 100 100 25 1 Engines are authorized by GP -02 and will not be included in this construction permit. 3.4 Ambient Air Impact Analysis As outlined in the Colorado Modeling Guideline — Updated Tables (Updated 5-20-2011), modeling is. required for sources subject to the Prevention of Significant Deterioration (PSD). The Broomfield Compressor Station will not be a major PSD source. New sources whose total controlled emission levels are greater than those listed in Table 5 are required to submit a dispersion modeling analysis as part of a complete construction permit application. Table 5. Emissions Levels for New Sources, where Modeling may be Required Pollutant Requested Emission Rate from a New Source or Facility -Wide Net Emissions Increase from a Modification CO NOx SO2 PM n) PM2.5 100 tpy 40 tpy 40 tpy 15 tpy 5 tpy Section 7 of the Colorado Modeling Guidelines provides information on the specific data required for permit applications. New sources and modifications with emission less than the thresholds in Table 5 do not need to provide any modeling related data. As presented in Table 4, based on the total facility emissions, an impact analysis is not required for the compressor station. In addition, VOC and HAPs are not specifically listed in Table 5, and therefore, ozone modeling and HAPs modeling are not routinely performed as part of the permit review process, VOC sources do not need to provide any modeling -related data beyond what is requested in the permit application and/or APEN forms. Thus, an ambient air impact analysis is not required. 4 AIR QUALITY REGULATORY REVIEW The following section describes the potentially applicable state and federal air quality regulations and whether the compressor station is subject to such requirements. A brief discussion of certain state and federal requirements and their applicability is included below. 13 Deciphering Denver's Ozone Problem: What's the Role of Oil & Gas Development? I I The Issue for Denier: Ozone Nonattainment • The Denver urban area is often out of compliance with the National Ambient Air Quality Standards (NAAQS) for ozone (03) in the summer. • At least a fifth of Denver's ozone is produced locally from the region's emissions of nitrogen oxides (NOx) and volatile organic compounds (VOCs). • Quantifying the most important regional sources of NOx and VOCs is key to Denver's efforts to comply with federal ozone standards. Ozone Basics • Regulated pollutant that is harmful to human health, ecosystems, and crops • Formed in the atmosphere from other starting ingredients: nitrogen oxides (N0x) reacting with volatile organic compounds (VOCs) • N0x and VOCs come from human activities such as the use of fossil fuels (motor vehicles, power plants) and from natural sources VOCs Sunlight, 02 — 4000 - 3t(Q - 2000 r6 - , 000 — 0 What's Unique about Denver's Ozone? Urban Boundaries Active Oil&Gas Wells Agriculture power Plants Measurement Site • Denver's locally produced ozone is fueled by large sources of NOx and VOC pollution that are in close proximity: - NOx from urban activity (fossil fuel combustion) - VOCs from oil and natural gas (0&NG) activity, urban activity, agriculture • Natural emissions of NOx and VOCs are low in the region NOAA Findings: How Do Local Emissions Influence Denver's Ozone Pollution? Method: Detailed measurements of NOx and VOCs near the center of Denver's nonattainment area Atmospheric chemical model of ozone's response to changes in NOx and VOCs c U c Modeled Locally Produced Ozone (ppb) ,�,r.`_.'.KU•••• a--0 Doubled Doubled aks 20 i•sw f 15 10 0 • r i 4'� �•V h.s Observed NO, 24 -hour Average 4S -' U yis 'It 0 5 10 15 20 lN(lx (Nth) - 24 -hour Average 25 VOC. Distribution (ppb of Carbon) O&NG VOCs Ob serred VOCs (Base Case) „ Zero O&NG VOCs • Alkanes Alkenes+Al kynes Aromatics Aldehydes+Ketones Alcohols 1Biogenics Oil and natural gas activities affect the types of VOCs in the atmosphere i _ In the Denver region, a few parts per billion (ppb) of ozone can affect compliance with the Federal ozone standards. 1 • At current levels of N 0x, oil a n d natural gas (O&NG) VOC emissions contribute to "19a% (t`'3 ppb) of the ozone produced in the north Denver metro region (see red bracket) • For any given level of NOR, increases in 0&NG emissions will increase ozone (compare black curve to green curve), but: - The ozone increase would be larger if NOx increases from its current level - The ozone increase would be smaller if NOx decreases from its current level Bottom Line: Ozone produced locally in the northern Front Range metropolitan area of Colorado is sensitive to NOx, as well as to VOCs from oil and natural gas activities Payoffs of this Research • Quantifies the roles of the Denver region's major emission sources in producing ozone pollution • Provides the scientific basis for air quality approaches that could bring the region into compliance with NAAQS D2 contact: Mackenzie Solomon, NOAA Office of Legislative and Intergovernmental Affairs, 202-482-2497, mackenzie.solomon@noaa.gov http: / / www. t i mescal!. corn/ Iongmont-local-news/ ci_32296572/ Iongmont-group- host i ng-cu-researcher-discuss-impacts-oi I Winds carry oil, gas pollutants into Boulder County, CU researchers say Researchers found strong correlation between winds from Weld County and increased levels of certain air pollutants By Cassa Niedringhaus Staff Writer POSTED: 05/27/2018 09:00:00 AM MDT UPDATED: 05/29/2018 11:07:19 AM MDT Jade Hunter, left, and John Beuford give their stand-up paddleboards a warm-up on the Boulder Reservoir on Friday afternoon. University of Colorado researchers studying air quality at Boulder Reservoir say there is a strong correlation between northeasterly winds from Weld County and levels of petroleum hydrocarbons in Boulder's air. (Paul Aiken / Staff Photographer) EDITOR'S NOTE: This story has been updated to correct the spelling of Brendan Blanchard's name Winds carry air pollutants into Boulder County from oil and natural gas development, likely in Weld County, according to local researchers. More than a year ago, University of Colorado researchers embarked on a project to track Boulder's air quality that is sponsored by Boulder County Public Health and in partnership. with the Colorado Department of Public Health and Environment. Since then, a system of instruments in a nondescript white shed next to Boulder Reservoir has quietly collected tens of thousands of data points about 19 air pollutant compounds in the atmosphere. ADVERTISING Earlier this month, the researchers announced one of their biggest and clearest findings: There is a strong correlation between northeasterly winds from Weld County and levels of petroleum hydrocarbons — such as methane, ethane and propane — in Boulder's air. "I am very surprised how obvious and predominant that signal is," said. Detlev Helmig, an associate professor at CU's Institute of Arctic and Alpine Research and the project's lead investigator. "I didn't think it would be that strong. This is so obvious. It's so clear. It didn't take a whole lot of detective work to show these dependencies." Helmig compared the various pollutants in the air to a trail mix of nuts, M&Ms and pieces of fruit. When winds blow from Weld County, he said, the trail mix is dominated by one type of nut: the petroleum hydrocarbons. Petroleum hydrocarbons are a type of volatile organic compounds, which can negatively affect the air quality and produce ozone, which in turn is bad for public health. In the short term, breathing ground -level ozone can cause coughing, throat irritation and chest tightness, CU noted in a story about the project. In the long term, it can increase rates of illness and death. VOCs "are a major ingredient driving the ozone production in the region," Helmig said. "That's, in the wider scale, the number one air pollutant that affects by far the highest number of people in this region, from a health perspective." 'A big industrial operation' Through their work, Helmig and the other researchers were able to show the spikes in petroleum hydrocarbons are most likely from Weld County oil and gas operations, which usually use heavy equipment, generate power on -site and have high truck traffic, all of which create pollution. "In all of these steps, it's a big industrial operation," Helmig said. "There are potential emissions all along the sequence of production steps." Urban emissions and vehicles appear to be smaller sources of VOCs, the researchers said. Cindy Copeland, a Boulder County air quality specialist, said county officials wanted to use the study to get a better idea of the pollution sources here, and they have already presented preliminary data to the state. They plan to analyze the data further to pinpoint more specifics they can use to improve air quality in collaboration with the state. "We have been actively engaged with the state's processes for continuing to reduce emissions from any source," Copeland said. "One of our big areas of concern is the ozone problem." Copeland said many people don't realize the area has an ozone problem, and they can contribute to the solution by driving less, especially during summer afternoons as temperatures rise. University of Colorado researchers, in partnership with the county and state, installed an air quality monitoring system near Boulder Reservoir last year. Now, in preliminary results, they've found a strong correlation between winds blowing from Weld eld County oil and gas facilities and increased methane and other chemicals in the air around the reservoir. (Paul Aiken /Straff, Photographer] 'Added sense of purpose' Another element of the project is that data is collected each hour and subsequently posted to a website that anyone can visit. The team wrote scripts for the data to post to the website automatically, but they have to troubleshoot when errors in the code arise. And they have a sense of urgency because they receive calls and emails from the public if they don't address the issue quickly. Helmig said this project has generated the most public interest of any of his research projects over the course of decades. "What has happened in this ease, which we've never had before, sometimes if things go wrong or stall we get calls or emails from citizens within a few hours. The people are watching that day and night," Helmig said, adding that people use the data to decide whether to venture outside their homes for a hike or other outdoor activity. The website has received more than 10,000 visits over the past year. Brendan Blanchard, a professional research assistant, has helped to keep the website running and improving, among other tasks. "There is an added sense of purpose, but it does come with pressure," Blanchard said. "It's good to be interacting with the public and see that it has a much more direct effect than writing a paper that gets read and cited by 50, 100, 200 scientists. This is reaching a couple hundred people a week, at least. That really adds into the effect it has when the website is down for two hours, let alone two days." The project is funded through September, and the group is looking for new funding to keep it going beyond then. Helmig said he hopes the existing data can inform legislators when they draft regulations to target certain emissions and to help them achieve airquality goals. He'd like to continue collecting data to measure whether those regulations work, too. "You need to watch it," he said. "Otherwise, you're just hoping." To see the data in real time, visit: instaar.colorado.edu/arl,lboulder reservoir.html. Grasso iedringhaus: 3493-473-11o6, eniedringhausduilycarnera.com Also see: http:, /ww.timescall.com/Iongmont-Iocal-news/c 32296572/Iongmont-group-hosting-cu- resea rcher-discuss-impacts-o i l Longmont group hosting CU researcher to discuss impacts of oil and gas production on air quality Longmont likely experiences highest levels of volatile organic compounds, ozone caused by oil, gas drilling of Boulder County municipalities, research suggests By Sam Lounsberry Staff Writer POSTED: 11/27/2018 07:45:59 PM MST I UPDATED: ABOUT A MONTH AGO Detlev Helmig points out data being displayed on a laptop next to flasks of air- samples Tuesday in a lab at the University of Colorado Sustainability Energy and Environment Community Building. Helmig, an associate research professor at the University of Colorado's Institute of Arctic and Alpine Research who led a study that attempted to isolate the impact of oil and gas development on overall air quality and ozone levels in Boulder County, will present his findings Wednesday in Longmont. (Matthew Jonas / Staff Photographer) Boulder County commissioners, after being briefed last month on the study results, used the data to justify their stand against large-scale, multi -well horizontal drilling projects recently marked by the county's filing of three lawsuits against two oil and gas companies with drilling proposals in the county. Advertisement The Longmont Public Forum group of community activists is hosting Detlev Helmig, an associate research professor at the University of Colorado's Institute of Arctic and Alpine Research who led the study, to discuss his work. Helmig's presentation at Front Range Community College will be followed by a discussion on plans to take action to reduce the risk to air quality at Union Reservoir, beneath which Longmont City Council agreed to allow fracking and horizontal drilling as part of a S3 million deal with two oil and gas companies to end surface drilling in the city. Helmig's research — which centers on air quality samples taken continuously for 18 months at Boulder Reservoir — and its finding that winds from the northeast blow air high in ozone levels from heavily drilled Weld County into Boulder County have created concern among county leaders. "One of the most striking conclusions of the research is how much we are all impacted by the oil and gas drilling occurring across the region, regardless of whether it's in our particular jurisdiction," Commissioner Elise Jones said. "... This highlights the critical need for statewide protections to safeguard public health. From ozone to carcinogenic toxins like benzene, we can't solve our air quality challenges just at the local level — statewide action is rr necessary. Gordon Pierce and Jeremy Neustifter, with the Colorado Department of Public Health's Air Pollution Control Division, pointed out that Colorado in 2014 became the first state in the nation to regulate thorough inspections of the emissions of hydrocarbons, including methane, from oil and gas facilities and that the rules were further tightened in 2017. "For oil and gas development, fracking is just a short-term — days to a few weeks — event in the development of a well. (The public health department) continues to be interested in better quantifying how these emissions, as well as longer -term production emissions, impact air quality across the state," Pierce said. Because of its proximity to Weld County, Longmont is more likely to experience higher levels of methane, ethane — natural gas molecules associated specifically with drilling operations — and ozone than other Boulder County municipalities, Helmig said. The ozone levels of the air containing emissions from Weld County drilling sites are higher than air coming from the more densely populated Denver area, the study found, and the Weld air "contributes significantly to exceedances of the ozone standard," Helmig's presentation to Boulder County commissioners noted. "We're living in a region here that has elevated levels of a number of pollutants, and they vary spatially. ... From my understanding of how ozone behaves, if we had winds from the west all the time, we would have a much lower ozone average," Helmig said in an interview. The study was motivated by the Front Range exceeding the U.S. National Ambient Air Quality Standard for ozone since 20O4. That threshold for ground -level ozone is currently 70 parts per billion. Ensuing failure to reduce the levels across the state have "raised questions about which emission sources are contributing to the Front Range's air quality concerns," according to CU web page explaining the air quality study that also shows the Boulder ! eservoir measurements in real time. The study found the Boulder Reservoir site in 2018 saw the highest eight -hour average ozone level across the Front Range at 89 parts per billion, as of last month's presentation by Helmig to commissioners. Boulder County funded the study with $183,772 for 18 months of continuous air quality monitoring that ended in September. The project to monitor the concentration of volatile organic compounds created specifically by oil and gas development at Boulder Reservoir is continuing with some funding from Earthworks, a nonprofit organization that, according to its website, is "dedicated to protecting communities and the environment from the adverse impacts of mineral and energy development while promoting sustainable solutions." Sam Lounsberry: 3O3-473-1322, slounsberry t,,prc iricmountainmedia.coin and twitter*.con/sorniiOztnz. https://www.greelevtri bu ne.com/news/longmont-grou p -discusses -air -poll utants-from-weld-that-are- drifting-into-other-comm unities/ Longmont group discusses air pollutants from Weld drifting into other communities Sara Knuth November 29, 2018 LONGMONT Air pollutants some say come from oil and gas operations in Weld County are drifting into neighboring communities and raising alarm bells for activists in Boulder County. But Weld County leaders said they are skeptical of the scale of the impact that local oil and gas operations have on air quality. In a forum hosted Wednesday by a group of activists called the Longmont Public Forum, Detlev Helmig, an associate professor at the University of Colorado Boulder's Institute of Arctic and Alpine Research, presented data collected for more than a year as part of a project to monitor air quality near the Boulder Reservoir. The study, which began in February 2017, monitors methane, volatile organic compounds and nitrogen oxides with instruments set up near the reservoir. Helmig, who leads the Boulder County Public Health -funded project, presented data that showed a strong relationship between oil and gas operations in Weld County — the No. I producer of oil and gas in the state and air pollutants such as ethane, propane and methane that were picked up by recording equipment at the Boulder Reservoir. It's not the first time air quality in the region, including Weld County, has come under the microscope recently. The Colorado Regional Air Quality Council in Denver announced in October that a nine -county region along the Front Range failed to meet the U.S. Environmental Protection Agency's ozone standard, which is 70 parts per billion and was set in 2015. The region also doesn't meet the EPA's 75 parts per billion standard set in 2008. "I think ozone really is the biggest player when you look at the largest scale and how many people get affected by that/' Helmig said of ground level ozone, which is created by chemical reactions between oxides of nitrogen and volatile organic compounds in the presence of sunlight. FOR MORE To see data collected by University of Colorado Boulder's Institute of Arctic and Alpine Research at Boulder Reservoir, visit http://instaar.colorado.edularllboulder reservoir.html. Emissions from sources such as industrial facilities and motor vehicle exhaust, according to the EPA, are major sources of the oxides and volatile organic compounds. When people are exposed to ozone, it can cause health problems ranging from shortness of breath to an increased frequency of asthma attacks. In July, Helmig said, the data collected at the Boulder Reservoir showed that the region's air quality went past the EPA's ozone standards several times. The study, which does not monitor ozone itself, instead identifies sources of volatile organic compounds, methane and nitrogen oxides. "We were about this threshold many, many times," he said, adding that ozone levels are lower at night and generally increase during the day. This year so far, the highest ozone volume was recorded at 89 parts per billion, and there was a stretch in August in which the reservoir exceeded the EPA's ozone standards of 70 parts per billion five days in a row. Helmig also showed a map that depicted ozone levels across the nation and pointed out there were improvements cities across the U.S. except, notably,in northern Colorado. "We're not part of the success story," he said. "We really stick out." oil and gas industry officials acknowledge the impact of oil and gas operations on ozone levels, but officials with the Colorado Oil and Gas Association said the industry is making efforts to reduce emissions. According to the association, oil and gas companies plugged and reclaimed an estimated 1,850 wells in 2017 and in June, officials expected to plug and reclaim an additional 2,150 wells in 2018. They estimated that the nearly 4,000 wells, plugged with cement and later reclaimed by planting grass, would result in emission savings of 2,843 tons per year of volatile organic compounds emissions, 25 tons per year of nitrogen oxide and 116 tons per year of carbon monoxide. In the summer, the time of year when ozone measurements reach their highest levels as the result of high temperatures and low winds, association officials said companies participate in voluntary emission reduction efforts ranging from reducing oil and gas vehicle traffic to taking aerial surveys of their sites to find and fix leaks. Dan Haley, the president and CEO of the Colorado Oil and Gas Association, said in a statement Thursday that the industry has lowered volatile organic compound emissions by nearly 50 percent in northern Colorado since 2011. Haley also said the study doesn't monitor ozone levels. "It's always important to point out that one of the biggest challenges Colorado faces when it comes to ozone formation is the fact that our unique topography and weather patterns result in significant amounts of emissions from states like California, and even countries like China, that circulate in our atmosphere and end up in Colorado, leading to additional ozone formation," Haley said. "This is a challenge other states do not have to confront, and that is not about pointing fingers at Boulder or Weld counties." Weld County Board of Commissioners Chairman Steve Moreno said it's disingenuous to say that Weld County is a leading source of ozone in the state. "I don't disagree that air quality is one of the things we need to improve on," he said. "But there are a number of factors that contribute to ozone. ... The wind doesn't always blow from east to west, and not every vehicle passes emissions tests." During Wednesday's discussion, when a member of the audience asked Helmig if the emissions were coming from Weld County, he said to be cautious the pollutants can come from a variety of sources depending on weather patterns. But he said it's surprising that the study, which determines the source of pollutants via past weather patterns, shows that high levels didn't necessarily come from Boulder or Denver, where the population is higher. Often, they traveled to Boulder from a northeastern direction, and Weld County is located northeast of Boulder. Helmig also showed the audience data collected at the reservoir on Dec. 22, 2017 the same day an Extraction Oil & Gas site east of Windsor experienced an explosion. According to the data, Helmig said, the site was likely leaking long before the explosion. "This leakage probably occurred over at least nine hours," Helmig said. "Any place closer to the source would have seen higher levels." Sara Knuth covers government for The Tribune. You can reach her at (970) 392-4412, sknuthgreeleytribune.com or on Twitter @SaraKnuth. LBNL-6990E Opportunities for Efficiency Improvements in the U.S. Natural Gas Transmission, Storage and Distribution System Jeffery B. Greenblatt Energy Technologies Area May 2015 Page 6 b. Prime movers Among prime movers, there are three main choices in use in the natural gas TS&D system: gas engines, gas turbines and electric motors. Gas engines. Similar to an internal combustion engine used in a vehicle, the gas engine (sometimes called a reciprocating engine) uses a chamber, filled with combusting natural gas, to drive a piston. While modern gas engines are quite efficient, they do have power limitations, and can have high vibration issues that affect reliability. Also, certain components may require frequent maintenance (INGAA, 2010a, p. 34). These issues are discussed more thoroughly in Sections 1 -C -ii and 2-A. Gas engines are normally divided into two general categories related to speed. These categories are slow -speed engines (≤600 rpm) and medium - speed engines (600-2,100 rpm). There are also two basic types of gas engine designs: the two-stroke cycle and four-stroke cycle. Either type can be turbocharged. The two-cycle engines require less displacement for the same rating. The differences in performance between these engine types are small, especially with turbocharging (CAGI, 2012, p. 448). Slow speed engines are in common use in integral gas engine compressors. "Integral" indicates the use of a common crankshaft to drive both the power cylinders and the compressor. Integral machines are typically subdivided according to power output: small (25-800 hp) and large (800-7, 000 hp). Small integral engines are used in oil field services 12 (gas gathering, gas injection, small gas processing plants). Larger integral engines are used in process plants, main line gas transmission, gas injection, and large gas plants (CAGI, 2012, p. 518). Medium -speed gas engines (600-2,100 rpm) are generally used for non - integral (separable) oil field compressors. Power sizes range from 5 to 3,600 hp, with the smaller end of the range (5-400 hp) generally operating at medium speed (1,400-1,800 rpm), while the larger end (300- 3,600 hp) are generally directly connected and operate at lower speeds (600-1,200 rpm). Across the industry, the trend is toward higher driver speeds to keep pace with increasing compressor speeds (CAGI, 2012, p. 519) Legacy internal combustion, slow speed gas engines have significantly less sophisticated controls and lower fuel efficiencies than state-of-the-art engines (INGAA, 2010a, p. 34). Gas turbines use hot exhaust gases produced from the discharge of a gas generator to drive a power turbine. Two types of turbines are used: 1. aeroderivative engines, based on gas turbines developed for the aviation industry, and 2. industrial turbines, which are designed specifically for industrial use. Aviation industry developments have contributed to performance improvements in both types of turbines (INGAA, 2010a, p. 34). Gas turbines have limited application in the process and oil and gas industry as prime movers. The gas turbine is relatively new compared to the gas engine, steam turbine or electric motor (see Section 1 -C -ii). However, there are some applications where gas turbines (typically driving reciprocating compressors) are more common. One application is offshore compression, where weight is a concern. Another application is refineries or process plants, where turbine exhaust heat can be utilized to improve overall plant efficiency (CAGI, 2012, p. 527). Smaller plants (<10,000 hp) will typically choose a gas engine over gas turbines, unless the waste heat can be utilized (see also discussion of waste heat recovery in Section 2 -A -iv). Gas engines have inherently better efficiency compared to smaller gas turbines (CAGI, 2012, p. 435). Efficiency trade- offs will be discussed further in Section 2-A. Electric motors are more reliable and more efficient as stand-alone pieces of equipment than either gas engines or gas turbines. They are able to ramp up more rapidly than gas -driven prime movers. They also have an advantage where air quality regulations are an issue because they do not emit nitrogen oxides and C02 at the point of use. There are a number of competing factors, however, that affect the suitability of electric motors over gas -based technology. One is the requirement for variable speed, while the other is the availability and proximity of a suitable electric power supply or substation. Reliability of the grid is also a concern, particularly in remote locations (INGAA, 2010a, pp. 34-35). While natural gas drivers are the primary technology for oil and gas field operations, electric motors are increasingly being used due to environmental considerations (CAGI, 2012, p. 520). There are three types of electric motors: induction, synchronous and DC. Each is described briefly below. 13 Induction is the most common type of electric motor. Induction motors generally have good efficiency and excellent starting torque, but rather high inrush current4 requirements. Induction motor efficiencies lie in the high 80% to low 90% range, depending on power. Smaller power induction motors are generally less efficient (CAGI, 2012, p. 522). Synchronous motors are the most common type of driver used for high - power applications, e.g., above 700 hp for speeds greater than about 450 rpm, or above 200 hp for lower speeds. These motors are typically more efficient than induction motors, with efficiencies in the range of 93%- 97%. Synchronous motors must be carefully analyzed because of their lower torque characteristics, however (CAGI, 2012, pp. 521-522). The use of DC motors as oil field compressor drivers has increased in popularity in recent years. The reasons for this increase are threefold: 1. Availability of DC traction motors, 2. Variable -speed capability of DC motors to control compressor capacity, and 3. Economic considerations of motor drive versus engine drive. However, when utilizing DC motors in a hazardous atmosphere, it is necessary to provide a continuous positive air pressure in the motor enclosure to assure that no gas can get into the motor and be ignited. Offshore oil field compressors are using more DC motor drivers because of the added speed flexibility, lower initial cost, and projected lower maintenance costs (CAGI, 2012, p. 523). However, it appears that these are not used much in gas compression applications. The improvement in electronics control has greatly increased the potential for motors to be utilized as compressor drivers, especially in oil field applications. This has happened because of technological advances in motor controls. It is now economical to buy induction motors or synchronous motors with variable -speed controls to adjust the compressor operating speed. DC motors, having inherent variable -speed capability, already provide the needed variable speed with little further equipment needed. Variable speed to control compressor performance is a very desirable characteristic of a compressor prime mover A i B C i D i E F i G 1 H \Drawings\BCS-CE-102.dgn NUMMI mg 0 cC U L `IY 1 a E C U :t r1 (■,Y1fl r T Nl - CO ri .i3 C) scl O_ c, u co CoO op N. 110 co • . N E ro LT 0 4-1 U a. 1 z 3 4 I F I CINDY IRENE SEILER & NICK EDWARD SEILER (PARCEL NO: 146929300005) PROPERTY CORNER N 1 248 822.17 E 3 164 036.02 WCR-4 1 PROPERTY CORNER N 1 261 427 E 3 164 011 USR18 OOXX BROOMFIELD COMPRESSOR STATION q fe ti DISCOVERY OVERALL SITE PLAN •6N WELD COUNTY, COLORADO PARCEL NO. 146929000045 1624. M 4, APPROXIMATE CENTERLINE'::<}V.s PIPELINE RIGHT OF WAY GRANT ASSOCIATED NATURAL GAS INC. UNSPECIFIED WIDTH REC. NO. 2233779 r I LEASE CORNER N 1 251 436.19 E �3 1{65 c 0042 I 4. 1 LEASE CORNER N 1 251 440.88 E 3 165 960.22 PROPERTY CORNER N 1 51 445. 2 APPROXIMATECENTERLINE RIGHT OF WAY GRANT KN WATTENBERG TRANSMISSION LLC. UNSPECIFIED WIDTH REC. NO. 2638336 ` II EXISTING OVERHEAD ELECTRIC r• JOHN E & DIANA G HOWARD ETAL (PARCEL NO: 146928200002) "Tar v r tit: JENNIFER M BARGEN (PARCEL NO: 146933200036) 4875 -_ a NOTES LEGEND EXISTING MAJOR CONTOURS EXISTING MINOR CONTOURS RIGHT-OF-WAY PROPERTY LINE LEASE BOUNDARY ADJACENT PROPERTY LINES DRAINAGE FLOW ARROW TRAFFIC FLOW ARROW ACCESS EASEMENT EXISTING DITCH LINE 100 YEAR FLOOD PLAIN 0 NORTH 100' 200' 1. THE BROOMFIELD DISCOVERY COMPRESSOR STATION IS LOCATED IN PART OF THE NORTHEAST 1/4 OF THE SOUTHEAST 1/4 OF SECTION 19, TOWNSHIP 01 NORTH, RANGE 67 WEST, 6TH PRINCIPAL MERIDIAN, WELD COUNTY, STATE OF COLORADO. 2. THE SITE SURVEY FOR THIS PROJECT WAS PREPARED BY ACKLAM, INC. AND WAS RECEIVED JULY 2018. HORIZONTAL DATUM : BASED ON COLORADO STATE PLANE COORDINATES, NORTH ZONE, NORTH AMERICAN HORIZONTAL DATUM, 1983 (Us SURVEY FEET), GRID. VERTICAL DATUM NORTH AMERICAN VERTICAL DATUM 1988. 3. THE LANDSCAPING AND LIGHTING PLANS TO BE SUBMITTED AS SEPARATE DOCUMENT (DWG BCS-EE-200, LIGHTING PLAN AND SCHEDULE). LIGHTING WILL BE DOWNCAST AND SHEILDED. 4. OFFSITE PIPING AND PIPING CONNECTIONS TO THE FACILITY DESIGNED BY OTHERS. iinow whaUs below 400' SCALE: 1" = 200' Call before you d 600' This document is copyrighted and is an instrument of service by Samuel Engineering (SE). It was prepared solely for the Owner's/Client's use on this project only. Use, copy or disclosure of any information shown, in whole or in part, without SE's consent, is strictly prohibited, is a copyright breach and may be prosecuted. Any unauthorized reuse shall be at the sole risk of the user. DWG NO. DESCRIPTION REFERENCE DRAWINGS w Li te �w W w NO, DESCRIPTION DATE BY REVISIONS w U BP w LJ Z Cez �w L MAS w ua z 0 J w W U A NO, L ISSUED FOR USR DESCRIPTION I 08/17/18 DATE MAS BY REVISIONS SCALE: 1" 200' DESIGNED: M. SKELSKEY DRAWN: M. SKELSKEY CHECKED: r APPROVED: tt t _ APPROVED: DATE 05/23/2018 05/23/2018 CLIENT: LOCATION: DISCOVERY DJ SERVICES, LLC WELD COUNTY, CO Samuel Engineering We Provide Solutions 8450 E. Crescent Parkway, Suite 200 Greenwood Village, CO 80111 Phone: 303.714.4840 Fax: 303.714.4800 TITLE BROOMFIELDCOMPRESSOR STATION DISCOVERY DJ BASIN FIELD COMPRESSION CIVIL GENERAL OVERALL SITE PLAN PROJECT NUMBER 18132 DRAWING NUMBER BCS-CE 102 REV. A A 1 B C D i E F 1 G H A i B 1 C i D I E i F i G i H 0 w U en co C PO kLa .5; U a U 0 in tin cu 8 E U l a) ' u mlCti 4-1 en c ELI 00 ri a)0 - s U .. '0 ri CO ri C7:3 CsJ 2N m «o nai 62: u_ O a4-1 U 1 z 3 4 NORTH 25' 50' 100' 150' SCALE: 1" = 50' IN LEGEND RIGHT-OF-WAY PROPERTY LINE SECTION LINES DRAINAGE FLOW ARROW TRAFFIC DIRECTION ARROW RECYCLED ASPHALT PAVEMENT PROPOSED CHAIN LINK FENCE EASEMENT LINE IJSRi8 OOXX BROOMFIELD COMPRESSOR STATION DISCOVERY DJ BASIN FIELD COMPRESSION PLOT PLAN WELD COUNTY, COLORADO PARCEL NO, 146929000045 1 011 LEASE CORNER N 1 251 436.19 E 3 165 300.42 FUTURE SUBSTATION DARRELL JOHNSTON & ERN LTD PARTNERSHIP (PARCEL NO: 146929200040) 7' CHAIN LINK SECURITY FENCE 659.82' S89°35'36"W 122 126 ? o O CONSTRUCTION rn TRAILERS (TEMPORARY) 9.995 ACRES 110 128 123E El ersi 115 022 121 o 125 9 c O 118 �- 124 6 221 D D 220 315 314 120 311 SITE DRAINAGE SWALE PIG LAUNCHER SITE LEASE CORNER N 1 250 776.39 E 3 165 305.10 This document is copyrighted and is an instrument of service by Samuel Engineering (SE). It was prepared solely for the Owner's/Client's use on this project only. Use, copy or disclosure of any information shown, in whole or in part, without SE's consent, is strictly prohibited, is a copyright breach and may be prosecuted. Any unauthorized reuse shall be at the sole risk of the user. 30' EXISTING GAS PIPELINE EASEM ENT DWG NO. DESCRIPTION REFERENCE DRAWINGS 2 U 5' BERM STORMWATER DETENTION POND DESIGN VOLUME = 40337 CF NO BUILD/STORAGE AREA NO. N 1 251 440.88 E 3 165 960.22 ENTRANCE GATE DESCRIPTION LEASE CORNER N 1 250 781.07 E 3 165 964.90 i DATE BY REVISIONS BP oG w w z o5 re= aw MAS w z �" W Z J w TMH APPROX. 670' X 50' WIDE ACCESS EASE. REC. NO. XXXXXX PLANT ACCESS ROAD EXISTING OVERHEAD ELECTRIC WCR p 'v VICINITY MAP 1/4 CORNER SEC 29/SEC 28 3.25" ALUM, CAP PLS 37890 2006 NORTH (1 " = 1000, LEGAL DESCRIPTION THE SUBJECT PROJECT IS LOCATED IN PART OF THE NORTHEAST 1/4 OF THE SOUTHEAST 1/4 OF SECTION 19, TOWNSHIP 01 NORTH, RANGE 67 WEST, 6TH PRINCIPAL MERIDIAN, WELDCOUNTY, STATE OF COLORADO. NOTES 1 2 3 PROPOSED SITE ACCESS WILL BE FROM WELD COUNTY ROAD 17. WCR 17 IS COUNTY MAINTAINED WITH AN EXISTING 60' RIGHT-OF-WAY. THE SITE SURVEY FOR THIS PROJECT WAS PREPARED BY ACKLAM, INC. AND WAS RECEIVED JULY 2018. HORIZONTAL DATUM : BASED ON COLORADO STATE PLANE COORDINATES, NORTH ZONE, NORTH AMERICAN HORIZONTAL DATUM, 1983 (Us SURVEY FEET), GRID. VERTICAL DATUM : NORTH AMERICAN VERTICAL DATUM 1988. THE LANDSCAPING AND LIGHTING PLANS TO BE SUBMITTED AS SEPARATE DOCUMENT (DWG BCS-EE-200, LIGHTING PLAN AND SCHEDULE). LIGHTING WILL BE DOWNCAST AND SHEILDED. EQUIPMENT LIST 010/022 110 111 112 113 114 115 116 117 118/119 HEADER SKIDS INLET ESD SKID INLET SCRUBBER SKID MCC BUILDING AIR SKID PUMP SKID FUEL GAS SKID 3 PHASE SEPARATOR SKID NGL METER SKID GAS METER SKID 120/122 123 124/126 128 210/217 220/221 310/311 314/316 411/412 430 FILTER SKID HYDROPHOBIC FILTER TEG CONTACTOR INLET METER SKID COMPRESSOR SKIDS VRU COMPRESSORS TEG DEHYDRATION UNIT B-TEX UNITS COMBUSTORS SLOP TANKS METAL SIGN MOUNTED TO POLE W/RIVETS METAL POLE I la III CONCRETE BASE FOR POLES 4.0' BROOMFIELD COMPRESSOR STATION BROOMFIELD LOCATION COUNTY ROAD 17 BROOMFIELD, COLORADO USR18-60XX IN CASE OF EMERGENCY CALL: 911 NORTH METRO FIRE PROTECTION DISTRICT: (303) 452-9910 COMPANY EMERGENCY CONTACT (970) 987-2527 1 PROJECT SIGN Know wha belOw call before you d' O A NO. ISSUED FOR USR DESCRIPTION 08/16/18 DATE MAS BY REVISIONS SCALE: 1"= 50' DESIGNED: M. SKELSKEY DRAWN: M. SKELSKEY CHECKED: APPROVED: APPROVED: DATE 05/23/2018 05/23/2018 CLIENT: LOCATION: DISCOVERY DJ SERVICES, LLC DISC WELD COUNTY, CO VERY Samuel Engineering We Provide Solutions 8450 E. Crescent Parkway, Suite 200 Greenwood Village, CO 80111 Phone: 303.714.4840 Fax: 303.714.4800 TITLE BROOMFIELD COMPRESSOR STATION DISCOVERY DJ BASIN FIELD COMPRESSION CIVIL GENERAL PLOT PLAN PROJECT NUMBER 18132 DRAWING NUMBER BCS-CE- 104 REV. A Form APC6.1D2 remporr, File.= R calk, Mawla 4lbecd, f Sown Naar: larahU Culruw Swim, Allen 14th Calends DePaomol.i P.Hk Ik.IW na1Ieriroareer All PPIPWa (Petrel Dialaion Facility Wide Emissions Inventory Form ve, APr mis Pei.Fl�Fe•r 131. PM Hp [seamen. Fes. II J .1S1i p.pA+w rl Ian 1.0* Iw! Ir.Ame. 00 05 01 00 o an ILI 1651 60 16,1 00 1,1 el 14.rra lama• 1 a Ye IP Ib 12,4 15.115101 1,221 OA Mrs 761 0 SO ! 1 ie 11111 51.5.10 HAP to AMY r{II awl 163 IR1v 154% 11 444i *al 4+A 0. moo 00 no r+¢t�ia�T o Po W 55 Iai 11.2 e.r.il Pel.eYrcar"PTV 1A� MUNI is s}ro S 1 Ile Pe IN 1 iwR+ Amnia 1J11 f fla arm,- 616 %fa r4a mai *Li I el 1,4 11 ale 1144 Ann icerm.. Men uel rea.nl. • Plmlear.!dam. it +P; aka.. treW 01 ‘15.101111211119.splinia 1.1-•1,60.11050105.1041265 Pi1rl. 1..5114141 nrf 4,54 ea* Fee 1112 1116 005 001 0 05 oar 4. Odd 1,10 PAN 114 oo 5.5 02 12 New o lamp, 001 w+e ewa.a oo or 1612 06 -r.0.ee_4w..re 6 64 -aa-r4rt.44 luwe,e. CFI -kiampeas 01 2.1001.5•50 00 or or • 10 o. alpa.rer�.l� a4 06 Pm 15 • o 152 sa 55 5.4 14 Leer NMI OIL Lad a4 ELY Mel +ar wle�e..I Lr I L I If I al 1 I.A 1 PNA I M.+0.12B_LLIMLL_LISLIA.144 Ly1P4 WM I Mri IJR+41 V. 1 IM I LA I Li I LI L 1 1 44.4 I Lr I Mil I Ra I Ir+ 11111 IDOL 19 I C I Lora L ra t e..+e4...eAn art -1 IR+ I IA I Ii I ILl 1 w I 9A I L. 1 rA I u, 1 rr.r.r1 era A.lur. n m �f'�l Peter., I. Am Tura dreli !or arlleled b s4de Ida ..w.F u..a as d PF`Tre.i ern w e,41141 ar w m4y =mum rem !. Mi. animas raua..w im n.,•••• occ, Nee he Pena Ne. r ARS 11 .1444 mkar 1 KV rMcirPwr garb* a - Bma. 1UFTLP= ==4TImakpt.e""` Tom- Tdxer Art- i.an.hr+ u • Ulayinorars 141- !rice .a.4-,.4o_e PearMAlYr Mall - klNr4 4 APC4lsmrrt.ri.i Sa.s.ku4b 4.4.1ed .44n aarerletl. 1rrwrriawn ••••• 1 1.1,4 1+ 1 14 1 la I u I a1 i LI I aI I RI I AF I LI c�a1 r.arw.lxFrl 41"In Form APCD-102 Company Name: Elevation Midstream, LLC Source Name: Buffalo Compressor Station Source AIRS ID: TBD Colorado Department of Public Health and Environment Air Pollution Control Division Facility Wide Emissions Inventory Form Ver. April, 2015 Uncontrolled Potential to Emit (PTE) Controlled Potential to Emit (PTE) Criteria (TPY) I HAPs (lbslyr) Criteria (TPY) I HAPs lbs/yr) AIRS ID Equipment Description TSP PM19 PM2.5 5O2 NOx VOC CO i HCHO Acetal Acro BZ Tol EB Xyl n -Hex Meth 224-TMP TSP Pv110 PM2.5 5O2 NOx VOC CO i HCHO Acetal Acro BZ Tol EB Xyl n -Hex Meth 224-TMP TBD D - I: TEG Dehy -- -- -- -- 1.5 1009.8 6.8 I -- -- -- 219,347 137,645 34,782 69,161 23,424 -- 92 -- -- -- -- 1.5 31.4 6.8 I -- -- -- 9,248 4,597 837 1,511 1,071 -- 4 TBD D-2: TEG Dehy -- -- -- -- 1.5 1009.8 6.8 I -- -- -- 219,347 137,645 34,782 69,161 23,424 -- 92 -- -- -- -- 1.5 31.4 6.8 I -- -- -- 9,248 4,597 837 1,511 1,071 -- 4 TBD SC -1: CondensaLe Surge CorLrol Vessel -- -- -- -- 0.5 13.2 11.6 I -- -- -- 271 109 17 311 41 5 -- 2 -- -- -- -- 0.5 0.7 0.6 I -- -- -- 14 5 1 2 21 -- 11 I I I I Permitted Sources Subtotal= APEN Only - Permit Exempt Sources 9.0 0.0 0.0 0.9 3.5 2032.7 14.2 I 0I 0 0 438,966 275,398 69,5811 138,353 47,264 0 186 9.9 9.9 9.9 0.93.5 63.5 14.2 I I 0 9 9 18,510 9,199 1,674 3,924 2,163 0 8 I I I I I I I I I I I I I I APEN Only Subtotal = APEN Exempt! Insignificant sources 9.0 0.0 0.0 0.9 9.9 9.9 I 9.0 I 0 0 0 0 0 9 0 9 0 0 9.9 9.9 9.9 0.9 9.0 0.0 I 0.0 I 0 9 9 0 0 0 9 0 0 9 Please See Aua;hed List -- -- -- -- 0.11 1.4 0.0 I -- -- -- 3 -- -- -- 13 -- -- -- -- -- -- 0.0 1.4 0.0 I -- -- -- 3 -- -- -- 13 -- -- I I I I I I I I I Insignificant Subtotal = Total, All Sources = 0.0 0.0 0.0 0.0 0.0 1.4 9.0 I 0 0 0 3 0 0 0 13 0 0 0.0 0.0 0.0 0.0 0.0 1.4 0.0 I 0 0 0 3 0 0 0 13 0 0 I 9.0 0.0 0.0 0.9 3.5 2034.0 14.2 I 0 0 0 438,969 275,398 69,589 138,353 47,277 0 186 I 9.9 9.9 9.9 0.9 3.5 64.9 14.2 I 0 9 9 18,513 9,199 1,674 3,924 2,176 0 8 Uncontrolled HAPs Summary Uncontrolled Total, All HAPs Controlled HAPs Summary Controlled Total, All HAPs (TPY) = 0.0 0.0 0.0 219.5 137.7 34.8 69.2 23.6 0.0 0.1 (TPY)=I 0.0 I 00 I 0.0 I 9.3 I 4.6 I 0.8 I 1.5 I 1.1 I 0.0 I 0.0 I I (TPY) =I 484.9 (TPY) =I 17.3 Footnotes: I. This form should be completed to include both existing sources and all proposed new or modifications to existing emissions source 2. If the emissions source is new then enter "proposed" under the Permit No. and AIRS ID data column 3. HAP abbreviations include: BZ = Benzene Tol = Toluene EB = Ethylbenzene Xyl = Xylene HCHO = Formaldehyde 4. APEN Exempt/Insignificant Sources should be included when warranted 224-TMP = 2,2,4-Trimethylpentane Acetal = Acetaldehyde Acro = Acrolein n -Hex = n -Hexane Meth = Methanol Form APCD-102 Company Name: Llcention Midsucnln, LU. Source Name: Dodger Central Guth,: ring Facility Source AIRS TI): Proposed Colorado Department of Puhlic Ilealth and Environment Air Pollution Control Division Facility Wide Emissions Inventory Form Ver. April 2015 Uncontrolled Pnlcntiul In Tsai( (PITT Caalr,JIcd Plllc„ liar 11, [mil (111111 C ilcriu (TP\') I 11APn Ol,n/yr) Criteria (TPS) I HAP (iss's')) AIRS IT) Tauipmcal llexriplinn TSP PN110 PM35 503 VOc 303 CO . ndn0 Acc0,J Aeru Iii T,1 7,13 ITO ,.net Mc11, 331TMP TSP PM10 P9175 503 NO: ROC CO . TICIIO Acc0,1 Aern HZ Tiu 114 ITO „-nee Meth 224 TM! Pup1u.5: 41' 1Pio. s :Alai, Ts;45 — — — — — 72265 — I — — 21.111 11,0517 4976 1.'91_' 17,270 — 17 0 — — — — 09 162 4.2 I — — 1,2 056 7702 2670 -9.79 061.7 — 009 Pup1u.5: 41752 Au. z.: N'x15)Tura — — — — — "1265 — I — — — 24.111 1105.7 4076 13017 17,270 170 — — — — 00 162 4.2 i — — 120,6 24.70 '970 0617 — 009 005:1 •115•. 21651S,nbiloo. Recuee• 01Tui:1, -- .- -- .- -- 1.4 -- -- -- -- 21.,0 9.2 0.,0 I2 75.0 -- -- -- -- -- -- .- 1.4 '- -- -- -- 21.0 5.5 .. 12 00.0 -- -- A I'.•11e -. 1272 S ! 1 R 1•ue, 01 T1 1, -- .- -- .- -- 1 4 -- I -- -- -- 21 ,0 9 - 0 2 70.0 -- -- -- -- -- .- 1.4 .- I -- -- 21.,0 n 7 0 I2 00.0 -- -- Pr .5 210315 kl On -Sp, C61 T,3. — — — — — 1025 I __— — 1_04 717.6 50 915 6,024 — — — — — 01 6_I 107 I --— 752 775 111`7 46 7010 — — Pup1u.5-. 210,2Sub1;&OHSIp, Oil T,3. — — — — — 1026 I — — — 1_04 7166 22547 916 6,224 — — — — — 01 6_I e"1 I — — - 752 77.5 112 46 '11010 — — Pr 2181715:T0�01 TmJ. . - - - — — If I — i - - - — 277,_1 126.1 404 161 1061 — — — — — — 001 05 00' 1 — — — 140 6_7 20 05 07.1 Pr 1u.5:. 21,12 TiaLliej. T0, 011 Tail. - - - - - 1f 1 - I - - - 270.1 1261 404 161 1,061 - - - - - - 011 05 00, 1 - - - 140 6.7 20 0A 37 1 - - PcrmincJ Source, suhlnlul - APTV Only- Pcrmil Ttempl Sa,urecn 0.0 0.0 0.0 0.0 0.0 897.6 0.0 I 0.0 0.0 0.0 51.991 2_1712_ 1.516 3.401 48.870 0.0 317 0.0 0.0 0.0 0.0 2.0 47.5 9.1 I 0.0 0.0 0.0 2.639 1.204 81 172 2_595 0.0 1.79 Pneet5. 115x05) Tint, R peen C6 WriCiaili5builtril 105 0.9 04 0.1 122 10.2 i I0 - - 77 05 - - 475- - 09 09 09 01 122 0' 102 i 10-2 - - 1�7 _ 0 0 - - 4 "1'. ' - - Pup1u.5:. n 1 o. o ,itenito, 01 01 01 0.1 10 01 02 1 06 04 - 04 0.2 11 L, 1 - - - 01 01 01 01 10 L, 1 0.2 1 06 04 - 04 0.2 — 01 — — 1 1 APTV OW, Suhlnl,J — APTV Exempt i In.'„ ' ncnnl mores. 1.0 ].0 ].0 0.] 112_ 0.8 10.4 i - 19 0 0 ] 1 0 0 438 0 0 ].0 ].0 ].0 0.1 112_ 0.8 ]0.4 i 19 0 0 ] ] n 0 438 0 0 Pmwsed Sepria5a Ratite, C63 "iiMnoaliii 055 065 055 007 41 0_I -7 1 1168 _ 1 L_b l_ - - i — — 0_ — — — 2. — A I'. set 1 \f 1 1 T 41 -- '- -- '- -- i - -- - -- - 4,2 7 - - 0.02 — i -- -- - 4 — -- R r. =1=•: ru, r r. e�,r„.,•1 ., -- — -- — - 09- -- -- -- 4.4501-05 4s7r.on sn0rr nor -,ti 1:12) n7 - �o9r o% - - -- — -- -- rrr... r..a �.n,r-r rrr .rrrr.. 5.00E -00R f ne•i P ..- s \css -- - -- - -- 0.02 I -- -- -- -- - -- -- - -- -- -- -- '2 - I -- -- -- - -- -- -- Pmwse2 C5Dearttoi 055.45, — — — — — SI — i — — — 10? m4 41.7 160 �- - - - - - - 0_007 07 001 i - - - 0- 4.6 21 05 01 Pup14.5:. T)ui. T_5n ii;O. - - - - - 000 - i - - - - - - - - - - - - - - - 090 - i - - - - - InugnillemlSuhlnl,J- TIIl1J. All Sourco- 0.7 0.7 0.7 0.1 9.1 7.0 7.7 1 14 0 0 11 92 42 10 331 40 0 0.7 0.7 0.7 0.1 9.1 2_7 7.7 1 14 0 0 1 5 _ 1 32_8 40 0 1.7 1.7 1.7 0.2 22.3 905.9 18.1 I 12 0 0 52.003 ?1805 1578 3.418 49.619 40 36 1.7 1.7 1.7 0.2 24.3 51.0 1 27.1 I 32 0 0 2.641 1.209 85 173 3361 40 1!neunlrnll:J RAP. Summa,)) 1!nnmlrnll1J Told. All HAP, C,nlrnlled RAP, Sum -ram C1x,lrnll1J Told. All RAP: {TP411 0.0 I 0.0 I 0.0 I 21,.0 I 11.9 I 0.9 I 1.7 I 74.9 I 0.0 I OP I iTPV11 0.0 I 0.0 I 0.0 I 1.3 I 0.6 I 0.0 I 0.1 I 1.7 I 0.0 I 0.0 1 (TP4)1 65.1 I (TPY)-I 3'8 Footnotes: 7. This(him shoo Idhe completed to include both existing sources todoll proposed new or modiCicstions to existing emissions sources 2. Cthe emissions source is now then cnlar "proposed' under the Permit No. and AIRS iD data columns 3. [MS ahhlcemotions include. BZ - Cien'o0ne 224-TMP - 224-Tri methylpentane To] - Toluene rectal - Acetaldehyde RR - Tilly Ihenoene ..9cm - AcInlain xy] - xylanc n -Rex - n-Ile0nnc 110110 - Pormaldohydo Meth- Mcth;mo I 4. APLI2 LscmptInsigni Iicant Sources should ho inc udod when warnmtod. Company Name 4/6/2018 Page 1 of 1 Article 12. 12-701 Potential Site Specific Mitigation Measures AE. Vehicle Tracking Control Practices. Vehicle tracking control practices must be used to control potential sediment discharges from operational roads, well pads, and other unpaved surfaces. Practices could include road and pad design and maintenance to minimize rutting and tracking, controlling site access, street sweeping or scraping, tracking pads, wash racks, education, or other sediment controls. Traction chains from heavy equipment shall be removed before entering a County road. AF. Water Quality. A water quality control plan that establishes that all operations shall use most effective performance techniques and best management practices to minimize impacts to water quality, including plans for water quality testing, prevention of illicit or inadvertent discharges, and containment of pollutants as required by state and federal agencies. AG. Weed Control. Oil and gas operations must keep wells and surface production facilities free of weeds. The Applicant is also responsible for ongoing weed control along access roads during construction and operation, until abandonment and final reclamation is completed per County or other applicable agency regulations. For access roads and off -site pipeline easements, the appropriate weed control methods and species to be controlled must be determined through review and recommendation by the County Weed Coordinator by reference to the Boulder County Noxious Weed Management Plan and, where appropriate, in coordination with the requirements of the surface owner. AH. Well Abandonment or Decommissioning. The Applicant must comply with any COGCC rules regarding well abandonment, decommission, or reclamation. Upon plugging and reclaiming a well, the Applicant must provide the County with surveyed coordinates of the decommissioned or reclaimed well. Unless otherwise requested by the surface owner, the Applicant must leave onsite a permanent physical marker of the well location. 12-701 Potential Site Specific Mitigation Measures Application of these potential mitigation measures will be site -specific and based on the land use impacts of the particular oil and gas operation, the environmental impacts of the particular oil and gas operation, the Applicant's ability to undertake particular mitigation measures given the current state of technology, and consideration of any associated standards or rules adopted by the COGCC, the Air Quality Control Commission, or the EPA. A. Air Quality. 1. Minimization of Hydrocarbon Emissions. To protect air quality, hydrocarbon emissions control measures may be required, including, but not limited to, one or more of the following: a. Electrification from the power grid or from renewable sources of all permanent operation equipment with engines or motors that can be electrified. b. Pipelines for water delivery to the site. c. Pipelines for transportation of oil and gas away from the site. d. Limitations on truck traffic to and from the site. e. Implementation of "tan kless" production techniques. f. Environmentally sensitive and efficient production techniques, such as using natural gas onsite rather than flaring. g. For well pads that are not electrically operated, use of quiet design mufflers (also referred to as hospital grade or dual dissipative) or equivalent. h. Use of acoustically insulated housing or covers to enclose the motor or engine. i. Manufacture test or other data demonstrating hydrocarbon destruction or control efficiency that complies with a design destruction efficiency of 98% or better. j. Bleed and vent restrictions on continuous bleed pneumatic devices, intermittent vent pneumatic devices, compressor engines, heater treaters, dehydrator reboilers, process heaters -pilot flames. k. Proof that any flare, auto ignition system, recorder, vapor recovery device or other equipment used to meet the hydrocarbon destruction or control efficiency requirement is installed, calibrated, operated, and maintained in accordance with the manufacturer's recommendations, instructions, and operating manuals. I. Emissions controls of 90% or better for glycol dehydrators. m. Zero -emission desiccant dehydrators. n. Hydrocarbon control of 95% or better for crude oil, condensate, and produced water tanks with uncontrolled actual emissions of VOCs greater than five (5) TPY. o. Year-round application of odor requirements as set forth in 5 C.C.R. 1001-9, 5 XII (as amended). p. Electronic surveillance monitors to detect when pilot lights on control devices are extinguished. q. Drilling, completion and operation of wells using closed loop pitless systems for containment and/or recycling of all drilling, completion, flowback and produced fluids. r. Emission controls of hydrocarbon emissions of 95% or better for centrifugal compressors and reciprocating compressors. Boulder County Land Use Code • June 1, 2017 12-15 Sec. 22-5-100. - Oil and gas Goals and Policies. A. OG.Goal 1. Promote the reasonable and orderly exploration and development of oil and gas mineral resources. 1. OG.Policy 1.1. The County should encourage cooperation, coordination and communication between the surface owner and the mineral owner/operators with respect to any developments of either the surface or the mineral estate. 2. OG.Policy 1.2. Oil and gas support facilities which do not rely on geology for locations should locate in commercial and industrial areas, when possible, and should be subject to review in accordance with the appropriate sections of this Code. 3. OG.Policy 1.3. Ensure that tax revenues for all oil and gas operations (including disposal well oil operations) are properly collected. a. Recommended Strategy O6.1.3.a. Study the distribution of tax revenue to determine where the greatest impacts from oil and gas activity are found and identify how those impacts can be mitigated. B. OG.Goal 2. Ensure that the extraction of oil and gas resources conserves the land and minimizes the impact on surrounding land and the existing surrounding land uses. 1. OG.Policy 2.1. Encourage oil- and gas -drilling activities to be coordinated with seasonal production schedules associated with agricultural activities. Promote and encourage the use of directional drilling to protect surface rights of agricultural lands and possible future land uses. 2. OG.Policy 2.2. Encourage the clustering of oil and gas drill and well sites whenever possible. 3. OG.Policy 2.3. Existing service roads should be used to provide access for oil and gas and other mineral extraction activities. 4. OG.Policy 2.4. Support the limited number of surface drilling windows allowed on a section of land. Encourage use of minimal drill window areas by directional drilling from existing drilling windows. Discourage efforts to increase the amount or size of drilling windows. 5. OG.Policy 2.5. The authorized by law, extractions to the areas impacted, fr County should use its regulatory powers, to the extent to minimize the impacts of oil, gas and other mineral land and land uses and ensure complete restoration of the om start-up through termination of production. 6. OG.Policy 2.6. Promote the safety of all citizens and structures that are in relatively close proximity to oil and gas facilities. a. Recommended Strategy OG.2.6.a. Develop ways to ensure safety for citizens and structures that are in relatively close proximity to oil and gas facilities. b. Recommended Strategy OG.2.6.b. Actively enforce zoning and building permit requirements for oil and gas facilities, including field monitoring to ensure compliance. c. Recommended Strategy OG.2.6.c. Develop mitigation options that maintain safety while reducing setbacks. 7. OG.Policy 2.7. New subdivisions should be planned to accommodate current and future oil- and gas -drilling activity to the extent oil and gas development can reasonably be anticipated. a. Recommended Strategy OG.2.7.a. Encourage changes to state laws and regulations to allow landowners seeking to subdivide land the ability to designate a single combined surface drill window adequate for drilling and production operations as an option to the current default multiple - window requirement. 8. OG.Policy 2.8. Oil- and gas -drilling activities should be planned to accommodate current and future surface subdivision activities to the extent such development can reasonably be anticipated. 9. OG.Policy 2.9. Impose protective measures through available state, County and federal regulations to ensure that the mineral operator conducts operations in a manner that will minimize current and future environmental impacts. 10. OG.Policy 2.10. Promote that well sites are reclaimed and closed by techniques which address that the future use of the property is not impaired because of environmental or safety problems, or because of the existence of improperly abandoned or unlocated equipment, such as wellheads or flowlines. 11. OG.Policy 2.11. Subdivision applicants that can show written evidence that an adequate attempt has been made to obtain a Surface Use Agreement will be allowed to continue the process to completion. C. OG.Goal 3. Prevent surface and groundwater contamination from oil and gas minerals exploration and extraction. 1. OG.Policy 3.1. Support regulations for cementing wells (including injection wells) to prevent commingling of water, oil and gas into other formations. 2. OG.Policy 3.2. The extraction of oil and gas minerals should attempt to conserve ground and surface water. 3. OG.Policy 3.3. The extraction of oil and gas minerals should minimize the impact on the quality and quantity of ground and surface water. (Weld County Code Ordinance 2002-6; Weld County Code Ordinance 2008-13) Sec. 22-5-130. - Alternative energy resources. Due to the volatility of traditional energy resources, the County supports and encourages development and use of alternative energy resources. Alternative energy sources do not replace the traditional sources of energy; rather, expanding global energy demands require a "new energy economy" that supports and enhances traditional sources of energy. (Weld County Code Ordinance 2008-13) Sec. 22-5-160. - Use of resources Goals and Policies. A. UR.Goal 1. Support and encourage the use of natural and other resources available in the County by the residents of the County. 1. UR.Policy 1.1. Support the development of power -generating facilities in the County that benefit the residents of the County and employ the resources extracted, developed or available in the County. 2. UR.Policy 1.2 In order to validate the recognition of a right to extract Minerals, the statement listed below should be incorporated into all land use maps/plats and Homeowners' Associations (HOA) documents. RIGHT TO EXTRACT MINERAL RESOURCES STATEMENT Weld County has some of the most abundant mineral resources, including, but not limited to, sand and gravel, oil, natural gas, and coal. Under title 34 of the Colorado Revised Statutes, minerals are vital resources because (a) the state's commercial mineral deposits are essential to the state's economy; (b) the populous counties of the state face a critical shortage of such deposits; and (c) such deposits should be extracted according to a rational plan, calculated to avoid waste of such deposits and cause the least practicable disruption of the ecology and quality of life of the citizens of the populous counties of the state. Mineral resource locations are widespread throughout the County and person moving into these areas must recognize the various impacts associated with this development. Often times, mineral resource sites are fixed to their geographical and geophysical locations. Moreover, these resources are protected property rights and mineral owners should be afforded the opportunity to extract the mineral resource. (Weld County Code Ordinance 2008-13; Weld County Code Ordinance 2015-7) All Stationary Sources of Air Pollution near the source: 123-9F71 DISCOVERY DJ SERVICES - WEST BRIGHTON CS The table can be copied and pasted into Excel or Word. Dist Longitude Latitude AIRS -ID Facility Owner 4.5 3.8 4.1 2.8 2.6 2.5 1.5 1.3 1.1 2.4 0.8 3.4 0.8 4.7 4.7 1.3 1 1.4 4.8 4.3 2.9 3.6 4.5 4.1 -104.9137 -104.894 -104.8526 -104.8691 -104.9189 -104.9174 -104.8914 -104.8821 -104.8846 -104.9213 -104.8999 -104.934 -104.8887 -104.9491 -104.9497 -104.908 -104.8889 -104.8997 -104.8421 -104.8546 -104.8909 -104.8694 -104.9217 -104.8837 39.98308 39.98709 40.00169 40.00398 40.00707 40.0071 40.00758 40.01374 40.01421 40.0147 40.01502 40.0152 40.0154 40.01693 40.02038 40.02518 40.02888 40.03278 40.03896 40.04544 40.0474 40.04741 40.05608 40.05678 001-2180 001-1664 123-6118 123-9E5D 123-9 F2 F 123-9F2A 123-6041 123-9D14 123-0141 123-6037 123-9CED 123-0221 123-0075 123-6591 123-6656 123-8687 123-9D11 123-1911 123-1981 123-2341 123-6966 123-4744 123-9C8F 123-0184 GREAT WESTERN OPERATING COMPANY LLC PETROSHARE CORPORATION PDC ENERGY, INC. GREAT WESTERN OPERATING COMPANY LLC Facility Name GREAT WESTERN OPERATING - OCHO LD PAD PETROSHARE - Zarlengo 23, 24-4 PDC Schmidt 33, 44-35 GREAT WESTERN OPERATING - MARCUS LD PAD PDC ENERGY, INC. PDC ENERGY- JACOBUCCI 32 SEC PAD 3 PDC ENERGY, INC. PDC ENERGY- JACOBUCCI 32 SEC PAD 1 & 2 K.P. KAUFFMAN COMPANY, INC. KP KAUFFMAN CO- AMOCO-CHARTER-SCHNEIDER KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE OIL & GAS ONSHORE - 36166295 PUBLIC SERVICE COMPANY OF COLORADO - NATL PUBLIC SERVICE- YOSEMITE AIR BLEND PLANT K.P. KAUFFMAN COMPANY, INC. K.P. KAUFFMAN CO-FINDLAY BATTERY KERR-MCGEE OIL & GAS ONSHORE LP Kerr-McGee Oil and Gas Onshore- 36164761 DCP OPERATING COMPANY, LP DCP OPERATING COMPANY, LP KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE OIL & GAS ONSHORE LP NOBLE ENERGY, INC. KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE OIL & GAS ONSHORE LP KERR-MCGEE GATHERING, LLC DCP OPERATING CO- MARTHA KIRKMEYER C.S DCP OPERATING CO - SURREY C.S. KERR-MCGEE - 35005819 KERR-MCGEE - 35005824 KERR-MCGEE - 36156425 KERR-MCGEE O&G ONSHORE- 36165657 KERR-MCGEE OIL & GAS - 36163972 KERR-MCGEE 62483 KERR-MCGEE 62102 NOBLE ENERGY, INC. - ENG-11364500 KERR-MCGEE 62651 -BRINK 15-15A KERR-MCGEE OIL & GAS - 36146148 KERR-MCGEE GATHERING - FREDERICK CS APEN Reported Actual NOx Emissions Total: 24 sources of NOx total 291.64 tpy w/in 5 km of 40.02118 N, 104.89408 W (Geographic, WGS 1984) Tabular facility data (updated daily) provided by the Stationary Sources Program Inventory and Support Unit, More info at https://www.colorado.gov/airquality/permits.aspx. APEN emissions data valid as of 1/7/2019. Nitrogen C O3 NAA? 19.05937 Y 0Y 0.00083 Y 9.49321 Y 1.65588 Y 2.4847 Y 0.10001 Y 1.78003 Y 50.9115 Y 0.016 Y 0.6841 Y 17.15 Y 25.8 Y 0.04486 Y 0.02286 Y 0.00464 Y 1.30978 Y 1.26001 Y 0.03561 Y 0.09603 Y 1.78 Y 0.09859 Y 1.06 Y 156.7914 Y 291.64 TPY USR18-0106 Broomfield South Compressor Station compared to Elevation's Buffalo Compressor Station at full engine build -out. Rocky Mountain's Natural Gas Engine driven Compressors at the Broomfield South site. Power Controlled Potential to Emit (TPY) Controlled HP KiloWatts Quant. Total Total NOx VOC CO HAP's 1 0.7457 kW MW Numbers from CDPHE. APCD-102* Form, Page 28 listingthree engines 2,500 1,864 3 5,593 5.6 38.4 51.7 20.8 7.7 Numbers from CDPHE. APCD-102 Form, apportioned tcone engine 2,500 1,864 1 1,864 1.9 12.8 17.2 6.9 2.6 Numbers from CDPHE. APCD-102 Form, Page 28 forsix engines - Full buildout 2,500 1,864 6 11,185 11.2 76.8 103.3 41.6 15.4 Elevation's Motor driven Compressors at the Buffalo Site. Numbers from CDPHE. APCD-102 Form, for 16 compressors - Full Buildout 5,500 4,101 16 65,622 65.6 3.5 64.9 14.2 17.3 Numbers from CDPHE. APCD-102 Form, apportioned tcone compressor. 5,500 4,101 1 4,101 4.1 0.2 4.1 0.9 1.1 TPY = Tons Per Year HAP=HazardousAirPollutants in TPY Ozone isn't emitted by any particular industry or human activity. Rather, in the presence of sunlight, ozone forms by the combination of precursors, such as nitric oxides (N0x) and volatile organic compounds (V0Cs). Put simply: VOCs + NOx + Sunlight = Ozone County should press Rocky Mountain Midstream to use electric motor driven compressors. *Form APCD-102 is part of APEN permit application dated October 16, 2018 wrw 2019-01-06 Petition to require the use of electric powered compressors at the proposed Broomfield South Compressor Station. Petition summary and Compressor Stations are required for the pipeline transport of natural gas from wells to processing plants and ultimately to background market. They are often powered by large engines that use some of the natural gas for fuel. Even equipped with catalytic converters, these engines produce massive amounts of pollutants -- potentially putting out hundreds of tons of pollutants per year. A significant result of the pollutants is the formation of ozone. The installation and operation of any oil and gas operation should, to the maximum extent practicable, avoid causing degradation to air quality. The negative health effects of resultant pollutants coupled with the low topography along the Big Dry Creek causing polluted air to regularly collect and persist, lead to the need to use electric compressors. Action petitioned for We, the undersigned, are concerned citizens who urge our leaders to act now to prohibit the use of natural gas engine driven compressors at the Broomfield South Compressor Station. Printed Name Signature Address Comment Date 2019-01-01--wrw Selena Baltierra To: Subject: Chris Gathman RE: Is it possible for Weld to request a CDPHE Pollution study? - Exhibit for USR18-0106 From: wwvcoffbn7@aol.com <wwycoffbn7@aol.com> Sent: Thursday, December 27, 2018 12:29 PM To: Jason Maxey <Thaxey@weldgov.com> Cc: Elisa Kunkel <ekunkel@weldgov.com> Subject: Is it possible for Weld to request a CDPHE Pollution study? This email originated from outside of Weld County Government. Do not click links or open attachments unless you recognize the sender and know the content is safe. Mr. Maxey, Several involved neighbors are working to minimize the impact of a proposed Compressor Station (CS). It is the Rocky Mountain Midstream CS that is under review in USR18--0106. The Board of County Commissioners will hear this case on January 9. The site for this CS is in a low area, along the Big Dry Creek. There are also other engine driven CS sites existing or approved near by. Elevations has just had a much larger CS approved about one mile West of this location. The Elevations installation will use motor driven compressors and while almost six times the size will generate much less in the way of pollutants. I have attached a spreadsheet that shows the dramatically different potential to emit figures of the two installations. Power to the Elevations installation will come from a new Substation being built by Tri-State Generation and Transmission. The senior planner there assures us that the new Substation will enough capacity to supply the Rocky Mountain Midstream plant through United Power if requested. Those of us who live in the area know that stale air often sits in the Big Dry Creek low area. However the Colorado Department of Health and Environment (CDPHE) does not normally study a CS of the size that is proposed. Due to the slightly less than common contours and conditions of the area would it be possible for Weld County to request a CDPHE Pollution study? Feel free to call me at 303.659.7259. Best Regards. Bill Wycoff 1 USR18-0106 Broomfield South Compressor Station Power Controlled Potential to Emit (TPY) Controlled HP = KiloWatts Quant Total Total NOx VOC CO HAP's 1 = 0 74569987 kW MW Numbers from CDPHE APCD-102 Form Rocky Mountain's Natural Gas Engine driven Compressors at the Broomfield South site 2,500 = 1,864 6 11,185 11 2 72 4 85 5 33 0 114 Numbers from CDPHE APCD-102 Form Elevation's Motor driven Compressors at the Buffalo Site 5,500 = 4,101 16 65,622 65 6 3 5 64 9 14 2 17 3 TPY = Tons Per Year HAP = Hazardous Air Pollutants in TPY Ozone is a secondary pollutant. Ozone isn't emitted by any particular industry or human activity. Rather, in the presence of sunlight, ozone forms by the combination of precursors, such as nitric oxides (NOx) and volatile organic compounds (VOCs). Put simply: VOCs + NOx + Sunlight = Ozone County should press Rocky Mountain Midstream to use electnc motor driven compressors. wrw 2018-12-27 Broomfield Compressor Station USRI8-0106 Weld County Board of County Commissioner Hearing January 9, 2019 10:00 pm I Company Overview Experienced Management Team • Multiple management personnel in Northern Colorado Front Range. • S S • • Recent capital infusion acquisition by Williams/KKR joint venture demonstrates and reinforces the continued long-term commitment to Colorado and the DJ Basin. Williams is the Operator of the newly named Rocky Mountain Midstream, re-establishing their Front Range presence. Strong preference for local hiring. 90% local hires to date. ✓ Vast majority of our contractors are local. ✓ Proud to be moving former Coloradans back home. Laser focused on Colorado projects for nearly three years. Bringing decades of experience building projects across the U.S. ✓Thousands of pipeline miles. ✓ Multiple compressor stations, treating and processing facilities. Strong Track Record • Goal Zero: Safety Culture. • Stop Work Authority given to everyone. I I No Notices of Violations (NOVs) with PHMSA, OSHA, or EPA/CDPHE attributable to our Front Range assets. DOT regulated pipeline construction audit completed in Adams and Weld Counties with no findings. • Well -capitalized to meet our commitments to the communities where we work and our vendors with whom we do business. Broomfield Station Details Broomfield Compressor Station • Located on an 10 -acre site � South of WCR 6, on the West side of WCR 17 Broomfield Compressor Station • Site Overview E 3 165 960.22 0 0 + / Pr) <\'‘ tl LEASE CORNER N 1 250 776.39 E 3 165 305.10 LEASE CORNER N 1 251 436.19 E 1ss 300142 � 2 I 11 0 N 0 r LEASE CORNER N 1 251 440.88 PROPERTY CORNER N 1. 2s51 44542 E 3 1q 618.t8 I ACCESS ROAD LEASE CORNER N 1 250 781.07 E 3 165 964.90 STORMWATER DETENTION POND DESIGN VOLUME = 40337 CF NO BUILD/STORAGE AREA EXISTING OVERHEAD ELECTRIC JOHN E & DIANA G HOWARD ETAL (PARCEL NO: 146928200002) i 750' TO COUNTY WELD ROAD 17 _ . .. des., V v 0 0 I 1� I f I DEHY - 0 r - I 1 t 1° FUTURE SUBSTATIONi BUILDING I 1 FO O 1 JI PI PERACK �--,. • da I `r COMPRESSOR ' `� O J BUILDING 1r 0 O O O I1 `\, ,....„ SLUG CATCHEREl i u ■ c ■y : liklitita Qm0 O O jo ANal TRUCK LOADOUT � MI�C E�!UIPMENT� COMPRESSOR 1 I BUILDING 1y, � �pma I:_�nO O 1 . lal I r 1 �1a loo a I I LAUNCHERS POND OUTLET I RECEIVERS DETENTION POND 'k� AND SPILLWAY - - - - - - -- - ' DESIGN CAPACITY 0.926 AP i = CR EQUIVALENT 0-0 tkij +�-o DRIVE GATE TfVIET L TlM-H13 SD V111-1 GHNJN LINK STRI aR EQU IVALEIT --- ACC ROAD FLARE • PUMP SIC) CONTACT 7OVsER DEHYDR4110 NSKID I a �e 0__/` T[. WELD COUNTY ROAD 17. ram ES'S OR SKID INLET ESO \SKID 5LX GATGI1L ■ time Ni+ COMPRESSOR SKID 1O o COI-APRESS R SKID GDIIIPI5ESSD SKID 1OO DOMPRESSOR SkID I SLOP T.& IWS B-TE L'JIT 0 Eta GAF SI<IC FJMF 'SKID --- CONTACT TRIER CONTACT MA79.irn E? PAP tn 9 FLARE • • Ii _ a 8 == 1 .. C I:FESS0R SKID at4 II , 0 CD APRE;SOR SkD 9s ( '3 — COMPRESSOR SKID I uEHYIikCTIciJ SKI_ I DEWIIKA11► A1 SKI I,,NCATE TVLIETAL 2150 REDE5TRIPN SWING GATE W/ CHAIN LNK et Ea 1; taF•�LE�±T IRAN CAIE nil ETA_ 2'1 50 PEUESN IAN 5NING CATE IN/ CHAIN UNtr. EQL aLEyT -c _ DETENTION POND I HARvLS BRCW MULCH LAME IMF FEW 17' Tf?'P, SDRINKLER. ' 51-1 WATERING t&cI JIS 11-r: !Ps ae I Y a ,# ,9 +_ -r 4 1+ 9 + 7 1 HP SI I I 1 1 I I a I r* si Ma IS MIMISF MI MS I• :� � u • MB la r I sal Slom I I I I 3317 '. S j •�iA CKl;A''ic General Design of Our Compressor Stations I I I I Engineered for safety. Designed to minimize noise and emissions. Sited on approximately 10 acre property. Major equipment is contained to -6 acres. Property enclosed fence with access -restricted gate. � Equipment and buildings are painted to blend in with the surrounding area (Canyon Tan). 11 Safety Culture 12 Strong Culture of Safety • Safety not just a word we use - it has meaning. � Safety is deeply embedded in our culture and informs the way we think, make decisions, design and operate our facilities. • We believe preventing a hazardous situation is the best way to ensure the safety of our employees, contractors and the public. • All of our facilities meet or exceed industry standards and regulations. • All employees and contractors have Stop Work authority/responsibility. � Variety of safety systems to protect the public and employees. ✓ Automatic shutdown systems at all facilities. ✓ Safe work permitting process. ✓ Written procedures and energy isolation safeguards. ✓ See Something, Say Something. ✓ Written Emergency Response Plans (ERPs) ✓ History of working directly with Emergency Responders through table -top exercises or drills. Environmental Stewardship 14 Environmental: Emissions & Noise � State of Colorado air permit required. ✓ Some of the most stringent requirements in the country. ✓ Regular emissions testing. ✓ Routine maintenance and inspections. ✓ Leak Detection and Repair • The station would meet state and local rules for public noise in a zoned area. • Each compressor is enclosed in a noise -insulated building. • Voluntarily use hospital -grade mufflers and "quiet tip" fans to minimize noise. ✓ 12 blades instead of 8, pitched in way that minimizes noise • Spill Prevention Control and Countermeasures (SPCC) plan. Operational Excellence 16 How We Operate Our Compressor Stations • Thorough safety review before start-up. • Management of Change (MOC) processes and training. • All operators trained in accordance with established safety procedures. � Monthly training regarding safe operations and injury prevention. ✓ Both classroom and onsite. • Facility monitored by trained plant operators 24 / / 365. • Daily checks of all equipment. 17 Safety Features of our Compressor Stations • Remote monitoring (SCADA) and automatic shutdown systems. � Safety relief valves to prevent overpressure. � Multiple redundant safety systems, including manual shutdowns. • Electrically grounded equipment. � Comprehensive safety training program. • Detailed emergency response plan. All affected jurisdictions supplied copies. I Work directly with local fire district representatives regarding emergency response scenarios. 18S, Community Pride 19 Good Neighbors � We value being a good neighbor and a responsible operator. • Focus on safety & stewardship promoting positive impacts in our communities. � Prioritize volunteer opportunities and support local organizations Good Partners • Helping meet the energy needs of over 4 million Colorado households. • Good paying jobs, tax revenue and ROW payments to local landowners. • Striving to be your best neighbor and a positive corporate citizen. Fort Lupton Family Boys and Girls Club of Festival Metro Denver Cardinal Academy Track and Field Champion Partner 2018 Weld County Fair 100t" Anniversary 20 USR18-0106 W. Wycoff 2019-01-08 Document Description Outline - Talking Points A-1 B-1 Weld County Code: 22-5-100 and 22-5-130 B-2 Boulder County Code C-1 Proposed Gas fueled CS to CS - compared nearby electric Spreadsheet C-2 Emissions Data Electric, Buffalo CS - APCD-102 Form C-3 Emissions Data Gas Broomfield CS - APCD-102 Form C-4 USR Map Broomfield Six of site showing gas compressor units D-1 Prime for Compressors Advantages Electric Page 3 Top -Movers - of - G-1 Denver Ozone Basics Nonattainment - Often out of - Compliance G-2 Local News Pollution -- It is on a problem Broomfield CDPHE Page 13 listing levels H-1 that trigger application impact And that emission this does modeling it. In due analysis. to being below 40 TPY site of NOx.. not require part Emissions Data Gas Broomfield CS - APCD-102 Form (again) H-2 showing But this is 39.6 half TPY of the NOx. build for the USR. at out shown on J-1 Air Pollution Sources 5 km the within a radius centered near proposed site. J-2 Air Pollution Map the 5 km the of area with sources. J-3 Air Pollution Sources 10 km the within a radius centered near proposed site. L-1 Blank form petition USR18-0106 Commissioners: Item Topic A-1 A. There is so much to cover. However, no doubt the Board is well versed in pollution and many other issues. Therefore, I will hit high points. B-1 B-2 B. It is County policy to promote, encourage and stimulate clean air and renewable energy. County Code 22-5-100 and 22-5-130. C-1 C-2 C-3 C-4 C. Here is a spreadsheet (C-1) that compares the recently approved, nearby Buffalo Compressor Station (CS) that uses electric motors to the proposed Broomfield South CS. We can look at the single -unit rows to see the stark differences in emissions. The full build -out numbers are also amazingly different. Especially considering how much larger the Buffalo CS is to the Broomfield CS. The next two items are sources for the spreadsheet. The last item shows the layout for the six gas engines of the CS buildout. D-1 D. Tn-State gave assurance that the new Arnold Substation will have capacity for this CS. Due to torque -speed curve differences between electric motors and gas engines, larger horsepower motors are generally required to replace gas engines. An often -used relationship is that a motor needs to be rated 1 2/3 times larger than the engine it replaces. Therefore, motors at the Broomfield South CS might have to be about 4,200 horsepower. D-1 is part of a paper on ways compressors can be powered. Page 3, top speaks to electric being used due to environmental considerations. None E. While use of electric will not make the air better, use of engines will make it worse. None F. Xcel is shooting to be carbon free by 2050. An increasing percentage of available power will be renewably sourced. Please set up the CS for eventual and progressive use of renewable energy and not lock it to gas. G-1 G-2 G. Sources should not "cause or contribute" to exceedances of National Ambient Air Quality Standards. We are in an ozone "Nonattainment Area". G-1 is an informative flyer on air quality. G-2 contains several local news pieces on air pollution. H-1 H-2 H. Page 13 (H-1) of the application to the Colorado Department of Public Health and Environment (CDPHE) has a table that states at 40 TPY of NOx output the facility does not require an impact analysis. Page 28 (H-2) of the application shows a total of 39.6 TPY for the facility with only three engines of this six -engine USR. With all six engines the output will approach 80 TPY. Officials at CDPHE permitting look at the 39.6 figure, see that it is below 40 and note that no action Is required. None I. If the BOCC is favorable toward the use of engines, the BOCC should have Rocky Mountain perform a cumulative modeling impact 'analysis that includes the full build -out. Such a study would include and account for nearby sources and the topography. J-1 J-2 J-3 J. Nearby Sources: Since this proposed site is not yet in the CDPHE database, these items are centered on the Brighton West CS, on CR 19, North of CR 4. Table J-1 lists 24 sources of NOx total 291.64 TPY within 5 km of 40.02118N, 104.89408W. J-2 is a map relating to the sources. One source produces 156.8 TPY of NOx. An average of 3.7 TPY per square kilometer. Table J-3 lists 98 sources of NOx total 810.25 TPY within 10 km of 40.02118N, 104.89408W. An average of 2.6 TPY per square kilometer. The area close to the proposed site has a 42% greater pollution load than the larger, surrounding area. This CS merits an impact analysis to use gas. None K. An aspect of this location is the topography of the area. The site will be in a low area adjacent to the Big Dry Creek. Those of us who live here often experience how air can collect and stagnate. A major reminder comes from smells generated by the Northglenn Wastewater Plant at CR 2 and 11. This is no place for a significant pollution contributor. L-1 L. While several folks hold the notion that if this plant is to be built, it ought to use electric motors, an idea emerged to find out what others thought about it. With very limited time, several folks visited households close to the site with a petition. Once people learned of what is proposed, their position was unanimous that this is not good. Not one person felt that the air around here should be more polluted. Households: 17_ Signatures: _34_ None M. This is not "just a business decision". It is health and environment decision. None N. Rocky Mountain Midstream wants the gas resource. That is OK. But the residents of the County and State should not have to pay for it with their health and degraded environment. Please require electric motors for this CS or have a continuance with a request for Rocky Mountain to perform a cumulative modeling impact analysis that includes the full build -out. Thank you Bill Wycoff wrw 2019-01-08 S t -k Petition to require the use f electric powered copressors at th pro •posed Broofiee • South Cpressor Station. Petition summary'and ` Compressor Stations are required for the pipeline transport of natural gas from wells to processing plants and ultimately to background` ;, " " ' ' market They are often powered by large engines that use some of the natural gas for fuel Even equipped with catalytic °"" - converters, these engines produce massive amounts of pollutants -- potentially putting out hundreds of tons of pollutants per year A significant result of the pollutants is the formation of ozone The installation and operation of any oil and gas operation should, to the maximum extent practicable, avoid causing degradation to air quality - R The negative health effects of resultant pollutants coupled with the low topography along the Big Dry Creek causing polluted air to regularly collect and persist, lead to the need to use electric compressors Action petitionedfor' - ` ,,,,, �� _ >, - , t _ `,_ . _ We, the undersigned, are concerned citizens who urge our leaders to act now to prohibit the use of natural gas engine driven compressors at the Broomfield South Compressor Station Printed Name,- w "" ` ' Signat a >r''. ' -, , Addi.e`ss':v, - '-, ,`Comment , Dates (bv0 iu ik,eZ -a.6. aci tkle PlallQ 100 muckcioary, /4/1q Areez.4.,-i�j_ge( 5 p fll C jf //‘//, Z1Jia '17 e Coy/��r�44,-41-Z-71/-e._-V195- CA.2_--r-a /N/0 'sue-, ,� an&y�m,ss,or\s r-6 - / �odlor be, C 'Snci ca /-6.-/A �, ic.Ar\a\ Sect -O ,a)..4_-.6 55z99 c_r< z- 1---6-(? ,.Itivek ---e tom Q.c• ri I - -1 M r'xi Su111 ��a �, � � ra13 crc 1� �PA,� �i Ulll%1�� ✓nG LO�� jlja�,�l.G G' U 1-1011q t/ aY-3-c \fie 42,7__ Sc( CIL .Z Azz QuA-L, - Teo iwet a / ,z_.. _ eve- e),y e77. ' 2019-01-01--wrw Petition to require the use of electric powered co pressors at the proposed rotmf eld South Com • ressor Static ae Petition•sumrnary and' Compressor Stations are required for the pipeline transport of natural gas from wells to processing plants and ultimately to background market They are often powered by large engines that use some of the natural gas for fuel Even equipped with catalytic converters, these engines produce massive amounts of pollutants -- potentially putting out hundreds of tons of pollutants per year A significant result of the pollutants is the formation of ozone The installation and operation of any oil and gas operation should, to the maximum extent practicable, avoid causing degradation to air quality The negative health effects of resultant pollutants coupled with the low topography along the Big Dry Creek causing polluted air to regularly collect and persist, lead to the need to use electric compressors Action petitioned for- We, the undersigned, are concerned citizens who urge our leaders to act now to prohibit the use of natural gas engine ` ; driven compressors at the Broomfield South Compressor Station Printed Name. - SSignature 'Address",' _ ; Comment% , `.' ',' :' ',Date,= flt�2Ez. WON ��Q 1/4_ iS°IC� CR.IS' e vzu'/ciA/C 4(#0.1— oet t f (itkap/Q,,A5 cokc f.&, S-17 h9ed_ ci eft N t c -'?-72 mil a L • --7,c .•.,, /5- 5-6. 63 IC, 4 . i.6-- ' 1 '/J /- s - l 1 421,-;,..A. rt Of c.i24 A ‘,6--- c_t,,,fr-- 9 1.j CA •e- / 1 /� -i-Daj_ "Af».Ae -,c) a_. ) --- a' /1-717- vy 1 , t)s-/Atk it-- '6Z qt_ yLc="PP8-6Itte- c_50_., c__,?/ --4- ra 1.1 0 " t3,11 W y Go_ri 810Q Oppir 33 3 c12.7 I ' Le4J.5- no -f- /14,41(.e_.e_ 4/k. avbar 2419 -6/-45- Ater .S gi3, . r (41,? /7 Zo e is f / -6-17 jtvtrti fecZ CkArreiv- _ 41 6A-11_,- q't'E c it- i -3-- Iv, 06,51-rwz. v),..si-dA,A4 , _ g _ 19 2019-01-01--wrw Petiti t�s3� a k� rep bus Y 'ctionFpetitionedi,for„ kt n to require the use el electric ®veered co ; pressors at the proposed r® # afield South Cmpressor Station. Compressor Stations are required for the pipeline transport of natural gas from wells to processing plants and ultimately to market They are often powered by large engines that use some of the natural gas for fuel Even equipped with catalytic converters, these engines produce massive amounts of pollutants -- potentially putting out hundreds of tons of pollutants per year A significant result of the pollutants is the formation of ozone The installation and operation of any oil and gas operation should, to the maximum extent practicable, avoid causing degradation to air quality The negative health effects of resultant pollutants coupled with the low topography along the Big Dry Creek causing polluted air to regularly collect and persist, lead to the need to use electric compressors We, the undersigned, are concerned citizens who urge our leaders to act now to prohibit the use of natural gas engine driven compressors at the Broomfield South Compressor Station '14,401-11.40614,1,i'; ` srti �- � ti rF 75i r}� k1y1 y r� , S . r q. z , , ;; , a 4 , ,� .4 �� Y ` , Y , z , 4,, .1' R i na uir� .� , , � rr^ � '� �' ' ^, �' ii r 7' ;, w =�,° 15. } ' iL �, p 4 C , Y .!,' 5 +1' �<�� Y f ','Address%f � ,y � � ,'0-7-,;,,,f4.1, �. f v, ^ �c7^ '�' � iw !,',,c,;,. S�� +I r ,r �;- /'� py� � .rc , Vr ,� } ; � - , � t � � S 1 i "`x7 x�� F.S"r>a4. r , - M , 4 l tk - " 1 J4� { . i, 2 l^ 4` 1 _ K � - e .� vY.t r. 1 r s � d.r.,k9,).. t �. .�,- „j �F� .� It+ll„q 1�'N,F, ,10\,-. 11 J K\GO`CA a4S-C1 4. ( 1-l1 K -)c - 4 i r1 _ill. `i 9 ,� nom; J{ i�OV4ti �'xr �ii!{ weigh 'Eh�IY (.475,k- e4 o{eto-VIo� t,� n, �,(1,-O,,i,,-,T _-, _ (e_2 171Gj ri G lip it J deogedl le 6L4:-:- / QI(p/�d� /-6—ao1, Melt ._c kf— -7 37 ? c -r' 4-4,-,51-x/, 13,-e4-4,,,9 c 64 A if ay 6eI /E/-aii+,„fi..e..A. 7s 79 ex. h/ grii,%4-17 wets y� e�/, e, tier�� / _ 7- l 2019-01-01--wrw s Petition to require the use of electric p®°,y,, - red c roomfield South Compress, O F � press , rs at the proposed Stati11no Petitiondsummary and "� Compressor Stations are required for the pipeline transport of natural gas from wells to processing plants and ultimately to background ' " ` market They are often powered by large engines that use some of the natural gas for fuel Even equipped with catalytic ;.�" converters, these engines produce massive amounts of pollutants -- potentially putting out hundreds of tons of pollutants per year A significant result of the pollutants is the formation of ozone The installation and operation of any oil and gas ≤< T'Y operation should, to the maximum extent practicable, avoid causing degradation to air quality �, The negative health effects of resultant pollutants coupled with the low topography along the Big Dry Creek causing polluted air to regularly collect and persist, lead to the need to use electric compressors Actionypetitooned;;for ,` We, the undersigned, are concerned citizens who urge our leaders to act now to prohibit the use of natural gas engine ---, driven compressors at the Broomfield South Compressor Station Printed Name-; ' , 'Sighatige' - ,' ,, " ' ,Address, , , ,`;'',C,,-.''Corriin`entt; „ ` '` ,'Date,,-, D'eaviiii'l 1 o'.‘6,f-e. L - -d ....... 4_,....... .2,->zy cke 17, 131e1C-2 1,,s--/ 9 / -5 -) 9 Ke o e 2®3 q roG ( `7 13YL ty Ine___/ tin t c ferJ 2019-01-01--wrw 6' Petition to require the use .:f electric power;- d compressors at the proposed ;r..omfi&d South Compresstr St; ti n. Petition -lain -luau -40' ''' Compressor Stations are required for the pipeline transport of natural gas from wells to processing plants and ultimately to background t' ' Y_^ F ' market They are often powered by large engines that use some of the natural gas for fuel Even equipped with catalytic converters, these engines produce massive amounts of pollutants -- potentially putting out hundreds of tons of pollutants per year A significant result of the pollutants is the formation of ozone The installation and operation of any oil and gas operation should, to the maximum extent practicable, avoid causing degradation to air quality . � The negative health effects of resultant pollutants coupled with the low topography along the Big Dry Creek causing polluted air to regularly collect and persist, lead to the need to use electric compressors � Il � "t �'tJ Action:in, ; ; We, the undersigned, are concerned citizens who urge our leaders to act now to prohibit the use of natural gas engine ''„ °'rr Jnr driven compressors at the Broomfield South Compressor Station Printed Name--. __ ° _- > Signature - -A'diiress Coinnient ' " r .s _, , `, Date- ' -- L&X AM -Mt AB e7/2803C/7 £r-hkpt CO �3 1-��-i 9 L/.�)4 t✓A1-1414 (>0,e244 e4-/2417/---- 9z ex -x-47 ar"y U3 y� ¢, JG5eh �Jiene•-+ann h?ohitoh e.a $a 7a CA 9oba3 /�/��, / / je! GR. Jhq//lO/1 --- e,Z 6'8 CiZ'ti /'?"- 4 lw co $66O.3 AC'/g ?va 5havinm leutii co /J g7_(ig w� U 3 y �U,3 (- (p -q Peflqacv► o rI` Qi.i7%� gfC K. �A0Wei etosfr Ptf .--/K \K.r *ail y-- 1 cali(A) ckq 1-G-(0 J p H 14 1AL 01 4 c)=rik ae...41), U.\ --- 5v & tkd G R 17 .6°6 0 3 3G3-1Z5-SSt,Co i-4,-fi A 11 W? -1-}-, c,r A .1.t� h ��h r�l patti.4„ait)c)-gta p., 3d- - 41.3',x-- I2)cr3 /.1,11) 43)11 /� -� / iL 2019-01-01--wrw Petition to require the use of electric powered compressors at the proposed Broomfield South Cstmpressor Station. � ' } ?�`` r :u � n }'� s `_jr;., r ; , 44 ,4 41 ^ ; '�° ' . FE Compressor Stations are required for the pipeline transport of natural gas from wells to processing plants and ultimately to market They are often powered by large engines that use some of the natural gas for fuel Even equipped with catalytic converters, these engines produce massive amounts ofpollutants -- potentially y putting out hundreds of tons of pollutants per year A significant result of the pollutants is the formation of ozone The installation and operation of any oil and gas operation should, to the maximum extent practicable, avoid causing degradation to air quality The negative health effects of resultant pollutants coupled with the low topography along the Big Dry Creek causing polluted air to regularly collect and persist, lead to the need to use electric compressors ,., �,,�11'0,.,- - P � .� ft �G ::. �` ,0 We, the undersigned, are concerned citizens who urge our leaders to act now to prohibit the use of natural gas engine driven compressors at the Broomfield South Compressor Station bit David fficuto Sheik/9'-ohm M eliK6/2113-I-40-r La/XZm7 '4Pe&R/L) 7ld9 i fd Col d /0ly al44., / /s- (oYcl Co c -1 go). /4S 13ui �' re. -x.# -a) you, l- kouse and see 4060 you IIk�� as goief-as /,OY / p[ea e.' cfU 4.,5 C "r P*/ +OA 2019-01-01--wrw Selena Baltierra From: Sent: To: Subject: Attachments: Ladies of the Clerk to the Board, Kim Ogle Friday, November 2, 2018 8:25 AM Esther Gesick; Isabella Juanicorena; Chloe Rempel; Selena Baltierra; Tisa Juanicorena; Stephanie Frederick Discovery to RMM - Name Change.pdf Discovery to RMM - Name Change.pdf Representatives for Discovery DJ Services have provided notice that there is a name change for all past and future land use permits and obligations with Weld County government, resulting from their company being acquired by Williams Companies. Inc. and Kohlberg Kravis and Roberts and Company. Documentation attached. Thank you Kim Ogle Planner Weld County Planning Services 1555 North 17th Avenue Greeley, Colorado 80631 970.400.3549 Direct 970.353.6100 x 3540 Office kogle@weldgov.corri 1 i•scror September 21, 2018 All Clients, Vendors, Suppliers and Contractors Subject: Acquisition of Discovery Di Services, LLC by Williams Companies, Inc. and Partner KKR & Co. Inc. To Whom It May Concern: Effective August 3, 2018, Discovery Di Services, LLC was acquired by affiliates of Williams {NYSE: WMB) and KKR & Co. (NYSE: KKR) and effective September 4, 2018 Discovery DJ Services, LLC was renamed Nii,ocitry Mountain Midstream Lit'. Williams, through a new joint venture with KKR, will now operate the Discovery DJ assets. The federal tax ID for Rocky Mountain Midstream LLC formerly Discovery Di Services, LLC will remain as 81-2253251. Please find enclosed both the Secretary of State filing supporting name change as well as a new W-9 for Rocky Mountain Midstream LLB. The following entity name changes are also effective September 4, 2018 and the associated Secretary of State filings for each are also enclosed. ORIGINAL DISCOVERY DJ ENTITY NAMES CHANGED TO Discovery DJ Services LLC Rocky Mountain Midstream LLC Discovery DJ Marketing LLC Rocky Mountain Midstream Marketing LLC Discovery_Midstream JV Holdings LLC Rocky Mountain Midstream JV Holdings LLC _ Effective November 1, 2018 Williams will start processing all Rocky Mountain Midstream LLC invoices for services rendered and/or goods received post acquisition. Also note this change does not affect work/service currently in progress, Service procurement under existing Discovery Di Services, LLC contracts will continue under the terms and conditions of those agreements. To ensure you continue to receive timely payment of your invoices, please see attached Accounts Payable invoice process and address change .notification We look forward to working with you and strive to make this transition period as trouble -free as possible. If you have any questions regarding this notice please feel free to contact Yuri Vargas, Discovery DJ Services AP (214) 414-1980 ext. 112. Williamss Accounts Payable PO Box 21218 Tulsa, OK 74121-1218 NOTICE OF ROUTING CODE AND CHANGE OF BILLING ADDRESS EFFECTIVE NOVEMBER 1, 2018 October 1, 2018 Dear Vendor in Accounts Receivable and Sales Departments: Williams, through a new joint venture with KKR, has recently acquired and will now operate the Discovery CJ assets. The legal name of the new entity is Rocky Mountain Midstream LLC. The following entity name changes are now in effect: Previous Discover DJ entity name Discovery DJ Services LLC Discovery DJ Marketing LLC Discovery Midstream JV Holdings LLC New Rocky Mountain Midstream entity name Rocky Mountain Midstream LLC Rockyllountain Midstream Marketing LLC Rock Mountain Midstream JV Holdings LLC We look forward to working with you and are committed to continuing to pay your invoices in a timely manner. The information below will help us accomplish that goal. Effective Nov. 1, 2018, please follow the steps outlined below to help us ensure your invoices are processed without delay. We do not anticipate processing delays if your paper invoices include the appropriate entity name and routing code (which may be obtained from the purchaser) and are mailed to the address included below. 1. Invoices may be emailed led to APInv of ces wi I li ams.com (see vendor email requirements below) or mailed to: Williams Accounts Payable for Rocky Mountain Entities IBM Tulsa Delivery Center — North 10 P.O. Box 21218 Tulsa, OK 74121-1218 2. All invoices must contain a routing code in order to be processed for payment: • For non -PO invoices, the routing code will be "NXM M ROC ;�" • Invoices associated with Former Discovery DJ Services purchase orders (PC) written prior to Nov. 1, 2018 should use routing "N MMROC MN" and include the Discovery DJ Services PC and AFE number • New POs created on or after Nov. 1, 2018 should be invoice to Rocky Mountain Midstream LLC, and should use the routing code "NXM99" followed by the Po number. The routing code should be listed in the upper 1/3 of the first page of the invoice. Please be aware that the routing code may change on future purchases/sales; therefore, it is important that you verify the routing code at the time the materials or services are ordered. The new routing code replaces any previously used routing codes. Invoices without routing codes may be returned to you with a request to obtain a routing code from the purchaser before payment is made. a. Invoices should include a contract number when applicable. If available, please include Po numbers, Master Service Agreement (MBA) numbers and Requests for Service (RFS) numbers on the first page of the invoice, in addition to the required routing code. 4. Payment Terms will be paid according to Rocky Mountain Midstream LLC standard terms, Net 30 from receipt date, unless a different term exists in an executed MA, Po or other contract. If you have any questions related to this process change, please contact: Williams Accounts Payable Customer Service at (866) 778-2665, or in Tulsa, (918) 573-7575 Yuri Vargas, Discovery DJ Services Accounts Payable at 214-414-1980, Ext. 112 Vendor Email Guidelines The following email account has been created to accept invoices by email: APInvoices r 'i II iams.com 1. Emails and invoice attachments must follow these specifications: • Submit only one invoice per email. • Email subject should include vendor name and invoice number. • If an invoice has supporting documentation it should be combined into one file and emailed as a single attachment, • Size limitation on the email is 10 M B . • File name cannot be longer than 60 characters. • No zipped files should be submitted. • Files must be in PDF (cannot be an editable PDF), Excel or Word format. • Do not include any text in the email as it will not be read or attached to your invoice. • Remove all graphics or URLs from your email signature. 2. Invoices must still have the Routing Code and PO/RFS number (if applicable) on the first page of the invoice to be processed for payment. • If an invoice comes in with backup documentation and the routing code is on the backup documentation only, the invoice and backup documentation will be returned unpaid. * The routing code must be valid. If it is missing one digit or alpha character, it will be returned, • Routing codes should be given to you at the time services are requested or items are ordered. • If you contact Williams Accounts Payable Customer Service for a routing code, you wi l l be directed back to your Witliams purchasing contact to obtain this information. 3. Additional Information that must be included on the invoice: • Invoice number, date and amount. • Vendor name and address. • Remit to address. 4. All emails received after 3:00 p.m. T will be processed with the next day's receipt date. 5. Emails will not be read for direction or clarification. 6. Emails requesting payment status, questions concerning invoices, etc., will not be answered. • Send all documents other than invoices (inquiries, statements, change of address notifications, etc.) to WiIIiamsA P us.ibm.com_ 7. You will be notified whether your email was accepted or rejected. 8. Invalid, illegible or incomplete invoices and those missing a Routing Code will not be processed and will be returned to you unprocessed through email or U.S. mail. 9. Contact information: • API nvo ices wi II iams.corn is used for the receipt of invoices only. • Emails containing invoice inquiries, requests for payment status, etc., will not be answered. • For all AP inquiries and payment information, contact Williams Accounts Payable Customer Service via email to WilliamsAPOussibm.com or call (866) 778-2665 or (918) 573-7575. Form (Rev. November 201 7) Deparinnt of the Treasury Internal Revenue Service Go to wwwwirtgov/FozmW9 for Instructions and the latest Information. 1 Name (as shown on your Income tax return). Name is required on this line; do not leave this line blank. a, a 0 tag a. co Request for Taxpayer Identification Number and Certification $2QkY Mountain Midstream Holdings LLC 2 Business name/disregarded entity name, if different from above Rock t�l�lounta rn Midstream LLC ASS 3 Check appropriate box for federal tax classification of the person whose name Is entered on line 1, Check only one of the following seven boxes. Individual/sole proprietor or ❑ C Corporation S Corporation Partnership ■ Trust/estate single -member LLC O Limited liability company. Enter the tax classification (C=C corporation, S=8 corporation, P=Partnership) !� Note: Check the appropriate box in the line above for the tax classification of the single -member owner, too not check LW if the LLC is classified as a single -member LLC that is disregarded from the owner unless the owner of the LLC Is another LC that is not disregarded from the owner for U.S. federal tax purposes. Otherwise, a single -member LW that Is disregarded from the owner shouldcheck the appropriate box for the tax classification of its owner, ■ Give Form to the requester. Do not send to the IRS. Other (see InactructionS) ► S Address (number, streets and apt. or suite no,) See Instructions. One Williams Center, PO Box 2400 Tax Deg MD 47 City, state, and ZIP code Tulsa O 74102-2400 _ 7 List account number(s) here (optional) r 4 Exemptions (codes apply only to certain entitles, not individuals; see instructions on page 3): Exempt payee code (If any) Exemption from FATCA reporting code (if any) ge Moira to Accounts maintained oulskfe the US) Requester's name and address (optional Tax * aysr Identification Number (TI Nale _ Enter your TIN In the appropriate box. The TIN provided must match the name given on line 1 to avoid backup withholding. For individuals, this is generally your social security number (SSN). However, for a resident alien, sole proprietor, or disregarded entity, see the instructions for Part 1, later. For other entities, it is your employer identification number (EEN). If you do not have a number, see How to get a TIN, later. Social security number �l _ or Note: if the account is in more than one name, see the instructions for line 1. Also see What Name end Employer ider ificata numes number To Give the Requester for guidelines on whose number to enter. Codification Under penalties of perjury, I certify that: .18131-- 1 8!3 3 6 1. The number shown on this form is my correct taxpayer identification number (or I am waiting for a number to be issued to me); and 2. I am not subject to backup withholding because: (a) I am exempt from backup withholding, or (b) I have not been notified by the Internal Revenue Service (IRS) that I am subject to backup withholding as a result of a failure to report all interest or dividends, or (a) the IRS has notified me that I am no longer subject to backup withholding; and 3. I am a U.S. citizen or other U.S. person (defined below); and �l. The FNMA code(s) entered on this form (if any) indicating that I am exempt from FATCA reporting is correct. Certification instructions. You must cross out item 2 above if you have been notified by the IRS that you are currently subject to backup withholding because you have failed to report all interest end dividends on your tax return. For real estate transactions, item 2 does not apply. For mortgage interest paid, acquisition or abandonment of secured property, cancellation of debt, contributions to an Individual retirement arrangement (IRA), and generally, payments other than interest and dividends, you are not required to sign the certification, but you must provide your correct TIN. Soo the instructions for Part II, later. Sign Here Signature of MS. person $' General Instructio s Section references are to the Internal Revenue Code unless otherwise noted. Future developments. For the latest information about developments related to Form W-9 and its Instructions, such as legislation enacted after they ware published, go to w►wwirs.gov/'FormW9. Purpose of Form An individual or entity (Form W-9 requester) who is required to file an information return with the IRS must obtain your correct taxpayer identification number (TIN) which may be your social security number ($N), individual taxpayer Identification number (ITIN), adoption taxpayer identification number (ATIN), or employer Identification number (EN), to report on an information return the amount paid to you, or other amount reportable on an Information return. Examples of information returns include, but are not limited to, the following. Form 1 Ogg-1NT (interest earned or paid) Date ID. M� hiding • Form 1098-DIV (dividends, in those from stocks or mutual funds) • Form 1099 -MI SO (various types of income, prizes, awards, or gross proceeds) • Form 1099-B (stock or mutual fund sales and certain other transactions by brokers) # Form 1Ogg-8 (proceeds from real estate transactions) * Form 1090-K (merchant card and third party network transactions) * Form 1098 (home mortgage interest), 1098-E (student loan interest), 1098-T (tuition) * Form 1099-C (canceled debt) • Form 1099-A (acquisition or abandonment of secured property) Use Form W-9 only if you are a U.S, person (including a resident alien), to provide your correct TIN, 1f you do not return Form W-9 to the requester with a TIN„ you might be subject to backup withholding. Sea What Is backup withholding, later. Cat. No, 10231X Form While (Rev. 11401fl Under penalties of perjury, I certify that: 1. Rocky Mountain Midstream LLC TIN: 81-225325•1 is a limited liability company that is disregarded for federal income tax purposes pursuant to IRS Regulation Section 301.7701-3 and is owned by: Rocky Mountain Midstream Holdings Ile T1N: 83-1118336 2. Both entities are U.S. persons (as defined on the front of the Form W-9). I - Signature: :hPi "De Title of Signor: Tax Assistant Date: 9/21/2018 a Form 424 (Revised 05/11) Submit in duplicate to: Secretary of State P.11 Box 13697 Austin, TX 78711.3697 CertificateofAmendment 512. 4 34 55 FAX: Si '/46 4 7 - Pilia 1t1 See 'instructions _ • EntityInformation The name of the II ling entity is: Discovery Di Services LW err M as reserved .for office use. • Sammy to FILED � � � secntary �°�td'?ems SEP 0 4 2018 Corporations Section State the name of t entity as currently shaven. ' ter the.records ofthe saacialy of eta. If the amendment changes the twine of the entity, state the old name and not the new name. The filing entity is a: (Select the appropriate entity type Wow.) [. Forirofit Corporation ] Nonprofit CCotporation Cooperative Association Limited Liability Company ■ I. [�Professional corporation [l Processional Limited Liability Company ■ Professional Association O Limited Partnership The file number issued to the filingentity by the secretary of state is: S2431854 The date of formation of the entity is: 04/07120 16 • Amendments • 1. Amended Name (If the purpose. of the certificate ofamendment is to change illumine of the nntity, use the following statement) The{ amendment changes the certificate of formation to change the article or provision ision that Ming entity. The article or provision is amended to read as knows: The name of the filing entity is: (state the new name of the entity below) Rocky Mountain Midstream MC. The name of lie entity mug contain an or i Bonet *sigma= or accepted abbreviation of such term, as applicable, e a 2. Amended Registered Agent/Registered Office The amendment changes the certificate of formation to change the article or provision std g the* name of the registered agent and the registered office address of the filing t . The article. of provision is amended to read as follows: t Penn 424 6 Y 7.qC M e • PdILW28I1 CT Spann Oat Registeitd Agent (Complete either A. °r B, but not boihr Also complete C). [El A. The registered agent is an ci ani. tjon (Smut be entity nit eve) by the name of: CT core System . • OR ID 13. The registered agent is an individual resident of the state whose name . �: Pies/ Naas f it - _ .. Sex The person executing this instrument affirms that the person designated as the new has consented to serve as registered agent. • C. The business address of the registered t t d, the registered office address is: 1999 Bryan Strut, Suite 900Z 1. .met 4 s PICA .t ,) CI C 3. Other Added, Altered, or Deleted Provisions Other changes or additions to the certificate of formation may ma in the space pr ded below. If theprovided is insufficient, i�� r the additional text by providing space information an attacbm�t to this form. Please road the instructions to this form for further infor ion on. thrmat TexcArea irk attached. addendum, if any, is. incorporated try by reference.) Add each of the following provisions to the . d�rt��it �� f�tson. The identification or reference of the added provision and the full text are as follows: Address of Governing Person 1 has been changed to One Williams Center, Tulsa, OK 74172. U Alter each of the llo►w provisions of the certificate of formation. The identification or reference of the altered provision and the full text of the provision as amended ate as follows: in Delete each of the provisions identified below from the certificate of formation, Statement of Approval The amendments to the certificate of formation have been approved in the manner required by the Texas Business Organizations Code and by the governing documents of the entity. • Form.424 7 • TXISUC eadlIADVI C Tian t Effectiveness of Filin(Select either A, B or C,)1 A. (4 This document becomes effective when the document is tiled by the secretary of state. • B. 0 this document becomes effective at a later date, which not is.marathon � t riirie(90) days from the date of signing. The delayed effective date is: C. 0 This document takes effect upon the occurrence of a future event or f other than .the passage oftime. The 90th day after the date of signing is:' The followhig event or fact will paw the document to take et et in the manner described below: • Execution The undersigned signs this document subject to the penalties imposed by law for the submission. of a. materially false, or fraudulent instrument and certifies under penalty of perjury that the. undersigned is authorized under theprovisions o f lawgoverning the entity to execute the filing instrument. • Date: O9/1B By: Ala= its sole bigember ET, Signer , sothorizal person Larry C. Larsen, Oenerel Manager Printed or typed DEC of authorbed person (see instructions) • Form 414I ntassocaostunsi 1 Ct RumOthts n 1 a w p 4 i• • T • • f 1 1 • 3 • • 4 r. • 4 bE 1 S Corporations Section P'.0►.Box 13697 Austin, Texas 78711-3697 • R r Office of the Secretary of State CERTIFICATE OF FILING OF Rocky Mountain Midstream LLC 802431854 [formerly: Disccrvery Dit Services L ] . Rolando B. Pablos Secretary of State it The undersigned, as Secretary of State of Texas, hereby certifies that a Certificate of Amendment for the above named entity has been received in this office and has been found to conform the • #applicable provisions of law. ACCORDINGLY, the undersigned, as Secretary of State, and by virtue of the authority secretary by law, hereby issues this certificate evidencing filing effective on the date shown below. Dated: 09/04/2018 Effective: 09/04 018 B Rolando B. Pablos Secretary of State B Phone: (512) 463-5555 Prepared by: Kika Garza Come visit us on the Internet at hitp: .sos.s ate trus/ Fax; (512) 463-5709 Dial: 74 mil for Relay Services TID: 10303 Document; 834758030002 . Corporations Section P.O.Box 13 697 Austin, Texas 787114697 Office of the Secretary of State September 05, 2018 CT Corporation System 701 Brazos, Ste. 720 Austin,, .1X 78701 USA • loosen RE: Rocky Mountain Midstatam LLC File Number: 802431854 le • . Rolando B. Pablos Secretary of State It has been our pleasure to file the Certificate of Amendment for the referenced entity. Enclosed is the certificate evidencing filing. Payment of the filing fee is acknowledged by this If we may be of further service at any time, please let us know. Sincerely, • Corporations Section Business & Public Filings Division (512) 4634555 Enclosure I II • Come visit us on the Internet at http:hipvww.sos.stateiterial Fax: (512) 463-5709 Dial: 7-1-1 for Relay Services 111:10323 Document: 834758030002 • I Phone: (512) 463-5555 Prepared by: Kika Garza CoparationsSection PABox 13697 Austin, Tim 787114697 I • August 3i 2018 CT pSystem 701 Brazos, Ste. 720 Austin, IX 78701 USA IRicky Mountain Mi4stream File Number 803098794 • omC Of the Secretary of State' • • • • S • • • • • • • . Rotafldo H. Pablos rotState a • a� • • • • • Enclosed is IS certileate of transfer*aeration of ism for the referenced ea* name, Effectana asofthe date,the name resent hat been irausimed to the person named as applicant in enclosed fi for of • If we cin be offiudaer seiviee at awydrae, please let us know: M Sincirely, ti • Commotions Section' Business lic Wings Division (512) 4634555 . &clam • i A a p • • • p. P • F. a • I • f' , Y i I, a r. • , • • • • e • • I • • • F f • • 'visit se on the hand at attritimtinot atittattuil• Phone: •001) 463-5555 Par (512)4634719 7.14 by:Prepared ��i� "' Services . N a • • CSC Seetion ? 13697 Austin, Texas 717114697 I 4 • ti L Office of the Secretary of State • I • • Itolando B. Pablm awnaeyotaua CERWICATE OF TRANSEER OF RESERVA'UON OF NAME OF • Rocky Mom;,. MldsnamLLC . • . S The undersigned, as Secretary of State of Texas, heathy mifiea *when= of . a Rocky Mountain Midsiream which wreserved inthis office on cyan= r a period of one bunted twenty days his been tunisfermd pupa to the provisions of section 5.106 of the Texas Business Dated: 0813012018 6 • Larry C. jars= One Williams Con*, Suite 4700, OK 74172 1 • . • • I' • • 1 • s a • a a • Rolando B. Pablo!) Secretary of State Come visit to' on the friltemet at pihnovj statas , ' P (512) 4634555 Fax: (512) 40.5709 . Dbd: 761-1 y• Prepared br Elimbeds *Annie" Denton T1D: 10321 Document 834375210002 ces • • Y 9 i r t 1 • . • Form 506 (Revised 05/11)164 I Reason in duplicate to: .s • ecaeary of State P.O. Box 13697 Austin, IX 78711-3697 Notice of Transfer of 512 463-5555 Iltservation roan Entity FAX 512 4634709 Name _ In Fit: UU S Paitssel it • es •llh%_ a dee '' This sin resseved Ibr of use. FILED Piev‘i In the alesor . Secrefray of of T weIA Enti • u tige g r r • • The undersigned awlicant Mee the notice of transfer of the ruervadon of .nom, The endty name that being and is being transferred is: Mountain Midstream tiC Tht date of filing and file number of tha•re ation : 08122/2018 803091179 _ mateldiyhy File ► bye ME3O2ma Commations Sectkm 4. Name of Applicant ,.•+ . The name of the applicant on theleservation of nsrMs DI be transftned is: cheryl Mahon .. �rr • + L Name of Pernott 'to Whom Iesernfion O A. The transferee is an organized. entity by the name of: OR B. The tteralbree is an individual by the name -of Larrirrr IC. , I Larsen I sari Rants ALL Ins . rSalsa _ • 4 - Address' of Trbnnsfer : One Willy Center, Suite 4700 awe • imba USA 74172 Sta Como Zip Code Embattle -id r The undersigned signs this document sulkiere penning; i law for tip submission rntsst+an of a materially fain or fraudulent moment. . Data: i Signature of a scans, appi "'- isattorney or spit 3 J • Selena Baltierra To: Subject: Esther Gesick RE: USR18-0106, BOCC meeting of February 11. Caterpillar offers a line of electric motor compressor packages. From: wwycoffbn7@aol.com <wwycoffbn7@aol.com> Sent: Monday, January 28, 2019 4:33 PM To: Esther Gesick <egesick@weldgov.com> Cc: 2hazelfrank@gmail.com; Bohn@RMVsupply.com; b.stoneback66@gmail.com Subject: USR18-0106, BOCC meeting of February 11. Caterpillar offers a line of electric motor compressor packages. Caution: This email originated from outside of Weld County Government. Do not click links or open attachments unless you recognize the sender and know the content is safe. MS. Gesick. While not quite sure how this best works. I am sending to you documents for the Commissioners use in deciding the outcome of USR18-0106. Thank you for letting me know that while the public portion of the meeting is over that additional material could be submitted to the Commissioners before the final decision meeting. If this is not the best way, just let me know. There are more items that will be sent regarding this case. Documents could be sent directly to each Commissioner, but I seems as though all the items should also go into the file on the USR. Please let me know if there is anything I need to do. Thank you. Best Regards, Bill Wycoff 303.659.7259 1 LBNL-6990E Opportunities for Efficiency Improvements in the U.S. Natural Gas Transmission, Storage and Distribution System Jeffery B. Greenblatt Energy Technologies Area May 2015 Page 6 b. Prime movers Among prime movers, there are three main choices in use in the natural gas TS8tD system: gas engines, gas turbines and electric motors. Gas engines. Similar to an internal combustion engine used in a vehicle, the gas engine (sometimes called a reciprocating engine) uses a chamber, filled with combusting natural gas, to drive a piston. While modern gas engines are quite efficient, they do have power limitations, and can have high vibration issues that affect reliability. Also, certain components may require frequent maintenance (INGAA, 2010a, p. 34). These issues are discussed more thoroughly in Sections 1 -C -ii and 2-A. Gas engines are normally divided into two general categories related to speed. These categories are slow -speed engines (≤600 rpm) and medium - speed engines (600-2,100 rpm). There are also two basic types of gas engine designs: the two-stroke cycle and four-stroke cycle. Either type can be turbocharged. The two-cycle engines require less displacement for the same rating. The differences in performance between these engine types are small, especially with turbocharging (CAGI, 2012, p. 448). Slow speed engines are in common use in integral gas engine compressors. "Integral" indicates the use of a common crankshaft to drive both the power cylinders and the compressor. Integral machines are typically subdivided according to power output: small (25-800 hp) and large (800-7,000 hp). Small integral engines are used in oil field services 12 (gas gathering, gas injection, small gas p ocessing plants). Larger integral engines are used in process plant , main line gas transmission, gas injection, and large, gas plants (CAGI, 2012, p. 518). I Medium -speed gas engines (600-2,100 rpm) are generally used for non - integral (separable) oil field compressors. Power sizes range from 5 to 3,600 hp, with the smaller end of the ran a (5-400 hp) generally operating at medium speed (1,400-1,800 rpm), while the larger end (300- 3,600 hp) are generally; directly connected and operate at lower speeds (600-1,200 rpm). Across; the industry, the trend is toward higher driver speeds to keep pace with increasing com ressor speeds (CAGI, 2012, p. 519). Legacy internal combustion, slow speed g s engines have significantly less sophisticated controls and lower fuel effi iencies than state-of-the-art engines (INGAA, 2010a,� ip. 34). l Gas turbines use hot ehaust gases produFed from the discharge of a gas generator to drive a power turbine. Two t pes of turbines are used: 1. aeroderivative engines, based on gas turb nes developed for the aviation industry, and 2. industrial turbines, which are designed specifically for industrial use. Aviation industry developm nts have contributed to performance improvements in both types f turbines (INGAA, 2010a, p. 34). I' Gas turbines have limited application in t e process and oil and gas industry as prime movers. The gas turbine is relatively new compared to the gas engine, steam turbine or electric otor (see Section 1 -C -n). However, there are some applications wh re gas turbines (typically driving reciprocating compressors) are mo a common. One application is offshore compression, where weight is a c ncern. Another application is refineries or process plants, where turbin exhaust heat can be utilized to improve overall plan 'efficiency (CAGI, 012, p. 527). Smaller plants (<10,000 hp) will typic lly choose a gas en irie over gas turbines, unless the waste heat can be Utilized (see also di cussion of waste heat recovery in Section 2 -A -iv). Gas engines have inher ntly better efficiency compared to smaller gas, turbines (CAGI, 2 q 12, p. 435). Efficiency trade- offs will be discussed further in Section 2- . Electric motors are more reliable and more efficient as stand-alone pieces of equipment than either gas engines or gas turbines. They are able to ramp up more rapidly than gas -driven prime movers. They also have an advantage where air quality regulations are an issue because they do not emit nitrogen oxides and CO2 at the point of use. There are a number of competing factors, however, that affect the suitability of electric motors over gas -based technology. One is the requirement for variable speed, while the other is the availability and proximity of a suitable electric power supply or substation. Reliability of the grid is also a concern, particularly in remote locations (INGAA, 2010a, pp. 34-35). While natural gas drivers are the primary technology for oil and gas field operations, electric motors are increasingly being used due to environmental considerations (CAGI, 2012, p. 520). There are three types of electric motors: induction, synchronous and DC. Each is described briefly below. 13 Induction is the most common type of electric motor. Induction motors generally have good efficiency and excellent starting torque, but rather high inrush current4 requirements. Induction motor efficiencies lie in the high 80% to low 90% range, depending on power. Smaller power induction motors are generally less efficient (CAGI, 2012, p. 522). Synchronous motors are the most common type of driver used for high - power applications, e.g., above 700 hp for speeds greater than about 450 rpm, or above 200 hp for lower speeds. These motors are typically more efficient than induction motors, with efficiencies in the range of 93%- 97%. Synchronous motors must be carefully analyzed because of their lower torque characteristics, however (CAGI, 2012, pp. 521-522). The use of DC motors as oil field compressor drivers has increased in popularity in recent years. The reasons for this increase are threefold: 1. Availability of DC traction motors, 2. Variable -speed capability of DC motors to control compressor capacity, and 3. Economic considerations of motor drive versus engine drive. However, when utilizing DC motors in a hazardous atmosphere, it is necessary to provide a continuous positive air pressure in the motor enclosure to assure that no gas can get into the motor and be ignited. Offshore oil field compressors are using more DC motor drivers because of the added speed flexibility, lower initial cost, and projected lower maintenance costs ( AGI, 2012, p. 523). However, it appears that these are not used much in as, compression applications. The improvement in e ectromcs control has greatly increased the potential for motors to be utilized as compressor drivers, especially in oil field applications. This has happened because of technological advances in motor controls. It is now economical t9 buy induction motors or synchronous motors with variable -speed 9ontrols to adjust the compressor operating speed. DC motors, having inher nt variable -speed capability, already provide the needed variable spee with little further equipment needed. Variable speed to control compr ssor performance is a very desirable characteristic'of a compressor rime mover 4 -stage mode While a vehicle is fueling, the package automatically switches to 2 -stages, increasing the flow rate up to I0x Once the vehicle is full, the pack- ages automatically switches back to 4 -stage and fills storage "If you are planning to build a CNG fueling station, J -W PowerFill Technology increases flow rates without increasing horsepower, significantly increases use of onsite storage, reduces starts and stops on equipment, and ultimately enhances the customer's fueling experience;" said James Barr, vice president at J -W Pow- er Co "We designed and built a CNG compressor package that can decrease fill times significantly by maximizing your on -site fuel storage by allowing the com- pressor to change the number of stages dynamically to utilize high pressure from storage to yield a higher flow rate" Headquartered in Add ison,Texas, USA, J -W Power Co is a wholly owned sub- sidiary of J -W Energy Co that special- izes in leasing, sales, parts, and service of natural gas compression packages J -W Power Co leases and operates its com- pression lease fleet in the United States with compressor packages ranging from 18 to 1775 hp (13 to 1324 kW) WINDROCK NAMES US REGION- AL SALES MANAGER Kevin Lemery has joined Windrock as a regional sales manager, supporting the US midcontinent and Bakken region Le- mery, based in Tulsa, Oklahoma, has held various roles in management, sales, and marketing He has a bachelor's degree in business administration from Oklahoma State University and is working toward his master's degree at Jack Welch Man- agement Institute Windrock specializes in the develop- ment, manufacture, and distribution of online monitoring systems and portable analyzers, software, sensors, and tech- nical services for reciprocating engines, compressors, and rotating machinery worldwide OHIO COMPRESSOR STATIONS BEGIN SERVICE Rover Pipeline LLC (Rover) has re- ceived US Federal Energy Regulatory Commission (FERC) approval to com- mence service of three compressor stations in Ohio, USA — the Clartngton Compressor Station (Monroe, Ohio), the Seneca Compressor Station (Noble, Ohio), and the Cadiz Compressor Sta- tion (Harrison, Ohio) Rover initially applied to FERC in February 2015 to construct, own, and operate a new in- terstate natural gas pipeline system to include 710 miles (1 142 km) of supply laterals and mainlines, and related com- pression and metering facilities, from the Marcellus and Utica shale supply areas in West Virginia, Pennsylvania, and Ohio, USA, to a point of interconnection with the Vector pipeline system in Livingston County, Michigan, USA Facilities at each compressor station include natural gas -fired compressors, a compressor building with acoustic miti- gation, an office/control/utility building, a storage/maintenance building, gas and utility piping, separators, gas coolers and heaters, safety equipment, an emergency generator, and parking areas GCM The AXH;manufacturing complex consists,of ;; x wN ,� _ six�planng 553,,5,00 SF on 67 acres,: gascompressionmagazine corn j FEBRUARY 2018 `r hY✓t EAGAN DEL CAT ELECTRIC MOTOR FOUR CATERPILLAR ELECTRIC MOTOR PACKAGES FOR NEW MEXICO GAS PLANT APPLICATION BY BRENT HAIGHT Ragan Power & Compression (Reagan) has elivered four Caterpillar (Cat) electric mo- tor -driven compressor packages to a midstream company headquartered in Dallas, USA, for a gas plant application in Loving, New Mexico, USA The order marks the first for Caterpillar since it added electric motors to its product portfolio The units were packaged at Reagan's Brous- sard, Louisiana, USA, shop Best known for its custom packaging in carbon dioxide (CO2) com- pression, Reagan is an authorized distributor and packager for Ariel Corp (See "A New Reagan," May 2017 Gas Compression Magazine, p 34) The company designs and manufactures gas compres- sion packages from 50 to 8000 hp (37 to 5968 kW) for the upstream, midstream, and down- stream oil and gas markets Each package features a 2250 -hp (1677 -kW) Caterpillar CN2586 electric motor and a 4 -throw Ariel JGD compressor "This is a midstream application that called for 1200 rpm at 2250 hp per package," said Ja- son Sowels, director of business development at Reagan "The speed and horsepower are variable for added flexibility in changing conditions These packages are for inlet and residue compression Two of the motors go to the inlet, and the other two go to residue for this gas plant Through the process of evaluating electric motors offered throughout the industry, the Caterpillar option provided significantly more value for the applica- tion We were presented with a few electric mo- tor options It eventually came down to Caterpil- lar and one other manufacturer The Cat motor had more in its standard spec than the other manufacturer — improved speed range, better shaft material, better cooling for VFD [variable - frequency drive] turndown When all the chips were put on the table, the Cat motor was the best fit for this application" According to Caterpillar, its electric motor lineup has been designed and built specifically for reciprocating compressor applications Available in power ratings ranging from 1500 to 5000 hp (1 120 to 3730 kW), Cat's electric motors can operate in direct -online -drive or VFD applications Standard features include Class I, Division 2 Groups A, B, C, and D (T3) ratings and a high -strength 4140 alloy (42CrMo4) forged, keyless shaft. "We've seen a growing trend toward the utilization of electric motors and drives in gas compression applications as shale gas proximity to areas serviced by utility power has grown," said Edward Porras, account manager for Cat- erpillar Oil & Gas "The Cat electric motors and drives complement Caterpillar's existing prod- uct portfolio of gas compression reciprocat- ing engines designed for the gas compression industry We are excited to have delivered our first electric motor order, and look forward to building our relationship with Reagan Power & Compression" gascompressionmagazine corn I FEBRUARY 2018 Selena Baltierra From: Sent: To: Cc: Subject: Chris Gathman Wednesday, January 30, 2019 2:19 PM Selena Baltierra; Isabella Juanicorena; Jessica Reid Esther Gesick FW: [EXTERNAL] Fwd: USR18-0106, BOCC meeting of February 11. Caterpillar offers a line of electric motor compressor packages. Item of correspondence for USR18-0106. From: Norton, Matt <Matthew.Norton@williams.com> Sent: Wednesday, January 30, 2019 12:45 PM To: wwycoffbn7@aol.com; White, Lito <Leland.White@williams.com> Cc: 2hazelfrank@gmail.com; b.stoneback66@gmail.com; john@rmvsupply.com; Kim Ogle <kogle@weldgov.com>; Chris Gathman <cgathman@weldgov.com> Subject: RE: [EXTERNAL] Fwd: USR18-0106, BOCC meeting of February 11. Caterpillar offers a line of electric motor compressor packages. Caution: This email originated from outside of Weld County Government. Do not click links or open attachments unless you recognize the sender and know the content is safe. Good morning Mr. Wycoff I appreciate your research efforts and thank you for your email. I had a good call with Hazel Frank last week, and as I explained to her at that time, from the beginning the Broomfield CS was originally conceived and designed to use natural gas engines as the primary source of power for on -site compression that moves producer gas to market via processing facilities in the south. Regardless of electrical availability and the additional cost to provide land, lines and substations; the mandated use of 5000+ HP electric motors for this project would in all likelihood cause it to become economically and commercially unviable. This also creates uncertainty for producers in the area who have contracted with us to provide services. As I explained recently to a permit engineer at CDPHE, we permit our sites according to what producers in the area initially commit to and what makes engineering sense for a particular facility. Those commitments are based on forecasting that attempts to look years in to the future for the entire DJ basin. At any given time, a projects overall priority can change dramatically causing resources to shift elsewhere. Requiring electric -driven compression at this facility on Day 1 would most definitely result in such a shift. We currently have the following approved plans on file with Weld County: Facility Decommissioning, Pipeline Decommissioning, Sound, Stakeholder Communications, and site -specific Landscaping and Visual Mitigation plans. In addition, the language regarding adherence to Dark Skies Standards or equivalent has been included in (I believe) every above -ground facility USR we have received from Weld County. We expect that same or similar language to be included in the Broomfield CS USR should it be approved by the BOCC, and we expect to continue to comply with those requirements. Regarding facility siting in proximity to the various RUAs within Weld County, there are specific boundaries for these districts, and oil and gas production well -pad operations are accepted within the boundaries of all Weld County RUAs as a "use -by -right" under state law. It is feasible (if not uncommon) for "well -pad operations" to include the same types of activities that will be performed at the Broomfield CS location, but many producers choose to outsource those operations to midstream entities like Rocky Mountain Midstream among others. As a midstream company registered with the COGCC, we have opted to remain outside the RUA boundary since their biannual exception process does not align with our current permitting needs and there is less input from the public for such a process. This choice also aligns with the previous desires expressed by officials during our West Brighton facility siting that we make every effort to 1 locate our facilities outside of RUA boundaries. It is entirely plausible that should facilities such as the Broomfield CS adjacent to a Weld County RUA be denied, that new and existing well pads inside of RUA boundaries will begin co - locating the dehydration and larger compression equipment required to transport produced gas and oil to 3rd parties. My opinion is that such activities would likely result in less, not more, community input and dialogue. Lastly, our landscape designer Kimley-Horn is preparing enhanced representations of what our proposed landscaping would likely look like for the Broomfield CS both up close and from the 1,000+ foot distances at which our closest neighbor/well-pad located in the floodplain to the south will have line -of -sight. While the remaining neighbors appear to be upwards of one-half mile or more away, we look forward to obtaining additional input regarding landscaping suggestions, as well as sharing the KH representations before the next hearing. I have also been asked by Mrs. Franks that we consider a wooden fence to the surround the location. While we are not opposed to this type of screening, it would likely block most if not all of any landscaping. My apologies for the length of this email, but I wanted to speak to your original concerns and provide some overall color for the additional folks on this email. I'm glad we all had the chance to speak after the hearing earlier this month, and I look forward to our continued discussions regarding how we can mitigate the impacts our facility may have to your quality of life. Best Regards, Matt Norton From: White, Lito <Leland.White@williams.com> Sent: Tuesday, January 29, 2019 5:10 PM To: Norton, Matt <Matthew.Norton@williams.com> Subject: FW: [EXTERNAL] Fwd: USR18-0106, BOCC meeting of February 11. Caterpillar offers a line of electric motor compressor packages. FYI - From: wwycoffbn7@aol.com <wwycoffbn7@aol.com> Sent: Tuesday, January 29, 2019 3:38 PM To: White, Lito <Leland.White@williams.com> Cc: 2hazelfrank@gmail.com; b.stoneback66@gmail.com; john@RMVsupply.com Subject: [EXTERNAL] Fwd: USR18-0106, BOCC meeting of February 11. Caterpillar offers a line of electric motor compressor packages. Hi Lito, Per my goal of keeping transparent and maintaining involvement with the USR process while your team develops responses to the Commissioner's requests to further evolve your application, I am forwarding an email that I sent to the "Clerk to the Board". My intention is to send additional emails for inclusion into the file that relate to some of the subjects the Commission would like Rocky Mountain Midstream to address. For example, I have a bit of a focus on the Dark Sky Standards. I would expect that, while a verbal commitment was made at the hearing, there would be documentation going to the Commission. Perhaps it is in a newer version of the "Development Standards". I will ask Mr. Gathman if there is a revised "Development Standards" document that includes changes made at the last BOCC meeting. If there is, it might have revisions to the construction vehicle, haul route too. I attend most Board meetings of the Todd Creek Village Metropolitan District (TCVMD). At the last meeting, the Directors there were interested in fact that the Weld Board of County Commissioners was seeking to preserve the quality of the area adjacent to their RUA. While TCVMD has accomplished securing enough water to start building a major development, they are now focused on finalizing sewer plans so that construction can begin in Weld County. 2 Best Regards, Bill From: wwycoffbn7@aol.com To: egesick@weldgov.com Cc: 2hazelfrank@gmail.com, john@RMVsupplv.com, b.stoneback66@gmail.com Sent: 1/28/2019 4:33:11 PM Mountain Standard Time Subject: USR18-0106, BOCC meeting of February 11. Caterpillar offers a line of electric motor compressor packages. MS. Gesick, While not quite sure how this best works, I am sending to you documents for the Commissioners use in deciding the outcome of USR18-0106. Thank you for letting me know that while the public portion of the meeting is over that additional material could be submitted to the Commissioners before the final decision meeting. If this is not the best way, just let me know. There are more items that will be sent regarding this case. Documents could be sent directly to each Commissioner, but I seems as though all the items should also go into the file on the USR. Please let me know if there is anything I need to do. Thank you. Best Regards, Bill Wycoff 303.659.7259 This email originates outside of Williams. Use caution if this message contains attachments, links or requests for information. 3 Esther Gesick From: Sent: To: Cc: Subject: Norton, Matt <Matthew.Norton@williams.com> Friday, February 1, 2019 7:29 PM wwycoffbn7@aol.com Esther Gesick; Chris Gathman; Kim Ogle; 2hazelfrank@gmail.com; john@RMVsupply.com; b.stoneback66@gmail.com; watneyone@gmail.com; White, Lito Re: [EXTERNAL] USR18-0106 -- 15 Megawatts available now from the Brighton Substation, two miles East of USR site. Caution: This email originated from outside of Weld County Government. Do not click links or open attachments unless you recognize the sender and know the content is safe. Thank you again Mr. Wycoff. At last inquiry to our power provider for providing three phase power to another of our sites further south, the cost of running the requisite power lines was approximately $1 million per mile. I will try and touch base with you next week to discuss those cost, how they might be offset or shared, and provide an update on what delivery times might be for the 5000 hp electric motors. Have a good weekend and look forward to talking soon. Matt (817) 455-5799 On Feb 1, 2019, at 4:26 PM, "wwycoffbn7@aol.com" <wwycoffbn7@aol.com>wrote: MS. Gesick, I am sending additional information for the Commissioners use in deciding the outcome of USR 18-0106 . The other week, I contacted United Power to inquire about available power in the area of this USR. United Power's Robert Maxwell (303.659.0551) was clear that 15 Megawatts of power could be easily provided from the capacity of the Brighton Substation that is located on the East side of County Road 21, South of County Road 6. This is just a bit over 2 miles East of the USR site. 1 Constructing the expected 13 kilovolt lines to the site would be a very normal undertaking. Please let me know if there is anything I need to do Thank you Best Regards, Bill Wycoff 303 659 7259 This email originates outside of Williams Use caution if this message contains attachments, links or requests for information 2 Selena Baltierra From: Sent: To: Cc: Subject: Attachments: Selena, Please add to the File. Esther Gesick Tuesday, February 5, 2019 1:22 PM Selena Baltierra wwycoffbn7@aol.com FW: USR18-0106: Colorado and Xcel state goals to be Carbon Free by 2050, United Power to increase use of Renewable power. 2018-12-08-UnitedPower-to-increase-Quantity-of-Renewable-electricity.pdf; 2018-12-04-Xcel -Goal-to-be-Carbon-Free-by-2050-State-by-2040.pdf 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 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: wwycoffbn7@aol.com <wwycoffbn7@aol.com> Sent: Tuesday, February 5, 2019 12:24 PM To: Esther Gesick <egesick@weldgov.com> Cc: Chris Gathman <cgathman@weldgov.com>; Kim Ogle <kogle@weldgov.com>; 2hazelfrank@gmail.com; john@RMVsupply.com; b.stoneback66@gmail.com; watneyone@gmail.com; leland.white@williams.com; Matthew.Norton@williams.com Subject: USR18-0106: Colorado and Xcel state goals to be Carbon Free by 2050, United Power to increase use of Renewable power. Caution: This email originated from outside of Weld County Government. Do not click links or open attachments unless you recognize the sender and know the content is safe. MS. Gesick, I am sending additional information for the Commissioners use in deciding the outcome of USR 18-0106. Attached are two recent, Denver Post items: one on Colorado and Xcel stating goals to be Carbon Free, and one on United Power to increase use of Renewable power. 1 They reinforce the notion that the Compressor Station (CS) should be built to use electric power to make use of the growing amount renewable power becoming available and almost eliminate the CS as a source of CO2 and other pollutants Please let me know if there is anything I need to do Thank you Best Regards, Bill Wycoff 303 659 7259 2 ENERGY BATTLE Tri-State provider faces loss of Montrose utility Cooperative upset by rates, lack of use of renewable power sources BY JUDITH KOHLER THE DENVER POST The move by a Montrose -based electric cooperative to buy out its contract with wholesale energy provider Tri-State Generation and Transmission Association is the latest effort by Colorado utilities to cut reliance on fossil fuels and boost the use of renewable energy. The Delta -Montrose Electric Association said it intends to end its contract with wholesale power provider Tri-State Generation and Transmission to take better advantage of the falling costs of renewable sources. Delta -Montrose filed a complaint with state regulators that the fee Tri-State wants for letting the cooperative out of its contract is unreasonable and discriminatory. Brighton -based United Power, the largest member cooperative in Tri- States' four -state service territory, is taking a different route to resolve its issues with rates and the demand for more renewable energy. United Power, whose service area includes southern Weld County and Denver's northeast suburbs, has proposed a change in the bylaws that would allow the cooperatives to buy an undetermined percentage of their power from other sources. "Many of our members are asking for more of a mix of renewables," United Power spokesman Troy Whitmore said Friday. "The purpose is to get a more active conversation going with Tri-State." The hope is to discuss a possible change in the bylaws during Tri- State's annual meeting in April, Whitmore added. Tri-State, based in Westminster, generates and transmits power to 43 member cooperatives in four states: Colorado, Wyoming, New Mexico and Nebraska. The cooperatives, which include United Power and Delta - Montrose Electric Association, in turn provide electricity to their members, including businesses and households. Tri-State has been criticized by some cooperatives it serves and renewable -energy advocates for relying too heavily on coal at a time when the costs of wind and solar energy are falling and concerns about climate -changing emissions from fossil fuels are increasing. "We believe this is in the best interest of our membership. That's our bottom line," Virginia Harman, the Delta -Montrose cooperative's chief operating officer, said of the complaint filed with the Colorado Public Utilities Commission. Delta -Montrose has been talking to Tri-State for more than a decade about ways to stabilize its rates, which have jumped 56 percent since 2005, Harman said. The cooperative's complaint says Delta -Montrose wants to develop more local, cost-effective renewable energy resources but Tri-State hasn't been receptive. It has objected to a 5 percent limit on the amount of energy that Tri-State members can generate on their own. Tri-State will have 20 days to respond to the formal complaint by Delta -Montrose, and the Public Utilities Commission will decide how to proceed, spokesman Terry Bote said. "We are disappointed that (Delta -Montrose) has decided to attempt to litigate this matter rather than negotiate their withdrawal. Tri-State continues to believe that negotiations on withdrawal are far preferable to litigating this matter," Tri-State spokesman Lee Boughey said in a statement. Regarding the proposal by United Power, Boughey said in an email that engagement between Tri-State's members on their contract is not surprising and the board of directors "regularly considers the contract to ensure the association meets the needs of its members. These discussions continue." Tri-State's wholesale rates have remained stable four of the last five years, won't increase next year and are forecast to remain stable in the years to come, Boughey added. In addition, 3o percent of Tri-State's power comes from renewable energy sources and the association is currently negotiating to add more renewable sources. "We acknowledge that Tri-State has added renew-ables," Whitmore said. The problem, added Whitmore, is that United Power pays roughly 28.5 percent more than adjacent customers of Xcel Energy -Colorado and the fear is the gap will continue to grow. That's a big disadvantage when communities served by United Power are trying to attract businesses to the area, he said. United Power members also want to increase the amount of renewable energy sources used and reduce carbon dioxide emissions, Whitmore added. BUSINESS ENERGY Xcel Energy wants carbon -free electricity by 2050 Colorado's largest utility ups the ante in its plan for renewables Joe Amon. The Denver Post Turbines that are part of Xcel Energy's Rush Creek Wind Farm and Transmission project in Matheson mix agriculture and technology in the largest single-phase wind project in the United States. Photographed on Sept. 18, 2018. By JUDITH KOHIER lkohler@denverpost.com The Denver Post PUBLISHED: December 4. 2018 at 3:51 pm UPDATED: December 4, 2018 at 336 pm Xcel Energy, Colorado's lax gest electric utility, is upping its renewables game with the announcement Tuesday that it has a goal of being 100 - percent carbon free by 2050. The Minneapolis -based company that serves eight states has been a leader in the quest to increase the use of renewable energy sources, said Ben Fowke, the utility's chairman, president and CEO. "This isn't new to us. We've been leading the clean -energy transition at Xcel for quite a while now. Investing in renewables has really been part of our DNA for over 20 years now," Fowke said at a news conference for the announcement Tuesday at the Denver Museum of Nature and Science. The move to more wind, solar and other renewable energy sources is not only good for the environment but also good for the bottom line of both the company and its customers, Fowke added. "That has allowed us to reduce out carbon footprint by 35 percent across all our eight states since 2005," Fowke said. Xcel Energy already had a goal of reducing carbon dioxide emissions by nearly 60 percent and increasing its use of renewable energy sources to 55 percent of its mix by 20►6 as part of its Colorado Energy Plan, which was approved by state regulators in August. The new plan includes a goal of reducing carbon emissions by 84 percent by 2030 across eight states and getting to zero emissions of the greenhouse gas by 2050. Fowke and Alice Jackson, president of Xcel's Colorado operation, said they don't know of any other utility in the country that has set a goal and timeline for producing no carbon emissions. Colorado Gov. -elect Jared Polls. who has a goal of getting 100 percent of the state's electricity from renewable sources by 2040, said he is excited about "Xcel having the most aggressive goal of any utility in the country." Polls, speaking at the Xcel Energy news conference, said he would like to see Colorado achieve the zero -carbon goal even earlier and wants to work with municipal utilities and rural electric cooperatives to achieve the goal. "Colorado has always been a very innovative state and I think it's great that we're showing the country the way to keep rates low, have cleaner air and to do our part for our climate and embrace the future of clean energy and make it work for Colorado businesses and individuals," he said. Fowke and Jackson conceded in a media briefing before the news conference that some of the technology required to meet the new goal might not currently exist. "I'm betting on the technologS'," said Fowke, referring to the many advances that have made wind and solar energy comparable to or less expensive than fossil fuels. Jackson said state policies, including laws and regulations, might have to be changed to make it easier for utilities to invest in the research and development of new technology. She and Fowke also acknowledged that attaining zero emissions of carbon dioxide might involve the use of nuclear power and capture and sequestration of emissions from fossil fuels. Fowke stressed that providing affordable and reliable power across Xcel's territory is the priority. Stemming the effects of climate change, fueled by heat -trapping carbon dioxide emissions, is also of concern he said. The latest National Climate Assessment by the federal government shows that the effects of climate change are getting worse, he noted. "I think it drives home the sense of urgency," Fowke said of the report. Popular In the Community Sponsored 0 1> INJECTION -SITE PROPOSAL'S FUTURE U., catfromcolo After the safe injection sites are up and run... BUD LIGHT GETS EARFUL FROM ANGRY CORN LO TheRealTaboot So now if you don't load up your beer wi... VAPE AND PLAY OPENS AS DENVER'S SECOND M boulderdam69 Whattt .... a DUMPP! =D SUPER BOWL L BRADY. NEW E benec 31 Mehh! Both played like 0 TAGS: CLIMATE CHANGE, COLORADO ENERGY PLAN, EMISSIONS. ENERGY, ENVIRONMENT. JARED POLIS, MORE BUSINESS NEWS, RENEWABLE ENERGY. SOLAR ENERGY. XCEL ENERGY Judith Kohler Judith Kohler joined The Denver Post in August 2018 and is part of the business team, writing about energy, aerospace, agriculture and other topics. She spent 21 years with The Associated Presff-R8008, jor nrmipt. f1'oBylwlj migiQpFd1 iiiKohler Colorado and Wyoming. SPONSORED CONTENT Transfer your debt and pay no interest for 18 months L By CompareCards C aonparecan, If you're suffering from high interest rate charges, transfer your debt to one of these balance transfer cards with 0% intro APR and start saving... Selena Baltierra To: Subject: Esther Gesick RE: [EXTERNAL] USR 18-0106 BOCC Continuation Hearing 2/11/19 From: Norton, Matt <Matthew.Norton@williams.com> Sent: Tuesday, February 5, 2019 9:59 PM To: Hazel Frank <2hazelfrank@gmail.com> Cc: Esther Gesick <egesick@weldgov.com>; Chris Gathman <cgathman@weldgov.com>; B Wycoff <Wwycoffbn7@aol.com> Subject: Re: [EXTERNAL] USR 18-0106 BOCC Continuation Hearing 2/11/19 Caution: This email originated from outside of Weld County Government. Do not click links or open attachments unless you recognize the sender and know the content is safe. Thanks for pointing that out Hazel. Looking forward to seeing you Monday. Matt (817) 455-5799 On Feb 5, 2019, at 4:05 PM, Hazel Frank <2hazelfrank@gmail.com>wrote: Dear Ms. Gesick: My recollection of the BOCC hearing on USR 18-0106 held on January 9, 2019 is that it was agreed that the Development Standards for this USR would be amended to reflect the agreement that this USR would comply with the Residential level noise standards and the Dark Sky policy. These amendments may already have been made but, if not, I would appreciate it if the Commissioners could be made aware of these two items so that, if necessary, they can amend the Development Standards accordingly at the February 11, 2019 hearing. Regards, Hazel Frank This email originates outside of Williams. Use caution if this message contains attachments, links or requests for information. 1 Selena Baltierra To: Subject: Esther Gesick RE: USR18-0106: Tri-State provides a significant proportion of renewable energy and is building more renewable sources. From: yvvvycoffbn7@aol.com <wwycoffbn7@aol.com> Sent: Wednesday, February 6, 2019 3:09 PM To: Esther Gesick <egesick@weldjov.com> Cc: Chris Gathman <cgathnan@weldgov.com>; Kim Ogle <kogle@weldgov.com>; 2hazelfrank@gmail.com; john@RMVsupply.com; b.stoneback66@gmail.com; watneyone@gmail.com; leland.white@williams.com; Matthew.Norton@williams.com Subject: USR1S-0106: Tri-State provides a significant proportion of renewable energy and is building more renewable sources. Caution: This email originated from outside of Weld County Government. Do not click links or open attachments unless you recognize the sender and know the content is safe. MS. Gesick, I am sending a final batch of additional information for the Commissioners use in deciding the outcome of USR18-0106. Attached are two recent, Denver Post items: one on Tri-State's 100 Megawatt solar panel project, and one where Tri-State contends that nearly a third of the energy used within its association comes from renewable sources. They reinforce the notion that the Compressor Station (CS) should be built to use electric power to make use of the growing amount renewable power becoming available and almost eliminate the CS as a source of CO2 and other pollutants. Please let me know if there is anything I need to do. Thank you. Best Regards, Bill Wycoff 303.659.7259 BUSINESS ENERGY Tri-State announces new 100 -megawatt solar project in southern Colorado Westminster -based energy supplier says nearly a third of its power comes from renewable sources Tri-Stab Generstion and Transmission Association ' ..-••..foal. a'�...ei t:•vt. •t _�-44..p ► .• - ••• �ti�y.�.. "�'�n(N•`..`._. .""lisl. grn.t" iry may An artists rendering of the Spanish Peaks Solar Project planned for southern Colorado. By JUDITH KOHLER jkohler@denverpost.com The Denver Post PUBLISHED: January 11.2019 at 5:06 pm ( UPDATED: January 11, 2019 at 5:11 pm Tri•State Generation and Transmission Association is more than doubling the power it will get from solar energy with a new 100 -megawatt installation about 20 miles north of Trinidad. ADVERTISING Tri-State said Friday that it is teaming up with Boulder -based juwi Inc. on the 660 -acre project, which will install more than 300;000 photovoltaic solar panels on single -axis tracking arrays that follow the sun. The energy wholesaler will buy the entire output of the project over the 15 -year contract. The Spanish Peaks Solar Project will serve about 28,000 rural homes and support 1S0 jobs during construction, which will start in 2022. The project is expected to be in service no later than 2023 and could start producing power earlier, Tri-State spokesman Lee Boughey said. This will be the second project Tri-State has undertaken with juwi, the U.S. subsidiary of Germany -based renewable energy company juwi AG. The 30 -megawatt San Isabel Solar Project in Las Animas County started generating electricity in 2016. The new project is the wholesale power supplier's "largest, most cost-effective solar project to date," Tri-State CEO Mike McInnes said in a statement. "By developing renewable projects through Id -State, our members take advantage of an economy of scale unavailable in smaller projects," McInnes said. The Spanish Peaks Solar Project will be in the service territory of the San Isabel Electric Association, a Tri-State member that serves all or parts of seven counties in southern Colorado. "This project is just another significant step forward into the future not only for San Isabel Electric's members but for electric co-ops across Colorado and the West," San Isabel Electric CEO Reg Rudolph said. Westminster -based Tri-State is owned by 43 member electric cooperatives and public power districts and supplies electricity to members in New Mexico, Colorado, Nebraska and Wyoming. Some member cooperatives and renewable energy advocates have criticized Tri-State for relying too heavily on coal at a time when the costs of wind and solar energy are falling and concerns about climate -changing emissions from fossil fuels are increasing. The Taos, N.M.-based Kit Carson Electric Cooperative paid $37 million to break its contract with Tri-State in 2016 because of rising rates and a desire to increase use of renewable energy sources. The Delta -Montrose Electric Association, based in Montrose, wants to buy out its contract with Tri-State, saying its rates have increased 56 percent since 2005. A complaint the cooperative filed to ask the Colorado Public Utilities Commission to intervene says it wants to develop more local, cost-effective renewable energy resources but Tri-State hasn't been receptive. However, Tri-State said Friday that nearly a third of the energy used within its association comes from renewable energy sources. Boughey said that amount is expected to increase as Tri-State adds more renewable sources and retires two coal -generating units, one by the end of 2022 and another by the end of 2025. In addition to the Spanish Peaks and San Isabel solar projects, Tri-State also purchases the full output of the 30 -megawatt Cimarron and 25 - megawatt Alta Luna solar projects in New Mexico. From its start, the not -for-profit Tri-State has used federal hydropower and since 2008 has added more than 4Th megawatts of utility -scale wind, solar and other renewable projects, the company said. Popular In the Community Sponsored 3 PRESIDENT TRUMP HAD A "GREAT MORNING' PLA... jRe3289S3 Who cares? Apparently DARLENE... COLORADO LAWMAKERS DENVER PUBLIC SUNDAY. FEB. BRING BACK BILL TO HE... SCHOOLS HAS SPENT M... LETTERS: ELEC vggreen catfromcolo CtIm Time to excise the I woncer how many health insurance ind... worke-s in the privat... TAGS: CLIMATE, CLIMATE CHANGE, COAL. COLORADO PUBLIC UTILITIES COMMISSION, ELECTRICITY, EMISSIONS, MORE BUSINESS NEWS, RENEWABLE ENERGY, SOLAR, SOLAR ENERGY, TRINIDAD, WIND ENERGY peter) i For example were widesp Judith Kohler Judith Kohler joined The Denver Post in August 2018 and is part of the business team, writing about energy, aerospace, agriculture and other topics. She spent 21 years with The Associated PrespFsfiewigaPA414t tW 41tr 1I `IClilJ gt611RQ Mi i Kohler Colorado and Wyoming. ENERGY Tri-State asks court to deny breakup BY JUDITH KOHLER THE DENVER POST Tri-State Generation and Transmission has shot back at a western Colorado utility that wants out of its contract, asking a district court to deny the smaller cooperative's efforts. Tri-State filed a complaint in Adams County District Court on Tuesday, asking the court to clarify the Delta -Montrose Electric Association's obligations under its contract with Tri-State. The complaint also asks the court to determine that the Colorado Public Utilities Commission doesn't have the authority to intervene in the dispute between Tri-State and Delta -Montrose. Delta -Montrose asked the utilities commission in December to rule that the fee Tn-State wants to let the cooperative out of its contract is "unjust, unreasonable, and discriminatory." The Montrose -based cooperative said the state commission has jurisdiction in the matter because Tri-State is a public utility. And the cooperative picked up support Thursday from 53 legislators who back state regulators getting involved. "We understand that Tri-State would like to pull the case away from the Public Utilities Commission, which is charged with protecting the public interest, and that is unfortunate," said Jasen Bronec, Delta - Montrose CEO. "But, just today more than 50 legislators, including every single member of our local legislative delegation, sent a letter to the PUC supporting DMEA's filing before the PUC and our efforts to protect our members. We think that speaks volumes for the scope of support that we have." In filings with the district court and state regulators, Tri-State argues the utilities commission doesn't have the authority to nullify Tn-State's bylaws, force the renegotiation of Delta-Montrose's contract with Tri- State or decide breach -of -contract claims. "We believe the court will confirm our board's authority to determine the terms and conditions under which a member may withdraw from our association," Tri-State CEO Mike McInnes said in a statement. Delta -Montrose is one of 43 member cooperatives served by Tri-State, a Westminster -based wholesale energy provider whose territory spans Wyoming, Colorado, Nebraska and New New Mexico. Tri-State spokesman Lee Boughey said in an email Friday that 34 of its member cooperatives have filed statements supporting the position that the state utilities commission doesn't have jurisdiction in the contract dispute. Tri-State has been criticized by some of its member cooperatives and renewable energy advocates for relying too much on coal at a time when solar and wind energy prices are dropping and concerns about climate change linked to fossil fuel emissions are rising. Delta -Montrose has said its rates have jumped 56 percent since 2OO5 and that it could lower costs by using more renewable energy. Tri-State has said that nearly a third of the energy used within its association comes from renewable energy sources. In 2016, Kit Carson Electric Cooperative in Taos paid $37 million to break its contract with Tri-State. Selena Baltierra From: Sent: To: Cc: Subject: Norton, Matt <Matthew.Norton@williams.com> Sunday, February 10, 2019 9:10 PM Chris Gathman Esther Gesick; Selena Baltierra; Norton, Matt Re: [EXTERNAL] USR 18-0106 BOCC Continuation Hearing 2/11/19 This email originated from outside of Weld County Government. Do not click links or open attachments unless you recognize the sender and know the content is safe. Chris I'll see you all in the morning when we will be requesting a two-week continuance as RMM seeks to finalize the landscaping plan additions with our new architect, and gain additional information on the costs and lead times associated with the potential use of electric motors. This should not be considered a request to amend our current USR application for Broomfield Station, or a commitment to utilize electric motors in the initial development stages. RMM is committed to adequately answering the questions posed by the BOCC at the last hearing, and therefore we will need more time to ensure our ability to do so appropriately. Thank you for your patience. Matt (817) 455-5799 On Feb 8, 2019, at 9:07 AM, Chris Gathman <cgathman@weldgov.com>wrote: OK. Thanks Matt. Have a good weekend and see you Monday! From: Norton, Matt <Matthew.Norton@williams.com> Sent: Friday, February 08, 2019 9:01 AM To: Chris Gathman <cgathman@weldgov.com> Subject: RE: [EXTERNAL] USR 18-0106 BOCC Continuation Hearing 2/11/19 Caution: This email originated from outside of Weld County Government. Do not click links or open attachments unless you recognize ti sender and know the content is safe. I should have the final approved slides ready before Monday morning and will email them when approved. It will probably be a fairly large file, so if it bounces back due to size then I'll bring a jump drive too. Thx, mn 817-455-5799 From: Chris Gathman <cgathman@weldgov.com> Sent: Friday, February 8, 2019 8:45 AM To: Norton, Matt <Matthew.Norton@williams.com> Subject: RE: [EXTERNAL] USR 18-0106 BOCC Continuation Hearing 2/11/19 Dear Matt, Just following up on Monday's hearing. Are you planning on having an updated power point presentation? 1 If so — please send it to myself, Esther Gesick and Selena Baltierra — sbaltierra@weldgov corn Regards, Chris Gathman Planner III Weld County Department of Planning Services 1555 N 17th Avenue tel 970-400-3537 fax 970-400-4098 <image001 jpg> 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: Norton, Matt <Matthew Norton@williams corn> Sent: Tuesday, February 05, 2019 9 59 PM To: Hazel Frank <2hazelfrank@gmail corn> Cc: Esther Gesick <egesick@weldgov corn>, Chris Gathman <cgathman@weldgov com>, B Wycoff <Wwvcoffbn7@aol corn> Subject: Re [EXTERNAL] USR 18-0106 BOCC Continuation Hearing 2/11/19 z r - -' Caution This email originated from outside of Weld County Government '0,c; not click links or open attachments unlesswyou `recognize tl gl n a� w x t s & 'r : � ��.r sender and know the content is safe �� f �, c Thanks for pointing that out Hazel Looking forward to seeing you Monday Matt (817) 455-5799 On Feb 5, 2019, at 4 05 PM, Hazel Frank <2hazelfrank@gmail corn> wrote Dear Ms Gesick My recollection of the BOCC hearing on USR 18-0106 held on January 9, 2019 is that it was agreed that the Development Standards for this USR would be amended to reflect the agreement that this USR would comply with the Residential level noise standards and the Dark Sky policy These amendments may already have been made but, if not, I would appreciate it if the Commissioners could be made aware of these two items so that, if necessary, they can amend the Development Standards accordingly at the February 11, 2019 hearing Regards, Hazel Frank 2 This email originates outside of Williams Use caution if this message contains attachments, links or requests for information 3 Rocky Mountain Midstrea Broomfield Compressor U Station USRI 8-0106 Weld County Board of County Commissioner Hearing Continued from January 9, 2019 February 25, 2019 9:00 am 1 Broomfield Station Site Layout Broomfield Compressor Station • Located on an 10 -acre site � South of WCR 6, on the West side of WCR 17 Broomfield Compressor Station • Site Overview E 3 165 960.22 0 0 + / Pr) <\'‘ tl LEASE CORNER N 1 250 776.39 E 3 165 305.10 LEASE CORNER N 1 251 436.19 E 1ss 300142 � 2 I 11 0 N 0 r LEASE CORNER N 1 251 440.88 PROPERTY CORNER N 1. 2s51 44542 E 3 1q 618.t8 I ACCESS ROAD LEASE CORNER N 1 250 781.07 E 3 165 964.90 STORMWATER DETENTION POND DESIGN VOLUME = 40337 CF NO BUILD/STORAGE AREA EXISTING OVERHEAD ELECTRIC JOHN E & DIANA G HOWARD ETAL (PARCEL NO: 146928200002) 4 i 750' TO COUNTY WELD ROAD 17 _ . .. des., V v 0 0 I 1� I f I DEHY - 0 r - I 1 t 1° FUTURE SUBSTATIONi BUILDING I 1 FO O 1 JI PI PERACK �--,. • da I `r COMPRESSOR ' `� O J BUILDING 1r 0 O O O I1 `\, ,....„ SLUG CATCHEREl i u ■ c ■y : liklitita Qm0 O O jo ANal TRUCK LOADOUT � MI�C E�!UIPMENT� COMPRESSOR 1 I BUILDING 1y, � �pma I:_�nO O 1 . lal I r 1 �1a loo a I I LAUNCHERS POND OUTLET I RECEIVERS DETENTION POND 'k� AND SPILLWAY - - - - - - -- - ' DESIGN CAPACITY 0.926 AP i = 5 Compressor Station initial phase elevation views 11111111111111 Looking West Looking East 11110111111111111111I11111111111111111 � Landscaping Plan submitted to Weld County for review and approval. 1 HP SI I I 1 1 I I a I r* si Ma IS MIMISF MI MS I• :� � u • MB la r I sal Slom I I I I 3317 '. S j •�iA CKl;A''ic Landscaping Proposal Detail I I ti. 4 0 C1151 t= ® f SHEET L1.2: ! 1 M 11 i i P i I f I u _ SHEET L1.3 n SHEET 11.4 II Llir k t7S14 a its I I I I Plant Schedule DECIDUOUS TREES EVERGREEN TREES Ay%Isiffie -.115 it 0 ORNAMENTAL TREES CODE OTY BOTANICAL NAME COMMON NAME CONT CAL SIZE 7 eltis occidental's Common Huckberry B & B 2.5" CAL. 10'-i2" HT GS 5 Catalpa speciosa Northern Catalpa B & B 2.5" CAL_ _ 10'-'12" HT T 18 Oiled it. is trig ca nthos Honey Locust B & B 2.5" CAL. 10'427 HT GM 8 Quercus macrocarpa Burr Oak B & E .5" CAL. 10.-12. HT CODE OT? BC' 1 Arc I AL NAME COMMON NAME CONT CAL SIZE J1E 12 Jun iperus virg in iana Eastern Red Cedar B & B 8' -10% HT PC 26 Picea pungens Colorado Spruce B & B 8" -10 HT PD 14 Pseudotsuga menzie ii Douglas Fir B & B 8' -10' HT PP 17 Pinus ponderosa Ponderosa Pine B & B 81_lO% HT CODE OTY BOTANICAL NAME COMMON NAME CONT CAL SIZE AG 15 Acer gl.abrum Rocky Mountain Maple B & B " CAL 8' -10c HT CC 14 Cercis canadensis Eastern Reribud B & B " CAL 8' -10' HT MS 8 Malus x ~Spring Snow' Spring Snow Crab Apple B & B 2" CAL '_l0t HT Plant Schedule SHRUBS GRASSES CODE CITY BOTANICAL NAME COMMON NAME CONT SPACING SIZE BR 61 Berber's thunbergii RoseGlow- Rosy Glow Barberry 5 GAL 36" OC 18" FULL CB 21 Cotoneaster apiculatus Coral Beauty Co aneaster 5 GAL 6D' ..C_ 18" FULL CF 21 Comus sericea - Havi ram eaT Yellow Twig Dogwood 5 GAL 17' O_ ._ 24" HULL CR 6 Comus sericea Red Twig Dogwood 5 GAL 60" O. _ 24" FULL Fl 18 Forsythia x intermedia. Border Forsythia 5 GAL 8' GC. 24" FULL PM 28 Physocarpus monogynus Mountain Ninebark 5 iGAL 36" OC 18" FULL RG 37 Ribes aureu m Golden Currant 5 GAL 60" O_C_ 36" FULL RT 36 Rhus trilobata Skunkbush Sumac 5 GAL 60" O.. _ 18" FULL SC 6 yringa .x chinensis Chinese Lilac 5 GAL 10% 0.C_ 30" FULL VC 17 Viburnum carlesii Korean Spice Viburnum 5 GAL 48" OC 24" FULL VS 19 Viburnum opulus 'Sterile' Cranberry Bush 5 GAL 10 CLO . 30" FULL CODE CITY BOTANICAL A E COMMON NAME ONT SPACING SIZE AN 51 Andropogon gerardii Big Blue Stern 3 GAL 24" OC 36" FULL MJ 25 Miscanthus sinensis Japanese Silver Grays 3 GAL 24" OC 12" FULL. PA 87 f ennisetum alcpecurcides Fountain Grass 3 GAL 24" OC 12" FULL. QGfir,a:te rr I Merin vwr cl4sn U etc crw.i PROPOSED MAIM QV?, 4 Y 1 I • on -' a a • Q _ L �1 i PROPOSED PENCE LIRE MP.) LIt*re )LiftIrrpp Ira ft P' I trei 1 r S i ■ • _r I • PROPOilk Or R ANCE uis i'Tfn 4w8*t4 LPf ;winin I • • 1 1 1 1 1 1 1 1 • 1 1 F wttD reed Lhc ;-'IR4 1 1 1 b� S _ 1 1 1 1 1 1 1 1 • _ • _ r _ • _ r _ r _ r _ • _ • _ lu r N 1 '0Der. Li* "i ICE I}E4T1I4 IlMiNIice! IS t -i 0 r • 1 1 F wttD reed Lhc ;-'IR4 1 1 1 b� S _ 1 1 1 1 1 1 1 1 • _ • _ r _ • _ r _ r _ r _ • _ • _ lu r N 1 '0Der. Li* "i ICE I}E4T1I4 IlMiNIice! IS t -i 0 r Existing Station Photos Fort Lupton Compressor Station (pre -landscaping) 16 . *ix Ny it f ` -d 1+11 FM .R K -s-- - - a- PL - sr T • .•n 4-. • Ste` RT. f e'. Fx 41 darie_-tar+ilialc - a alkor-" 1. P.-_ — Tea. a i. .t,_ ' weitor- y,. at Permitting USR vs. Environmental 20 Permitting • A County USR/CU permitting for facilities will always be the critical path due to public input, development and land use constraints, engineering lead time commitments, and constructability challenges regarding future growth. • The USR/CU permitting process requires that a proposal front load a development or project with every conceivable structure or piece of equipment on the initial application. • The CDPHE air permitting, while time consuming, offers several different options for permitting the same types of facilities. • Environmental permitting uses single point of contact for engineering, permit application changes and permit writing. There is also a well defined process that also provides a step-by-step structure and allowance for future permit modifications, if needed. • Air permitting is geared more towards immediate needs, and does not require that future uncommitted stand-alone projects be initially considered. 21 Proximity to RUA 22 i r ri F ft Vi . . t. Final BEGS sCte 1 6 elEt 2,000+atcres; 12 mrles of perimeter 'atte6 berg BreS site: • Fin F;S site 19 s,._`i 2 _miles of perimeter (41; 2018 Goo• Ie 1230A7'B9 12317407 '`0.2305210 '12336568 12309076 X103 `12308793 ►a.. 1230%794 ['n is SAL 123204 I 'l Jlil`a7.419 12308004 12311 . -32 8075 1230 41! 24 12310625 123091.84 123411.,7340. 123419,43 7.541 12307178 12301890 ti 1137P+ /2311305 12310198 -12307815 02309074 1230759J,_ t41 4779 12344776 '&12114273 273 12343'99'3 12322659 1233160 RU A in MANGE )12309197 /2342433 1-2342242 123 6934 12309084 1230781s I 12307772 772 12338031 123132:2 22(7728 1230 8800 1417229 12308799: '123 9138 /2307703 1-2307580 123088 12308;802 12309Q 1240:9135 .3/4, 1231 66211 a 123D79.58 - 12,300703 12320784 12310197 �2f 12309215 123210681 12331597 x147345 12T38234 `'to, C411: I 114-714: ti -l@ 12336233 38391 1233&3931232{9985 732 7 17:338341 ,�21 ;� 12338418-4330.417 12 33841 5'1 233841 8 10492` 12320103 1231'9959 1026 112 3203002 12320230 - 12305002 12322999 - • 123210/10 -12308928 0'321032:1 12319948 12310'126 12310488 _, 12319553 12320055 `12321528 12321027 1230715.2 12325942 123311018'1 12320896 12310490 12341121 12345385 23d0886A - 12310042 12320918 _ 1232091g g _ 1232Q84 12311440 wet G a: U nty Sc uth 12319892 12331121 12331 1115 • C Legend Well Spots (Statu ) D, [0 0 Drilling (DC) PTItl Injection CIa' I • [! C Producing (PR) Pio. [s C SIBut-In (SI) • al Temporarily Abandoned (TA) • C ,Plaiting on Completion (WO) C Approved Permit to Drill (XX) 12308041 `12'310491 123225* 12308266 1232/343 "°x12309161 12316268 '7-'12316155 12316155 12.346t64 12348079 1 'i 2310324 12322420 420 12310:350 12'31.44. 5 12_036442 I1231 44253 . '12315082'; a a 2; 12321412 12323748 123'i 6888 12308•00$ 2308793 12304 123099 6 12309957 *92308794 308087 07963 1230903$' f23 f6B 12341169 2 30879 1239874 Final BFCS site 1236 1232- 12308848 12308981 1 34194 c,12341940 12323794 1230717$ 1230921 123 307'917 12310199 12309089 12310907 '12307815 123894 2308797 ' 12307732 12308942 12337846 12337888 • 1233768112137677' C 2337678 12308799 2319038 12308800 12307689 12307703 '42311305 123101 98 12331923 12336931 `' 12310196 12Q9196 12309074 123,E 1231322 ;12309191 /2310125 23t81'19 12331611 71233'1609 i c y, "2 Ri l 12309215 1232g784 5 123'31597' 1233159 2335235 IS d�� '� ~' 12338232 12338234 35155 12330 912320985 1233831 12338393 12321066 12319946 12307152 ' 2'1 1232.1023 12338420 '12336419 `12332413 M2320230 12310113 12320692 912571 423475712342542 12342543 12321341 •1232O 1232102.8 12325942 123 12311440 12331/21 12331115 12319892 12309700 12308041. 12:x21344 '1231.0491 /2308200 Imagery Date: 5/31/2018 40001'14.59" N 104°53'1}.22" elev 5019 tt 12321343 322534 e•�e alt 2423 ft 27 Compression Driver Selection Natural Gas vs. Electric 28 Natural Gas vs. Electric • NG engines can be leased on an as -needed basis and require no substation or specialized energy delivery infrastructure. This allow for maximum flexibility within a gathering system compression fleet. � NG engine leases are structured to provide guaranteed uptime, which incentivize preventative maintenance. • No such uptime guarantees are available from electric supply companies, and no contracts are available that reimburse customers for loss of revenue from blackouts, rolling mandatory curtailments, or weather related interruptions. • Electric service of scale requires upfront lead times for a typical site that were not feasible considering desired in-service dates. This is why the addition of electric for future expansion was included for peak shaving. • We believe that businesses should be allowed to build, grow and expand based on its customer needs. � In our judgement, clean -burning natural gas driven compression is the best and first choice for providing our customers the services negotiated in our contracts. Recent project -based experience • To perform an engineering review of BFCS, the Power Company (PowCo) requires RMM supply approximately $100k � Such a review is expected to require at least 1-2 months to complete even a basic assessment of what would be needed. • Lead-time for PowCo work if a substation construction is involved are 9-15 months depending on complexity of the work on the PowCo site. � Typical PowCo substation cost approximations are $5MM for a new facility, and typically $3.0-$4.5MM for modification of an existing facility and would be borne solely by RMM. • Electrical transmission line costs ranges from $500K -$750K per mile, and these costs would be borne solely by RMM. Based on all the information presented, we believe we have shown that natural gas engine -driven compression can be and has been constructed to meet or exceed Weld County Development Standards and represents a balanced use of resources in the affected area. Good Morning Commissioners. Thank you again for an opportunity to contribute to the decision process that impacts family and neighbors. I will do not intend to repeat the February 11 material that you have in file, but only focus on two areas. First is to show the results of a somewhat, similar oil and gas set of facilities that evolved into something that ought to be avoided when considering new projects. The location is at CR4 and 19. It was established well over 30 years ago. It was a time when Denver, Boulder and Greeley seemed far away. Here are pictures of another Howard Farms Leased property. It is leased to Crestone, Rocky Mountain Midstream and possibly others. Let's take a quick look around. Photos of 2019-02-10 02-CR4-W-of-19-to-N On CR 4, West of CR 19 looking to the North. 03-CR4-W-of-19-to-N A little further East 04-CR4-W-of-19-to-N E A bit further East. This is an injection well. I think it has been there over 30 years. 06-CR4-W-of-19-to-N Still going East. An entrance from CR 4. 07-CR4-W-of-19-to-N A little more detail of the gear that is stored on site. 08-CR4-and-19-to-W This is the corner of CR 4 and 19, looking West down CR 4. No attempt to hide the equipment. 09-CR19-to-NW A bit further North on CR 19. 10-CR4-and-19-to-SW This is a look back to the SW at the corner of 4 and 19. Clearly an agriculture environment. 11-CR19-to-W 19 -to -W Headed North on 19. 12-CR 19 -to -N W A bit further North, seems to be a storage area for tanks. 1 14-CR19-to-W-Sign The Crestone Peak sign Note the County sign 15-C R 19 -to -W -U S R -Notice A bit more detail of the County sign That it could have been removed almost six months ago seems to communicate something of how much the applicants care about keeping the area up How much cost would be involved in removing this trash from the fence/ 16-CR19-to-E This is the view to the East of the signs Future RUA, current Agriculture There is a flock of geese in the center A bit further East (one mile) is the Brighton Sub -Station that United Power has said has capacity to serve the proposed Compressor Station If a new power cable is required, this is an engineer's dream assignment 17-CR19-to-SE Again at the site of the signs, this is the view to the SE The buildings are Xcel facilities Please note the fence, the substantial buffer, the buildings are plain, but not heavily industrial There is a perimeter of boulders along the fence line to slow down anyone who might try to drive through the fence 18-CR19-to-NW Again back by the signs, but looking to the Northwest 19-CR19-to-W This is from the same site, but to the West Lots of open ground for the RUA Clearly Industrial, No Buffers exist, little space set aside or left for Buffer construction Hard to see how this meets the intent of an agricultural zoned area The Elevation Midstream Central Gathering Facility proposed design harmonizes with the area's existing buildings Hard to see how this site can be compatible with the goals that were set up in establishing the Equinox/Todd Creek Metropolitan District RUA While this site has evolved into the conditions of the photos, it would be most unfortunate to have another location that is so close, take the same direction The proposed CS should have adequate screening, the buildings should look more like horse barns and grain bins than industrial operations If this USR is approved, it should establish significant buffer space with adequately designed structures and plantings to avoid this sort of result 2 Second, I wish to touch on material sent to the file since the last meeting that reinforces how Colorado is determined to continue moving toward renewable power • Tri-State provides a significant proportion (1/3) of renewable energy and continues to build and access renewable power sources • Both Xcel and the State of Colorado have goals to be Carbon free by 2050 • United Power plans to increase its use of renewable power Why is this going on'? - Moving to renewable power reduces the energy sector's impact on public health and the environment It also increases the resiliency of the electrical grid A quick look at Item two reinforces how NOx and VOCs are essential to generating Ozone It makes sense to minimize emissions for improved public health Item two (yes, it is from the earlier presentation) shows the huge difference in CO2 and ozone generating emissions when comparing electric and motor driven compressors Please think about the how the initial build of three motor driven compressors can produce almost 11 times the full build out of 19 electric compressors The motor driven compressors are not part of the pollution solution here they are part of the problem The natural gas product will be a solution to energy needs in many places, but it is not needed or helpful powering compressors here Things can sometimes be minimized But 38 4 tons per year of NOx is a lot, 20 8 tons of CO is a lot I think about our local, Ft Lupton sourced, athlete Brian Shaw, multiple winner of "World's Strongest Man" titles His personal best lift is recorded as 1017 pounds, just a bit over a half ton Sure, the emissions get dispersed and diluted, but it is still a lot of mass being produced as opposed to next to nothing Thank you for your time and attention wrw 2019-02-25 3 w ' illtalr CRESTONE PEAK RESOURCES 8885 Weld County Road Brighton, CO 80603 In case of Emergenry. Contact 911 This facility is under Remote Video Surveillance ,s' t ublic hearings concerning this property C►punt. Planning Commission and Board of County Commissioners. Both hearings will be held at: WELD COUNTY ADMINISTRATION BUILDIN 1150 "0" Street • Greeley, CO80631 Planning Commission Hearing will be held on Request A Site Specific DH► .rc me SRew�ler,err' ns Plan '� � �c r�ti;n4 r e r it or'Ifleral Facilities including Oil urce 'gal �� end ��`-' '� � � - suppo air Service including ti r1� � --`- �� c n and related equipment) '�� cif c �5 _�p�,rent ,nstr.:40401 of >' a7'Mructionoffice trailers facility in the A {Agricultural) Zone during the Case Number. itootirk31 Acres: r 0R FuRTHR INFORMATION PLEASE HE WELD MANNING 0-351-€100, ext ❑fi,�, G1� SAT T E COUNT DEPARTMENTT qtr . aa eime mar -� _wars L an - --a J r 4 • 1. • 9 -a - -a — a i apf Ifirgi els i'I+ji s WAY �� - zor -ImMama am - r s a a -i Lint a -mot• : — 9iafic+ 1 Selena Baltierra From: Sent: To: Cc: Subject: Norton, Matt <Matthew.Norton@williams.com> Thursday, March 7, 2019 8:50 AM Esther Gesick; Selena Baltierra; Jessica Reid Chris Gathman RE: BroomfieldCS Caution: This email originated from outside of Weld County Government. Do not click links or open attachments unless you recognize the sender and know the content is safe. With that April date being so far out there, I'll just plan to go ahead and present what I have so far in response to our actions for the issues raised at the last hearing and the commissioners can decide at that time if they need more information or if more time is needed. Thx, mn 817-455-5799 From: Esther Gesick <egesick@weldgov.com> Sent: Wednesday, March 6, 2019 3:17 PM To: Norton, Matt <Matthew.Norton@williams.com>; Selena Baltierra <sbaltierra@weldgov.com>; Jessica Reid <jreid@weldgov.com> Cc: Chris Gathman <cgathman@weldgov.com>; Esther Gesick <egesick@weldgov.com> Subject: [EXTERNAL] RE: BroomfieldCS Hello Matt, Thanks for the heads up. I just spoke with Chris Gathman and reviewed the Commissioners' schedule. The earliest, available date with all five present would be Monday, April 8th. You will need to be present to make the request, and it will be at the Board's discretion as to whether they proceed or grant your request. 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 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: Norton, Matt <Matthew.Norton@williams.com> Sent: Wednesday, March 6, 2019 2:34 PM To: Esther Gesick <egesick@weldgov.com>; Selena Baltierra <sbaltierra@weldgov.com>; Jessica Reid <;reid @oweldgov.com> Cc: Chris Gathman <cgathman@weldgov.com> Subject: RE: BroomfieldCS 1 Caution This email originated from outside of Weld County Government Do not click links or open,attachrnents unless you recognize'the °- ; r, sender and know the content is safe , _ - - L _ =s a � s - All We will not yet be prepared to present by Monday 3/11 Is it possible to reschedule this for the week of 3/18 or do we need to be there to formally request a continuance? Our preference is for all five commissioners to be in attendance Thx, inn 817-455-5799 From: Esther Gesick <egesick@weldgov corn> Sent: Wednesday, February 27, 2019 12 53 PM To: Selena Baltierra <sbaltierra@weldgov corn>, Jessica Reid <Ireid@weldgov corn> Cc: Norton, Matt <Matthew Norton@williams corn>, Chris Gathman <cgathman@weldgov corn> Subject: [EXTERNAL] RE BroomfieldCS Please incorporate in the file as an Exhibit 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 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: Norton, Matt <Matthew Norton@williams corn> Sent: Tuesday, February 26, 2019 4 59 PM To: Chris Gathman <cgathman@weldgov corn> Cc: Esther Gesick <egesick@weldgov corn> Subject: BroomfieldCS Caution This email originated from outside of Weld County Government Do not click links or open attachments unless you,recognize the ti i'' sender and know the content is safe , ` -� Chris I found out today that are unable to acquire enough land to use as a guaranteed buffer around the ten acre BFCS site The JV partnership has been made aware of the additional conditions for approval and we have meetings with the primary producer in the corning days I hope to know by next Friday if we will be moving forward with the USR process or going another route Thanks for all your help in this process Matt (817) 455-5799 This email originates outside of Williams Use caution if this message contains attachments, links or requests for information 2 This email originates outside of Williams Use caution if this message contains attachments, links or requests for information 3 Rocky Mounta n Midstream I Broomf eld Compressor I Station USRI 8-0106 Weld County Board of County Commissioner Hearing Original hearing date January 9, 2019 March 11, 2019 9:00 am I Landscaping Addition Detail (NW site quadrant view shed) I r` t I S _ Its r■,1" • PROPOSED DISCOVERY al S ilICE8LW FACILITY LIE • tit I N _ 1 NW Corner Landscaping Original a 4 Y • FLIPitatt rocs war 44 clip - Sit;9i1LY: LLK 1 1 1 III 11 u 1 1 1 1 L .f NW Corner Landscaping Updated — I: - 'Future Substation n MI IS SI -At • ti t ari (U) Ncig l I I i • ct scSict etaia we ink Mrthtal Litt ;►*K; • 1 1 I _ • 1 1 1 1 • Color Scheme Example Photos (from local Ag/Farm Examples) : - � 'rai\ _a,„.:_ stite;1111 rea Land Buffering 13 wet G a: U nty Sc uth 12317407 ='123082n '12336568 12309476 /2303769 °003 12308793 3955 1:230g704 .cop ,33 123204 12'33 915 _' 12 307383 • 12308.274 -12309673 , 1230 94 12306302 12308795 12308)-95 1230871f_ [12308067 1 r 5_' alit; 23D 1231062 1230€114 12308004 /2308560 _12308015 • 12837864 12333 1230706 12306981 - 17341168 123 11 3' 12320024 1232'1..7.Q...3 1: /2309829 12308848 12323194► j 12307890 31i 29 12310200 223 :12 1 12310199 el 1230921 `' !• 1t2336792 12338787 12336797 12307917 12309089 1231 0907 N 12307615 123113 12310198 1233 09 1233d933 33 '12309196 12307591 '12321360 02 T 9 '123434 12313 12322659 10131604 RU In MANGE tia KaarAct _12300074 12309197 12342433 1i-2342242 12308930 12309083 '12347 72 1230 781 1233.0 3O 92313220 3 23088011 12 789. 1 '42698123089542 123; 873 ::1233.7677 12308799 1231 9038 12307703 12307689 /2306801 7729 12308802 123047' 12320784 12310197 :12307345 38391 101 1233839312320986 12338341 ,, 3210 .23 2 a 1384161 36. 17 12320103 12309038 -P33 E 3,1 123384151233841a 7,-2 38351 123-10492 4' /2309215 12321066 /2331597 12:738234 12338233 1a.30778.1 u77b7 1230.9135 12316621 • 12'!17958 •1220 1703 "1230 E850 12321028 12320362 12320230 1.2320907 12308002 999 2321010 12320324 2018 Coogl: 123104'1 12341t211 12308864 12310042 12:45385 12320918 /2320919 12 320894 1231.59 2 12309611 • C Legend Well Spots (Statlu ) D• k Drilling (DC) " C Injection CIa' I • [! C Producing (PR) Pio. [s C Shut- I n (SI) • al Temporarily Abandoned (TA) It 15T C Waiting on Completion (WO) Rvi CI Approved Permit to Drill (XX) 12320691 'I 2309161 /2316268 12320737 12309404 3'102fi 12309613 12310905 1.2321533 12310488 123210 12 30715.2 1232594 0692 12310113 12342572 123442543„ 12310112 12318155 12348079 12346164 12309700 12309622 12308041 Rocky Mountain Midstream is unable to buy additional land surrounding the Broomfield Station that can be used as a buffer. The mineral rights for the entire remaining parcel are owned by . producer with plans to develop further. Existing remaining Ag land is sandwiched between existing horizontal well pads. RMM will commit to supporting requirements that future development meet the visual mitigation standards that we and our nei.hbors desire. 16 Noise Surveys and Models 17 Mustang vs. Broomfield Ambient dBA Levels Table 1 Average Daytime and Nighttime Ambient Noise Levels Discovery Midstre am - Mustang Compressor Station Location 1 Location 2 Location 3 Average Ambient Average Nighttime Am ie nt Noise e Levels Average Nighttime Ambient ime Noise Average Daytime Ambient nt Noise Levels Average age Nighttime AmbientNoise Daytime Noise Average Daytime A mbie ntN V' is a Levels Levels Levels Levels a MA dB A A A dBA . 46.0 48.4 55.7 50.7 48.2 43.4 Table 1 Rocky Mountain Midstream - Broomfield Compressor Station Location 1 Location 2 Location 3 Location 4 Location 5 Average Daytime Average Nighttime Ambient Noise Average Daytime Average Nighttime Ambient Noise Average Daytime Ave rage Nighttime Average Nighttime Average Daytime Ambient Noise Levels Average Nighttime Ambient Noise A`°e n ge Daytime Ambient Noise Ambient Noise Ambient Noise Ambient Noise Ambient Noise Levels Ambient Noise Levels Levels Levels Levels Levels Levels Levels dBA (FBA ■■rr dBA dBA dBA dBA (■fMA Levels dBA dBA 39.7 39.7t 37.3 r. ar • r 34.7 Mustang Station dBA Contribution Findings Table 4-3 Modeled Scenarios Modeled Sceiiario eseription Scenario 1 Baseline —Compressor skids are modeled with .specified MAX I , engine exhaust' silencers; compressor skids are enclosed in acoustical buildings with IC -42 rated walls, an STC-47 rated STC_25 r rated r 11 -up doors and 4 -inch acoustical louvers: additionally.. Flarsco 180-2.Z coolers and an FMC Ml 2. condensate pump are modeled, scenario 2 Mitigated Compressor skids are. modeled with modified. MAXIM engine exhaust silencers with a minimum .rtio loss pper Table 4-2; acoustical buildings are modeled witli S -inch acoustical louvers, will a minimum insertion loss pper fable. 4 - the F IC --I\ 112 condensate pum is surrounded with a 12.- foot -high permanent sound wall rated SIC -40. Behrens and Assoclatcs, Inc. Environmental Noise control The noise modeling results for Scenario 2 indicate that the a proposed operations of the Mustang Compressor Station are predicted to comply with the allowable noise limits of the Weld County, CO noise standar& at all modeled receptor locations with implementation of the proposedspecified exhaust silencers, acoustical louvers d acoustical sound bier_ 19 Broomfield Station dBA contribution findings are expected to be issued in the coming days. Like the identical Mustang Station, where the background ambient dBA levels are higher, we expect the Broomfield CS mitigated sound levels to be in compliance with the our filed Facility Noise Mitigation Plan, and the Weld County Standards. These findings from our consultant will be filed with the existing USR paperwork as soon as available, and before construction begins. Mustang Compressor Station Noise Modeling Report Antonio King Staff Acoustical Engineer September 11, 2018 Prepared for: Discovery Midstream Partners 1782 Platte Street Denver, CO 80202 Prepared by: Behrens and Associates, Inc. 13806 Inglewood Avenue Hawthorne California, 90250 Jason Peetz Engineering Manager Corporate Office: l la«thorne. Cal i lurn is Carson. California Alecto. Texas - Napa Califbrnia Longmont. Colorado - McDonald. Pennsylvania 800-679-8633 ��'% \1 .env ironniental-noise-control .cuiii \\ \\ .dri I Inignoisecontrol.coni Behrens and Associates, Inc. Environmental Noise Control 1. Introduction The following report provides a noise modeling assessment of the proposed equipment at the Mustang Compressor Station operated by Discovery Midstream Partners in relation to the Weld County, Colorado noise regulations. The Mustang Compressor Station (40° 14'41.25" , 104°96'21.57"W) is located 0.18 miles east of Weld County Road 49, approximately 10 miles south of Kersey, Colorado. Single-family residentials are located northeast and south of the site. Figure 1-1 identifies the pad location. To assess the predicted noise levels of the proposed compressor station. manufacturer sound level performance data of equipment, exhaust silencers, and acoustical buildings was used. The noise model was developed using SoundPLAN 8.0 software. The following is provided in this report: • A brief introduction of the fundamentals of noise. • A review of the applicable Weld County noise standards. A discussion of the noise modeling methodology and results. Figure 1-1 Proposed Mustang Compressor Station Location Introduction 7 Behrens and Associates, Inc. Environmental Noise Control 2. Noise Fundamentals Sound is most commonly experienced by people as pressure waves passing through air. These rapid fluctuations in air pressure are processed by the human auditory system to produce the sensation of sound. The rate at which sound pressure changes occur is called the frequency. Frequency is usually measured as the number of oscillations per second or Hertz (Hz). Frequencies that can be heard by a healthy human ear range from approximately 20 Hz to 20,000 Hz. Toward the lower end oft. 's range are low-pitched sounds, including those that might be described as a "rumble" or "boom". At the higher end of the range arc high-pitched sounds that might be described as a "screech" or "hiss". Environmental noise generally derives, in part, from a combination of distantnoise sources. Such sources may include common experiences such as distant traffic, wind in trees, and distant industrial or farming activities. These distant sources create a low-level "background noise" in which no particular individual source is identifiable. Background noise is often relatively constant from moment to moment, but varies slowly from hour to hour as natural forces change or as human activity follows its daily cycle. Superimposed on this low-level, slowly varying background noise is a succession of identifiable noisy events of relatively brief duration. These events may include the passing of single -vehicles, aircraft flyovers, screeching of brakes, and other short-term events. The presence of these short-term events causes the noise level to fluctuate. Typical indoor and outdoor A -weighted sound levels are shown in Figure 2-1. Detailed acoustical definitions have been provided in Appendix A — Glossary of Acoustical Terms. COMMON OUTDOOR NOISE LEVEL COMMON INDOOR SOUND LEVELS dB (A) SOUND LEVELS 6-747-200 Takeoff at 2 mi. Gas Lawn Mower at 3 t. Diesel Truck at 150 ft. DC -9-3i0 Takeoff at 2 mi. Noisy Urban Daytime B-757 Takeoff at 2 mi. Commercial Area Quiet Urban Daytime Quiet Urban Nighttime Quiet Suburban Nighttime Quiet Rural Nighttime !may 1 I )).. I a Ici - 1'10 Rock Band r 100 Inside Subway Train (New York) Food Blender at 3 ft_ BO 70 60 at 3 H. 50 40 30 20 10 Garbage Disposal at 3 ft. Shouting at 3 ft. Vacuum Gleaner at10 O ft. Normal Speech Large Business Office Dishwasher Next Room Small Theatre, Large Conference Room (Background) Library Bedroom at Night Concert Hail (Daokgrour c0 Broadcast & Recording Studio Threshold of Hearing Figure 2-1 Typical Indoor and Outdoor A -Weighted Sound Levels Noise Fundamentals 8 Behrens and Associates, Inc. Environmental NoiseControl 3. Weld County Noise Standards The modeling analysis was developed to predict operational noise levels at adjacent properties and verify compliance of operations with the Weld County noise standards. The Weld County code establishes permissible sound levels by type of property and hours of the day. The measurement location is defined in Section 14-9-50-A.2. "A noise originating on private property shall be measured at or within the boundary of the property from which the noise complaint is made". Based on the language in the Weld County code, the Residential noise level limits listed in Table 3-1 will be used throughout the report. Table 3-1. Home Rule Charter for the County of Weld, Colorado, Chapter 14, Article I — Noise, Section 14-9-40 — Maximum Permissible Noise Levels Land Use Maximum 7:00 Noise am to next NBA) 9:00 pm Maximum Noise (dBAi 7:00 am 9:00 pm to next Residential or Commercial 55 dBA 50 dBA Industrial Area or Construction 60 dBA 55 dBA Nonspecific Areas 70 dBA 65 dBA Weld County Noise Standards Behrens and Associates, Inc. Environmental Noise Control 4. Mustang Compressor Station Noise Modeling 4.1 Noise Modeling Methodology The noise modeling was completed with use of three-dimensional computer noise modeling software. All models in this report were developed with SoundPLAN 8,0 software using the ISO 9613-2 standard, Noise levels are predicted based on the locations, noise levels and frequency spectra of the noise sources, and the geometry and reflective properties of the local terrain, buildings and barriers. The predicted noise levels represent only the contribution of the proposed compressor station operations and do not include ambient noise or noise from other facilities. Actual field sound level measurements may vary from the modeled noise levels due to other noise sources such as traffic, other facilities, other human activity, or environmental factors. The equipment sound level data used in the Mustang Compressor Station modeling was sourced from equipment manufacturer data per approved project design documentation. The modeling results predicted are dependent on equipment and mitigation orientation as indicated per provided project documentation. Table 4-1 lists the sound power levels of the modeled equipment. Table 4-4 shows the transmission loss data for the elements of the acoustical enclosure surrounding the compressors, Table 4-1 Equipment Modeled for Mustang Compressor Station Quantity Equipment Manufacturer/Model Source Sound Power Level (dBA) 8 8 Compressor Engine 3608 Compressor Exhaust with Maxim Silencer 16 3608 Cooler Exhaust 16 1 3608 Cooler Intake 3608 Cooler Side Condensate Pump CAT 3608 MCCOF4-4-2018 -C 3 - 4726 HARSCO 180-2Z HARSCO 180-2Z HARSCO 180-2Z FMCMl2 125.4 113.7 99.4 96,8 92.4 108.7 Mustang Compressor Station Noise Modeling 10 Behrens and Associates, Inc. Environmental Noise Control Table 4-2 Acoustical Performance Data Transmission/insertion Loss (dB) Equipment Description Octave Band Center Frequency (Hz) 63 125 250 500 1k 2k 4k 8k Roll -up Door (STC 25) 10.0 14.0 16.0 20.0 25.0 29.0 23.0 20.0 4 -inch Acoustical Louver 4.0 7.0 6.0 9.0 13.0 14.0 14.0 12.0 8 -inch Acoustical Louver - 7.0 7.0 13.0 20.0 22.0 17.0 Building Wall (STC 42) 10.8 18.5 33.0 42.1 49.1 54.2 53.7 Building Roof Assembly (STC 47) 15.4 31.4 39.6 45.8 44.0 50.1 59.5 Permanent Sound Wall (STC-40) 24.0 19.0 32.0 38.0 44.0 45.0 49.0 Maxim Silencer 44726 31.0 39.0 43.0 40.0 33.0 31.0 32.0 31.0 Modified Silencer 44.0 52.0 56.0 53.0 46.0 44.0 45.0 44.0 4.2 Noise Sensitive Receptors The noise sensitive receptors have been chosen to be consistent with the requirements of the Weld County, Colorado noise standards. The requirements indicate that a noise originating on private property shall be measured at or within the boundary of the property from which the noise complaint is made. As such, receptor locations were chosen at the surrounding property lines of the Mustang Compressor Station to represent potential regulatory measurement points should a complaint be made. Figure 4-1 shows the A -weighted noise sensitive receptor locations. Mustang Compressor Station Noise Modeling Behrens and Associates, Inc. Environmental Noise Control Figure 4-1 Noise Sensitive Receptor Locations (dBA) Mustang Compressor Station Noise Modeling Behrens and Associates, Inc. Environmental Noise Control 4.3 Noise Modeling Results Two modeling scenarios were created to investigate various options at the proposed site and are described in Table 4-3. The results of the noise modeling are presented in Table 4-4. The locations in the tables correspond to the receptor locations identified in Figure 4-1. The results of the noise modeling are also shown as noise contour maps. Figure 4- 3 shows the Scenario 1 Noise Contour Map in dBA and Figure 4-4 shows the Scenario 2 Noise Contour Map in dBA. The noise contours are provided in 5 dB increments with the color scale indicating the sound level of each contour. The proposed Mustang Compressor Station layout is shown in Figure 4-2. Table 4-3 Modeled Scenarios Modeled Scenario Description Scenario 1 Baseline — Compressor skids are modeled with specified MAXIM engine exhaust silencers; compressor skids are enclosed in acoustical buildings with STC-42 rated walls, an STC-47 rated roof, STC-25 rated roll -up doors and 4 -inch acoustical louvers; additionally, Harsco 180-2Z coolers and an FMC M12 condensate pump are modeled. Scenario 2 Mitigated — Compressor skids are modeled with modified MAXIM engine exhaust silencers with a minimum insertion loss per Table 4-2 acoustical buildings are modeled with 8 -inch acoustical louvers with a minimum insertion loss per Table 4-2; the FMC -M12 condensate pump is surrounded with a 12- foot -high permanent sound wall rated STC-40. Table 4-4 Noise Modeling Results (dBA) Location Description Scenario 1 Scenario 2 Receptor 1 Receptor 2 Receptor 3 Receptor 4 Receptor 5 Receptor 6 North property line of Parcel 121312100004 54.2 49.8 Northeast property line near 24133 County Road 36 48.7 45.6 East property line of Parcel 121312100004 55.7 49.7 South property line near 23900 County Road 34 1/2 48.1 44.9 South property line near 23790 County Road 34 1/2 49.2 46.1 South property line near 23650 County Road 34 1/2 49.0 46.1 Allowable Noise Level At or within the boundary of the property from which the noise complaint is made. 55.0 Day / 50.0 Night The noise modeling results for Scenario 1 indicate that the proposed operations of the Mustang Compressor Station are predicted to exceed the allowable noise limits of the Weld County, CO noise standards at Receptors 1 and 3. The predicted noise levels at Receptors 1 and 3 exceed the Weld County noise limits by up to 5.7 dBA. Mustang Compressor Station Noise Modeling 13 Behrens and Associates, Inc. Environmental Noise Control The noise modeling results for Scenario 2 indicate that the proposed operations of the Mustang Compressor Station are predicted to comply with the allowable noise limits of the Weld County, CO noise standards at all modeled receptor locations with implementation of the proposed specified exhaust silencers, acoustical louvers and acoustical sound barrier. Mustang Compressor Station Noise Modeling 14 Behrens and Associates, Inc. Environmental Noise Control Figure 4-2 Proposed Mustang Compressor Station Layout FMC M12 Condensate Pump CAT 3608 Engine wi Maxim Silencer Harsco 180-2Z Cooler• Acoustical Building Mustang Compressor Station Noise Modeling 15 Behrens and Associates, Inc. Environmental Noise Control Figure 4-4 Scenario 2 Noise Contour Map (dBA) Average Noise Level, Leg dBA 0 _ 30.0 35.0 40.0 45.0 50.0 55.0 0.0 65.0 70.0 75.0 0.0 85.0 90.0 400 $0i feet Mustang Compressor Station Noise Modeling Behrens and Associates, Inc. Environmental Noise Control 5. Conclusion Predictive noise models were created to represent the proposed operations at the Mustang Compressor Station operated by Discovery Midstream Partners. Manufacturer sound level performance data of equipment, exhaust silencers, and acoustical buildings was used in the models to asses to noise impact. Noise sensitive receptor locations included in the modeling were placed in accordance with the applicable noise standards of Weld County, Colorado. Based on the modeling results of the Mustang Compressor Station, our analysis indicates that the baseline predicted noise levels will exceed the allowable nighttime noise limit of 50 dBA at multiple receptor locations by as much as 5.7 dBA, with implementation of the recommended mitigation measures outlined in Table 4.3, all modeled receptor locations are predicted to comply with the Weld County maximum permissible daytime and nighttime (IBA limits. Conclusion 18 Behrens and Associates, Inc. Environmental Noise Control Appendix A - Glossary of Acoustical Terms Glossary of Acoustical Terms 19 Behrens and Associates, Inc. Environmental Noise Control Ambient Noise The all -encompassing noise associated with a given environment at a specified time, usually a composite of sound from many sources both near and far. Average Sound Level See Equivalent -Continuous Sound Level A -Weighted Decibel Scale The human ear is more sensitive to some sound frequencies than others. It is therefore common practice to apply a filter to measured sound levels to approximate the frequency sensitivity of the human ear. One such filter is called the A -weighted decibel scale which emphasizes sounds between 1,000 and 5,000 Hertz by discounting the frequencies outside of this range. As the human ear is less sensitive to low frequency noise, the A -weighted decibel scale begins to increasingly discount noise below 500 Mertz. Measurements conducted utilizing the A -weighted decibel scale are denoted with an "(A)" or "A" after the decibel abbreviation (dB(A) or dBA). The A -weighted scale is nearly universally used when assessing noise impact on humans. C -Weighted Decibel Scale High level low frequency noise can propagate large distances from its source. Although not always audible, high levels of low frequency noise can induce vibrations in objects or structures which could become evident in ways that might be annoying to humans (e.g., rattling of windows). The -weighted decibel scale, which was developed to estimate human ear sensitivity to high noise levels, is a flatter filter that does not discount low frequency noise as much as the A -weighted decibel scale. As a result, a C -weighted decibel measurement could be significantly higher than an A -weighted decibel measurement if the noise being measured contains a heavy low frequency content. Measurements conducted utilizing the C -weighted decibel scale are denoted with an "(C)" or "C" after the decibel abbreviation (dB(C) or dBC). C -weighted noise level limits are sometimes included in noise regulations as a way to address low frequency environmental noise issues. Community Noise Equivalent Level (CNEL) A 24 -hour A -weighted average sound level which takes into account the fact that a given level of noise may be more or less tolerable depending on when it occurs. The CNEL measure of noise exposure weights average hourly noise levels by 5 dB for the evening hours (between 7:00 pm and 10:00 pin), and 10 dB between 10:00 pm and 7:00 am, then combines the results with the daytime levels to produce the final CNEL value.. It is measured in decibels, dbs. Day -Night Average Sound Level (Ldn) A measure of noise exposure level that is similar to CNEL except that there is no weighting applied to the evening hours of 7:00 pm to 10:00 pm. It is measured in decibels, dB. Glossary of Acoustical Terms Behrens and Associates, Inc. Environmental Noise Control Daytime Average Sound Level The time -averaged A -weighted sound level measured between the hours of 7:00 am to 7:00 pm. It is measured in decibels, dB. Decay Rate The time taken for the sound pressure level at a given frequency to decrease in a room. It is measured in decibels per second, dB1s. Decibel (dB) The basic unit of measurement for sound level. Direct Sound Sound that reaches a given location in a direct line from the source without any reflections. Divergence The spreading of sound waves from a source in a free field, resulting in a reduction in sound pressure level with increasing distance from the source. Energy Basis This refers to the procedure of summing or averaging sound pressure levels on the basis of their squared pressures. This method involves the conversion of decibels to pressures, then performing the necessary arithmeticcalculations, and finally changing the pressure back to decibels. Equivalent -Continuous Sound Level (Leq) The average sound level measured over a specified time period. It is a single -number measure of time - varying noise over a specified time period. It is the level of a steady sound that, in a stated time period and at a stated location, has the same A -Weighted sound energy as the time -varying sound. For example, a person who experiences an Leq of 60 dB(A) for a period of 10 minutes standing next to a busy street is exposed to the same amount of sound energy as if he had experienced a constant noise level of 60 dB(A) for 10 minutes rather than the time -varying traffic noise level. It is measured in decibels, dB. Fast Response A setting on the sound level meter that determines how sound levels are averaged over time. A fast sound level is always more strongly influenced by recentsounds, and less influenced by sounds occurring in the distant past, than the corresponding slow sound level. For the same non -steady sound, the maximum fast sound level is generally greater than the corresponding maximum slow sound level. Fast response is typically used to measure impact sound levels. Field Impact Insulation Class (FIIC) A single number rating similar to the impact insulation class except that the impact sound pressure levels are measured in the field. Glossary of Acoustical Terms Behrens and Associates, Inc. Environmental Noise Control Field Sound Transmission Class (FSTC) A single number rating similar to sound transmission class except that the transmission loss values used to derive this class are measured in the field. Flanking Sound Transmission The transmission of sound from a room in which a source is located to an adjacent receiving room by paths other than through the common partition. Also, the diffraction of noise around the ends of a barrier. Frequency The number of oscillations per second of a sound wave Hourly Average Sound Level (HNL) The equivalent -continuous sound level, Leq, over a 1 -hour period. Impact Insulation Class (TIC] A single number rating used to compare the effectiveness of floor/ceiling assemblies in providing reduction of impact -generated sound such as the sound of a person's walking across the upstairs floor. Imp act Noise The noise that results when two objects collide. Impulse Noise Noise of a transient nature due to the sudden impulse of pressure like that created by a gunshot or balloon bursting. Insertion Loss The decrease in sound power level measured at the location of the receiver when an element (e.g., a noise barrier) is inserted in the transmission path between the sound source and the receiver. Inverse Square Law A rule by which the sound intensity varies inversely with the square of the distance from the source. This results in a 6dB decrease in sound pressure level for each doubling of distance from the source. Ln Percentile Sound Level The noise level exceeded for n% of the measurement period where n is between 0.01% and 99.99%. Usually includes a descriptor i.e. A -weighting. Common Ln values include LA10, LA50, and LA90 levels. LA10 would represent the A -weighted sound level that is exceeded for 10% of the measurement period. Masking The process by which the threshold of hearing for one sound is raised by the presence of another sound. Maximum Sound Level (Lmax) The greatest sound level measured on a sound level meter during a designated time interval or event.. Glossary of Acoustical Terms Behrens and Associates, Inc. Environmental Noise Control NC Curves (Noise Criterion Curves) A system for rating the noisiness of an occupied indoor space. An actual octave -band spectrum is compared with a set of standard NC curves to determine the NC level of the space. Noise Isolation Class (NIC) A single number rating derived from the measured values of noise reduction between two enclosed spaces that are connected by one or more partitions. Unlike STC or NNIC, this rating is not adjusted or normalized to a measured or standard reverberation time. Noise Reduction The difference in sound pressure level between any two points. Noise Reduction Coefficient (NRC) A single number rating of the sound absorption properties of a material. It is the average of the sound absorption coefficients at 250, 500, 1000, and 2000 Hz, rounded to the nearest multiple of 0.05. Normalized Noise Isolation Class (NNIC) A single number rating similar to the noise isolation class except that the measured noise reduction values are normalized to a reverberation time of 0.5 seconds. Octave The frequency interval between two sounds whose frequency ratio is 2. For example, the frequency interval between 500 Hz and 1,000 Hz is one octave. Octave -Band Sound Level For an octave frequency band, the sound pressure level of the sound contained within that band. One -Third Octave The frequency interval between two sounds whose frequency ratio is 2"(1/3). For example, the frequency interval between 200 Hz and 250 Hz is one-third octave. One -Third -Octave -Band Sound Level For a one -third -octave frequency band, the sound pressure level of the sound contained within that band. Outdoor -Indoor Transmission Class (OITC) A single number rating used to compare the sound insulation properties of building facade elements. This rating is designed to correlate with subjective impressions of the ability of facade elements to reduce the overall loudness of ground and air transportation noise. Peak Sound Level (Lpk) The maximum instantaneous sound level during a stated time period or event. Pink Noise Noise that has approximatelyequal intensifies at each octave or one -third -octave band. Glossary of Acoustical Terms 23 Behrens and Associates, Inc. Environmental Noise Control Point Source A source that radiates sound as if from a single point. RC Curves(Room Criterion Curves) A system for rating the noisiness of an occupied indoor space. An actual octave -band spectrum is compared with a set of standard RC curves to determine the RC level of the space. Real -Time Analyzer (RTA) An instrument for the determination of a sound spectrum. Receiver A person (or persons) or equipment which is affected by noise. Reflected Sound Sound that persists in an enclosed space as a result of repeated reflections or scattering. It does not include sound that travels directly from the source without reflections. Reverberation The persistence of a sound in an enclosed or partially enclosed space after the source of the sound has stopped, due to the repeated reflection of the sound waves. Room Absorption The total absorption within a room due to all objects, surfaces and air absorption within the room. It is measured in Sabins or metric Sabins. Slow Response A setting on the sound level meter that determines how measured sound levels are averaged over time. A slow sound level is more influenced by sounds occurring in the distant past that the corresponding fast sound level. Sound A physical disturbance in a medium (e.g., air) that is capable of being detected by the human ear. Sound Absorption Coefficient A measure of the sound -absorptive property of a material. Sound Insulation The capacity of a structure or element to prevent sound from reaching a receiver room either by absorption or reflection, Sound Level Meter (SLM) An instrument used for the measurement of sound level, with a standard frequency -weighting and standard exponentially weighted time averaging. Glossary of Acoustical Terms Behrens and Associates, Inc. Environmental Noise Control Sound Power Level A physical measure of the amount of power a sound source radiates into the surrounding air. It is measured in decibels. Sound Pressure Level A physical measure of the magnitude of a sound. It is related to the sound's energy. The terms sound pressure level and sound level are often used interchangeably. Sound Transmission Class (ST) A single number rating used to compare the sound insulation properties of walls, floors, ceilings, windows, or doors. This rating is designed to correlate with subjective impressions of the ability of building elements to reduce the overall loudness of speech, radio, television, and similar noise sources in offices and buildings. Source Room A room that contains a noise source or sources Spectrum The spectrum of a sound wave is a description of its resolution into components, each of different frequency and usually different amplitude. Tapping Machine A device used in rating different floor constructions against impacts. It produces a series of impacts on the floor under test, 10 times per second. Tone A sound with a distinct pitch Transmission Loss (TL) A property of a material or structure describing its ability to reduce the transmission of sound at a particular frequency from one space to another. The higher the TL value the more effective the material or structure is in reducing sound between two spaces. It is measured in decibels. White Noise Noise that has approximately equal intensities at all frequencies. Windscreen A porous covering for a microphone, designed to reduce the noise generated by the passage of wind over the microphone. Glossary of Acoustical Terms 25 Behrens and Associates, Inc. Environmental Noise Control June 28, 2018 Discovery Midstream Partners 7859 Walnut Hill Lane, Suite 335 Dallas, TX 75320 Attention: Lito White Subject: Ambient Sound Level Report Re: Mustang Compressor Station Dear Mr. White: Per your request, an ambient sound level survey was performed near the proposed Mustang Compressor Station in La Salle, Colorado from Friday, June 15 to Monday, June 18, 2018 to measure and document the ambient sound levels near the site. The following report documents our findings. Ambient Sound Level Survey An ambient sound level survey, including A -weighted dB(A) sound level data, was performed for the proposed Mustang Compressor Station to measure and document ambient sound levels for hourly, 15 minute and daily averages. Per Weld County Code Ordinance 2008-4, Sec. 14-9- 50 Measurements with sound level meters shall be made when a wind velocity at the time and place of such measurement is not more than five (5) miles per hour, or more than twenty-five (25) miles per hour with a windscreen properly attached to the microphone. Sound Measurement and Modeling Instrumentation The instrumentation used for the monitoring locations were Svantek model 971 integrating and. logging sound level meters with windscreens, which were calibrated prior to deployment. The metering systems were deployed in accordance with the standard Weld County Code Ordinance 2008-4, Sec. 14-9-50, and in a locked box for security. The measured noise levels are presented graphically in Attachments 2 through 7 and in tabulated form in Attachments 8 through 13. The ambient noise levels were used to determine the typical daytime (7am to 7pm) and nighttime (7pm to 7am) averages at the monitored locations. The daytime and nighttime average was calculated using the arithmetic hourly noise levels measured at the locations. The calculated ambient average daytime and nighttime noise levels are summarized in Table 1. Corporate Office: Hawthorne, California Carson, California — Aledo, Texas — Napa, California Longmont, Colorado — McDonald, Pennsylvania Calgary, Canada Phone 800-679-8633 Fax 310-331-1538 www.environmental-noise-control.eom www.drillingnoisecontrol.com Behrens and Associates, Inc. Environmental Noise Control Table 1 Average Daytime and Nighttime Ambient Noise Levels Discovery Midstream - Mustang, Compressor Station Location I Location 2 Location 3 Average Ambient Daytime Noise Levels Average Ambient Nighttime Levels Noise Average Ambient Daytime Leve Is Noise Average Nighttime Ambient Noise Levels Average Daytime Ambient Noise Levels Average Ambient Nighttime Nois Levels e dBA dBA dBA cIBA dBA dBA 46.0 48.4 55.7 50.7 48.2 43.4 Very truly yours, Colin M. Drolshagen Lead Acoustical Technician Corporate Office: Hawthorne, California Carson, California — Aledo, Texas — Napa, California — Longmont, Colorado — McDonald, Pennsylvania Calgary, Canada Phone 800-679-8633 Fax 310-331-1538 www.environmental-noise-control.com www.drillingnoisecontrol.cam Behrens and Associates, Inc. Environmental Noise Control a__... C- a' 0 • 80 75 70 65 60 55 50 40 35 30 25 20 15 10 0 Discovery Mustang Ambient Sound Midstream Compressor Station Level Survey - Location 1 � cIBA in d 40 35 30 25 20 ci- J C 15 0 in 10 5 0 GL CL..a. a...Gz. , LL GL GL. < < ct< < < cc ,: C . G. Gi. CL G. a. Ll... GL .2, •e < < < ctcc< < pc < a. a. a.... GL CL.... ,.1 C . CL .et cc`'t < < < cc < <tic CL... a. CL a. , OCO©OOC©OOCkhcccccccccCOO000©OOCO©OOr 00000000000, acicoac coacnococa)©000000 � mot- iirti , i6�,� cv m 4 u7 r-. co � si � „Fel coM . , cccccccccC©OOCCOOOCC©4OdaE'erccOccccIcC©O °cocaacicac coocc000cc000...acc .#- � (6(6,:ic ;4 Aim 4 � ciseic; & 6 � a-� �t June 15 -June 18, 2018 )c,cc,oao° � ,i 66 6 c � � m 4 c,n R as crti Attachment 2.. Behrens and Associates, Inc. Environmental Noise Control ,,._,� E 80 75 70 65 60 55 50 45 40 55 30 25 20 15 10 Mustang Ambient Sound Discovery Compressor Level Midstream Station Survey - Location 1 dBA —Wind 40 35 30 25 20 15 10 a _ 0- 15 •- c E 2 . o til - _ 22222 mrrimmmmm r kJ 52a OOCCOO°kisaaaccaac,ciCaOOOCaOO 0 oc ,:ri i,F■- c !0!0 m ammmmmmmmzmmma222a5222mmzmmmmmmmmmzzza5 m 252 22mmmmmmmmflf lm 000c oc 0 tm iJ mot' 0 0 c:,,,,,,arn -ie-n mmrnrnrr,mmrenrn mmer, fi, 6 ,--I .k m 4 c6 R. �o o; : si ,�-� i`si ri� ,..ei vn =no C00Ooaacaacc c,OOO©OOOCO©OOOO©cacacacccOOO mmenmmromrnrnrnrow. my) ran mfr. men tD r 6 ,:i ,--� r� t:6 4 kCr E s ci 6 Lei, �,� 15 -June 18, 2018 men mmien mrnre, mien mrnrnrot, r6 Wit' u'i ci is 0 Gti e . cal ;i Ai rn 4 u ; tom- �6 4J, s rl (z.i Lei, rir-iri June Attachment Behrens and Associates, Inc. Environmental Noise Control _ C- a' li a ei 80 75 70 65 60 55 50 45 40 35 30 25 20 15 10 0 Discovery Midstream Mustang Compressor Station Ambient Sound Level Survey - Location 2 �dBA Wind 40 35 30 25 2 0 15 10 5 0 - 2 a) J c O in GL 0 ei O. a. 0 Ui O. 0 ci, Q. 0 < ca < c m < O < a A: < a cry < Ca +� a. 0 ei < a cn < as A: C a 6 < Co le4 O. 0 ifi a. 0 Cr, a- 0 a. 0 a a m a a a crc ci 1.4 a. 0 r--- a. 0 iii a. 0 t*- a. a. a- a. � < a. 0 M. 0 0 Co 0 a a Lii r:-: cii r m June 15 -June 18, 2018 0 el Attachment 4 Behrens and Associates, Inc. Environmental Noise Control Sound Leve Discovery Midstream Mustang Compressor Station Ambient Sound Level Survey - Location 2 cdBA Wind 80 40 75 70 35 65 60 55 50 45 55 30 25 20 15 10 5 o L I 22222 52222 cmmmmmmmmzmmm222225222mmzmmmmmmmm222225 252 22mmmmmmmmflf lm cL c�. a. a. a a. a. a. a. cL ... -, .t .e .c < act .t .ct . , a. a. cz. a. a. a. a... a. Q . a. a..< < < < < < < < a. a. a. asa. a. eL a. a. a. < cc .d cc < < < OCO©ooccooO nccccioc ccccco©ocC©OOCQOOOccccccccc000000OCO©OOOC ©cccccccccOOO 000000 c000C5-imrammrnerjr3mmmrnrOrOenrOrricilenrOrnmrnerjrnrommrrrnrornrnef rOrOrrirt'renrOrOMMenrOrommrrrnrornmrnenrorn i mot' i:ri ii IC 166 fi, 6 ti 4-' ;Li t:si m 4 6 R �O O; d 1 ,-i Ai ci hft OH 6 %:i 1*-� Ai rra kCr A: i3 a; 6 r'kJ iii ief u'i ci A: 0 ci 'Q ri 1 ri rn 4 u i tom- tic; c5. s rl ('%i el ei ,- ri el eiri ri ri ,- ,—I ri ri ri t-1 vn June 15 -June 18, 2018 30 25 S 20 2 15 10 0 Attachment 5 Behrens and Associates, Inc. Environmental Noise Control Sound Leve 80 75 65 60 55 50 45 40 35 30 25 20 15 10 5 a Discovery Midstream Mustang Compressor Station Ambient Sound Level Survey - Location 3 nBA —Wind 0 0 0 0 0 ri m r-- cg's, C < C C a c ... ... . .. .. .. m .r-� tri a . Q.. Q. Q. < C C < C o a o a © t:r; t:r; .. ... .. June 15 -June 18, 2018 2 2 2 2 2 2 CO. O_ Q. Q. CD 0.. ... Cr;.. .. l N C o tLei < C C < C a 9 9 a 9 .. .. .. .:. .. m Cn crti el 40 35 30 25 s 20 - 2 15 10 5 a Attachment Behrens and Associates, Inc. Environmental Noise Control cu ai C Sound Leve Discovery Midstream Mustang Compressor Station Ambient Sound Level Survey - Location 3 dBA Wind 80 40 75 70 65 60 5S 50 45 35 30 25 20 15 10 5 o I h 22222 52222 cmmmmmmmmzmmma222a5222mmzmmmmmmmmmzzza5 252 22mmmmmmmmflf lm cL c.. a. a. a a. a. a. a.cL .....1 < < < < < cd C ca.a. a. a. a.. ,. . a. c..... a .<< < ec< < < < < a. a.g. s. cL c�.... , cL a. a. a. ec.c.c.d .c.c.d < , OCO©ooccooO ncccc ccccccco©occ©0000OOOoccccccc c,OOO©OOOCO©OOOC ©ccccccc.ccOOO 000000000045.immmmrr3mmmmrnrnrOtri enrOcenrOrOmrnrirornmmrrcrammmenrOrOrOrOMMenrOmmmrrrnmmmrr3rnrornM J mot' orb ii IC 166 fi, 6 ti —I 4-& liLi N m 4 r-. �O O� d c�J �-� t i iD t ck OH 6 R-1 ,-i Ai rra crr A: 66 &i 6 r~J w ec ief u'i ci A- 0 Gti C5 ri cal ri rri 4 Li r 6 rl ('%i el ei ,- —I el ri ri ri ,- ,—I ri ri ri t-1 vn June 15 -June 18, 2018 35 30 25 I 20 2 15 10 0 Attachment 7 Behrens and Associates, Inc. Environmental Noise Control Discove ry Midstream - Mustang Compressor Station Location 1 - Hourly Averages Time dBA lime dBA 1:00 PM 55.5 1:00 AM 45.9 2:00 PM 52.3 2:00 AM 45.5 3:00 PM 50.5 3:00 AM 44.5 4:00 PM 55.0 4:00 AM 48.0 5:00 PM 55.1 5:00AM 47.4 6:00 PM 56.1 6:00 AM 47.4 7:00 PM 52.1 7:00 AM 47.2 8:00 PM 52.1 8:00 AM 48.1 9:00 PM 47.5 9:00 AM 49.5 10:00 PM 47.0 10:00 AM 50.8 1 1 :00 PM 47.2 11:00 AM 48.8 Sat 16 -Jun 47.1 12:00 PM 48.0 1:00 AM 48.7 1:00 PM 48.7 2:00AM 51.3 2:00PM 49.6 3:00 AM 51.2 3:00 PM 50.9 4:00 AM 50.3 4:00 PM 50.6 5:00 AM 50.7 5:00 PM 57,4 6:00 AM 53.9 6:00 PM 52.0 7:00 AM 48.1 7:00 PM 51.5 8:00AM 47.8 8:00 PM 48.2 9:00AM 44.9 9:00 PM 48.9 10:00 AM 44.3 10:00 PM 47.9 1 1:00 AM 42.7 1 1:0 0 PM 46A 12:00 PM 50.0 Mon 18 -Jun 45.9 1:00PM 51.1 1:00 AM 43.2 2:00 PM 63.4 2:00 AM 40.9 3:00 PM 51.5 3:00 AM 44.3 4:00 PM 44.9 4:00 AM 48.8 5:00 PM 51.8 5:00AM 53.0 6:00 PM 46.7 6:00 AM 54.5 7:00 PM 48.6 7:00 AM 53.4 8:00 PM 50.1 8:00 AM 52.6 9:00 PM 49.1 9:00 AM 48.7 10:00 PM 47.9 10:00 AM 50.0 11:00 PM 46.5 11:00 AM 46.3 Sun 17 -Jun 44.5 12:00 PM 48.4 Attachment 8 Behrens and Associates, Inc. Environmental Noise Control Discovery Midstream - Mustang Compressor Station Location 2 - Hourly Averages Time dBA lime dBA 1:00 PM 51.3 1:00 AM 54.0 2:00 PM 56.3 2:00 AM 53.7 3:00 PM 51.3 3:00 AM 46.4 4:00 PM 59.5 4:00 AM 44.0 5:00 PM 57.8 5:00AM 47.3 6:00 PM 63.8 6:00 AM 51.9 7:00 PM 58.7 7:00 AM 46.3 8:00PM 51.7 8:00AM 47.1 9:00PM 45.6 9:00AM 50.2 10:00 PM 52.5 10:00 AM 53.6 11:00 PM 43.9 11:00 AM 55.8 Sat 16 -Jun 42.2 12:00 PM 52.6 1:00 AM 45.2 1:00 PM 57.1 2:00 AM 48.8 2:00 PM 58,9 3:00 AM 47.7 3:00 PM 60.8 4:00 AM 46.4 4:00 PM 57.1 5:00 AM 53.3 5:00 PM 54.6 6:00 AM 50.2 6:00 PM 60.2 7:00 AM 43.0 7:00 PM 59.4 8:00 AM 38.7 8:00 PM 48.4 9:00 AM 42.0 9:00 PM 47.2 10:00 AM 43.6 10:00 PM 44.8 1 1:00 AM 47.1 11:00 PM 43.5 12:00 PM 50.8 Mon 18 -Jun 43.5 1:00 PM 51.7 1:00 AM 39.2 2:00 PM 71.6 2:00 AM 40.3 3:00 PM 60.5 3:00 AM 43.8 4:00 PM 43.3 4:00 AM 46.4 5:00 PM 62.5 5:00 AM 48.2 6:00 PM 51.1 6:00 AM 49.2 7:00 PM 48.4 7:00 AM . 47.0 8:00 PM 46.1 8:00 AM 45.5 9:00 PM 45.9 9:00 AM 49.9 10:00 PM 50.8 10:00 AM 42.6 11:00 PM 52.1 11:00 AM 41.1 Sun 17 -Jun 50.1 12:00 PM 40.0 Attachment 9 Behrens and Associates, Inc. Environmental Noise Control Discovery Midstream - Mustang Compressor Station Location 3 - Hourly Averages Time dBA lime dBA 1:00 PM 44.3 1:00 AM 40.2 2:00 PM 43.5 2:00 AM 39.2 3:00 PM 44.3 3:00 AM 35.2 4:00 PM 49.1 4:00 AM 40.3 5:00 PM 47.3 5:00 AM 40.1 6:00 PM 52.3 6:00 AM 45.0 7:00 PM 48.2 7:00 AM 41.4 8:00 PM 44.4 8:00 AM 49.4 9:00PM 40.6 9:00AM 41.4 10:00 PM 43.6 10:00 AM 43.7 11:00 PM 39.8 11:00 AM 44.7 Sat 16 -Jun 34.4 12:00 PM 42.9 1:00 AM 34.3 1:00 PM 47.0 2:00 AM 35.9 2:00 PM 46.9 3:00 AM 38.3 3:00 PM 50.8 4:00 AM 39.4 4:00 PM 45.3 5:00 AM 44.1 5:00 PM 43.5 6:00 AM 43.2 6:00 PM 48.2 7:00 AM 45.5 7:00 PM 45.7 8:00 AM 44.7 8:00 PM 411.8 9:00 AM 44.0 9:00 PM 42.0 10:00 AM 44.2 10:00 PM 41.8 11:00 AM 41.3 1 1:0 0 PM 39.4 12:00 PM 44.8 Mon 18 -Jun 39.3 1:00 PM 43.5 1:00 AM 38.9 2:00 PM 65.9 2:00 AM 31.8 3:00 PM 57.0 3:00 AM 35.1 4:00 PM 42.1 4:00 AM 39.1 5:00 PM 52.2 5:00 AM 51.3 6:00 PM 42.6 6:00 AM 55.1 7:00 PM 42.6 7:00 AM 43.5 8:00 PM 43.4 8:00 AM 43.0 9:00 PM 36.9 9:00 AM 41.2 10:00 PM 39.7 10:00 AM 42.9 11:00 PM 40.5 11:00 AM 42.8 Sun 17 -Jun 39.9 12:00 PM 39.4 Attachment 10 Behrens and Associates, Inc. Environmental Noise Control January 31, 2019 Rocky Mountain Midstream 7859 Walnut Hill Lane, Suite 335 Dallas, TX 75320 Attention: Scott Elery Subject: Ambient Sound Level Report Re: Proposed Broomfield Compressor Station Dear Mr. Elery: Per your request, an ambient sound level survey was performed near the proposed Broomfield Compressor Station in Brighton, Colorado from Friday January 25, to Monday January 28, 2019 to measure and document the ambient sound levels near the site.. The following report documents our findings. Ambient Sound Level Survey An ambient sound level survey, including A -weighted dB(A) sound level data, was performed for the proposed Broomfield Compressor Station to measure and document ambient sound levels for hourly, 15 minute and daily Leg averages during typical operations. Per Colorado Revised Statue (CRS) Title 25, Sec. 25-12-103 Measurements with sound level meters shall be made when the wind velocity at the time and place of such measurement is not more than five miles per hour. The sound level averages in Table 1 omit the data collected where the wind speed exceeded 5 miles per hour. Sound Measurement and Modeling Instrumentation The instrumentation used for the monitoring locations were Type 1 Svantek model 971 integrating and logging sound level meters with windscreens, which were calibrated prior to deployment. The metering systems were deployed in accordance with ANSI standards, and in a locked box for security. The measured noise levels are presented graphically in Attachments 2 through 11 and in tabulated form in Attachments 12 through 16. The noise levels were used to determine the typical daytime (7am to 7pm) and nighttime (7pm to 7am) averages at the monitored locations. The equivalent sound level, or Leq, is a sound energy average, calculated over a stated time period. The overall daytime and nighttime averages were calculated using the hourly average Leq noise levels measured at each location over the entire deployment period. The calculated average daytime and nighttime noise levels are summarized in Table 1. Corporate Office: Hawthorne, California Carson, California - Aledo, Texas - Napa, California - Longmont, Colorado - McDonald, Pennsylvania Calgary, Canada Phone 800-679-8633 Fax 310-331-1538 www.environmental-noise-controLeom www.drillingnoisecontrol.com ehrens and Associate!, Inc. Environmental Noise Control Table 1 Rocky Mountain Midstream - Broomfield Compressor Station. Location 1 Location 2 Location 3 Location 4 Location 5 Average Ambient Daytime Levels Noise Average Nighttime Ambient Levels Noise Average Daytime Average Nighttime Ambient Levels Noise Average Ambient Daytime Levels Noise Average Nighttime Ambient Levels Noise Average Ambient Daytime Levels Noise Average Ambient Nighttime Levels Noise Average Ambient Daytime N ois a Average Nighttime Ambient Levels Noise Ambient Noise Levels Levels dBA dBsik dBA dBA dBA dBA dBA (IBA dBA dBA 39.7 39.7 s 3T3 43.3 37.1 38.9 37.0 40.3 34.7 35.7 Very truly yours, Cohn M. Dr'olshagen Lead Acoustical Technician Corporate Office: Hawthorne, California Carson, California — Aledo, Texas — Napa, California Longmont, Colorado — McDonald, Pennsylvania Calgary, Canada Phone 800-679-8633 Fax 310-331-1538 www.environmental-noise-control.com h www.drillingnoisecontrol.com Behrens and Associates, Inc. Environmental Noise Control Sound Leve 80 70 65 60 55 50 45 40 35 30 25 20 15 1_0 5 C Rocky Mountain Midstream Broomfield Compressor Station Ambient Sound Level Survey - Location 1 dBA Wind Q. Q. Q. 0 0 00 0 0 0 0 C Crn C C 0 a 01 0 0 Q. Q. Q. a- a. a- te 0 00 0 0 0 0 0 ri ^I 0 0 0 0 0 0 0 0 0 0 C J 0 0 0 a 00 0 O 0 1 9 0 0 0 C. 9 Of O 0 6J 1 I x r; s -I � 11 (:r; Lri I ar1 '- l r-1 en 6.r'J r:C a`; January 25 -January 28, 2019 40 35 30 25 r 20a- 2 15 10 a Attachment 2 Behrens and Associates, Inc. Environmental Noise Control C Sound Le ve 80 75 70 65 60 55 50 45 40 35 30 25 20 15 10 5 0 Rocky Mountain Midstream Broomfield Compressor Station Ambient Sound Level Survey - Location 1 dBA —Wind 4:02.{:6., a. a. a. Q. C. a. a. a. a. O..<< < < Cr00c 0Cr00000000Gcoccco t�cOO OCrC C O gel? rnmrnremm . . .. . .. . . . . . .. . . . . . .. . .: . �"� r�l rn Wit' un S.G r co cr o E^wl r -r rq rn Ln it A I n mmmmmmmma 000c 0}0000 m rn rn m m re) e rn r cocnC}+riNriNro 522 000 �- r. GG O ,-1 rtil rw m sn r-� r,l rn 4 u 45 cc O r l m 4 un Lo rw.% CO are �rf �Itmmi earl January 25 -January 28 2019 A r 1 a. a. a. Q- Q- < < itc Etc get act c a. a. a. a. a. a. a. a. a. Q- « set id Etc get ett < act trt < COO C00cccccocci cC 0 00CO= 0000000cccccc, c cccc0 cflin mcnrnmmmmrnmmmmrnmrrmr rnmrOmmcc? cp. rru cc? mrnrnmmmrnrnmmm .. • 0 40 35 30 25 20 - 2 is 10 0 Attachment Behrens and Associates, Inc. Environmental Noise Control Sound Leve 80 70 65 60 55 50 45 40 35 30 25 20 15 1_0 5 C Am Rocky Mountain Midstream Broomfield Compressor Station bient Sound Level Survey - Location 2 cBA Wind Q. Q. Q. 0 0 00 0 0 0 0 C Crn C C O a O1 O O Q. Q. Q. a- a. a- te 0 00 0 0 0 0 O ri ^I O O O 0 0 0 0 0 0 O C J O O O a 00 O O 0 1 9 0 0 0 C. 9 Of O O 6J 1 I x r; s -I � 11 (:r; Lri I ar1 '- l r-1 en 6.r'J r:C a`; January 25 -January 28, 2019 40 35 30 25 200- 2 15 10 a Attachment 4 Behrens and Associates, Inc. Environmental Noise Control C Sound Le ve 80 75 70 65 60 55 50 45 40 35 30 25 20 15 10 5 a Rocky Mountain Midstream Broomfield Compressor Station Ambient Sound Level Survey - Location 2 cdBA Wind <O.a.raa=a.a.Q.aaa.O...<< Ettett Cr0000CrCr000Cr000OaCocc °C.CrC}CrCrC C s OC?Ca lcrymmrncnm &Ir S.G co 0`y , rin+� cry r n V I � I d _ 1 eccercett<<<Q- a. a. a. a. a a a- Q- a. Q- a. < < < Etc get act lca. a o- a- Q- a. a O- ci- Q. a < icc stt cc Etc get act ett act < < aa00000000000C~0000000aa000aci000000000000000000acio a0cO mmrnmcrymenmr•mmenmmmr rnrnrnrnmmrnanrnmmmrnrhrflm�^�`irOmmm�rerun mmrnrnrnmmmrnrnmm LOr- cc al c= +ri N ri r,J m L Imo- GG c Cy 1--I re4 m tal OOi cnC eirq rsl n z r - c Cy t-1 r l -I in] rn km re% co O', Cr rel January 25 -January 28 2019 • 40 35 30 25 20 - 2 15 10 Attachment Behrens and Associates, Inc. Environmental Noise Control Sound Leve 80 75 70 65 60 55 50 45 40 35 30 25 20 15 1_0 5 0 Rocky Mountain Midstream Broomfield Compressor Station Ambient Sound Level Survey - Location 3 idBA —Wind 0 0 0 2 0 C 0 C P C C C C 0 a 6:1-; 0 C; 0 0 o 0 0 C C 'C" 1 en January 25 -January 28, 2019 < cC C < C C C C J 0 0 0 C 0 0 0 6:r; N - th-; 40 35 30 25 20cL 2 15 10 0 Attachment 6 Behrens and Associates, Inc. Environmental Noise Control 80 75 70 65 60 5 5 50 c 4o 35 Sound Le ve 45 30 25 Rocky Mountain Midstream Broomfield Compressor Station Ambient Sound Level Survey - Location 3 dBA 20 _ 15 10 5 a < Q. Q.. Q., a. a. a. 0000000 ; NI rerct n 0000000G00s s mmmrnrnmmmrnrnm ................:...... .... 22222222222222222 22222 a. Q. Q.. Q. 00000 m cc? Cr? rel • J i Al r J 222222222222222222222222222 2 2222222222 Q- a. a. . a. Q- Q- < < < itc Ett get act lca. Q- a. a. a. a a. a. a. c- < ict set itc < 00* .0s 000000C:)oc_a(:)ao00C 0000000000000o0000oC:) m (rn cr. c mirn cc) m m m m en m m m m rn m r m rera nn ro m m rn rn m m fit a) rft- 0 Tmmi � t ry m Li) o r-.. COD � � � (7,4 r -r5 mi- u") 45 r� Cr) 0I -H r-4 � � � rN m It un Lo m January 25 -January 28 2019 0 rn • . 0 40 55 30 25 20 - 2 15 10 0 Attachment Behrens and Associates, Inc. Environmental Noise Control Sound Leve Rocky Mountain Midstream Broomfield Compressor Station Ambient Sound Level Survey - Location 4 dBA Wind 80 40 75 70 65 60 55 50 45 40 35 30 25 20 _ 15 10 5 C Q. Q. Q. 0 0 00 0 0 0 0kHr; Les; C Crn cC c 0 0 0 0 ::; 0 0 0 0 00 0 0 ri ^I C 0 0 0 0 0 0 0 0 0 C J 0 0 0 a 0 0 0 0 1 0 0 0 0 C. 9 Of 0 0 6:r; r a Li r a vi i rte. tH January 25 -January 28, 2019 35 30 25 r 20 a- 2 15 10 a Attachment 8 Behrens and Associates, Inc. Environmental Noise Control cu C_ Sound Le ve 80 75 70 65 60 55 50 45 40 35 30 25 20 15 10 5 0 Rocky Mountain Midstream Broomfield Compressor Station Ambient Sound Level Survey - Location 4 dBA n a 1 1 ak a. Q. Q. a Q. Q. a. Q. Q.. Q. Q. a. < < < < gCC < < < Q. Q. a. Q. a. Q. am Q. as a. Q. Q. < < gCC < gCC < gCC gd < gCC ECC Q.. Q. Q. Q. Q. Q. a Q. Q. Ca. Q. Q.. < gd < < < OCOC)OCrOOOCrOOOOactOOCacociOO©OOOOOOOOOOOOOOOOoicoOc OaciOOOOOOO©OOOOOOOOOOOcioOOco t0C.CrCaCrCrC.9OOPr'crymmre) ernmmmmrncrycrmmCr?Cr?mrn(Pa mr'mmrricfrnrnrnmrnrnrommmrmrnc^hCr). r c r`arOnncn mmmmr r mnrnrn 1:4e\k—I rfi u", S.G t CO Ch C � E^wl � r+r rn r� CC c= a-� N r I f' QZ - GO � C m tair"-- Cn C el NI el ni gt LZ CC CI m ust CO Crl rel January 25 -January 28 2019 m • . 0 40 35 30 25 2 20 - 2 15 10 0 Attachment Behrens and Associates, Inc. Environmental Noise Control Sound Leve Rocky Mountain Midstream Broomfield Compressor Station Ambient Sound Level Survey - Location 5 cBA Wind 80 40 75 70 35 65 60 55 50 45 40 35 30 25 20 10 15 30 25 20 O- 2 15 10 5 C Q. Q. Q. 0 0 00 0 0 0 0 C Crn cC o c O 0 o O O Q ri 0 0 O ,-� Cr; r ti; C o a 'C" 1 rn < CC EC Q. Q. Q. Q. Q. Q. ' C ' ' CC O O O 0 0 0 0 0 0 O C J O O O a O O CI 0 1 ' 0 0 0 CI 'O CI 0 O jr; r a r 'l i rte. January 25 -January 28, 2019 a Attachment 10 Behrens and Associates, Inc. Environmental Noise Control cu J C Sound Le ve 80 75 70 65 60 55 50 45 40 35 30 25 20 is 10 5 a Rocky Mountain Midstream Broomfield Compressor Station Ambient Sound Level Survey - Location 5 dBA Wind <0. a. a. a. a. Q. Q. Q. Q. a. 0. < < <act < set < < < < < < Q. Q. Q. Q. Q. a. Q. Q. Q. Q. OOOOOOOOOOOOOOGOoOOOcOOO©OOOOOOOOOOO 00000000000001 r,mm61cc) mmri1cncl)ro e)0101 ri)0101 i"%j gets isci Ai Cr; R.G 04; a i I r -I 1'+.I ir; 4 eta 66 R add Re4 Ai GG ar; OOOOOOOO¢ OOOOO rn mm mm mmm mm mmm roil ��rvm4E)R N-cOC 0� January 25 -January 28 2019 a.. a. Q. Q. Q. Q. O. Q. Q. Q.a.a.<<<<<<C< OOOOOOOOOOOOO R:Dc:,GOOO re) ran re) O1 rill) re) O1 re) O) re) m ell ell rr) m m cn crj 40 35 30 25 20 - 2 15 10 0 Attachment 11 Behrens and Associates, Inc. Environmental Noise Control Rocky Mountain Midstream-Broomfiel€l Compressor Station Location 1 - Hourly Averages Time dBA Time dBA 1 1 :00 AM 43.0 11:00 PM 35.6 12:00 PM 45.7 Sun 27 -Jan 3 5.9 1:00 PM 46.1 1:00 AM 34.8 2:00 PM 46.8 2:00 AM 35.2 3:00 PM 45.9 3:00 AM 32.4 4:00 PM 40.1 4:00 AM 31.4 5:00 PM 43.0 5:00 AM 34.4 6:00 PM 40.7 6:00 AM 38.9 7:00 PM 40.1 7:00 AM 39.3 8:00 PM 41.1 8:00 AM 44.6 9:00 PM 40.7 9:00 AM 46.9 10:00 PM 36.2 10:00 AM 56.4 11:00 PM 39.2 11:00 AM 59.5 Sat 26 -Jan 41.3 12:00 PM 65.8 1:00 AM 40.5 1:00 PM 66.1 2:00 AM 35.3 2:00 PM 55.4 3:00 AM 33.0 3:00 PM 43.5 4:00 AM 31.9 4:00 PM 59.2 5:00 AM 34.6 5:00 PM 53.1 6:00 AM 41.0 6:00 PM 52.0 7:00 AM 45.2 7:00 PM 65.8 8:00 AM 48.0 8:00 PM 63.4 9:00 AM 48.1 9:00 PM 45.6 10:00 AM 66.9 10:00 PM 54.9 11:00 AM 57.4 11:00 PM 57.8 12:00 PM 39.6 Mon 28 -Jan 44.1 1:00 PM 46.6 1:00 AM 36.8 2:00 PM 45.4 2:00 AM 31.4 3:00 PM 46.1 3:00 AM 31._3 4:00 PM 45.5 4:00 AM 3 3.2 5:00 PM 41.5 5:00 AM 44.9 6:00 PM 36.7 6:00 AM 53.1 7:00 PM 35.9 7:00 AM 53.5 8:00 PM 36.3 8.00 AM 47.8 9:00 PM 37.9 9:00 AM 41.1 10:00 PM 37.8 10:00 AM 37.1 Attachment 12 Behrens and Associates, Inc. Environmental Noise Control Rocky Mountain Midstream - Broomfield Compressor Station Location 2 - Hourly Averages Ti m e dBA Time (I B .t 11 :00 AM 48.3 11:00 PM 36.2 12:00 PM 50.9 Sun 27 -Jan 3 7.1 1:00 PM 53.8 1:00 AM 39.2. 2:00 PM 53.5 2:00 AM 35.6 3:00 PM 50.0 3:00AM 32.9 4:00 PM 43.4 4:00 AM 33.1 5:00 PM 43.4 5:00 AM 35.8 6:00 PM 40.7 6:00 AM 38.2 7:00 PM 42.9 7:00 AM 3. 3 8:00 PM 40.2 8:00 AM 46.7 9:00 PM 41.0 9:00 AM 51.2 10:00 PM 38.3 10:00 AM 60.0 11:00 PM 40.0 11:00 AM 62.3 Sat 26 -Jan 42.8 12:00 PM 68.3 1:00 AM 41.9 1:00 PM 68.3 2:00 AM 36.6 2:00 PM 57.8 3:00 AM 33.1 3:00 PM 43.8 4:00 AM 33.7 4:00 PM 61.4 5:00 AM 33.9 5:00 PM 55.4 6:00 AM 41.7 6:00 PM 55.0 7:00 AM 45.2 7:00 PM 67.4 8:00 AM 47.5 8:00 PM 65.4 9:00 AM 46.6 9:00 PM 46.3 10:00 AM 43.2 10:00 PM 63.2 11:00 AM 45.9 11:00 PM 72.3 12:00 PM 38.5 Mon 28 -Jan 53.2 1:00 PM 45.9 1:00 AM 35.4 2:00 PM 51.4 2:00 AM 30.3 3:00 PM 50.2 3:00 AM 30.0 4:00 PM 46.7 4:00 AM 34.3 5:00 PM 42.6 5:00 AM 59.8 6:00 PM 36.9 6:00 AM 68.5 7:00 PM 37.7 7:00 AM 69.8 8:00 PM 38.1 8:00 AM 63.5 9:00 PM 39.2 9:00 AM 44.0 10:00 PM 39.9 10:00 AM 38.8 Attachment 13 Behrens and Associates, Inc. Environmental Noise Control Rocky Mountain Midstream - Broomfield Compressor Station Location 3 - Hourly Averages Ti me dBA Time dBA 11:00 AM 41.9 11:00 PM 37.0 12:00 PM 45.4 Sun 27 -Jan 37.8 1:00 PM 46.0 1:00 AM 3 7.3 2:00 PM 48.3 2:00 AM 38.7 3:00 PM 46.1 3:00AM 41.5 4:00 PM 40.0 4:00 AM 42.3 5:00 PM 42.5 5:00 AM 37.5 6:00 PM 43.4 6:00 AM 40.7 7:00 PM 43.2 7:00 AM 40.O 8:00 PM 40.6 8:00 AM 42.4 9:00 PM 44.9 9:00 AM 44.1 10:00 PM 39.9 10:00 AM 53.4 11:00 PM 39.1 11:00AM 54.7 Sat 26 -Jan 42.8 12:00 PM 63.6 1:00 AM 40.6 1:00 PM 62.9 2:00 AM 38.2 2:00 PM 51.9 3:00 AM 35.1 3:00 PM 42.8 4:00 AM 34.4 4:OO PM 55.9 5:00 AM 36.2 5:00 PM 51.3 6:00 AM 41.0 6:00 PM 48.5 7:00 AM 41.6 7:00 PM 62.5 8:00 AM 46.1 8:00 PM 59.9 9:00 AM 50.4 9:00 PM 43.6 10:00 AM 44.9 10:00 PM 46.5 11:00 AM 43.1 11:00 PM 62.4 12:00 PM 39.8 Moon 28 -Jan 44.4 1:00 PM 43.7 1:00 AM 38.0 2:00 PM 44.6 2:00 AM 33.4 3:00 PM 44.9 3:00 AM 34.4 4:00 PM 46.1 4:00 AM 35.5 5:00 PM 45.6 5:00 AM 49.6 6:00 PM 36.8 6:00 AM 59.6 7:00 PM 37.7 7:00 AM 60.4 8:00 PM 39.3 8:00 AM 51.8 9:00 PM 38.4 9:00 AM 41.1 10:00 PM 37.5 10:00 AM 382 Attachment 14 Behrens and Associates, Inc. Environmental Noise Control Rocky Mountain Midstream - Broomfield Compressor Station Location 4 - Hourly Averages Time dBA Time c1 B .t 1 1 :00 AM 45.2 11:00 PM 37.6 12:00 PM 43.2 Sun 27 -Jan 38.9 1:00 PM 41.9 1:00 AM 37.4 2:00 PM 47.1 2:00 AM 37.1 3:00 PM 47.6 3:00 AM 42.0 4:00 PM 40.3 4:00 AM 39.6 5:00 PM 42.4 5:00 AM 38.0 6:00 PM 42.4 6:00 AM 40.6 7:00 PM 42.3 7:00 AM 39.3 8:00 PM 41.4 8:00 AM 46.3 9:00 PM 43.7 9:01 AM 50.3 10:00 PM 42.4 10:00 AM 61.2 11:00 PM 40.6 11:00 AM 62.1 Sat 26 -Jan 44.5 12:00 PM 70.0 1:00 AM 43.0 1:00 PM 68.7 2:00 AM 40.6 2:00 PM 58.4 3:00 AM 37.2 3:00 PM 45,0 4:00 AM 36.4 4:00 PM 62.1 5:00 AM 36.6 5:00 PM 56.1 6:00 AM 40.8 6:00 PM 53.8 7:00 AM 42.4 7:00 PM 67.8 8:00 AM 45.5 8:00 PM 67.3 9:00 AM 48.0 9:00 PM 46.1 10:00 AM 44.2 10:00 PM 50.9 11:00 AM 47.7 11:00 PM 60.2 12:00 PM 39.9 Mon 28 -Jan 43.3 1:00 PM 45.2 1:00 AM 37.5 2:00 PM 44.2 2:00 AM 31.8 3:00 PM 43.8 3:00 AM 33,7 4:00 PM 43.7 4:00 AM 34.3 5:00 PM 48.4 5:00 AM 45.9 6:00 PM 36.8 6:00 AM 54.5 7:00 PM 38.1 7:00 AM 55.4 8:00 PM 37.7 8:00 AM 49.4 9:00 PM 38.2 9:00 AM 40.1 10:00 PM 37.6 10:00 AM 41.3 Attachment 15 Behrens and Associates, Inc. Environmental Noise Control Rocky Mountain Midstream - Broomfield Compressor Station Location 5 - Hourly Averages Ti me dBA Time dBA 11 :00 AM 43.9 11:00 PM 43.9 12:00 PM 49.3 Sun 27 -Jan 49.3 1:00 PM 48.0 1:00 AM 48.0 2:00 PM 48.8 2:00 AM 48.8 3:00 PM 46.1 3:00 AM 46.1 4:00 PM 40.8 4:00 AM 40.8 5:00 PM 41.6 5:00 AM 41.6 6:00 PM 40.9 6:00 AM 40.9 7:00 PM 39.8 7:00 AM 39.8 8:00 PM 38.9 8:00 AM 38.9 9:00 PM 38.3 9:00 AM 18.3 10:00 PM 35.9 10:00 AM 35.9 11:00 PM 35.5 11:00 AM 35.5 Sat 26 -Jan 39.8 12:00 PM 39.8 1:00 AM 35.8 1:00 PM 35.8 2:00 AM 35.3 2:00 PM 35.3 3:00AM 31.6 3:00 PM 31.6 4:00 AM 32.2 4:00 PM 32.2 5:00 AM 32.5 5:00 PM 32.5 6:00 AM 39.0 6:00 PM 39.0 7:00 AM 40.3 7:00 PM 40.3 8:00 AM 44.2 8:00 PM 44.2 9:00 AM 47.0 9:00 PM 47.0 10:00 AM 43.8 10:00 PM 43.8 11:00 AM 43.1 11:00 PM 43.1 12:00 PM 38.5 Mon 28 -Jan 38.5 1:00 PM 52.7 1:00 AM 52.7 2:00 PM 4.5.4 2:00 AM 45.4 3:00 PM 45.5 3:00 AM 45.5 4:00 PM 42.8 4:00 AM 42.8 5:00 PM 42.9 5:00 AM . 42.9 6:00 PM 34.6 6:00 AM 34.6 7:00 PM 34.2 7:00 AM 34.2 8:00 PM 33.1 8:00 AM 33.1 9:00 PM 32.0 9:00 AM 32.0 10:00 PM 32.4 10:00 AM 32.4 Attachment 16 Hello