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Home My WebLink About20151074.tiff SITE SPECIFIC DEVELOPMENT PLAN AND USE BY SPECIAL REVIEW (USR) APPLICATION FOR PLANNING DEPARTMENT USE DATE RECEIVED: RECEIPT # /AMOUNT # 1$ CASE # ASSIGNED: APPLICATION RECEIVED BY PLANNER ASSIGNED: Parcel Number 0 9 6 5 - 2 7 . 1 - 0 0 - 0 2 2 (12 digit number - found on Tax I.D. information, obtainable at the Weld County Assessor's Office, or www.co.weld.co.us) Legal Description Please see included Lease , Section 27 , Township 5 North, Range 63 West Zone District: NA , Total Acreage: 35 , Flood Plain: NA , Geological Hazard: NA , Airport Overlay District: NA FEE OWNER(S) OF THE PROPERTY: Name: 70 Ranch, LLC Work Phone # 303 816 1010 Home Phone # Email info©highsierraenergy.com Address: 8301 E. Perntice Ave #100 Address: City/State/Zip Code Greenwood Village , CO 80111 Name: Work Phone # Home Phone # Email Address: Address: City/State/Zip Code Name: Work Phone # Home Phone # Email Address: Address: City/State/Zip Code APPLICANT OR AUTHORIZED AGENT (See Below:Authorization must accompany applications signed by Authorized Agent) Name: NGL Water Solutions DJ, LLC Work Phone # 303 815 1010 Home Phone # Email info@highsierraenergy.com Address: 3773 Cherry Creek North Drive #1000 Address: City/State/Zip Code Denver, CO 80209 PROPOSED USE: Salt Water Disposal Facility I (We) hereby depose and state under penalties of perjury that all statements, proposals, and/or plans submitted with or contained within the application are true and correct to the best of my (our)knowledge. Signatures of all fee owners of property must sign this application. If an Authorized Agent signs, a letter of authorization from all fee owners must be included with the application. If a corporation is the fee owner, notarized evidence must be included indicating that the signatory has to legal authority to sign for the corporation. ,L44 449Jj 1 /22/15 Signature: Owner or uth Agent Date Signature: Owner or Authorized Agent Date g g g USE BY SPECIAL REVIEW QUESTIONARRE NGL WATER SOLUTIONS DJ , LLC C12 FACILITY January 22, 2015 NGLWS C12 Facility: Site Specific Development Plan and USR 1. Explain, in detail, the proposed use of the property NGL Water Solutions DJ, LLC proposes that this site would allow for construction and operations of a saltwater disposal facility. This facility will include an offload area, a tank farm, and pump house building. 2. Explain how this proposal is consistent with the intent of the Comprehensive Plan pursuant to Chapter 22 of the Weld County Code. Section 22-2-70, 22-4-140.A. EP.Goal 1, Section 22-4-140. B. EP.Goal2 and Section 22-6-20.C. 1 ECON . Policy 3 .1 of the Weld County Code describes allowing industrial development that is compatible with the surrounding environment. The site does not currently hinder the agricultural landscape of its surrounding neighbors due to operations as a self-contained facility. 3. Explain how this proposal is consistent with the intent of the Weld County Code, Chapter 23 (Zoning) and the zone district in which it is located. The proposed facility is a Class II Oilfield Waste Disposal Facility — Saltwater Injection Facility which is classified as a Mineral Resource Development Facility, Oil and Gas Support Service per Chapter 23-3-40 A.2 of the Weld County Code. This facility is allowed, with the site's current A (Agricultural) Zone District, through a Use by Special Review process. The site will not interfere with the neighboring agricultural landscape, nor will it keep its neighbors from conducting agricultural activities. This site is, and will remain fully contained . A water quality pond will be added to the site per the attached drainage letter. 4. What type of uses surround the site (explain how the proposed use is consistent and compatible with surrounding land uses). The property surrounding this site is a mix of agricultural and Oil/Gas infrastructure. As described above, this site is fully contained and will not hinder the production, or landscape, of its neighbors. 5. Describe, in detail, the following: a. Number of people who will use this site In a 24-hour period, there will be 10 total employees that will operate the SWD facility. There will be no more than 5 employees on site at any one time. NGL Water Solutions would also like to request unlimited truck trips to this facility in a 24-hour period 7 days a week. On average, there will be 160 trucks per day. b. Number of employees proposed to be employed at this site This site will employ 10 employees with no more than 5 at any one time in a 24 hour period . c. Hours of operation NGL Water Solutions would like to request 24-hour operations at this facility. d. Type and number of structures to be erected (built) on this site Initially the facility will include a pump house building, a concrete containment area, and a concrete truck offload pad with a canopy covering part of the offload pad. The pump building will include a 1200 square foot occupied space that will include a break room, restrooms and an office. Future structures have been identified on the USR map as may be needed for expansion . Drainage calculations have included the runoff from these structures. e. Type and number of animals, if any, to be on this site No animals will be on this site. f. Kind of vehicles (type, size, weight) that will access this site and how often Liquid transportation trucks weighing up to forty (40) tons will visit this site. NGL Water Solutions would like to request unlimited truck trips to this facility in a 24-hour period 7 days a week. In addition to the tanker truck traffic employees and service trucks will be accessing the site as needed. g. Who will provide fire protection to the site This site is located in the Platte Valley Fire Protection District. h. Water source on the property (both domestic and irrigation) The site will have a commercial drinking water well . i. Sewage disposal system on the property (existing and proposed) Disposal of sewage will be handled by septic system . j. If storage or warehousing is proposed, what type of items will be stored The pump house building will store pumps and other equipment. 6. Explain the proposed landscaping for the site. The landscaping shall be separately submitted as a landscape plan map as part of the application submittal. The disturbed area, including drainage feature, will be seeded with an approved xeric seed, see included erosion control plan for additional notes and requirements. 7. Explain any proposed reclamation procedures when termination of the Use by Special Review activity occurs. The disposal system tank farm, offload bays, and processing buildings will be removed once the processing facility is terminated . All tanks and associated piping will be removed and disposed of off-site. The site will be re-graded to match surrounding site grading for required drainage patterns. Any contaminated soils will be removed and disposed of off-site at an approved facility. See included Closure Plan for further detail . 8. Explain how the storm water drainage will be handled on the site. Please see attached Water drainage letter performed by Wernsman Engineering. 9. Explain how long it will take to construct the site and when the construction and landscaping is scheduled to begin. Contingent upon the USR 28 day review process, NGL will submit for grading and building permit with request for early release. Construction will start as soon as USR conditions of approval, grading and building permit approvals are in place. It is anticipated that construction will take approximately 6 months after mobilization . 10. Explain where storage and/or stockpile of wastes will occur on this site. Please refer to the Waste Management Plan attached. 11. Please list all proposed on-site and off-site improvements associated with the use (example: landscaping, fencing, drainage, turn lanes, etc.) and a timeline of when you will have each one of the improvements completed. Site improvements will include, tank containment area, truck off-load area, sidewalk between tank containment and pump building, landscaping that will consist of seeding the disturbed area per attached erosion control plan, a 3-strand barbed-wire fence, facility sign and drainage & grading per the attached grading plan . Construction, LLC M2861 W. 120th Ave., Suite 250 Westminster, CO 80234 Phone: (720) 708-6535 Mr. Kim Ogle Weld County, Department of Planning 1555 North 17th Avenue Greeley, Colorado 80631 Re: C12 USR 7 day review response January 22, 2015 Dear Mr. Ogle, Public Health and Environment Design, Secondary Containment, and Unloading Pad — Detailed construction documents will be provided prior to construction. Engineering 1. Traffic distribution - Ninety (90) percent of truck traffic will be local and contained within 70's Ranch. The remaining Ten (10) percent will come from the North West via Weld County Road 388, of which Six (6) percent will come from the South via Highway 34 to Weld County Road 61, Three (3) percent will come from the West via Weld County Road 53 and Three (3) percent will come from the North via Weld County Road 59. Zero (0) percent will come from the South via Weld County Road 69. Planning 1. See revised C1 drawing. Lighting will consist of: One (1) LED pole mounted down light located near the parking lot, LED down lights between tanks to light walkway, wall mounted LED sconces above pump building doorways, and metal halide surface mounted down lights at the canopy. 2. Subdivision Exemption application has been submitted, case number SUBX15-0003. 3. See attached revised lease agreement. 4. Application fee has been included. Sincerely, t44 ,4//1/7/ Theodore A. Lopez, Jr., Owner M3 Construction, LLC /-I" M3CON-1 OP ID: SB ACOR0 CERTIFICATE OF LIABILITY INSURANCE DATE(MMIDDIVVVY) 4...------ 01/20/2015 THIS CERTIFICATE IS ISSUED AS A MATTER OF INFORMATION ONLY AND CONFERS NO RIGHTS UPON THE CERTIFICATE HOLDER. THIS CERTIFICATE DOES NOT AFFIRMATIVELY OR NEGATIVELY AMEND, EXTEND OR ALTER THE COVERAGE AFFORDED BY THE POLICIES BELOW. THIS CERTIFICATE OF INSURANCE DOES NOT CONSTITUTE A CONTRACT BETWEEN THE ISSUING INSURER(S), AUTHORIZED REPRESENTATIVE OR PRODUCER,AND THE CERTIFICATE HOLDER. IMPORTANT: If the certificate holder is an ADDITIONAL INSURED, the policy(ies) must be endorsed. If SUBROGATION IS WAIVED, subject to the terms and conditions of the policy,certain policies may require an endorsement. A statement on this certificate does not confer rights to the certificate holder in lieu of such endorsement(s). PRODUCER CONTACT Thomas J.Sisk&Company,Inc. PHONE FAX 1700 Broadway,Suite 1000 ac.No.E=t):303-831-7100 (A/C,No): 303-831-7377 Denver,CO 80290 E-MAIL Dave Tacha ADDRESS: INSURER(S)AFFORDING COVERAGE NAIC N INSURER A:Crum &Forster INSURED M3 Construction LLC INSURER B:Liberty Mutual 2861 W 1d 0th z AveINSURER C:Pinnacol Assurance 2861 W 120th A #250 Westminster, CO 80234 INSURER D:Hartford Insurance Group INSURER E: INSURER F: COVERAGES CERTIFICATE NUMBER: REVISION NUMBER: THIS IS TO CERTIFY THAT THE POLICIES OF INSURANCE LISTED BELOW HAVE BEEN ISSUED TO THE INSURED NAMED ABOVE FOR THE POLICY PERIOD INDICATED. NOTWITHSTANDING ANY REQUIREMENT, TERM OR CONDITION OF ANY CONTRACT OR OTHER DOCUMENT WITH RESPECT TO WHICH THIS CERTIFICATE MAY BE ISSUED OR MAY PERTAIN, THE INSURANCE AFFORDED BY THE POLICIES DESCRIBED HEREIN IS SUBJECT TO ALL THE TERMS, EXCLUSIONS AND CONDITIONS OF SUCH POLICIES.LIMITS SHOWN MAY HAVE BEEN REDUCED BY PAID CLAIMS. INSR ADDL SUBR POLICY EFF POLICY EXP LTR TYPE OF INSURANCE INSD WVD POLICY NUMBER POLICY EFF POLICY EXP LIMITS (MOLIC/YEFF (POLIC/YEXP A X COMMERCIAL GENERAL LIABILITY EACH OCCURRENCE $ 1,000,000 CLAIMS-MADE X OCCUR X EPK-104591 07/01/2014 07/01/2015 DAMAGETGRENTED PREMISES(Ea occurrence) $ A X Professional EPK-104591 07/01/2014 07/01/2015 MED EXP(Any one person) $ A X Pollution EPK-104591 07/01/2014 07/01/2015 PERSONAL&ADV INJURY $ 1,000,000 GEN'L AGGREGATE LIMIT APPLIES PER: _GENERAL AGGREGATE $ 2,000,000 POLICY JECT PRO- LOC PRODUCTS-COMP/OP AGG $ 2,000,000 OTHER: Emp Ben. $ 100,000 AUTOMOBILE LIABILITY COMBINED SINGLE LIMIT $ 1,000,000 (Ea accident) B X ANY AUTO X BAS56177772 07/01/2014 07/01/2015 BODILY INJURY(Per person) $ ALL OWNED SCHEDULED BODILY INJURY(Per accident) $ AUTOS AUTOS PROPERTY X HIRED AUTOS X AUTOOWNED (Per accidentDAMAGE $ ) X UMBRELLA LIAB X OCCUR EACH OCCURRENCE $ 5,000,000 A EXCESS LIAB CLAIMS-MADE X EFX-101587 07/01/2014 07/01/2015 AGGREGATE $ 5,000,000 DED RETENTION$ $ WORKERS COMPENSATION X PER 0TH- AND EMPLOYERS LIABILITY STATUTE ER Y/N C ANY PROPRIETOR/PARTNER/EXECUTIVE 4157496 07/01/2014 07/01/2015 E.L.EACH ACCIDENT $ 1,000,000 OFFICER/MEMBER EXCLUDED? N/A (Mandatory in NH) E.L.DISEASE-EA EMPLOYEE $ 1,000,000 If yes,describe under DESCRIPTION OF OPERATIONS below E.L.DISEASE-POLICY LIMIT $ 1,000,000 D Equipment X 31UUMVT3222 07/01/2014 07/01/2015 DESCRIPTION OF OPERATIONS/LOCATIONS/VEHICLES (ACORD 101,Additional Remarks Schedule,may be attached if more space is required) Certificate Holder is listed as an Additional Insured for all Liability policies (exluding Workers Compensation)as reqired by written contract but only to the extent of such contract. CERTIFICATE HOLDER CANCELLATION WELDCO2 SHOULD ANY OF THE ABOVE DESCRIBED POLICIES BE CANCELLED BEFORE THE EXPIRATION DATE THEREOF, NOTICE WILL BE DELIVERED IN Weld County, Colorado ACCORDANCE WITH THE POLICY PROVISIONS. c/o Public Works Department 1111 H Street AUTHORIZED REPRESENTATIVE PO Box 758 (Greeley,CO 80632 ©1988-2014 ACORD CORPORATION. All rights reserved. ACORD 25(2014/01) The ACORD name and logo are registered marks of ACORD Weld County Planning Dept. 1555 N. 17`h Avenue GRADING PERMIT Greeley, CO 80632 Phone: (970)353-6100 APPLICATION FORM Fax: (970)304-6498 Applicant Property Owner(If different than Applicant) Name Ted Lopez Name 70's Ranch. LLC Company M3 Construction Address 8301 E. Prentice Ave #100 Address 2861 W 120th Ave Ste #250 city Greenwood Village State CO Zip 80111 City Westminster State CO Zip 80234 Phone 303-815-1010 Business Phone 720-708-6535 E-mail info@highsierraenergy.com E-mail tlopez@m3-construct.com Signature Project Location Job Site Address WCR 388 & WCR 69, Weld County Parcel Number 0965-27-1 -00-022 Section/Township/Range 27/ 5N/ 63W Access Location: Site Accesses onto CR 388 (East, West, North, South) of CR 69 Project Information Is this a Use by Right or Planning and Zoning Case? n Use by Right bPlanning and Zoning Case Planning Land Use Case# (if applicable) USR15-0007 Is this in a Floodplain (verify with Planning Department)? (Yes No) • If yes enter your permit number(FHDP)# Description of Work Being Done Grading for salt water dispo - facility includes road, pump house, tank containment and offload bay. Construction Start Date April 1, 2015 Finish Date December 15, 2015 Acreage Disturbed by Project: 13.5 Acres Required Submittal Documents Grading Permit Application Form ,(Plans: include (1) 11"x17" set (wet ink stamped and signed by Colorado PE) & (1) Electronic Copy(PDF Format) • Grading Plan—contours labeled with elevations show any ponds or ditches • Erosion &Sediment Control Plan—showing placement of all BMP's to be installed • Typical BMP Installation Details & Notes—for all BMP's to be installed ' ixConstruction Stormwater permit from Colorado Department of Public Health & Environment(CDPHE) j(Fee (To Weld County): 1-5 Acres/$50 5-20 Acres/$100 20 Acres or Greater/$200+$1 per acre over 20 Pursuant to Weld County Code Section 8-12-60,the Weld County Department of Planning reserves the right to deny issuance of a Grading Permit to Applicant if the Applicant has not received final approval of any required land use application and/or prior to the satisfaction by Applicant of the terms and conditions of any approved land use application. By submitting this Grading Permit application,the undersigned Applicant,under penalty of perjury,verifies that: (1)they have received all pages of the Grading Permit application;(2)they have read and understand all of the permit requirements and provisions;(3)they have the authority to sign for and bind the Applicant if the Applicant is a corporation or other entity;(4)by virtue of their signature,the Applicant is,upon issuance of a Grading Permit by Weld County,bound by and agrees to comply with all Grading Permit requirements and conditions and all applicable Federal, State,and Weld County statutes, rules,and regulations. / Applicant Signaturg Printed Name M,�T1- 4Z�/V (2,4✓ Date �`/1/7S Revised 3/21/2014 Construction, LLC M2861 W. 120th Ave.,Suite 250 Westminster,CO 80234 Phone: (720) 708-6535 March 10, 2015 ,r . ,• Mr. Kim Ogle Weld County Planning Department 1555 North 17th Avenue Greeley, CO 80631 Re: Request for Early Release of Grading Permit- NGL C12 SWD Facility USR15-0007 Dear Mr. Ogle, This letter is being issued as a request for early release of the grading permits for NGL Water Solutions C12 SWD project prior to record of the final plat. We are requesting early release of the permits because this is a major part of the project scope and need to begin construction to S avoid any serious weather delays or any unforeseen conditions that may arise over the course of the project.We plan on beginning construction immediately following approval of this request. We look forward to your response. Sincerely, /IP,/ Theodore A. Lopez,Jr., Owner M3 Construction, LLC CC: Doug White- NGL Water Solutions Wayne Howard-Weld County Planning if= WERNSMAN s ENGINEERING, INC. 1011 42nd STREET • EVANS, CO 80620 Phone (970) 353-4463 Fax (970) 353-9257 November 11, 2014 Ms.Jen Petrik Drainage Engineer Weld County Public Works P.O. Box 758 Greeley CO 80632 RE: Drainage letter for High Sierra's C12 facility near CR 69 near Kersey CO Dear Ms. Petrik: This letter addresses the Water Quality Capture Volume (WQCV) requirements and existing and proposed drainage ways on the site The storm-water historically enters the site from the north and drains across the site to the south.The site varies greatly in elevation. ( See grading plan) The proposed plan will collect on site flows and direct them around the proposed improvements to three water quality ponds around the site. When the water quality pond(s) reach capacity at elevations shown, storm- water will leave the ponds as sheet flow, or continue to fill in natural low spots. From the two ponds on the south edge of the site, storm water will travel an average of 400 feet south on the lot to further dissipate flows before they travel onto the neighboring property to the south.The pond to the north edge of the site will flow as sheet flow north the property to the north. The proposed conditions imperviousness (including all future buildings but excluding the concrete containment areas that will retain storm water) is 10. The WQCV required for the site is 8490 cubic feet. Each of the three ponds shown on the grading plan provide at least 8831 cubic feet of storage. If you have any further questions or comments regarding this matter, please contact this office. Sincerely, Eric Wernsman P.E. r----..�. U I J J j -• ;. ,'/. `I`i`i��';ql;;;;,:i I ' / `1 7%%r' .•''/:0�.%.i i :, ;` ''\::•`',"$•'��2�„`."• ,s• `, / r '%:,ir(%r i% - .F-�% _ 2_ - sue=-_�., ;z - I ` ` ` r /rI \�.\` �:```c•i/iilr,` _rrr :. I / ••',/,‘,_.=-. , ` 1 i 1 r r • �`•• •�gri0 .t, '-�. 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N LU�•co 92: r Z y 5 � � () III I rod,.. 3 .;� mom NGL Water Solutions DJ,, LLC LEGEND: xenn EDGE OF BUILDING C12 GRADING PLA1V — — — —" — — ,,,,ASWALE CENTERLINE 3/10/2015 KHL EXTENT OF LEASE ------------ _ 1'-8D' ma,err r KEKSEY EXISTING GRADE CONTOUR -----IiIIKI - --- - _ FINISHED GRADE CONTOUR "" WELD COUNTY, COLORADO FINISHED GRADE INDEX CONTOUR C2 _ 12" STRAW WATTLES TYP �`-' -�_. Na Water Solutions DJ LL C f ;,•,, NOTE: ALL DISTURBED AREAS THAT 3 %%` ;i;='='---.'_ , ARE NOT PAVED SHALL BE C12EROSION CONTROL PLAN g g m -:-:----- _ ; , =�`'"- - , RE-SEEDED OR COVERED IN ROAD " o BASE TO ACHIEVE FINAL KERSEY t ^ •E - •--: TN;;_• _:,...,_.�___ __= STABILIZATION WELD COUNTY,COLORADO '1',!- �_F_^"_ ` _N•,I•, I NNE I ` ,I• -_- - ._:�- -- __ = _ s1, .�;, h_ `:- CONCRETE d 'l,',-;,;;-;:". 1-1'C'.%'iii4,:,d1 A 'I ! i ' i'4,,.i,;ii' �� '` `--+• `\A`` `+` Z N r,NrK 7 ';iii" „.y °';r`a`,```;�cc,,,, WASHOUT SILT FENCE gin.- •Ir�d!�1;pi:Ii �',J� I ,I AREA.. /" .�', , s . `;c --�' r _ TYPI�IrI 7._ 'J�- yY .'-- e rr_T.X_' % Lam. 'rte_ '�h "—..�. -_ •/ 6,0)1''---U1--..4. • ,,,,,--,:-„z; • /I� l _ _ - • . 1 .1; ,r,l ' y��i. aa(q`r '�. - 'Ss35.:.`�++"•, .I•' ,-,,:.:-.1.1441.41,-;�1 --•I �•''�-_� / � 1 �., •- al► - _ (_-__- __ -__ �"1, 1 ' .'\\`\�' �r7,,,'"`iLl,iil•1, •�Y.. --- �s ` `,`•+ I;. Sis------/ ' tit J F I� + `J(_- �_ • �:'� i ' ' \\ ,,L,"L `t -- - a3 ,, 1. 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VEHICLE TRACKING CONTROL _ GENERAL EROSION CONTROL NOTES SLOPE AND SWALE PROTECTION Iwc_MMrIAI rn.wwL GP.1o3 -CONTRACTOR SHALL INSTALL ALL PERIMETER MGYENE MO EROSION CONTROL OENCES MCYWMG WATTLE DIAMETER, ` BUT Nor LIMITED TO,SILT FENCE,NMET PROTECTION,VIC PM,1MEEL WASHOUT,ANO SEOMENI SEDIMENT TRAPPING AREA IFYP.J 9.Warms Thickness BARNS BEFORE COMMENCWE ANY LAND CLUNK M GRANNG ACRNMS.MME CONTRACTOR $EE NOT[5 — EN.'11111f/..,IFP VI RO ID$D-111 STALL MT TOPS*.SWUNG OPERATIONS TO YAWN THE AREAS M Iii.THEY rill.BE \\\ •, l//J,: WREOATEET MOR%MG ME GONSINUCOON OF UNDERGROUND UTILITIES SHALT BE W0.UG:0 AS A It•N]/t' WEWIDEN �: L1 / LMIO OSONIBI G ACUITY.ALL EXCAVATED MATERIAL SHALL BE RACED M UIR SEDIMENT NLL ��[�71'! a1 ...'.1e Ill 0 � 4, ERODE BACK MID NNE MEN.ALL MENON[S NALL BE'UNFILLED BY THE END OF TIC DAYS • � F Q NUM,'MGU SNALL BE PERMANENTLY STATRUTE°BEFORE CO,STRMCTON IS CONSIOCREO >�I ER J •• /9 - tz W" COMPLETE. UV XIIMS ', ` '.IL1 1..4,.. t AL UNSTIRRED AREAS AND SOL SIOD(RIES SHALL BE ADEQUATE'Y SUMUZEO AS DEFINE°M fiiP) L�Ay,7N AY •EApdCLYIN �y O% W tut URBAN ORNNAOC MOW CONTROL DISTRICT NOFC°),VOLUAE 3,CONSTRUCTION MST [II}A1E U["4.O 11, 'LO"G 7 LLI 1fj ANACENENT PRACTICES.SOD.3 0'MOOR CONTROL'ALL PSTURDE0 SEALS A.0 SOL • O. Z `33� C] STOCKPILES SHALL BE NATEMCO AND UNNTMNED M A ROULHENEO CONDITION AT ALL IIMES gr..): ) 0) — NDF)TOIDIGN7akhFlPfWJd WRING CONSTRUCTION nova)S TD PREVENT NND-CAUSED EROSION ALL LAND OSTTMBWG PI AN VIEW V '/w tJ Q ACTINTIES NLL NE IMMEOAIELY D15LONTINUEO MEN FUGITIVE MIST'ERUCTS ADJACENT n CVATIFN VIEW Ott5 `�J Ir PROPERTIES,A5 0(1ERIME0 BY CITY INSPECTOR PERMANENT EAR IEMPOMARY MARK SEED(SEE Kt 1 IMSrAu NAIVES ALOrrC OOx10URA ME.LENCO of SHORE ' *g! 'I ARIL 0005 MANUALOGE 00 11 FOR SECOND SPEGFICATOIS)SEAL STABILIZATION SHALT BE REUU11E0 W W L%TPIT a SKYE. , •TANNIN 7 OARS AFMER PPM ORAOE IS READIER IF 015TURBED AREAS(M SIDOIMLES ARE NUT 010110NT 10 FINAL GRADE NIMN 30 OARS FO LOWING ME ILETAL DISTURBANCE,ORIRAN= ziAIVESslut00 INSPEC001RLYM+O IID1[P0111? yGRE-OSIIUfLEMNCE,TENPOPAPY STABAIZARON MEASURES SHALL NE REOYMEO MO SEAL$TOCRPAC z M1mAI1IA:PTPRNv%rnxc RM,µa TP ENsawC MEY RxAwZ SNAIL CKCEEO TEN(ICJ FE[I W MDGMT. ALL 5EAl SIOCRRL[SALE SLCVES SHALL NOi E%CEE°A I YTNTRrN0E0 i MTMi Mix ME 5PL '.g;.:5,. C � 4. ),maw WW 1.PI WINO V NYi AT NC MA Oxn ` AS NEPEO SLOPE OF 4V.IN_ ]aIVE STARES YAY B[Uff0 rdN P£Axx.Lnl NSTMUMOrs / ,•-• ..- WATT0 I LE C, ,IS.,0 N N MI, .M1 IL I...n or.•<NMT.0I0I 15..0 ALL STORM 01ER INLETS SMALL BE PROIECIED FROM THE ENTRY OF SEGMENT-LACER RATER ( 9:t WATTLE SPACING TABLE E. •INSTALL NACRES SMPY WI0 THE TRENPI(IVEEP)IBUT �Nj' / 1 s` } Iii HAY BALES ARE NOT RECOGNIZED BY ME CITY O GREW"'AS AN Af.CEPTABIL FORM O'EROSION --- ADJACENT LATHES TONRT.ENO TO EM.WNW �� '1C �� ♦�`` L MORN SLIDE TYPE r1 Mt111t111 1PKI110 CKACENT W THE EMS / U �* MSPLCIIOM OF ALL EROSION ARID SEOUIENi CONTROL AMP'S SHALL 0E BLURRED AT TOTE END OF )981 5 SVALCS 1 A S NAPLES T°8[9-4x 0010 A FOR SLOPES,IS'Yw //r I T' 1V" 11 LASH OR 1( 44 IEC1 P.O...SNAILS /, /(IIIt.T6�.1 ‘ ill Ilillal ,� EACH DAYS RORK,MM NECESSARY MAWIENANCE MID REPAIRS PR0NOE0 IMMEOATELY-NNE DIY Wigelt2a MOM O"G EELEY INSPECTOR SHALL AT MALT 1SCNEINON,REWIRE ANY EROSON ES BE REPAIRED.REPLACED,RELDCATEO.MOORED.ON RENO ED SUCH HEC RESi5 SHALLALL A BC MIKES COMPLETE° NMN 5 PANNING DAYS FOLLOYANC RECEIPT OF ME rMITTEN 0011 R SlO ME INSPECTOR NI CONCRETE TRUCK WASHOUT PIT -0O01�, SILT FENCE INSTALLATIOK PUBLIC MINT OF NAY POLLUTE('NM OPT,MOO,OR DEBRIS SHALL BE 51EPT CLEAN AT THE ENO 1.0-91?-1481 1*EACH DAYS NMI CR ATTER STORM EVENTS.AS MGD55ANY.ALL TEMPOS TA AND PERIMETER PROFILE EROSON AND SEGMENT SHALL COWAN.MEASURES ALL BE W.V.AS SOON AS TAW FUROR. 005 PEEN MULLED SEGMENT Taws/845as.1u ELF CLEANED M O RENOWN OR STA&UZED, '« ATTACHING TWO SILT TIERCES REAL ALL E F R PR AREAS ARE PERYMFN L STABILIZER E RTE CONTRACTORINT IS I. %NEN ALL u FOR PROPERLY ARC PECASPOSNCSE C.ALL TA LRDM THE STE. TT IS NOT REUSPBLE ON -l1 'N 'M'ISKIT T• �� Rrc aPG N)N]1ro xwpMrAITLTA THE 110 ADO KR SHALL BE NEW NESPONSRLE TON THE LORD-1ERM STABRITY O WT AND FILL SLOPES AND THE SUCCESSFUL ESNABUSHMONT OF PERMMNENT%MUM NSUE COKR GM E%POSED CONTAINMENT BERM FROM i W 5070 A5 KOKEO T.THE MVO.voLo.E 3.CONSTRUCTION MT MANAGEMENT...RCE5. "'e.4YiN wP"..." i„,--3,..11:`,. ra sEcn°x 3 R'LNACHMc- PR EXCAVATED MATRAi. B FEET MIS, ALL ow A i=.4.1.0**, RiACNP rCR51IST(MR 0 ALL cTNSTRUOT%M EaPRR5 Cl MATEMMS USED C.STONER ON SITE MUST BE OSP040 O •OIIA BOTTOA MIN. CONCAETETRUCXS 3/ID(2015 �p1 A •P7LA,.p.L PROPERY MD MUST MEET ALL APPLICABLE MATERIAL SAFETY DATA SHEET CRITERIA tiaRR a w Iv.M.o WASHOUT HERE 5CNt L41. V L� Iwrcw Tarty THE STATE STORYWAIEA DISCHARGE PELLET MOLDED NYE BE UANEE FOR AMY MCLATONS 1 AOKK Ml rNAAPa11 NO ASI a y01405 A,H Wu.P1 M LIW+O P N.. A'P.P \y as1 R(0011110 MA:THE A 11DM?TAKEN BY STE CONMAGTON0.SIBCONIPACTOl5.MMNTENAHCE z r 0 Tom ff 10 0Lv sp<a To 0TH ONO OF OSLO.. r• mug w CREWS.FM ]SF1 OIw<AfR YO H 111oNn W NND aRPIIo NP mmOaT In srC PLR INIW s11R •SCR:2•Totl x S'NUM w.pr �� P.DOIR,C MP MOM LAPS M t'Tall PRRI,6"AZ" lig C•/ C TO• A.9,0,/,wrs 1.1r All MY)A.4NR rARM A PMEO MOW MAR KOMIE A RC Pty LallernS N EY f.wc u.IgM R,IMNp ORM NKr Two.s oat H„ \I.: *wan ^•�NR YRwOM.1rtAL EROSION CONTROL STRUCTURES EROSION CONTROL STRUCTURES /\3 MJ :/ ♦ .-=Vo } I I PP°N'Esst DETWL t2—T DETAIL 12-2 (�I J Zr .-.w..ao-�/— =o1:,'' ` s,,...,.. wTc: SCALE: N.T.S. OAR: MARCH 2002 SCALE: ILIA zarrAWeld County Public Works Dept. �' : u- :: x : . . 1,,...-4- 1 H Street ACCESS PERMIT P.O. Box 758 t; /L, --:4 r Greeley, CO 80632 APPLICATION FORM /C \hO Phone: (970)304-6496 Fax: (970)304-6497 Applicant Property Owner (If different than Applicant) Name Theodore A. Lopez, Jr. of M3 Costruction Name 70 Ranch , LLC Company NGL Water Solutions DJ , LLC Address 8301 E. Prentice Ave #100 Address 3773 Cherry Creek North Drive #1000 City Greenwood Village State CO Zip 80111 City Denver State CO Zip 80209 Phone 303 815 1010 Business Phone 303 815 1010 Fax Fax E-mail info@highsierraenergy.com E-mail info@highsierraenergy.com A = Existing Access A= Proposed Access Parcel Location & Sketch The access is on WCR 388 Nearest Intersection: WCR 388 & WCR 69 WCR Distance from Intersection 1100' NW Parcel Number 0965-27- 1 -00-022 Section/Township/Range 27/5N/63W ,I` cc cc Li Is there an existing access to the property:CYES NO Q N � 3 Number of Existing Accesses 0 Road Surface Type & Construction Information A1100' Asphalt I l Grp,el j Treated I Other wcR 388 Culvert Size & Type 18" CMP Materials used to construct Access Gravel 69 Construction Start Date 12/1 /14 Finish Date 6/1 /15 Proposed Use : Temporary (Tracking Pad Required)/ $75 ❑Single Residential/$75 ❑ Industrial/$150 ® Small Commercial or Oil & Gas/$75 ❑Large Commercial/$150 ❑ Subdivision/$150 ❑ Field (Agriculture Only)/Exempt Is this access associated with a Planning Process? CNo ER EIRE I PUD ElOther Required Attached Documents - Traffic Control Plan -Certificate of Insurance - Access Pictures (From the Left, Right, & into the access) By accepting this permit, the undersigned Applicant, under penalty of perjury, verifies that they have received all pages of the permit application; they have read and understand all of the permit requirements and provisions set forth on all pages; that they have the authority to sign for and bind the Applicant, if the Applicant is a corporation or other entity; and that by virtue of their signature the Applicant is bound by and agrees to comply with all said permit requirements and provisions, all Weld County ordinances, and state laws regarding facilities construction. Signature .Iii Printed Name Theodore A. Lopez, Jr.4 Date 1 /12115 Approval or Denial will be issued in minimum of 5 days. Approved by Revised Date 6/29/10 C 12 — looking NW C 12 — Looking into Access ( NE) r f '.-- + ": �f • _ "7r'M'w. L N�I�i�IN�M�4�'c,�.'♦V. !r�3� V �ail6ik ir.il f d 1 (I y1' tI \ �µs .ry y��,,�� ' ;� a'Y...t...?,-.‘";4,4; P rjF. . w:r \ ,• yy\ - r ,� � S, Q •. {...rC.•r 7J � f .Y .� f A rSV05'V' . r .?R�`. ' F" , ./ I , , 4: . C4 "t'•t Sr. fk i t '. 1 71 xt. krt \' .-' r Z ' 64',3,4,21'1s 1 ,>yy,.v. A i^, pi �}, I ?w •ht..•S � k t, ♦ yt, . ` ++ y .. v '. 1 rr, 6r - i i }�Ir y '\ > �E '♦ i �7 4� / ; \§l• I ,R�Y %_. ,. -Ai0T ) \ • ' eR . `I t t, 4 - fIQ/ v e R;1 � f'4•, � �- `�* _ti I ::.+NM k r tia v`� �¢U�' � � � 4 'e 'J4 > (A kkL' i' 'IC*. k'01 '.' Pt�i • �2„ ' '�Sfi _ T , tr ...r. -'tw�t•+.ai-ta....1,441, r.T ?%..4,7,4,....Tld : ,�rL •�:♦ '.,,,EA: 4 �`" { �1 ,i .S� r ; i „j;'� A♦ j ( \ ^i: rte- ��. '�Y ';r •.. C ,y'�• r;.t`k1 ;< 'tt b. !! '•fin}' • !'; , , 1, .<, r•. . ,l J Y• �It� ...... �t� } , f y � .. NW:: ✓• i r:...'.y.f ^Y t y! i ti �t , >ug # ,yf' Y 44 Y�}5►ya .�. I� � , , .{.ir A • . � >S .-•A- t'. ♦+i , F �:. a A•� } t.y Tq} ,-1),•:\y'',1,, a t,,.. ;4.0,.. J 1 r• -.. ! I , \I' hY�Y�� 1 e ~A L in 1 ,.10..40A. , tt .. II) . / it Vlrl .. .\ {•.9 k '. t 1 :pv� • -ir lw lee n 1♦4k �.., f g: t. ♦. . M 1 1_. w l c � r 'f Tom' �{• T1 5 ♦q r w.+! o� tJ 4 •,w , y,{ Yl�,, l +N ' U • X\ eyt�p�`t `Yi IL ` tt \. ��•ti � t`.'1 i1 },� • 1 �i •f l • y :::‘`,4\''.1 rat ♦� °CI, t . 44h. 4'1 [ '° ", � , � .1S�C �y; •♦yy 'i �,.M irF fel, • \i. 14' r 1S `.so 'tt- 'V. : ca l *'..e.. C 12 — Looking SE C 12 — Looking away from Access dillw---- I L • • _ . . , .j, __ • ~ .. ., . ., �, . 1/4. , ,. . ..„ 4i .t+ • 7c :1/2._ •_. .,_, '.. t. \"/ \"/ E' F' N 9 IN I N C12A WELL LOCATION , % rialaan 1. lb6 IIIS ,. . - - . :. . . n _ C12 WELL LOCATION \I 9 / b,; N r ROAD / WORK f/ HEAD - DRIVEWAY Ap C lA ---"h. ./ ROAD 500 WORK 0 A HEAD 4 O 0 i VI a 500 ' . .o n W G00810 O Map Data I Terms of Use I Report a map error A A rn A W W W. DESIGNED BY: ... PROJECT NO. C12 e 0 1 DRAWN BY: C.FAHLIN • FILE NAMEC12 - 20140912 - Site Plan a) C 1 2 SALT WATER SHEET CHK'D BY: ? - C0NSTRUCTI0NSHEET NO. C1 IF THIS BAR DOES CROSS CHK'D BY: .,e . DISPOSAL FACILITY CONCEPTUAL WELL LOCATIONS 101/22/15 DRAWING PRINTED NOT MEASURE 1 n THEN DRAWING IS APPROVED BY : ° REV. 2861 W 120TH AVE, STE 250 o DATE DRWN CHKD REMARKS NOT TO SCALE DATE : DECEMBER 2014 WESTMINSTER, CO 80234 NO. Water Solutions DJ PRELIMINARY DRAFT REV. 6 -, „ Kq i Energy Partners LP 8207 W. 20th St . , Suite B Greeley, CO 80634 October 21 , 2014 FedEx: Colorado Department of Public Health and Environment Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, CO 80246-1530 Subject: C-12 Salt Water Disposal Facility General Permit Applications and Construction Permit Application NGL Water Solutions DJ, LLC Weld County, Colorado To Whom It May Concern: NGL Water Solutions DJ, LLC is submitting this application for the C- 12 Salt Water Disposal Facility (Facility), a new facility, located at SENE SECTION 27, T5N, R63 W, Weld County, CO to request coverage under a GP01 for the oil heating tank, oil tanks, slop oil tank and sale oil tank; coverage under a GP05 for the desand tanks, sand and oil removal tanks and the produced water unloading sump; and coverage under a construction permit for the truck loadout and fugitive emissions. The facility will have a maximum facility throughput of 20,000 bbl/day of trucked in water. Facility wide emission units will include: Desanding Tanks (2 x 700 bbl) Sale Oil Tank (1 x 400 bbl) Sand and Oil Removal Tanks (2 x 1000 bbl) Produced Water Unloading Sump Oil Heating Tank (1 x 400 bbl) Electric Tank Heater Water Equalization Tanks (8 x 840 bbl) Loadout Post-Filter Tanks (2 x 1000 bbl) Fugitives Oil Tanks (3 x 400 bbl) Diesel Tank (1 x 500 gal) Slop Oil Tank (1 x 400 bbl) The facility emission calculations, application forms, APENs, and supporting documentation are included in the attachments. Appendix B APCD- 102 and APEN Forms A check for $3, 126. 10 in full payment of the APEN filing and general permit registration fees as broken down below is attached. Fee Breakdown $ 152.90 x 9 APEN Filing Fee = $ 1 ,376. 10 $250 x 3 Produced Water Tank Battery GP05 Registration Fee = $750 $250 x 4 Midstream Condensate Tank Battery GP01 Registration Fee = $ 1 ,000 If you have any questions or need additional information, please contact me at 970-356-5560 {jatterson@highsierraenergy.com). Sincerely, NGL Water Solutions DJ, LLC Josh Patterson VP of Operations Enclosures Appendix A — Construction Permit Application Appendix B — APCD-102 and APEN Forms Appendix C — Regulatory Review Appendix D — Facility Emission Calculations and Supporting Documentation Appendix E — Process Description, Process Flow, Facility Location, and Plot Plan Appendix A Construction Permit Application Appendix C Regulatory Review CDPHE Air Quality Control Regulations Regulation 1 - Emission Control for Particulate Matter, Smoke, Carbon Monoxide and Sulfur Oxides The Facility is not subject to Regulation 1 . (5 CCR 1001 -3). There are no combustion sources at the facility. Regulation 2 - Odor Regulation 2 (5 CCR 1001-4 Part A. 1 ) States 'No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits... ' . The Facility is subject to this regulation and NGL Water Solutions DJ, LLC will comply with the requirements of this regulation. Regulation 3 — Stationary Source Permitting The Facility is subject to Regulation 3 (5 CCR 1001 -5) because it meets the definition as a source of air pollutants. Per Regulation 3, a new source located within a nonattainment area must comply with Section II.B. An Air Pollutant Emission Notice (APEN) is required for each individual emissions point in a nonattainment area with uncontrolled actual emissions of one ton per year or more of any individual criteria pollutant for which the area is nonattainment. Because the Facility is located within an 8-hour ozone control area, an APEN is required for each emission point with VOC emissions greater than 1 ton per year, and 2 tons per year for all other criteria pollutants. This application is being submitted in compliance with the applicable sections of Regulation 3. Regulation 6 — Standards of Performance for New Stationary Sources The Facility is subject to Regulation 6 (5 CCR 1001 -8) Part A, `Federal regulations adopted by reference'. See below for Federal NSPS for applicability review. Regulation 7 — Emissions of Volatile Organic Compounds The Facility is subject to Regulation 7 (5 CCR 1001 -9) under Sections III and VI. Section III outlines general requirements for storage and transfer of volatile organic liquids. Section VI specifies requirements for the storage and transfer of petroleum liquid. The tanks storing oil at the Facility are subject to the requirements under Sections III, and VI. NGL Water Solutions DJ, LLC will comply with applicable requirements of this regulation. The facility is located in an Ozone nonattainment area and is therefore, potentially subject to Section XII. However, the facility does not meet the definition of affected operations with respect to Section XII of Regulation 7; therefore, it is not subject to Section XII. Regulation 8 — Control of Hazardous Air Pollutants The Facility is subject to Regulation 8 (5 CCR 1001 -10) Part E, `Federal regulations adopted by reference'. See Section 5 below for Federal applicability review. Dispersion modeling — Potential NOx and CO emissions are below the significant emissions rate (SER); therefore modeling is not required in accordance with CDPHE PS Memo 10-01 . Potentially Applicable Federal Air Quality Regulations Prevention of Significant Deterioration (PSD) Total potential emissions of any criteria pollutant from the Facility are less than 250 ton/year. Potential greenhouse gas (GHG) emissions at the Facility are below PSD major source threshold levels. Therefore, it is not subject to the PSD or the non-attainment NSR permitting programs. New Source Performance Standards (NSPS): The Facility includes sources which may potentially be subject to NSPS requirements included in Title 40 of the Code of Federal Regulations (CFR) Part 60. A review of each potentially applicable subpart is included below. Subpart A Subpart A, General Provisions, applies to any stationary source that contains an affected facility to which an NSPS standard is applicable. Subpart Dc There are only electric heaters operating at the Facility, therefore, this subpart does not apply. Subpart Kb Subpart Kb applies to volatile organic liquid storage vessels constructed, reconstructed, or modified after July 23, 1984, with a capacity greater than or equal to 75 m3 (471bb1). This subpart does not apply to storage vessels with a capacity greater than 151 m3 (949 bbl) storing liquid with a max true vapor pressure less than 3.5 kPa, or storage vessels with a capacity greater than 75 m3 but less than 151 m3, storing liquid with a max true vapor pressure less than 15.0 kPa. The oil tanks are less than the 75 m3 applicability threshold, therefore, this subpart does not apply to the oil tanks. There are several water tanks at the facility with storage capacities between 75 m3 (471 bbl) and 151 m3 (949.7 bbl) or greater than 151 m3 (949.7 bbl). The maximum true vapor pressure is less than the 15.0 kPa applicability threshold for tanks between 75 m3 and 151 m and less than the 3.5 kPa applicability threshold for tanks greater than 151 m3. Therefore, this subpart does not apply to any of the water tanks. Subpart GG There are no turbines at this facility. Therefore, this facility is not subject to 40 CFR §60.330 Subpart KKK The facility does not meet the definition of an "onshore natural gas processing plant" as defined by this subpart. Therefore, the facility is not subject to 40 CFR §60.630 Subpart LLL There are no sweetening units at this facility. Therefore, this subpart is not applicable. Subpart IIII, JJJJ There are no SI or CI internal combustion engines at the facility. Therefore, this subpart is not applicable. Subpart KKIK There are no turbines at this facility. Therefore, this subpart is not applicable. Subpart OOOO The storage tanks at this facility were constructed, modified or reconstructed after August 23, 2011 . However, the potential to emit, as defined by this subpart, is less than 6 tons per year per tank. In addition, the oil loadout limitation for the facility that will be contained in the construction permit will establish a practically enforceable limit on the tank throughputs to demonstrate that emissions from the tanks cannot exceed the OOOO threshold. Therefore, the tanks are not affected facilities under this regulation. There are no continuous high-bleed pneumatics at the facility. Therefore, the pneumatics are not affected facilities under this regulation. Maximum Achievable Control Technology (MACT): The Facility will be a true minor source of HAPs. Thus, there are no sources at the Facility which are subject to MACT major requirements. Because there are no dehydrators or engines at the facility, area source requirements for MACT HH and MACT ZZZZ do not apply. Greenhouse Gases (GHG): Because this is a water storage facility and there are no combustion sources, GHG are expected to be negligible. Appendix D Facility Emission Calculations and Supporting Documentation Calculation Methods The facility receives post flash produced water from oil and gas operations. Emissions were estimated as follows: 1 . Hydrocarbon Liquid Storage Tanks — Emissions were calculated using E&P TANKS with a sample analysis from a similar facility. The sample is considered representative because the facility receives similar trucked in liquids. Margin was added to the throughput to allow for operational flexibility and to provide a conservative estimate. 2. Produced Water Storage Tanks — Emissions were calculated using EPA TANKS using a mixed composition of water and condensate. The liquid sample from a similar facility showed that the condensate portion of the liquid has a Reid Vapor Pressure of 3.2 psig at 100°F, corrected API Gravity of 47.0 at 60°F, and a molecular weight of 147. 12 lb/lb- mol. The sample is representative of the oil coming into the facility. While the composition is similar to crude oil, gasoline RVP10 was conservatively used for the hydrocarbon portion of the liquid because any light end hydrocarbons present in the initial offload of the liquids would be present at the produced water system tanks. 3. Loadout — Working loss emissions from truck loading were estimated using the USEPA loadout equation from AP-42 Section 5.2, and the annual maximum volume of condensate loaded. 4. Fugitive Emissions — Process piping fugitive emissions were estimated using USEPA emission factors and estimated component counts. Appendix E Process Description, Process Flow, Facility Location, and Plot Plan Process description The Facility accepts production water from oil and gas exploration and production sites in Colorado and separates residual condensate and oil from the production water through a closed system of manifolded aboveground storage tanks. The refined production water is injected into one of two on-site class II injection wells for disposal. The oil recovered at the facility is transported offsite for further refinement. A simplified process flow diagram is attached. October 21, 2014 FedEx: Colorado Department of Public Health and Environment Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-B 1 Denver, CO 80246- 1530 Subject: C-12 Salt Water Disposal Facility General Permit Applications and Construction Permit Application NGL Water Solutions DJ, LLC Weld County, Colorado To Whom It May Concern: NGL Water Solutions DJ, LLC is submitting this application for the C-12 Salt Water Disposal Facility (Facility), a new facility, located at SENE SECTION 27, T5N, R63W, Weld County, CO to request coverage under a GP01 for the oil heating tank, oil tanks, slop oil tank and sale oil tank; coverage under a GP05 for the desand tanks, sand and oil removal tanks and the produced water unloading sump; and coverage under a construction permit for the truck loadout and fugitive emissions. The facility will have a maximum facility throughput of 20,000 bbl/day of trucked in water. Facility wide emission units will include: Desanding Tanks (2 x 700 bbl) Sale Oil Tank ( 1 x 400 bbl) Sand and Oil Removal Tanks (2 x 1000 bbl) Produced Water Unloading Sump Oil Heating Tank (1 x 400 bbl) Electric Tank Heater Water Equalization Tanks (8 x 840 bbl) Loadout Post-Filter Tanks (2 x 1000 bbl) Fugitives Oil Tanks (3 x 400 bbl) Diesel Tank ( 1 x 500 gal) Slop Oil Tank (1 x 400 bbl) The facility emission calculations, application forms, APENs, and supporting documentation are included in the attachments. A check for $3, 126. 10 in full payment of the APEN filing and general permit registration fees as broken down below is attached. Fee Breakdown $152.90 x 9 APEN Filing Fee = $ 1 ,376. 10 $250 x 3 Produced Water Tank Battery GP05 Registration Fee = $750 $250 x 4 Midstream Condensate Tank Battery GP01 Registration Fee = $1,000 If you have any questions or need additional information, please contact me at 970-356-5560 (Patterson@highsierraenergy.com). Sincerely, NGL Water Solutions DJ, LLC Josh Patterson VP of Operations Enclosures Appendix A — Construction Permit Application Appendix B — APCD-102 and APEN Forms Appendix C — Regulatory Review Appendix D — Facility Emission Calculations and Supporting Documentation Appendix E — Process Description, Process Flow, Facility Location, and Plot Plan Appendix A Construction Permit Application Air Pollution Control Division (APCD) - Construction Permit Application PLEASE READ INSTRUCTIONS ON REVERSE SIDE. 1. Permit to be issued to: NGL Water Solutions DJ, LLC 2. Mailing Address: 8207 West 20th Street, Suite B Greeley, CO 80634 3. General Nature of Business: Oil and Gas Produced Water Storage SIC code (if known) 4. Air Pollution Source Description: C12 Salt Water Disposal Facility (List permit numbers if existing source, Permit Pending, GP01 Pending, GP05 Pending attach additional pages if needed) Is this a Portable Unit? No 5. Source Location Address (Include Location Map) If portable, include the initial location and home base location SE ''A NE ''A SECTION 27, T5N, R63W 6. Reason for Application: (Check all that apply) New or Previously Unreported Source Administrative Permit Amendments ❑ Modification of Existing Source 0 Transfer of Ownership (Complete Section 9 & 10 below) 0 Request for Synthetic Minor Permit ❑ Company Name Change (Complete Section 9 below) ❑ Other: ❑ Other. 7. Projected Startup Date: 2014 tht/lam Signature of Legally Authorized Person oftompany listed in Section 1 Date Signed Josh Patterson, VP of Operations Phone: 970-356-5560 Type or Print Name and Official Title of Person Signing Above Fax: 970-356-5563 8. Check appropriate box if you want: ® Copy of preliminary analysis conducted by Division ® To review a draft of the permit prior to issuance These sections are to be completed only if a company name change or transfer of ownership has occurred 9. Permit previously issued to: 10. Transfer of Ownership Information Effective Date of Permit Transfer: As responsible party for the emission source(s) listed above, I certify that the business associated with this source has been sold, and agree to transfer the permit to said party. Signature of Legally Authorized Person of Company listed in Section 9 Date Signed Phone: Type or Print Name and Official Title of Person Signing Above Fax: Mail completed application, APENs, and filing fee to: Colorado Department of Public Health and Environment http://www.cdphc.state.co.us/ap/stationary.html Air Pollution Control Division Phone: (303) 692-3150 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 Revised August 2004 Appendix B APCD- 102 and APEN Forms of•Co` . Form APCD-100 Colorado Department of Public Health and Environment �' �` Air Pollution Control Division • 1876x,. Oil & Gas Industry Colorado Department of Public l-lealth Construction Permit Application Completeness Checklist and Environment Ver. September 28, 2009 Company Name: NGL Water Solutions DJ, LLC Source Name: C12 Salt Water Disposal Facility Date: October 2014 Yes No Are you requesting a facility wide permit for multiple emissions points? • In order to have a complete application, the following attachments must be provided, unless stated otherwise. If application is incomplete, it will be returned to sender and filing fees will not be refunded. Attachment Application Element Applicant APCD A APEN Filing Fees • B Air Pollutant Emission Notice(s) (APENs) & ■ Application(s) for Construction Permit(s) — APCD Form Series 200 C Emissions Calculations and Supporting Documentation /1 • D Company Contact Information - Form APCD-101 • E Ambient Air Impact Analysis • • ►1 Check here if source emits only VOC (Attachment E not required) F Facility Emissions Inventory — Form APCD-102 • MI Check here if single emissions point source (Attachment F not required) G Process description, flow diagram and plot plan of emissions unit and/or • facility • Check here if single emissions point source (Attachment G not required) H Operating & Maintenance (O&M) Plan - APCD Form Series 300 Check here if true minor emissions source or application is for a general permit (Attachment H not required) I Regulatory Analysis • • Check here to request APCD to complete regulatory analysis (Attachment I not required) Colorado Oil and Gas Conservation Commission (COGCC) 805 Series Rule • • Requirements- Form APCD-105 ►� Check here if source is not subject to COGCC 805 Series requirements (Attachment J not required) Send Complete Application to: Colorado Department of Public Health & Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Check box if facility is an existing Title V source: ■ Send an additional application copy Check box if refined modeling analysis included: • Send an additional application copy Page 1 of 1C12 Form APCD-100 Construction Permit Application Completeness Checklist Form APCD-101 co" Colorado Department of Public Health and Environmento ..�. z Air Pollution Control Division * • Colorado Department of Public Health Company Contact Information Form and Environment Ver. September 10, 2008 Company Name: NGL Water Solutions DJ, LLC Source Name: C12 Salt Water Disposal Facility Permit Josh Patterson Compliance Josh Patterson Contact': Contactr: 8207 West 20th Street, Suite B 8207 West 20th Street, Suite B Address: Street Address: Street - Greeley CO 80634 Greeley CO 80634 City State I Zip City State Zip Phone Number: 970-356-5560 Phone 970-356-5560 Number: Fax 970-356-5563 Fax Number: 970-356-5563 Number: E-mail: jpatterson@highsierraenergy.com E-mail: jpaerson@highsierraenergy.com Billing Billing Contact: Josh Patterson Contact: Josh Patterson (Permit (Annual Fees)1 Fees/ 8207 West 20th Street, Suite B 8207 West 20th Street, Suite B Address: Sit Address: Street Greeley CO 80634 Greeley CO 80634 City State _ Zip City State Zip Phone 970-356-5560 Phone 970-356-5560 Number: Number: Fax Number: 970-356-5563 Fax 970-356-5563 Number: E-mail: jpaerson@highsierraenergy.com E-mail: jpaerson@highsierraenergy.com Check how would you like to receive your permit fee invoice? Mail: ® E-mail: ❑ Fax: ❑ Footnotes: The permit contact should be the point of contact for technical information contained in the permit application. This may be a company representative or a consultant. 2 The compliance contact should be the point of contact for discussing inspection and compliance at the permitted facility. 3 The billing contact (Permit fees) should be the point of contact that should receive the invoice for fees associated with processing the permit application & issuing the permit. (Reg. 3, Part A, Section VI.B) ° The billing contact (Annual fees) should be the point of contact that should receive the invoices issued on an annual basis for fees associated with actual emissions reported on APENs for the facility. 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L o a) Q Z aso co� o c hi o C (O ( L o rii Z z o coj " � Ut_ CU ` � o Z _ _ a' :..+ W _mil c Q U •`= z en c°^ia O >6 CL L .c cn E Ea -~d 1E:132 I E (i) z oo a� c a o a_o 12 a_ L! 0 0CD cB o a -� Z Appendix C Regulatory Review CDPHE Air Quality Control Regulations Regulation 1 - Emission Control for Particulate Matter, Smoke, Carbon Monoxide and Sulfur Oxides The Facility is not subject to Regulation 1 . (5 CCR 1001-3). There are no combustion sources at the facility. Regulation 2 - Odor Regulation 2 (5 CCR 1001-4 Part A. 1 ) States 'No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits. . . '. The Facility is subject to this regulation and NGL Water Solutions DJ, LLC will comply with the requirements of this regulation. Regulation 3 — Stationary Source Permitting The Facility is subject to Regulation 3 (5 CCR 1001-5) because it meets the definition as a source of air pollutants. Per Regulation 3, a new source located within a nonattainment area must comply with Section H.B. An Air Pollutant Emission Notice (APEN) is required for each individual emissions point in a nonattainment area with uncontrolled actual emissions of one ton per year or more of any individual criteria pollutant for which the area is nonattainment. Because the Facility is located within an 8-hour ozone control area, an APEN is required for each emission point with VOC emissions greater than 1 ton per year, and 2 tons per year for all other criteria pollutants. This application is being submitted in compliance with the applicable sections of Regulation 3. Regulation 6 — Standards of Performance for New Stationary Sources The Facility is subject to Regulation 6 (5 CCR 1001-8) Part A, `Federal regulations adopted by reference' . See below for Federal NSPS for applicability review. Regulation 7 — Emissions of Volatile Organic Compounds The Facility is subject to Regulation 7 (5 CCR 1001-9) under Sections III and VI. Section III outlines general requirements for storage and transfer of volatile organic liquids. Section VI specifies requirements for the storage and transfer of petroleum liquid. The tanks storing oil at the Facility are subject to the requirements under Sections III, and VI. NGL Water Solutions DJ, LLC will comply with applicable requirements of this regulation. The facility is located in an Ozone nonattainment area and is therefore, potentially subject to Section XII. However, the facility does not meet the definition of affected operations with respect to Section XII of Regulation 7; therefore, it is not subject to Section XII. Regulation 8 — Control of Hazardous Air Pollutants The Facility is subject to Regulation 8 (5 CCR 1001-10) Part E, `Federal regulations adopted by reference'. See Section 5 below for Federal applicability review. Dispersion modeling — Potential NOx and CO emissions are below the significant emissions rate (SER); therefore modeling is not required in accordance with CDPHE PS Memo 10-01 . Potentially Applicable Federal Air Quality Regulations Prevention of Significant Deterioration (PSD) Total potential emissions of any criteria pollutant from the Facility are less than 250 ton/year. Potential greenhouse gas (GHG) emissions at the Facility are below PSD major source threshold levels. Therefore, it is not subject to the PSD or the non-attainment NSR permitting programs. New Source Performance Standards (NSPS): The Facility includes sources which may potentially be subject to NSPS requirements included in Title 40 of the Code of Federal Regulations (CFR) Part 60. A review of each potentially applicable subpart is included below. Subpart A Subpart A, General Provisions, applies to any stationary source that contains an affected facility to which an NSPS standard is applicable. Subpart Dc There are only electric heaters operating at the Facility, therefore, this subpart does not apply. Subpart Kb Subpart Kb applies to volatile organic liquid storage vessels constructed, reconstructed, or modified after July 23, 1984, with a capacity greater than or equal to 75 m3 (471 bbl). This subpart does not apply to storage vessels with a capacity greater than 151 m3 (949 bbl) storing liquid with a max true vapor pressure less than 3.5 kPa, or storage vessels with a capacity greater than 75 m3 but less than 151 m3, storing liquid with a max true vapor pressure less than 15.0 kPa. The oil tanks are less than the 75 m3 applicability threshold, therefore, this subpart does not apply to the oil tanks. There are several water tanks at the facility with storage capacities between 75 m3 (471bb1) and 151 m3 (949.7 bbl) or greater than 151 m3 (949.7 bbl). The maximum true vapor pressure is less than the 15.0 kPa applicability threshold for tanks between 75 m3 and 151 m and less than the 3.5 kPa applicability threshold for tanks greater than 151 m3. Therefore, this subpart does not apply to any of the water tanks. Subpart GG There are no turbines at this facility. Therefore, this facility is not subject to 40 CFR §60.330 Subpart KKK The facility does not meet the definition of an "onshore natural gas processing plant" as defined by this subpart. Therefore, the facility is not subject to 40 CFR §60.630 Subpart LLL There are no sweetening units at this facility. Therefore, this subpart is not applicable. Subpart IIII, JJJJ There are no SI or CI internal combustion engines at the facility. Therefore, this subpart is not applicable. Subpart KKKK There are no turbines at this facility. Therefore, this subpart is not applicable. Subpart OOOO The storage tanks at this facility were constructed, modified or reconstructed after August 23, 2011 . However, the potential to emit, as defined by this subpart, is less than 6 tons per year per tank. In addition, the oil loadout limitation for the facility that will be contained in the construction permit will establish a practically enforceable limit on the tank throughputs to demonstrate that emissions from the tanks cannot exceed the OOOO threshold. Therefore, the tanks are not affected facilities under this regulation. There are no continuous high-bleed pneumatics at the facility. Therefore, the pneumatics are not affected facilities under this regulation. Maximum Achievable Control Technology (MALT): The Facility will be a true minor source of HAPs. Thus, there are no sources at the Facility which are subject to MACT major requirements. Because there are no dehydrators or engines at the facility, area source requirements for MACT HH and MACT ZZZZ do not apply. Greenhouse Gases (GHG): Because this is a water storage facility and there are no combustion sources, GHG are expected to be negligible. Calculation Methods The facility receives post flash produced water from oil and gas operations. Emissions were estimated as follows: 1 . Hydrocarbon Liquid Storage Tanks — Emissions were calculated using E&P TANKS with a sample analysis from a similar facility. The sample is considered representative because the facility receives similar trucked in liquids. Margin was added to the throughput to allow for operational flexibility and to provide a conservative estimate. 2. Produced Water Storage Tanks — Emissions were calculated using EPA TANKS using a mixed composition of water and condensate. The liquid sample from a similar facility showed that the condensate portion of the liquid has a Reid Vapor Pressure of 3.2 psig at 100°F, corrected API Gravity of 47.0 at 60°F, and a molecular weight of 147. 12 lb/lb- mol. The sample is representative of the oil coming into the facility. While the composition is similar to crude oil, gasoline RVP 10 was conservatively used for the hydrocarbon portion of the liquid because any light end hydrocarbons present in the initial offload of the liquids would be present at the produced water system tanks. 3. Loadout — Working loss emissions from truck loading were estimated using the USEPA loadout equation from AP-42 Section 5.2, and the annual maximum volume of condensate loaded. 4. Fugitive Emissions — Process piping fugitive emissions were estimated using USEPA emission factors and estimated component counts. Appendix D Facility Emission Calculations and Supporting Documentation (4-, -� O O N M_ to O cis d u) tU) ..... V) 400 a) I. 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N N M bA b O CL, N to in rn c in N r- -- .o co cfl r., N O N w -yt r- N E L � Ts 0 O I— F— as a E N • co E tn CO r- (n I W —! CD 01 �/A I O} (D N 'Cl' �Y it Y c Z Q.O C Q N CO CO en o CO r J C V Y E O ._ c > _,,,, w _ cc: to v~-. ccs .E — p N m co a• tn W CC J r o "CI V ca a) N r-- a) cr) (.i al U E co E V � ) 'L a 'B — > C ctI I O -I En C i) C e- _ C «s Y H C it L 1— E CS 1-4 t C 0 13 O to a' 1_ o 0.' CL. CD al > a a r c a o O O C .fl O ca w .Q `o c d' O O c 0 .a C) -o oN ai `• I Z EN O �_ O H WO 0 0 d a.) 4. kr) -t O O -- N t M to -, O N U L EM U) 'i co i.+ C E U 2 L. CU CD CO 1.' o CU LL ,= o U D ^ C a to m a 'p U N V/ E , '- O > >+ 03 CNi ▪ CO E o a) Q. Z. > > at MC Co Z O Q N 0 C o -c ca O Y ch C t Na) a as �[ a> co C I E E O �° _ > Q 75 N E O a O O O In N O O (fl M M Tl CO_ C O cc 0 ii3O t n O O t n N O O O O O Q as J CC O u-i O t n t n O O O O O O O C Z •t -a — J _ c'7 C 7 N Co W c O -7Y C'1 (OO .... N (v O Z3 O Co CZ O Vi U Cl C O to i (n O a C - O > in - _ o .r X -n U v) O .— O o co co O Ry O � mO J C Q1 NocJEr �,v >,a a> o O _ co o m o c u OOOZ > N Z 000 U' U o en ...-C W3 = U LL('� C C o_ (n to ca E sue.. W ti) O C o a 2. � c `oa � o �� 0-. o C ^ rn O 'v v v C C 0 "' o ON cp .O C J 17 +-' C C i1 0 r.. O C c6 G U Y � v . . .. = O p tAL OL O M U m :c C a 5.,i_ CO Q1,O rn in O +' _O ••••• 00 _p r (qin O Q cf � � moQ m = a.' = 6o � EY � 0000 as �t mE2 o I Cn m t` ai n EP E oL C ta0UUU 03 . . .c m > > i rn _ T � of � � of -� v >o a) ..- et va.� o s a�`�'i o O = DUCnUF- 0 yCA - JQ > I- Z `n = (A (DX Cr •.- I- Ict > CL a) C ca O Hv I- a W m` a- in 4-4 d- O N (l a) M M 01) Ct O 0.. 04 N II V I gu Q N O 0 o 11 m of < to co a o O 8 u n j m > c0 In cc Q 0 p V N ~ m C C 'q 5 O O G U as W i1 4 m o 0 0 -6 Se 1So To m (Ni m rn w J (D co O � U 1 ea LL 7 cm g CT"; 0 0 is 03 Y _ -571 0 0 3 Dtie LL O m I- 0 0 a) CCI CU 0 O t CO 0 00 toa3 m Sga O = U) It W `ihm m m O C4 n M Cr) Y010 0 Y +N CQ. ; Cu `- M N Z '~ m mo (D C e Cg 0Q0 o Cn U > m cooO)C Q) Q N0 N E P oV x O 'a 0 y, ._ LL ...r co ,0 is O. _ c� •E J w v, + am m 02 N W a) ) ' to .(n '� > I N 1.r N ti m E EL tco D U E C Q j ≤ (NI� J N` V r _a d � p O cc ow > H OI m o `� E a C aJ L CZ IX H Cl) p a E czs -a C CI)C o t �" o V `m o a) co � O1 (2: — a) oN o nom_ c 0 o Q d a O a CD � CID O R gtv C.7 Z N o 9 a Q O 2la ° � H till tn -I- (0-- 0 O �. N a) M to O ccf a co el v o c o v, co ,�� to o a) o r N co MS E E cn W NZ N 76 o CI U- Q le- (U C rn E w u) o = -- U) O to to Q O ti N Cl) W = CA N CO Y it Y c c a Z p C F Cri to - O. n, M- c a Q a o a) m c�a Ce U) o CA = V J Ox > ;t CA .— >> CD 3 ca -E — U N Co Cn C a, W m o o co en .—cn CT O N ti .r 1— cv Ed N OE a E Y U, C � co 'e H C 0 = to 0 cn CZ a r LE$4,- sa C et a 0 Co 2 t O_ 2 o 0 a) It o CC (O = > N { ice inassi ` Q- Sr v O C .C v, 16 c •Kt O o O c -- cu -0 �n' CID Pa o al o o m Z o 0 0 ¢H W O O O °- ESP TANK V2 . 0 Calculation Report--- Developed by DB Robinson & Associates Ltd . 2014 . 10 . 03 * ***************************************************************************************** * Project Setup Information ****************************************************************************************** Project File : C : \Users\Jehuty\Desktop\C12 Update\TANKS Runs and Rosults\_C12 400 bbl Oil Heating 7 Model : Stable Oil Tank Calculation Method : AP42 Control Efficiency : 100 . 0% Filed Name : C12 Oil Heat Tank (1 x 400 bbl) . Modeled for one tank Well Name : C12 Date : 2014 . 10 . 03 ****************************************************************************************** * Data Input ****************************************************************************************** Separator Pressure : 23 . 00 [psig] Separator Temperature : 85 . 00 [F] Ambient Pressure : 14 . 70 [psia] Ambient Temperature : 70 . 00 [F] C10+ SG : 0 . 9240 C10+ MW : 194 . 40 -- Stable Oil No . Component mol % 1 H2S 0 . 0000 2 O2 0 . 0000 3 CO2 0 . 0000 4 N2 0 . 0000 5 Cl 0 . 0000 6 C2 0 . 0000 7 C3 0 . 0000 8 i-C4 0 . 0000 9 n-C4 0 . 0000 10 i-05 0 . 8300 11 n-05 0 . 8300 12 C6 4 . 8800 13 C7 14 . 4100 14 C8 9 . 9600 15 C9 14 . 9200 16 C10+ 39 . 7800 17 Benzene 0 . 8100 18 Toluene 4 . 2100 19 E-Benzene 0 . 2700 20 Xylenes 4 . 7700 21 n-C6 4 . 3300 22 224Trimethylp 0 . 0000 -- Sales Oil Production Rate : 600 (bbl/day] Days of Annual Operation : 365 [days/year] API Gravity : 47 . 0 Reid Vapor Pressure : 3 . 20 [psia] Bulk Temperature : 100 . 00 [F] -- Tank and Shell Data Diameter : 12 . 00 [ft] Shell Height : 20 . 00 [ft ] Cone Roof Slope : 0 . 30 Average Liquid Height : 10 . 00 [ft] Vent Pressure Range : 0 . 03 [psi] Solar Absorbance : 0 . 54 -- Meteorological Data City : Denver, CO page 1 E&P TANK V2 . 0 Calculation Report--- Developed by DB Robinson & Associates Ltd. 2014 . 10 . 03 Ambient Pressure : 14 . 70 [psia] Ambient Temperature : 70 . 00 [F] Min Ambient Temperature : 36 . 20 [F] Max Ambient Temperature : 64 . 30 [F] Total Solar Insolation : 1568 . 00 [Btu/ft^2*day] ********************************************** ******************************************** * Calculation Results * ****************************************************************************************** -- F-mission Summary Item Uncontrolled Uncontrolled [ton/yr] [lb/hr] Total HAPs 0 . 410 0 . 094 Total BC 1 . 819 0 . 415 VOCs , C2+ 1 . 819 0 . 415 VOCs , C3+ 1 . 819 0 . 415 Uncontrolled Recovery Info . Vapor 42 . 5400 x1E-3 [MSCFD] HC Vapor 42 . 5400 x1E-3 [MSCFD] GOR 0 . 07 [SCF/bbl] -- Emission Composition No Component Uncontrolled Uncontrolled [ton/yr] [lb/hr] 1 H2S 0 . 000 0 . 000 2 O2 0 . 000 0 . 000 3 CO2 0 . 000 0 . 000 4 N2 0 . 000 0 . 000 5 Cl 0 . 000 0 . 000 6 C2 0 . 000 0 . 000 7 C3 0 . 000 0 . 000 8 i-C4 0 . 000 0 . 000 9 n-C4 0 . 000 0 . 000 10 i-05 0 . 165 0 . 038 11 n-05 0 . 134 0 . 031 12 C6 0 . 374 0 . 085 13 C7 0 . 500 0 . 114 14 C8 0 . 142 0 . 032 15 C9 0 . 090 0 . 021 16 C10+ 0 . 001 0 . 000 17 Benzene 0 . 035 0 . 008 18 Toluene 0 . 070 0 . 016 19 E-Benzene 0 . 002 0 . 000 20 Xylenes 0 . 029 0 . 007 21 n-C6 0 . 276 0 . 063 22 224Trimethylp 0 . 000 0 . 000 Total 1 . 818 0 . 415 -- Stream Data No . Component MW Stable Oil Sales Oil Total Emissions mol % mol % mol % 1 H2S 34 . 80 0 . 0508 0 . 0000 0 . 0000 2 O2 32 . 00 0 . 0000 0 . 0000 0 . 0000 3 CO2 44 . 01 0 . 2437 0 . 0000 0 . 0000 4 N2 28 . 01 0 . 0102 0 . 0000 0 . 0000 5 Cl 16 . 04 0 . 9543 0 . 0000 0 . 0000 6 C2 30 . 07 0 . 6701 0 . 0000 0 . 0000 7 C3 44 . 10 2 . 1827 0 . 0000 0 . 0000 8 i-C4 58 . 12 1 . 1269 0 . 0000 0 . 0000 9 n-C4 58 . 12 4 . 6091 0 . 0000 0 . 0000 10 i-05 72 . 15 3 . 1066 0 . 8290 11 . 1943 11 n-05 72 . 15 5 . 0558 0 . 8292 9 . 0929 12 C6 86 . 16 4 . 1726 4 . 8784 21 . 7249 13 C7 100 . 20 10 . 3655 14 . 4090 25 . 1387 14 C8 114 . 23 10 . 8426 9 . 9604 6 . 2461 page 2 E&P TANK V2 . 0 Calculation Report--- Developed by DB Robinson & Associates Ltd. 2014 . 10 . 03 15 C9 128 . 28 5 . 5127 14 . 9211 3 . 5889 16 C10+ 194 . 40 45 . 9695 39 . 7838 0 . 0347 17 Benzene 78 . 11 0 . 5685 0 . 8099 2 . 2011 18 Toluene 92 . 13 0 . 2132 4 . 2101 3 . 6874 19 E-Benzene 106 . 17 0 . 0711 0 . 2700 0 . 0860 20 Xylenes 106 . 17 0 . 6802 4 . 7703 1 . 3452 21 n-C6 86 . 18 3 . 5939 4 . 3289 15 . 6599 22 224Trimethylp 114 . 24 0 . 0000 0 . 0000 0 . 0000 Mw 139 . 45 139 . 45 88 . 82 Stream Mole Ratio 1 . 0000 0 . 9999 0 . 0001 Heating Value [BTU/SCF] 4817 . 75 Gas Gravity [Gas/Air] 3 . 07 Bubble Pt . @ 100F [psia] 1 . 48 1 . 48 RVP @ 100F [psia] 10 . 09 10 . 09 SG @ 100F 0 . 807 0 . 807 page 3 In �- O •� O C) �� bA [-, c� O N C) U) 'i to ,a; cu o cos- LL V C co — Cca fn ID E o O a •N O w , O 3 y - _O A- `4- Q) It CO 1 O 0 -t 'a U) o c c E Q a rC GW a Zo F— Ce O >n >, cs CO = C CO Y O O Cl. C CO o E N +• ~ ¢ C U) C CO O O O O tL) CD O O (D c*) c�) > cCS 0 - U Y OttlOt1 Ono OO o0 ¢ E J C tf) Ln6Nr� r6 E N J co NrNrcQflt ) OO 00 I O W C « Y F- N o Nt — D ❑ C m tc') r t[) N z shC ra C 43 oa,E Cum O — O O Q) CD O .L] (n Q) )0 C O O En t .C CLS > • m O O in C f. 4 O C € O >-.1O,, >.n O :-.. r� r O Q) O O X % O L O O Cu 1/40 �O UU ❑ Z > w Z U` U` C7U` 0 v X 0 O `n CNI o cN C C a) E L rn O O m � U) aQ a • _ a) o m N �� U v -00 V 4) C <n 'n MM j o mcor O`= C c G r L m L ' •` - . , 0 CD Y N m CC O m �. Q)� Cn41 L � � � m +, Q) c 00 C~ O Q) -� O cr) in O = V O C O C a+ .--.. (n = moa ma) o = coa) 0 ' ev0000 C � m 0 Cn m ai a c� °) v -' E 'os C es _VUUU '- > ≥ a� L. _ ea a) cn �= w �' o ai O � Q o a) U a) a) o o C Q rn a m V w o Z � � UcnU � ❑ � cn0 � ¢ > F- Z �' tu n � � oF'-'2u� � ja U Q — 0 a H CO 76 tg in 4-, O -� 0 N CNI G) CIO c3 C O N II U co- il C> co O- N O O - n m L 11 N co JF in m .25 a o n .- o ..- II r- a 4 ai co> co CC Q O d m 7 N u, C C d O V m 76 Q 4 m U O O t o o 8 0 ca ea Ia 5 °i k h U O N co Ilse It O O O o yia Cy E s 1.. = j O O Q co I O- co Es o m -I LL O co ^' O O W as as as O t t (1) O O -o E L cos m NO O4 o - m O r Q rip I tn tO LO CO y , O o O r N a m z O c Y � O o a W y C N CD I"' Q a) ,}• 'L" m r o O d C 03 a o v o F-- F-O o cC v- d CO> o in CD CO CO O O a) ID el Q 0 N O N co -- {L y - = NCTx - E Jo , ain �}—.+ E LL J D 0 LL Q Y-� Jm cp b' I N W sI Cl) t XIr ON j u � 0 O t g° .471. r 5 m C N = I— d'.2, ic RS v J W R Y t. co it O_ t C RI o • m \D ~ F- 0O a i X _ .---- 0 E O ca O N a o cn co a) ii: o- w O C L o 0 CD al > Q. (1) E C) :-. d .52 � c _o to cf O m a L.,O -a a m > CA Eo0-4 5 T o OU a ° C) O O C) C--- OD ctt Q. O v1 N u) CV C Cr) o m N Nvloo r r O CU E c0 CO E co W L - Cu o0 LL Cu .O I- I-- CU C MI E 0 o u) u W co t in co 't Y S Z � cL . �c ' s < m c is C a m re _ N CZ «s v) Q (I) o c -c o ;a o 'N — -n 0 (13 O ._ C x _ E 0 CO N 'ct E W co J r wit = V m N N- In m o c) > > ,71- I Cn ..x it CZ _ Y H PTh CO R = I.. . OO O C Q Cnu'it:CU C L N Cl)) o rti O 't Q. LI- 0 W o o m '' o O a) CCc > E ca N a`) t) .fl O c y c O O OCo o Jai C-i Cn N we ni c 8 m . . N co L a g U Z E N O - v Q W U U U °- ai H in 0vil O (N a) N- to ill CL O U) Cu, U) •L a, as o I- CU LL = c o cts 03 — u) a) `° Q. T3 E o O N Q" E co O r o = ›.+ a) 4 0 -C -6 II a cn cn Q J a s o a >, n V o oup Q -- o � 'D N _ Q .N r-+ cn o 0 0 O tn �- o 0 (O CO COio «i N y c.) o 'noou, uo 00 0o Q E E c J x ouriouiuir6 Coz, Cflw Cr) r ' - O 00 00 OE W C " AYE- N0 � cu = OC13 0 v O ocn C cIn- o o C. v U C CU o O m r a`) d- > u) � a cn n 1:2 a) ..G O p � l - L £ — ctt o cu O m co Cr; o 7 O CI O N O c _I 1= O 5' O 1O >'1O O C O �O r O a) 0 O X a] co C6 00 OOOZ > N Z (3OOO O o x O O co Cl c o o ctN cn cn vi N E T . . O Q'-' W 4.4 t �, O .N �. c w as a O . . f To co ai ai co a) °a" oN �n a) fl~ p rn cy v n a c c '� Cr) E • C D -In :. aj �/ COo Y c ;1 f. = o ELI, La .c co _c o to U a) ra co c tvrnv co a! L — a) OCO C C > I O To Lb I- a -5 » in O = i O c p y a.' (n CO O W Q C N w = 6 Q) a) O ..] O O p p co C k 3 U Cn ca o a`> >:, 'A E Q £ o E 3 � = E � m sUUUU o rna ` m 2 o a, '�- co O Q) ❑ c _� Q O J a) ~ U s O o U >'d O L coO c O U z � � UcI� UF- U ccnt� � Q > HZ �' � coc41ti pl— = cl� > a. a? Q m !� d O ` a) F- W CO tn 'It 4_c ._.. O O N (N(N (1) t"-- b.() cti a 0 N 0 II CI CD N 0 O m 11 N in co m g < 1n to a o IT o 0 O a m co a m > u > o rY a Q N -O IT; C C 8- 0 0 `o o 0 0 o o 0 CD Q 0 cn M -m cci ci co rn h an a CO CNI �m rm > � !� orn O 0 4..► tv E s L C v Si o 0 00 O CU DM u_2.1 o cn lL 1— 0 0 awl CD E CO o ..).� s. nCID m moo V To N 0 0 cp E > 3 m w m O litt O na tD LO � � n 0 .y ; O 0 t 4 a 'a C Z 0. t " _ CDIN � Q m r- O T = a o 0 0 ;t F.. LL 0 C� O CO V a I- N CO Cc C C N 0 N O a 0 ri ci O .N C3 Ca Cr 0 O vac n � U) E E v, vm m a n E w -o j F-' V in W X • N ti LL lL m O CU j m 'Cr o�� (n b t o .- N CD Q2 CS J c - m T m I a /\ r. 02 N .- to d•l ° 00 H Q X lA ._..- U) O p Cl0 H ` i a v1 (1) L -- — C.L. a t▪L N t' *.. L tit a) O\ a, O > a) ac ea � � tab 046 o 0 r tag s 0 o o 8 3. C, a -p a cu s, E U 0 N o 04 O ? s m 0 O pia in O 0 'Cr N a) bA at C1. O U) OD CO LO C CO .- N. U.) v 4.0 2 Qr`O 't N E N LL N N L - c) LL O I- L Ca d w .E o_ O 'Crr CO co • W cfl o III CD co t S C E Z O c tia c a act 1— O — a) m cl Cu cn N = Y (1) C -a Ca . > O _ F— O cizs ▪ C OE cc . v 'n an E E r O ca v N. a) co N. CD cn K - N N LL o O 7:1 71- U v)C C U ct; > E— I — _ co N 00 C 3 F— X c Y Q a clo Cu y L !.L O t O N O O' N c Cl. W O > E a) te a c >> cC N A a) a_ b•A O C .Q � c O ''t _0 o O a 0 __ -13 a' C/) V) o u. 'a c "' � o m o 8 al 7 Cl) r L a 7 O > U z E N ° E o WO U O a a) E&P TANK V2 . 0 Calculation Report--- Developed by DB Robinson & Associates Ltd. 2014 . 10 . 03 * Project Setup Information * ****************************************************************************************** Project File : C : \Users\Jehuty\Desktop\C12 Update\TANKS Runs and Rosults\C12 450 bbl Oil Tank (T3) . Model : Stable Oil Tank Calculation Method : AP42 Control Efficiency : 100 . 0% Filed Name : C12 Oil Tank (1 x 400 bbl) Well Name : C12 Date . 2014 . 10 . 03 ****************************************************************************************** * Data Input * ****************************************************************************************** Separator Pressure : 23 . 00 [psig] Separator Temperature : 85 . 00 [F] Ambient Pressure : 14 . 70 [psia] Ambient Temperature : 70 . 00 [F] C10+ SG : 0 . 9240 C10+ MW : 194 . 40 -- Stable Oil No . Component mol % 1 H2S 0 . 0000 2 O2 0 . 0000 3 CO2 0 . 0000 4 N2 0 . 0000 5 Cl 0 . 0000 6 C2 0 . 0000 7 C3 0 . 0000 8 i-C4 0 . 0000 9 n-C4 0 . 0000 10 i-05 0 . 8300 11 n-05 0 . 8300 12 C6 4 . 8800 13 C7 14 . 4100 14 C8 9 . 9600 15 C9 14 . 9200 16 CIO+ 39 . 7800 17 Benzene 0 . 8100 18 Toluene 4 . 2100 19 E-Benzene 0 . 2700 20 Xylenes 4 . 7700 21 n-C6 4 . 3300 22 224Trimethylp 0 . 0000 -- Sales Oil Production Rate : 200 [bbl/day] Days of Annual Operation : 365 [days/year] API Gravity : 47 . 0 Reid Vapor Pressure : 3 . 20 (psia] Bulk Temperature : 70 . 00 [F] -- Tank and Shell Data Diameter : 12 . 00 [ft] Shell Height : 20 . 00 [ft] Cone Roof Slope : 0 . 30 Average Liquid Height : 10 . 00 [ft] Vent Pressure Range : 0 . 03 [psi] Solar Absorbance : 0 . 54 -- Meteorological Data City : Denver, CO page 1 ESP TANK V2 . 0 Calculation Report--- Developed by DB Robinson & Associates Ltd. 2014 . 10 . 03 Ambient Pressure : 14 . 70 [psia] Ambient Temperature : 70 . 00 [F] Min Ambient Temperature : 36 . 20 [F] Max Ambient Temperature : 64 . 30 [F] Total Solar Insolation . 1568 . 00 [Btu/ft' 2*day] * Calculation Results * ****************************************************************************************** -- Emission Summary Item Uncontrolled Uncontrolled Controlled Controlled [ton/yr] [lb/hr] [ton/yr] [lb/hr] Total HAPs 0 . 160 0 . 037 0 . 000 0 . 000 Total BC 0 . 702 0 . 160 0 . 000 0 . 000 VOCs , C2+ 0 . 702 0 . 160 0 . 000 0 . 000 VOCs , C3+ 0 . 702 0 . 160 0 . 000 0 . 000 Uncontrolled Recovery Info . Vapor 16 . 6500 x1E-3 [MSCFD] HC Vapor 16 . 6500 x1E-3 [MSCFD] GOR 0 . 08 [SCF/bbl] -- Emission Composition No Component Uncontrolled Uncontrolled Controlled Controlled [ton/yr] [lb/hr] [ton/yr] [lb/hr] 1 H2S 0 . 000 0 . 000 0 . 000 0 . 000 2 O2 0 . 000 0 . 000 0 . 000 0 . 000 3 CO2 0 . 000 0 . 000 0 . 000 0 . 000 4 N2 0 . 000 0 . 000 0 . 000 0 . 000 5 Cl 0 . 000 0 . 000 0 . 000 0 . 000 6 C2 0 . 000 0 . 000 0 . 000 0 . 000 7 C3 0 . 000 0 . 000 0 . 000 0 . 000 8 i-C4 0 . 000 0 . 000 0 . 000 0 . 000 9 n-C4 0 . 000 0 . 000 0 . 000 0 . 000 10 i-05 0 . 076 0 . 017 0 . 000 0 . 000 11 n-05 0 . 060 0 . 014 0 . 000 0 . 000 12 C6 0 . 152 0 . 035 0 . 000 0 . 000 13 C7 0 . 183 0 . 042 0 . 000 0 . 000 14 C8 0 . 047 0 . 011 0 . 000 0 . 000 15 C9 0 . 027 0 . 006 0 . 000 0 . 000 16 C10+ 0 . 000 0 . 000 0 . 000 0 . 000 17 Benzene 0 . 014 0 . 003 0 . 000 0 . 000 18 Toluene 0 . 024 0 . 005 0 . 000 0 . 000 19 E-Benzene 0 . 001 0 . 000 0 . 000 0 . 000 20 Xylenes 0 . 009 0 . 002 0 . 000 0 . 000 21 n-C6 0 . 109 0 . 025 0 . 000 0 . 000 22 224Trimethylp 0 . 000 0 . 000 0 . 000 0 . 000 Total 0 . 702 0 . 160 0 . 000 0 . 000 -- Stream Data No . Component MW Stable Oil Sales Oil Total Emissions mol % mol % mol % 1 H2S 34 . 80 0 . 0508 0 . 0000 0 . 0000 2 O2 32 . 00 0 . 0000 0 . 0000 0 . 0000 3 CO2 44 . 01 0 . 2437 0 . 0000 0 . 0000 4 N2 28 . 01 0 . 0102 0 . 0000 0 . 0000 5 Cl 16 . 04 0 . 9543 0 . 0000 0 . 0000 6 C2 30 . 07 0 . 6701 0 . 0000 0 . 0000 7 C3 44 . 10 2 . 1827 0 . 0000 0 . 0000 8 i-C4 58 . 12 1 . 1269 0 . 0000 0 . 0000 9 n-C4 58 . 12 4 . 6091 0 . 0000 0 . 0000 10 i-05 72 . 15 3 . 1066 0 . 8286 13 . 2102 11 n-05 72 . 15 5 . 0558 0 . 8289 10 . 3988 12 C6 86 . 16 4 . 1726 4 . 8780 22 . 5161 13 C7 100 . 20 10 . 3655 14 . 4090 23 . 5142 14 C8 114 . 23 10 . 8426 9 . 9605 5 . 2671 page 2 ESP TANK V2 . 0 Calculation Report--- Developed by DB Robinson & Associates Ltd . 2014 . 10 . 03 15 C9 128 . 28 5 . 5127 14 . 9213 2 . 7479 16 C10+ 194 . 40 45 . 9695 39 . 7844 0 . 0162 17 Benzene 78 . 11 0 . 5685 0 . 8098 2 . 1879 18 Toluene 92 . 13 0 . 2132 4 . 2101 3 . 2715 19 E-Benzene 106 . 17 0 . 0711 0 . 2700 0 . 0694 20 Xylenes 106 . 17 0 . 6802 4 . 7704 1 . 0686 21 n-C6 86 . 18 3 . 5939 4 . 3287 15 . 7320 22 224Trimethylp 114 . 24 0 . 0000 0 . 0000 0 . 0000 MW 139 . 45 139 . 45 87 . 50 Stream Mole Ratio 1 . 0000 0 . 9999 0 . 0001 Heating Value [BTU/SCF] 4752 . 21 Gas Gravity [Gas/Air] 3 . 02 Bubble Pt . @ 100F [psia] 1 . 48 1 . 48 RVP @ 100F [psia] 10 . 09 10 . 09 SG @ 100F 0 . 807 0 . 807 page 3 E&P TANK V2 . 0 Calculation Report--- Developed by DB Robinson & Associates Ltd . 2014 . 10 . 03 * Project Setup Information * ****************************************************************************************** Project File : C : \Users\Jehuty\Desktop\C12 Update\TANKS Runs and Results\C12 450 bbl Slop-Sale Oil Model : Stable Oil Tank Calculation Method : APQ2 Control Efficiency : 100 . 0% Filed Name : C12 Slop/Sale Oil Tanks (1 x 400 bbl) . Modeled for one tank Well Name . C12 Date : 2014 . 10 . 03 ****************************************************************************************** * Data Input * ****************************************************************************************** Separator Pressure : 23 . 00 [psig] Separator Temperature : 85 . 00 [F] Ambient Pressure : 14 . 70 [psia] Ambient Temperature : 70 . 00 [F] C10+ SG : 0 . 9240 C10+ MW : 194 . 40 -- Stable Oil No . Component mol % 1 H2S 0 . 0000 2 O2 0 . 0000 3 CO2 0 . 0000 4 N2 0 . 0000 5 Cl 0 . 0000 6 C2 0 . 0000 7 C3 0 . 0000 8 i-C4 0 . 0000 9 n-C4 0 . 0000 10 i-05 0 . 8300 11 n-05 0 . 8300 12 C6 4 . 8800 13 C7 14 . 4100 14 C8 9 . 9600 15 C9 14 . 9200 16 C10+ 39 . 7800 17 Benzene 0 . 8100 18 Toluene 4 . 2100 19 E-Benzene 0 . 2700 20 Xylenes 4 . 7700 21 n-C6 4 . 3300 22 224Trimethylp 0 . 0000 -- Sales Oil Production Rate : 600 [bbl/day] Days of Annual Operation : 365 [days/year] API Gravity : 47 . 0 Reid Vapor Pressure : 3 . 20 [psia] Bulk Temperature : 70 . 00 [F] -- Tank and Shell Data Diameter : 12 . 00 (ft] Shell Height : 20 . 00 [ft] Cone Roof Slope : 0 . 30 Average Liquid Height : 10 . 00 [ft ] Vent Pressure Range : 0 . 03 [psi] Solar Absorbance : 0 . 54 -- Meteorological Data City : Denver, CO page 1 ESP TANK V2 . 0 Calculation Report--- Developed by DB Robinson & Associates Ltd . 2014 . 10 . 03 Ambient Pressure : 14 . 70 [psiaj Ambient Temperature : 70 . 00 [F] Min Ambient Temperature : 36 . 20 [F] Max Ambient Temperature : 64 . 30 [F] Total Solar Insolation . 1568 . 00 [Btu/ft^2*day] * Calculation Results * ****************************************************************************************** -- Emission Summary Item Uncontrolled Uncontrolled Controlled Controlled [ton/yr] [lb/hr] [ton/yr] [lb/hr] Total HAPs 0 . 270 0 . 062 0 . 000 0 . 000 Total HC 1 . 220 0 . 279 0 . 000 0 . 000 VOCs , C2+ 1 . 220 0 . 279 0 . 000 0 . 000 VOCs, C3+ 1 . 220 0 . 279 0 . 000 0 . 000 Uncontrolled Recovery Info . Vapor 28 . 9600 x1E-3 [MSCFD] HC Vapor 28 . 9600 x1E-3 [MSCFD] GOR 0 . 05 [SCF/bbl ] -- Emission Composition No Component Uncontrolled Uncontrolled Controlled Controlled [ton/yr] [lb/hr] [ton/yr] [lb/hr] 1 H2S 0 . 000 0 . 000 0 . 000 0 . 000 2 02 0 . 000 0 . 000 0 . 000 0 . 000 3 CO2 0 . 000 0 . 000 0 . 000 0 . 000 4 N2 0 . 000 0 . 000 0 . 000 0 . 000 5 Cl 0 . 000 0 . 000 0 . 000 0 . 000 6 C2 0 . 000 0 . 000 0 . 000 0 . 000 7 C3 0 . 000 0 . 000 0 . 000 0 . 000 8 i-C4 0 . 000 0 . 000 0 . 000 0 . 000 9 n-C4 0 . 000 0 . 000 0 . 000 0 . 000 10 i-05 0 . 133 0 . 030 0 . 000 0 . 000 11 n-05 0 . 105 0 . 024 0 . 000 0 . 000 12 C6 0 . 264 0 . 060 0 . 000 0 . 000 13 C7 0 . 318 0 . 073 0 . 000 0 . 000 14 CS 0 . 082 0 . 019 0 . 000 0 . 000 15 C9 0 . 047 0 . 011 0 . 000 0 . 000 16 C10+ 0 . 000 0 . 000 0 . 000 0 . 000 17 Benzene 0 . 024 0 . 005 0 . 000 0 . 000 18 Toluene 0 . 042 0 . 010 0 . 000 0 . 000 19 E-Benzene 0 . 001 0 . 000 0 . 000 0 . 000 20 Xylenes 0 . 016 0 . 004 0 . 000 0 . 000 21 n-C6 0 . 189 0 . 043 0 . 000 0 . 000 22 224Trimethylp 0 . 000 0 . 000 0 . 000 0 . 000 Total 1 . 221 0 . 279 0 . 000 0 . 000 -- Stream Data No . Component MW Stable Oil Sales Oil Total Emissions mol % mol % mol % 1 H2S 34 . 80 0 . 0508 0 . 0000 0 . 0000 2 02 32 . 00 0 . 0000 0 . 0000 0 . 0000 3 CO2 44 . 01 0 . 2437 0 . 0000 0 . 0000 4 N2 28 . 01 0 . 0102 0 . 0000 0 . 0000 5 Cl 16 . 04 0 . 9543 0 . 0000 0 . 0000 6 C2 30 . 07 0 . 6701 0 . 0000 0 . 0000 7 C3 44 . 10 2 . 1827 0 . 0000 0 . 0000 8 i-C4 58 . 12 1 . 1269 0 . 0000 0 . 0000 9 n-C4 58 . 12 4 . 6091 0 . 0000 0 . 0000 10 i-05 72 . 15 3 . 1066 0 . 8292 13 . 2102 11 n-CS 72 . 15 5 . 0558 0 . 8294 10 . 3988 12 C6 86 . 16 4 . 1726 4 . 8789 22 . 5161 13 C7 100 . 20 10 . 3655 14 . 4094 23 . 5142 14 CS 114 . 23 10 . 8426 9 . 9603 5 . 2671 page 2 E&P TANK V2 . 0 Calculation Report--- Developed by DB Robinson & Associates Ltd. 2014 . 10 . 03 15 C9 128 . 28 5 . 5127 14 . 9208 2 . 7479 16 C10+ 194 . 40 45 . 9695 39 . 7826 0 . 0162 17 Benzene 78 . 11 0 . 5685 0 . 8099 2 . 1879 18 Toluene 92 . 13 0 . 2132 4 . 2101 3 . 2715 19 E-Benzene 106 . 17 0 . 0711 0 . 2700 0 . 0694 20 Xylenes 106 . 17 0 . 6802 4 . 7702 1 . 0686 21 n-C6 86 . 18 3 . 5939 4 . 3293 15 . 7320 22 224Trimethylp 114 . 24 0 . 0000 0 . 0000 0 . 0000 MW 139 . 45 139 . 45 87 . 50 Stream Mole Ratio 1 . 0000 0 . 9999 0 . 0001 Heating Value [BTU/SCF] 4752 . 21 Gas Gravity [Gas/Air] 3 . 02 Bubble Pt . @ 100F [psia] 1 . 48 1 . 48 RVP @ 100F [psia] 10 . 09 10 . 09 SG @ 100F 0 . 807 0 . 807 page 3 NGL Water Solutions DJ , LLC Facility: C12 Salt Water Disposal Facility Permit It: TBD AIRS ID: TBD Emission Unit ID: SUMP Description: Produced Water Unloading Sump Dimensions Width 10 ft Length 10 ft Depth 11 ft Volume 1100 (ft 3) Capacity 196 bbl (ft 3 X 0. 1781 bbl/ft3) Capacity 8228 gal Effective diameter 11 .28 ft Throughput (gal/yr) 306,600,000 Emissions* Pollutant lb/yr TPY VOC 2437.69 1 .22 Benzene 46.78 0.02 Toluene 82.50 0.04 Ethylbenzene 2.02 0.00 Xylenes 31 .05 0.02 n-Hexane 371 . 11 0.19 Methanol 0.00 0.00 *Emissions were calculated using EPA TANKS 4.0.9d and are working losses only, because the sump is below ground HAPS Speciation * Analyte Mass Benzene 1 .92% Toluene 3.38% Ethylbenzene 0.08% Xylenes 1 .27% n-Hexane 15.22% Methanol 0.00% ` Speciation from E&P Tank Results 4-, -t O O N V en b ) _M ell O O ,_.._, co N r r W O if; E Cu i5 a) _> ID a) a) c as U) £ C.) +a Y U) c 'L a) cn �„� 4••• m • 0 n CZ o. 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C4 7r 0 0 cal \(3) M as O P II. tip "O L., E _ ECD CD "ZOO) CD CI V uivv " 6r� -eu Cn Q �\ OD N O ON a in O N .- O V t: O fJ O IC O t0 S (/j el -C H ch Ct D i Q .r m J GA 30 O • - s. C m n La. -Q srn as �C O0 a) r m E r EL N C4 o' m N a 7 rn 1 mp � t -s -m ^2 o O a mug > I ;-:- Li — won, Q Q 7 m O O m in min IS CA OZm � z7aEEE � m \ aiat m -(73 � 7 7O�- a " r� Z c $ ��j 7 7 ER x .v .`C o V m \ 1- N t--- g--. �• O \D N c� O a CO un O) cD Cr- CD o D N t` tri O N o n co ,;,d E I N ui CO N w 0 0 L ci Q F-- u.. I- c .crs O -a 4-, •— °o p to • ' E .V c CO N •7 O O Y W JCN , O N �- Y C Z CD C ° _0 al a re L- �- gin is Mil Cn a) m o .o -a it J N ._- E to ._ ( cC w W in O co N Q > O ti J O O O -• Ico C') in -CI *-3O CD itT N 1` N LO Ct E E 0 vv) cn D C C C a CLS a H o CS a. cci L L t CO L O a No > o c4 a) a) a� c o � 0 -> c Q d- 0 V O c CA U) O Z ,E O Eo - O o 4c( W U U v niii - r4 NGL Water Solutions DJ , LLC Facility: C12 Salt Water Disposal Facility Permit #: TBD AIRS ID: TBD Emission Unit ID: L-1 Description: Oil Loadout Throughput (gal/yr) 9, 198,000 Saturation Factor, S* 0.6 Vapor Pressure, P (psia) ** 2.8 Vapor Molecular Weight, M (Ib/lb-mol) ** 50 Liquid Temperature, T (°F) 60 Liquid Temperature, T (°R) 520 * From AP-42 Table 5.2-1 , for tank trucks in submerged loading: dedicated normal service ** From AP42 Table 7. 1 -2, Crude Oil (RVP 5), 60 deg Loading Loss (lb VOC/1000 gal) _ (12.46*S*P*M)/T AP42 Section 5.2 (1 /95) Loading Loss (lb VOC/1000 gal) = 2.01 Loading Loss Throughput Emissions Pollutant lb/1000 gal gal/yr lb/yr TPY VOC 2.01 9, 198,000 18513.45 9.26 Benzene 0.039 9,198,000 355.27 0. 18 Toluene 0.068 9, 198,000 626.57 0.31 Ethylbenzene 0.002 9,198,000 15.32 0.01 n-Hexane 0.306 9,198,000 2818.44 1 .41 Xylenes 0.026 9, 198,000 235.85 0. 12 Methanol 0.00 9, 198,000 0.00 0.00 NGL Water Solutions DJ, LLC Facility: C12 Salt Water Disposal Facility Permit U: TBD AIRS ID: TBD Process Piping Fugitives Cakutation Hours of Total HC Total VOC Component Type Emission Factors' Source Count Percent VOC Total VOC Emissions Operation Emissions Emissions (lb/hr/source) hrs (lb/hr) (lb/hr) WY Valve-gas(oil tanks) 0.009921 6 100.00% 8760 0.06 0.06 0.26 Flanges-gas (oil tanks) 0.000860 18 100.00% 8760 0.02 0.02 0.07 Connectors -gas (oil tanks) 0.000441 75 100.00% 8760 0.03 0.03 0.14 Others-gas (oil tanks) 0.019401 12 100.00% 8760 0.23 0.23 1.02 Open-Ended Lines-gas(oil tanks) 0.004409 15 100.00% 8760 0.07 0.07 0.29 Pump Seals-gas(oil tanks) 0.005291 0 100.00% 8760 0.00 0.00 0.00 Valve-gas (PW tanks) 0.009921 0 3.00% 8760 0.00 0.00 0.00 Flanges -gas (PW tanks) 0.000860 56 3.00% 8760 0.05 0.00 0.01 Connectors-gas(PW tanks) 0.000441 112 3.00% 8760 0.05 0.00 0.01 Others -gas(PW tanks) 0.019401 8 3.00% 8760 0.16 0.00 0.02 Open-Ended Lines-gas(PW tanks) 0.004409 0 3.00% 8760 0.00 0.00 0.00 Pump Seals-gas(PW tanks) 0.005291 0 3.00% 8760 0.00 0.00 0.00 Valve-Light Oil 0.005512 32 100.00% 8760 0.18 0.18 0.77 Flanges -tight Oil 0.000243 0 100.00% 8760 0.00 0.00 0.00 Connectors -Light Oil 0.000463 191 100.00% 8760 0.09 0.09 0.39 Others -Light Oil 0.016535 6 100.00% 8760 0.10 0.10 0.43 Open-Ended Lines-Light Oil 0.000309 2 100.00% 8760 0.00 0.00 0.00 Pump Seals-Light Oil 0.028660 1 100.00% 8760 0.03 0.03 0.13 Valve -Water/Oil 0.000216 92 100.00% 8760 0.02 0.02 0.09 Flanges-Water/Oil 0.000006 234 100.00% 8760 0.00 0.00 0.01 Connectors-Water/Oil 0.000243 364 100.0C% 8760 0.09 0.09 0.39 Others -Water/Oil 0.030865 4 100.00% 8760 0.12 0.12 0.54 Open-Ended Lines-Water/Oil 0.000551 20 100.00% 8760 0.01 0.01 0.05 Pump Seals-Water/Oil 0.000053 4 100.00% 8760 0.00 0.00 0.00 Valve-Heavy Oil 0.000019 3 100.00% 8760 0.00 0.00 0.00 Flanges-Heavy Oil 0.000001 0 100.00% 8760 0.00 0.00 0.00 Connectors -Heavy Oil 0.000017 17 100.00% 8760 0.00 0.00 0.00 Others-Heavy Oil 0.000071 0 100.00% 8760 0.00 0.00 0.00 Open-Ended Lines-Heavy Oil 0.003086 3 100.00% 8760 0.01 0.01 0.04 Pump Seals-Heavy Oil 0.028660 0 100.00% 8760 0.00 0.00 0.00 •EPA-453/R-95-017, Table 2-4 1275 I TOTALS: 1.31 1.06 4.65 HAPs Component Wt% lb/hr ton/yr lb/yr 82 0.53% 0.01 0.03 61 Not Reportable of 3.27% 0.04 0.19 375 Reportable EB 0.25% 0.00 0.01 28 Not Reportable Xyl 4.27% 0.06 0.24 488 Reportable n-Hex 3.14% 0.04 0.18 360 Reportable Tank Description p of Tanks VOC wt% Oil Vessels 6 100.00% Produced Water Vessels 4 3.00% for vapor factors only Offload and Sump 1 100.00% Diesel Tank 1 100.00% Emulsion Breaker Drum 1 100.00% Fugitive component counts based on hard counts from similar facilities Emissions presented take no credit(or the AVO program NGL Water Solutions DJ, LLC C12 Salt Water Disposal Facility Specific Gravity Calc Composition used in E&P TANK modeling analysis (Wt% • SG) C10+ C10+ MW MW Specific C10+ Component Mole % Mole% Wt % Wt% MW Calc C10+ Gravity Average normalized C 1 0.00% 0.00% 16.04 0.00 0.300 0 C 2 0.00% 0.00% 30.07 0.00 0.356 0 C 3 0.00% 0.00% 44.10 0.00 0.507 0 C 4 0.00% 0.00% 58.12 0.00 0.563 0 C 4 0.00% 0.00% 58.12 0.00 0.584 0 C 5 0.00% 0.00% 72.15 0.00 0.624 0 C 5 1 .66% 0.79% 72.15 1.20 0.631 0.0050 C 6 10.02% 5.70% 86.18 8.64 0.664 0.0378 C 7 18.62% 12.31% 95.88 17.85 0.709 0.0873 C 8 15.00% 11.30% 107.35 16.10 0.740 0.0836 C 9 14.92% 12.62% 116.95 17.45 0.785 0.0991 C 10 6.81% 17.12% 6.39% 11.16% 134.00 9.13 22.95 0.779 0.0498 0.0869 C 11 5.33% 13.40% 5.49% 9.59% 147.00 7.84 19.70 0.790 0.0434 0.0758 C 12 4.23% 10.64% 4.75% 8.30% 161.00 6.81 17.12 0.801 0.0380 0.0665 C 13 3.17% 7.97% 3.86% 6.74% 175.00 5.55 13.95 0.812 0.0313 0.0547 C 14 3.19% 8.02% 4.17% 7.28% 190.00 6.06 15.24 0.823 0.0343 0.0599 C 15 2.19% 5.51% 3.06% 5.34% 206.00 4.51 11.34 0.833 0.0255 0.0445 C 16 1.95% 4.90% 2.91% 5.08% 222.00 4.33 10.89 0.840 0.0244 0.0427 C 17 1.47% 3.70% 2.32% 4.05% 237.00 3.48 8.76 0.848 0.0197 0.0344 C 18 1 .07% 2.69% 1.80% 3.14% 251.00 2.69 6.75 0.853 0.0154 0.0268 C 19 1 .31% 3.29% 2.32% 4.05% 263.00 3.45 8.66 0.858 0.0199 0.0348 C 20 0.99% 2.49% 1 .85% 3.23% 275.00 2.72 6.85 0.863 0.0160 0.0279 C 21 1 .24% 3.12% 2.43% 4.24% 291.00 3.61 9.07 0.868 0.0211 0.0368 C 22 0.90% 2.26% 1 .85% 3.23% 305.00 2.75 6.90 0.873 0.0162 0.0282 C 23 0.86% 2.16% 1 .85% 3.23% 318.00 2.73 6.88 0.878 0.0162 0.0284 C 24 0.71% 1 .79% 1 .58% 2.76% 331.00 2.35 5.91 0.882 0.0139 0.0243 C 25 0.68% 1 .71% 1 .58% 2.76% 345.00 2.35 5.90 0.886 0.0140 0.0245 C 26 0.66% 1 .66% 1 .58% 2.76% 359.00 2.37 5.96 0.890 0.0141 0.0246 C 27 0.63% 1 .58% 1.58% 2.76% 374.00 2.36 5.92 0.894 0.0141 0.0247 C 28 0.34% 0.85% 0.90% 1.57% 388.00 1.32 3.32 0.897 0.0081 0.0141 C 29 0.33% 0.83% 0.90% 1.57% 402.00 1.33 3.34 0.900 0.0081 0.0141 C 30 plus 1.71% 4.30% 4.08% 7.13% 478.00 8.17 20.55 0.917 0.0374 0.0654 Total 100.0% 100.0% 147.12 0.794 C10+ 39.77% 100.0% 57.25% 100.0% 85.89 216.0 0.840 C10+ with margin of: 10% 56.57 194.4 0.924 Parameters (MW and SG) from above calculations correlate with sample results shown below: Specific Average MW Gravity 147.16 0.794 mol% Composition less HAP Benzene C6 0.81% C6 = 4.88% Toluene C7 4.21% C7 = 14.41% Ethylbenzene C8 0.27% C8 = 9.96% Xylenes C8 4.77% C10+ = 39.77% n-hexane C6 4.33% Representative Liquid Analysis Normalized to 63.23% °/43 of Hydrocarbons Mass % Vol % MoI% Mass % Vol % Mork 1 .954 300 propane P3 0.035 0.053 0.095 0.06% 0.08% 0.15% 2.072 361 .4 14 i-butane 0.066 0.088 0.135 0.10% 0.14% 0.21 % 2.173 402.94 P4 n-butane 0.346 0.443 0.706 0.55% 0.70% 1 .12% 2.543 470.415 i-pentane 0.654 0.784 1 .076 1 .03% 1 .24% 1 .70% 2.744 497.74 P5 n-pentane 1 .079 1 .28 1 .776 1 .71% 2.02% 2.81% 3.54 564.38 16 2,3-dimethylbutane 0.27 0.303 0.372 0.43% 0.48% 0.59% 3.609 568.916 2-methylpentane 0.977 1 .11 1 .345 1 .55% 1 .76% 2.13% 3.848 583.32 16 3-methyl pentane 0.629 0.703 0.867 0.99% 1 .11% 1 .37% 4.157 600 P6 n-hexane 1 .988 2.239 2.739 3.14% 3.54% 4.33% 4.645 622.73 17 2,2-dimethylpentane 0.064 0.071 0.076 0.10% 0.11% 0.12% 4.729 626.29 N6 methylcyclopentane 0.849 0.842 1 .198 1 .34% 1 .33% 1 .89% 4.787 628.72 17 2,4-dimethylpentane 0.152 0.167 0.18 0.24% 0.26% 0.28% 5.364 650.54 A6 benzene 0.335 0.283 0.509 0.53% 0.45% 0.81% 5.453 653.6 O7 2-methyl-c-hexene-3 0.036 0.039 0.044 0.06% 0.06% 0.07% 5.599 658.5 N6 cyclohexane 0.958 0.914 1 .352 1 .52% 1 .45% 2.14% 5.841 666.26 17 2-methylhexane 0.937 1 .025 1 .11 1 .48% 1 .62% 1 .76% 5.893 667.89 17 2,3-dimethylpentane 0.254 0.272 0.301 0.40% 0.43% 0.48% 5.993 670.92 X6 t-amylmethylether 0.25 0.247 0.291 0.40% 0.39% 0.46% 6.13 674.99 17 3-methylhexane 0.953 1 .03 1 .129 1 .51 % 1 .63% 1 .79% 6.348 681 .21 N7 1c13-dimethylcyclopentane 0.261 0.26 0.316 0.41% 0.41% 0.50% 6.449 684 NT 1t,3-dimethylcyclopentane 0.307 0.305 0.372 0.49% 0.48% 0.59% 6.551 686.76 N7 1t,2-di methyl cyclopentane 0.381 0.377 0.461 0.60% 0.60% 0.73% 7.069 700 P7 n-heptane 2.582 2.804 3.059 4.08% 4.43% 4.84% 7.971 722.71 N7 methylcyclohexane 2.789 2.691 3.372 4.41% 4.26% 5.33% 8.002 723.44 — unknown 0.041 0.043 0.049 0.06% 0.07% 0.08% 8.048 724.49 18 2,2-dimethylhexane 0.162 0.173 0.169 0.26% 0.27% 0.27% 8.487 734.34 N7 ethylcyclopentane 0.231 0.224 0.279 0.37% 0.35% 0.44% 8.59 736.56 18 2,4-dimethylhexane 0.2 0.213 0.208 0.32% 0.34% 0.33% 8.881 742.65 — unknown 0.17 0.18 0.177 0.27% 0.28% 0.28% 8.935 743.75 N8 1c,2t,4-trimethylcyclopentane 0.046 0.045 0.049 0.07% 0.07% 0.08% 9.254 750. 11 O7 O37 0.132 0. 134 0.159 0.21 % 0.21% 0.25% 9.754 759.58 A7 toluene 2.068 1 .771 2.665 3.27% 2.80% 4.21% 9.973 763.56 18 2,3-dimethylhexane 0.129 0. 134 0.134 0.20% 0.21 % 0.21% 10.017 764.34 18 2-methyl-3-ethylpentane 0.075 0.078 0.078 0.12% 0.12% 0.12% 10.338 769.96 18 2-methylheptane 1 .089 1 .158 1 .132 1 .72% 1 .83% 1 .79% 10.403 771 .05 18 4-methylheptane 0.325 0.343 0.338 0.51 % 0.54% 0.53% 10.476 772.318 3,4-dimethylhexane 0.056 0.058 0.059 0.09% 0.09% 0.09% 10.762 777.05 N8 1 c,2c,4-trimethylcyclopentane 0.796 0.776 0.843 1 .26% 1 .23% 1 .33% 10.813 777.88 3-methylhf 18 0.05 0.052 0.052 0.08% 0.08% 0.08% 10.842 778.36 18 3-ethylhexane 0.83 0.864 0.863 1 .31 % 1 .37% 1 .36% 10.928 779.75 N8 1t,4-dimethylcyclohexane 0.359 0.349 0.379 0.57% 0.55% 0.60% 11 .197 784.02 N8 1 ,1-dimethylcyclohexane 0.142 0.135 0.151 0.22% 0.21% 0.24% 11 .385 786.93 19 2,2,5-trimethylhexane 0.035 0.036 0.032 0.06% 0.06% 0.05% 11 .576 789.83 N8 3t-ethylmethylcyclopentane 0.052 0.05 0.055 0.08% 0.08% 0.09% 11 .859 794.03 N8 1t,2-dimethylcyclohexane 0.325 0.311 0.343 0.51 % 0.49% 0.54% 12.274 800 P8 n-octane 2.581 2.728 2.682 4.08% 4.31% 4.24% 13.339 819.05 19 2,3,4-trimethylhexane 0.086 0.086 0.079 0. 14% 0.14% 0.12% 13.617 823.75 O9 O52 0.25 0.258 0.235 0.40% 0.41% 0.37% 14.025 830.45 — unknown 0.798 0.846 0.75 1 .26% 1 .34% 1 .19% 14.06 831 .02 19 2,2,3-trimethylhexane 0.177 0.184 0.164 0.28% 0.29% 0.26% 14.35 835.63 N8 N4 0.236 0.225 0.25 0.37% 0.36% 0.40% 14.505 838.05 19 3,3-&3,5-dimethylheptane 0.337 0.345 0.312 0.53% 0.55% 0.49% 14.604 839.59 19 2,6-dimethylheptane 0.069 0.073 0.064 0.11 % 0.12% 0.10% 15.36 850.94 N8 N7 0.291 0.277 0.308 0.46% 0.44% 0.49% 15.439 852.09 A8 ethyl benzene 0.155 0.133 0.173 0.25% 0.21% 0.27% 16.147 862.11 A8 1,3-dimethylbenzene 2.181 1.874 2.439 3.45% 2.96% 3.86% 16.212 863.01 A8 1 ,4-dimethylbenzene 0.516 0.445 0.577 0.82% 0.70% 0.91 % 16.276 863.88 19 2,3-dimethylheptane 0.036 0.037 0.034 0.06% 0.06% 0.05% 16.425 865.92 19 3,4-dimethyiheptane 0.101 0.103 0.094 0.16% 0.16% 0.15% 16.714 869.79 19 3,4-dimethylheptane 0.387 0.393 0.358 0.61 % 0.62% 0.57% 16.809 871 .06 19 15 0.468 0.476 0.433 0.74% 0.75% 0.68% 17.171 875.79 — unknown 0.111 0.118 0.103 0.18% 0.19% 0. 16% 17.295 877.39 19 3-ethylheptane 0.518 0.53 0.48 0.82% 0.84% 0.76% 17.623 881 .54 N9 1c,2t,4c-trimethylcyclohexane 0.037 0.036 0.035 0.06% 0.06% 0.06% 17.738 882.98 N9 1c,2t,3c-trim ethyl cyclohexane 0.58 0.568 0.545 0.92% 0.90% 0.86% 17.976 885.93 N9 N18 0.04 0.038 0.037 0.06% 0.06% 0.06% 18.093 887.36 N9 N19 0.344 0.328 0.324 0.54% 0.52% 0.51 % 18.222 888.93 N9 N20 0.211 0.201 0.199 0.33% 0.32% 0.31 % 18.812 895.95 N9 N22 0.044 0.042 0.041 0.07% 0.07% 0.06% 19.162 900 P9 n-nonane 2.104 2.177 1 .948 3.33% 3.44% 3.08% 19.231 901.69 N9 1 , 1-methylethylcyclohexane 0.18 0.166 0.17 0.28% 0.26% 0.27% 19.408 906.01 N9 N25 0.07 0.066 0.066 0.11% 0.10% 0.10% 19.705 913.17 A9 i-propylbenzene 0.05 0.043 0.049 0.08% 0.07% 0.08% 19.806 915.58 110 111 0.134 0.136 0.111 0.21% 0.22% 0.18% 19.911 918.06 — unknown 0.065 0.069 0.054 0.10% 0.11% 0.09% 19.986 919.83 110 112 0.036 0.037 0.03 0.06% 0.06% 0.05% 20.114 922.84 2,4-dimeth 110 0.194 0.198 0.162 0.31 % 0.31% 0.26% 20.208 925.02 110 2,2-dimethyloctane 0.039 0.039 0.032 0.06% 0.06% 0.05% 20.489 931 .51 110 2,5-dimethyloctane 0.524 0.533 0.437 0.83% 0.84% 0.69% 20.68 935.87 — unknown 0.1 0.106 0.083 0.16% 0.17% 0.13% 20.733 937.07 N9 n-butylcyclopentane 0.054 0.051 0.05 0.09% 0.08% 0.08% 20.927 941 .44 110 3,3-dimethyloctane 0.333 0.335 0.278 0.53% 0.53% 0.44% 21 .193 947.34 110 3,6-dimethyloctane 0.117 0.118 0.098 0.19% 0.19% 0.15% 21 .25 948.6 — unknown 0.083 0.088 0.07 0.13% 0.14% 0.11 % 21 .571 955.61 A9 1 ,4-methylethylbenzene 0.384 0.331 0.379 0.61% 0.52% 0.60% 21 .649 957.31 — unknown 0.145 0.154 0.144 0.23% 0.24% 0.23% 21 .747 959.41 N10 N33 0.049 0.045 0.041 0.08% 0.07% 0.06% 21 .819 960.95 -- unknown 0.035 0.037 0.029 0.06% 0.06% 0.05% 21 .854 961 .7 A9 1 ,3,5-trimethylbenzene 0.148 0. 127 0.146 0.23% 0.20% 0.23% 21 .926 963.24 110 115 0.46 0.462 0.384 0.73% 0.73% 0.61% 22.031 965.48 110 116 0.037 0.037 0.031 0.06% 0.06% 0.05% 22.092 966.77 110 5-methylnonane 0.127 0. 129 0.106 0.20% 0.20% 0.17% 22.178 968.59 110 4-methylnonane 0.316 0.317 0.264 0.50% 0.50% 0.42% 22.291 970.94 A9 1 ,2-methylethylbenzene 0.384 0.323 0.379 0.61 % 0.51% 0.60% 22.409 973.41 110 3-ethyloctane 0.051 0.051 0.043 0.08% 0.08% 0.07% 22.509 975.48 N10 N35 0.049 0.046 0.042 0.08% 0.07% 0.07% 22.559 976.52 110 3-methylnonane 0.275 0.278 0.229 0.43% 0.44% 0.36% 22.634 978.07 N10 N36 0.037 0.034 0.031 0.06% 0.05% 0.05% 22.848 982.45 A9 1 ,2,4-trimethylbenzene 0.034 0.029 0.034 0.05% 0.05% 0.05% 22.974 985.01 110 120 0.893 0.896 0.745 1 .41 % 1 .42% 1 .18% 23.06 986.75 110 121 0.185 0.186 0.154 0.29% 0.29% 0.24% 23.393 993.42 O10 2,3-dimethyloctene-2 0.048 0.048 0.04 0.08% 0.08% 0.06% 23.461 994.76 N10 1t-methyl-2-n-propylcyclohexane 0.075 0.069 0.063 0. 12% 0.11% 0.10% 23.726 1000 P10 n-decane 1 .803 1 .834 1 .505 2.85% 2.90% 2.38% 23.994 1008.73 A9 1 ,2,3-trimethylbenzene 0.102 0.085 0.101 0.16% 0.13% 0.16% 24.053 1010.63 A10 1 ,3-methyl-i-propylbenzene 0.079 0.068 0.07 0.12% 0.11% 0. 11 % 24.162 1014. 14 I11 127 0.043 0.043 0.032 0.07% 0.07% 0.05% 24.213 1015.8 111 128 0.039 0.04 0.03 0.06% 0.06% 0.05% 24.242 1016.72 — unknown 0.046 0.049 0.035 0.07% 0.08% 0.06% 24.434 1022.86 N10 sec-butylcyclohexane 0.077 0.07 0.065 0.12% 0.11 % 0.10% 24.487 1024.54 111 130 0.095 0.095 0.072 0.15% 0. 15% 0.11% 24.548 1026.47 A10 1 ,2-methyl-i-propylbenzene 0.307 0.26 0.271 0.49% 0.41 % 0.43% 24.71 1031 .59 — unknown 0.067 0.071 0.06 0.11 % 0.11% 0.09% 24.748 1032.79 N11 N40 0.252 0.234 0.194 0.40% 0.37% 0.31 % 24.877 1036.83 111 132 0.067 0.062 0.052 0.11% 0.10% 0.08% 24.932 1038.53 — unknown 0.079 0.084 0.061 0.12% 0.13% 0.10% 24.997 1040.55 A10 1 ,3-diethylbenzene 0.049 0.042 0.044 0.08% 0.07% 0.07% 25.087 1043.34 A10 1 ,3-methyl-n-propylbenzene 0.271 0.234 0.24 0.43% 0.37% 0.38% 25.213 1047.23 A10 1 ,4-diethylbenzene 0.079 0.068 0.07 0.12% 0. 11 % 0.11 % 25.247 1048.29 A10 1 ,3-dimethyl-5-ethylbenzene 0.032 0.027 0.028 0.05% 0.04% 0.04% 25.316 1050.38 A10 n-butylbenzene 0.138 0.119 0.122 0.22% 0.19% 0.19% 25.395 1052.81 Ill 134 0.038 0.039 0.029 0.06% 0.06% 0.05% 25.485 1055.55 N11 N41 0.14 0.129 0.107 0.22% 0.20% 0.17% 25.592 1058.82 111 135 0.034 0.035 0.026 0.05% 0.06% 0.04% 25.669 1061 .14I11 136 0.169 0.17 0. 129 0.27% 0.27% 0.20% 25.769 1064. 13 11 1 138 0.161 0.161 0.122 0.25% 0.25% 0.19% 25.885 1067.61 A10 1 ,4,dimethy1-2-ethylbenzene 0.241 0.204 0.213 0.38% 0.32% 0.34% 25.926 1068.85 A10 A3 0.042 0.036 0.037 0.07% 0.06% 0.06% 25.981 1070.5111 139 0.074 0.074 0.056 0.12% 0.12% 0.09% 26.082 1073.51 I11 140 0.171 0.171 0.13 0.27% 0.27% 0.21 % 26.173 1076. 18 A10 1 ,2-dimethyl-4-ethylbenzene 0.081 0.069 0.072 0. 13% 0.11 % 0. 11 % 26.483 1085.29 I11 143 0.092 0.093 0.07 0.15% 0.15% 0.11 % 26.603 1088.79 — unknown 0.062 0.066 0.047 0.10% 0.10% 0.07% 26.663 1090.53 O11 undecene-1 0.055 0.055 0.042 0.09% 0.09% 0.07% 26.72 1092.2 A10 1 ,2-dimethyl-3-ethylbenzene 0.058 0.048 0.051 0.09% 0.08% 0.08% 26.788 1094.17 All 1 ,4-methyl-t-butylbenzene 0.07 0.061 0.056 0.11 % 0.10% 0.09% 26.863 1096.31 All 1 ,2-ethyl-i-propylbenzene 0.069 0.058 0.055 0.11% 0.09% 0.09% 26.991 1100 P11 n-undecane 1 .628 1 .625 1 .236 2.58% 2.57% 1 .95% 27.097 1104.16 A10 1 ,2,4,5-tetramethylbenzene 0.039 0.033 0.035 0.06% 0.05% 0.06% 27.155 1106.44 All 1 ,2-methyl-n-butylbenzene 0.053 0.044 0.043 0.08% 0.07% 0.07% 27.258 1110.47 A10 1 ,2,3,5-tetramethylbenzene 0.037 0.031 0.033 0.06% 0.05% 0.05% 27.287 1111 .6 -- unknown 0.06 0.063 0.053 0.09% 0.10% 0.08% 27.458 1118.22 — unknown 0.068 0.072 0.06 0.11% 0.11 % 0.09% 27.491 1119.51 All 1 ,2-methyl-t-butylbenzene 0.065 0.054 0.052 0.10% 0.09% 0.08% 27.647 1125.51 -- unknown 0.04 0.043 0.032 0.06% 0.07% 0.05% 27.763 1129.97 A10 5-methylindan 0.149 0.125 0.134 0.24% 0.20% 0.21% 27.948 1137.04 All 1 ,2-ethyl-n-propylbenzene 0.237 0.197 0.19 0.37% 0.31% 0.30% 28.039 1140.46 All 1 ,3-methyl-n-butylbenzene 0.032 0.026 0.025 0.05% 0.04% 0.04% 28.155 1144.84 All s-pentylbenzene 0.05 0.042 0.04 0.08% 0.07% 0.06% 28.348 1152. 11 N12 lt-M-2-(4-MP)cyclopentane 0.086 0.08 0.061 0.14% 0.13% 0.10% 28.401 1154.1 Al2 1 ,2-di-i-propylbenzene 0.042 0.035 0.031 0.07% 0.06% 0.05% 28.468 1156.59 — unknown 0.107 0.114 0.078 0.17% 0. 18% 0.12% 28.503 1157.88 1 ,4-di-i-prc Al2 0.119 0.099 0.087 0.19% 0.16% 0.14% 28.605 1161 .69 A10 tetrahydronaphthalene 0.119 0.091 0.107 0.19% 0.14% 0.17% 28.719 1165.91 112 145 0.175 0.173 0.122 0.28% 0.27% 0.19% 28.756 1167.28 A10 naphthalene 0.04 0.029 0.037 0.06% 0.05% 0.06% 28.893 1172.31 Al2 1 ,4-ethyl-t-butylbenzene 0.174 0.145 0.127 0.28% 0.23% 0.20% 29.137 1181 .23 112 147 0.04 0.04 0.028 0.06% 0.06% 0.04% 29.231 1184.64 112 148 0.062 0.061 0.043 0.10% 0.10% 0.07% 29.337 1188.45 Al2 1 ,3-di-n-propylbenzene 0.117 0.098 0.086 0.19% 0.15% 0.14% 29.46 1192.88 O12 dodecene-1 0.065 0.064 0.046 0.10% 0.10% 0.07% 29.658 1200 P12 n-dodecane 1 .414 1 .394 0.985 2.24% 2.20% 1 .56% 29.721 1202.79 — unknown 0.037 0.04 0.026 0.06% 0.06% 0.04% 29.777 1205.28 — unknown 0.036 0.038 0.025 0.06% 0.06% 0.04% 29.923 1211 .78 Al2 1 ,3,5-triethylbenzene 0.044 0.037 0.032 0.07% 0.06% 0.05% 30.01 1215.61 — unknown 0.298 0.316 0.218 0.47% 0.50% 0.34% 30.085 1218.92 — unknown 0.052 0.055 0.038 0.08% 0.09% 0.06% 30.193 1223.65 — unknown 0.051 0.054 0.038 0.08% 0.09% 0.06% 30.313 1228.91 — unknown 0.034 0.036 0.025 0.05% 0.06% 0.04% 30.352 1230.59 Al2 1 ,2,4-triethylbenzene 0.047 0.039 0.034 0.07% 0.06% 0.05% 30.634 1242.83 Al2 1 ,4-methyl-n-pentylbenzene 0.128 0.107 0.094 0.20% 0.17% 0.15% 30.674 1244.55 — unknown 0.049 0.052 0.036 0.08% 0.08% 0.06% 30.887 1253.69 Al2 n-hexylbenzene 0.095 0.079 0.07 0.15% 0.12% 0. 11 % 30.934 1255.72 -- unknown 0.095 0.1 0.069 0.15% 0. 16% 0.11% 31 .042 1260.33 — unknown 0.187 0.198 0.137 0.30% 0.31% 0.22% 31 .151 1264.97 — unknown 0.154 0.163 0.112 0.24% 0.26% 0.18% 31 .201 1267.07 — unknown 0.035 0.037 0.025 0.06% 0.06% 0.04% 31 .309 1271 .64 113 150 0. 128 0.125 0.082 0.20% 0.20% 0.13% 31 .406 1275.74 All 1 ,213,4,5-pentamethylbenzene 0.216 0.16 0.173 0.34% 0.25% 0.27% 31 .696 1287.89 — unknown 0.207 0.22 0.166 0.33% 0.35% 0.26% 31 .788 1291 .68 O13 tridecene-1 0.034 0.033 0.022 0.05% 0.05% 0.03% 31 .81 1292.61 — unknown 0.043 0.045 0.028 0.07% 0.07% 0.04% 31 .896 1296. 16 All 1-methylnaphthalene 0.036 0.027 0.03 0.06% 0.04% 0.05% 31 .988 1300 P13 n-tridecane 1 .189 1 .167 0.765 1 .88% 1 .85% 1 .21 % 32.064 1303.68 + C14+ 0.106 0.103 0.064 0.17% 0. 16% 0.10% 32.292 1314.8 + C14+ 0.039 0.038 0.024 0.06% 0.06% 0.04% 32.348 1317.52 + C14+ 0.041 0.04 0.025 0.06% 0.06% 0.04% 32.387 1319.41 + C14+ 0.085 0.083 0.051 0.13% 0.13% 0.08% 32.745 1336.63 + C14+ 0.06 0.058 0.036 0.09% 0.09% 0.06% 32.827 1340.54 + C14+ 0.055 0.054 0.033 0.09% 0.09% 0.05% 32.987 1348. 17 + C14+ 0. 158 0.154 0.094 0.25% 0.24% 0.15% 33.058 1351 .5 + C14+ 0.091 0.088 0.054 0.14% 0. 14% 0.09% 33.119 1354.4 + C14+ 0.063 0.061 0.038 0.10% 0.10% 0.06% 33.225 1359.41 + C14+ 0.099 0.096 0.059 0.16% 0.15% 0.09% 33.331 1364.41 + C14+ 0.121 0. 118 0.072 0.19% 0.19% 0.11% 33.479 1371 .34 + C14+ 0.118 0.115 0.071 0.19% 0.18% 0.11 % 33.542 1374.25 + C14+ 0.036 0.035 0.021 0.06% 0.06% 0.03% 33.655 1379.51 + C14+ 0.22 0.214 0.132 0.35% 0.34% 0.21% 34.098 1400 + C14+ 0.954 0.929 0.571 1 .51 % 1 .47% 0.90% 34.166 1400 + C14+ 0.041 0.04 0.024 0.06% 0.06% 0.04% 34.184 1400 + C14+ 0.053 0.051 0.032 0.08% 0.08% 0.05% 34.286 1400 + C14+ 0.062 0.061 0.037 0.10% 0. 10% 0.06% 34.437 1400 + C14+ 0.099 0.097 0.059 0. 16% 0.15% 0.09% 34.517 1400 + C14+ 0.073 0.071 0.044 0.12% 0.11 % 0.07% 34.844 1400 + C14+ 0.047 0.045 0.028 0.07% 0.07% 0.04% 35.125 1400 + C14+ 0.137 0.133 0.082 0.22% 0.21% 0.13% 35.234 1400 + C14+ 0.057 0.055 0.034 0.09% 0.09% 0.05% 35.357 1400 + C14+ 0.319 0.311 0.191 0.50% 0.49% 0.30% 35.48 1400 + C14+ 0.071 0.069 0.042 0. 11 % 0.11 % 0.07% 35.624 1400 + C14+ 0.049 0.048 0.03 0.08% 0.08% 0.05% 35.718 1400 + C14+ 0.044 0.043 0.026 0.07% 0.07% 0.04% 36.05 1400 + C14+ 0.906 0.881 0.542 1 .43% 1 .39% 0.86% 36.13 1400 + C14+ 0.038 0.037 0.023 0.06% 0.06% 0.04% 36.223 1400 + C14+ 0.044 0.043 0.026 0.07% 0.07% 0.04% 36.314 1400 + C14+ 0.052 0.051 0.031 0.08% 0.08% 0.05% 36.559 1400 + C14+ 0.034 0.034 0.021 0.05% 0.05% 0.03% 36.669 1400 + C14+ 0.047 0.045 0.028 0.07% 0.07% 0.04% 36.896 1400 + C14+ 0.044 0.043 0.027 0.07% 0.07% 0.04% 37.076 1400 + C14+ 0.048 0.047 0.029 0.08% 0.07% 0.05% 37.109 1400 + C14+ 0.094 0.092 0.056 0. 15% 0.15% 0.09% 37.203 1400 + C14+ 0.091 0.089 0.055 0.14% 0.14% 0.09% 37.296 1400 + C14+ 0.062 0.061 0.037 0.10% 0.10% 0.06% 37.344 1400 + C14+ 0.063 0.061 0.038 0.10% 0.10% 0.06% 37.59 1400 + O14+ 0.039 0.038 0.023 0.06% 0.06% 0.04% 37.734 1400 + C14+ 0.041 0.04 0.025 0.06% 0.06% 0.04% 37.876 1400 + C14+ 0.756 0.736 0.453 1 .20% 1 .16% 0.72% 38.657 1400 + C14+ 0.067 0.065 0.04 0.11 % 0.10% 0.06% 38.77 1400 + C14+ 0.209 0.204 0.125 0.33% 0.32% 0.20% 38.88 1400 + C14+ 0.046 0.045 0.028 0.07% 0.07% 0.04% 38.975 1400 + C14+ 0.084 0.082 0.05 0.13% 0.13% 0.08% 39.121 1400 + C14+ 0.051 0.049 0.03 0.08% 0.08% 0.05% 39.671 1400 + C14+ 0.645 0.628 0.386 1 .02% 0.99% 0.61% 39.851 1400 + C14+ 0.232 0.226 0. 139 0.37% 0.36% 0.22% 63.22 63.23 63.23 100.00% 100.00% 100.00% TECHNOLOGY LABORATORY, INC. / ENTRE PROFESSIONAL OFFICE PARK 1012 Centre Avenue / Fort Collins, Colorado 80526 (970) 490-1414 CERTIFICATE OF ANALYSIS CGRS Sampled: 06/15/09 PO Box 1489 Received: 06/15/09 Fort Collins, CO 80522 Analyzed: 06/18/09 Sample ID: Separation Tank Project #: 1-8019-10695aa Laboratory ID: 8S28-03 Matrix: Water HAZARDOUS AIR POLLUTANTS CAS Concentration Concentration Number Compound Analyzed (mo/L) (°/0 Wt/ Wt) 71-43-2 Benzene 1070 0.1070 108-88-3 Toluene 6246 0.6246 100-41-4 Ethylbenzene 931 0.0931 1330-20-7 Total Xylenes 10161 1.0161 1634-04-4 MTBE Non Detected 0.0000 91-20-3 Naphthalene 177 0.0177 540-84-1 Iso-Octane Non Detected 0.0000 110-543 n-Hexane 11909 1.1909 98-82-8 Isopropylbenzene 247 0.0247 QA/QC SURROGATE RECOVERIES Compound % Recovery % Rec. Limits Dibromofluoromethane 89 68-120 1,2 Dichloroethane-c14 86 70-119 Toluene-d8 96 80-114 Page 2 of 20 TECHNOLOGY LABORATORY, INC. CENTRE PROFESSIONAL OFFICE PARK / 1012 Centre Avenue Fort Collins, Colorado 80526 (970) 490-1414 CERTIFICATE OF ANALYSIS CGRS, INC. Sampled: 06/15/09 PO Box 1489 Received: 06/15/09 Fort Collins, CO 80522 Sample ID: Separation Tank-001 Project No. : 1-8019-10695aa Laboratory ID: 8528-03 Matrix: Water Date Parameter Result Units % Wt/Wt Method Analyzed DRO (TEPH) 7942 mg/L 0.7942 EPA-8015B 06/17/09 Methanol <10.0 mg/L 0.0000 EPA-8015B 06/16/09 Modified GRO (TVPH) 438342 mg/L 43.8342 EPA-8260B 06/18/09 Page 4 of 20 Detailed Hydrocarbon Analysis Summary Report - Report Date: 6/18/2009 11:38:08 AM RawFile: C:1Chem3211\DATA\TLIIDHA-061709-8528-02.D\DHA-061709-852802.CDF Acquired: 06/17/09 11 :15:44 Sample: Condensate-001 Analyzed: 6/18/2009 11 :31 :41 AM Processed 233 Peaks Reference File: C:\Chem3211\DHAReRPONA-V1.DHA Comments: Normalized to 63.2300% SUMMARY REPORT Group Type TotalfMase/01 Total(Vor/o) Total(MoI%) Paraffins: 16.7489 17.7420 17.4960 I-Paraffins: 15.1992 16.0238 15.8027 Olefins: 0.6206 0.6299 0.5896 Napthenes: 10.3480 9.9832 11 .7975 Aromatics: 9.7136 8.2373 10.2396 Total C14+: 6.9938 6.8074 4.1851 Total Unknowns: 3.3556 3.5592 2.8287 Oxygenates: Total: 0.2503(Mass%) 0.2473(Vol%) Total Oxygen Content: 0.0392(Mass%) Mullisubstituted Aromatics: 6.4361(Mass%) 5.4603(Vo1%) Average Molecular Weight: 118.2459 Relative Density: 0.7395 Vapor Pressure: 1 .9843 Calculated Octane Number: 62.2351 IBP T10 T50 T90 FBP Billing Point (Deg F) 82.11 195.80 391 .50 T90 488.66 Percent Carbon: 85.8715 Percent Hydrogen: 14.0893 Bromine Number (Calc): 0.4324 Page 5 of 20 Created with novaPDF Printer (www.novaPDF.com). Please register to remove this message. Detailed Hydrocarbon Analysis Detail Report - Report Date: 6/18/2009 11:38:35 AM RawFile: C:1Chem3211lDATA\TL11DHA-061709-8528-02.D1DHA-061709-8528-02.CDF Acquired: 06/17/09 11 :15:44 Sample: Condensate-001 Analyzed: 6/18/2009 11:31:41 AM Processed 233 Peaks Reference File: C:1Chern32111DHARef1PONA-VI.DHA Comments: Normalized to 63.2300% Molecular Weight and Relative Density Data Group Avg Mw_ Avg Rel. Density Cl 0.000 0.000 C2 0.000 0.000 C3 44.097 0.501 C4 58. 124 0.575 C5 72. 151 0.624 C6 85.075 0.697 C7 97.871 0.741 C8 111 .527 0.755 C9 126.460 0.753 C10 140. 135 0.766 Cl 1 154.203 0.781 C12 167.767 0.790 C13 184.318 0.757 Total Sample: 118.00 0.74 Octane Number Research Octane Number: 62.20 (Calculated from Individual Component Values) Contribution to Total by: Paraffins: 12.90 Iso-Paraffins: 18.20 Aromatics: 17.50 Napthenes: 12.50 Olefins: 0.82 Oxygenates: 0.40 Page 6 of 20 Created with novaPDF Printer (www.novaPDF.com). 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Detailed Hydrocarbon Analysis Detail Report - Report Date: 6/18/2009 11:38:35 AM RawFile: C:\Chem32111DATA\TLI1DHA-061709-8528-02.D1DHA-061709-8528-02.CDF Acquired: 06/17/09 11:15:44 Sample: Condensate-001 Analyzed: 6/18/2009 11 :31 :41 AM Processed 233 Peaks Reference File: C:\Chem32\1\DHARet1PONA-VI.DHA Comments: Normalized to 63.2300% Totals by Group Type & Carbon Number (in Mass Percent) Paraffins I-Paraffins Olefins Napthenes Aromatics Total Cl 0.00000 0.00000 0.00000 0.00000 0.00000 0.00000 C2 0.00000 0.00000 0.00000 0.00000 0.00000 0.00000 C3 0.03541 0.00000 0.00000 0.00000 0.00000 0.03541 C4 0.34550 0.06608 0.00000 0.00000 0.00000 0.41158 C5 1.07932 0.65402 0.00000 0.00000 0.00000 1 .73334 C6 1.98812 1 .87623 0.00000 1.80740 0.33487 6.00662 C7 2.58211 2.36062 0.16795 3.97004 2.06811 11.14883 C8 2.58079 2.91737 0.00000 2.24663 2.85199 10.59679 C9 2.10419 2.21533 0.25022 1 .56046 1 .10238 7.23258 C10 1 .80340 3.72118 0.04782 0.28619 1 .76131 7.61991 C11 1 .62794 0.98366 0.05522 0.39113 0.82801 3.88597 C12 1 .41356 0.27707 0.06493 0.08611 0.76687 2.60855 C13 1 .18855 0.12768 0.03447 0.00000 0.00000 1 .35069 Total: 16.74889 15.19925 0.62061 10.34797 9.71355 52.63026 Oxygenates 0.25034 Total C14+: 6.99378 Total Unknowns: 3.35562 Grand Total: 63.23000 Totals by Group Type & Carbon Number (in Volume Percent) Paraffins I-Paraffins Olefins Napthenes Aromatics Total C 1 0.00000 0.00000 0.00000 0.00000 0.00000 0.00000 C2 0.00000 0.00000 0.00000 0.00000 0.00000 0.00000 C3 0.05253 0.00000 0.00000 0.00000 0.00000 0.05253 C4 0.44320 0.08805 0.00000 0.00000 0.00000 0.53125 C5 1 .27972 0.78372 0.00000 0.00000 0.00000 2.06343 C6 2.23857 2.11695 0.00000 1 .75609 0.28289 6.39451 C7 2.80406 2.56525 0.17211 3.85725 1 .77106 11 .16972 C8 2.72763 3.07417 0.00000 2.16750 2.45148 10.42077 C9 2.17711 2.26289 0.25817 1 .49502 0.93868 7.13187 C10 1 .83420 3.75228 0.04798 0.26438 1 .48350 7.38235 C11 1 .62459 0.98188 0.05464 0.36300 0.66984 3.69395 C12 1.39379 0.27320 0.06357 0.07992 0.63984 2.45031 C13 1.16666 0.12539 0.03342 0.00000 0.00000 1 .32547 Total: 17.74205 16.02378 0.62989 9.98316 8.23728 52.61617 Oxygenates 0.24726 Total C14+: 6.80737 Total Unknowns: 3.55920 Grand Total: 63.23000 Page 7 of 20 Created with novaPDF Printer (www.novaPDF.com). 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Detailed Hydrocarbon Analysis Detail Report - Report Date: 6/18/2009 11:38:35 AM RawFile: C:1Chem32111DATAVTLIIDHA-061709-8528-02.D\DHA-061709-8528-02.CDF Acquired: 06/17/09 11:15:44 Sample: Condensate-001 Analyzed: 6/18/2009 11 :31 :41 AM Processed 233 Peaks Reference File: C:1Chem32l1\DHAReRPONA-VI.DHA Comments: Normalized to 63.2300% Totals by Group Type & Carbon Number (in MoI Percent) Paraffins I-Paraffins Olefins Napthenes Aromatics Total c 1 0.00000 0.00000 0.00000 0.00000 0.00000 0.00000 C2 0.00000 0.00000 0.00000 0.00000 0.00000 0.00000 C3 0.09532 0.00000 0.00000 0.00000 0.00000 0.09532 C4 0.70567 0.13497 0.00000 0.00000 0.00000 0.84064 C5 1 .77589 1 .07612 0.00000 0.00000 0.00000 2.85200 C6 2.73877 2.58463 0.00000 2.54946 0.50893 8.38179 C7 3.05910 2.79670 0.20306 4.80000 2.66453 13.52339 C8 2.68210 3.03189 0.00000 2.37677 3.18907 11 .27982 C9 1 .94762 2.05050 0.23531 1.46742 1 .08882 6.78967 C10 1 .50466 3.10476 0.04047 0.24221 1 .56313 6.45524 C11 1 .23638 0.74774 0.04249 0.30095 0.66414 2.99169 C12 0.98516 0.19315 0.04580 0.06074 0.56103 1 .84587 C13 0.76531 0.08221 0.02244 0.00000 0.00000 0.86996 Total: 17.49599 15.80265 0.58956 11 .79754 10.23964 55.92538 Oxygenates 0.29085 Total C144-: 4.18505 Total Unknowns: 2.82871 Grand Total: 63.23000 Page 8 of 20 Created with novaPDF Printer (www.novaPDF.com). Please register to remove this message. Detailed Hydrocarbon Analysis Detail Report - Report Date: 6/18/2009 11:38:35 AM RawFile: C:1Chem32111DATA\TLIIDHA-061709-8528-02.DIDHA-061709-8528-02.CDF Acquired: 06/17/09 11 :15:44 Sample: Condensate-001 Analyzed: 6/18/2009 11:31:41 AM Processed 233 Peaks Reference File: C:1Che n32111DHAReRPONA-VI.DHA Comments: Normalized to 63.2300% NOTE: Components with a Weight % of Less Than 0.01 Not Reported. Components Listed in Chromatographic Order Page: 5 Minutes Index Group Component Mass % Volume % Mol % 1 .954 300.000 P3 propane 0.035 0.053 0.095 2.072 361 .400 14 i-butane 0.066 0.088 0.135 2.173 402.940 P4 n-butane 0.346 0.443 0.706 2.543 470.400 15 i-pentane 0.654 0.784 1 .076 2.744 497.740 P5 n-pentane 1 .079 1 .280 1 .776 3.540 564.380 16 2,3-dimethylbutane 0.270 0.303 0.372 3.609 568.900 16 2-methylpentane 0.977 1 . 110 1 .345 3.848 583.320 16 3-methylpentane 0.629 0.703 0.867 4.157 600.000 P6 n-hexane 1 .988 2.239 2.739 4.645 622.730 17 2,2-dimethylpentane 0.064 0.071 0.076 4.729 626.290 N6 methylcyclopentane 0.849 0.842 1 .198 4.787 628.720 17 2,4-dimethylpentane 0.152 0. 167 0.180 5.364 650.540 A6 benzene 0.335 0.283 0.509 5.453 653.600 O7 2-methyl-c-hexene-3 0.036 0.039 0.044 5.599 658.500 N6 cyclohexane 0.958 0.914 1 .352 5.841 666.260 (7 2-methylhexane 0.937 1 .025 1 .110 5.893 667.890 17 2,3-dimethylpentane 0.254 0.272 0.301 5.993 670.920 X6 t-amylmethylether 0.250 0.247 0.291 6.130 674.990 17 3-methylhexane 0.953 1 .030 1 .129 6.348 681 .210 N7 1 c,3-dimethylcyclopentane 0.261 0.260 0.316 6.449 684.000 N7 1t,3-dimethylcyclopentane 0.307 0.305 0.372 6.551 686.760 N7 lt,2-dimethylcyclopentane 0.381 0.377 0.461 7.069 700.000 P7 n-heptane 2.582 2.804 3.059 7.971 722.710 N7 methylcyclohexane 2.789 2.691 3.372 8.002 723.440 _ unknown 0.041 0.043 0.049 8.048 724.490 (8 2,2-dimethylhexane 0.162 0. 173 0.169 8.487 734.340 N7 ethylcyclopentane 0.231 0.224 0.279 8.590 736.560 18 2,4-dimethylhexane 0.200 0.213 0.208 8.881 742.650 — unknown 0.170 0. 180 0.177 8.935 743.750 N8 1 c,2t,4-trimethylcyclopentane 0.046 0.045 0.049 9.254 750. 110 O7 O37 0.132 0. 134 0.159 9.754 759.580 A7 toluene 2.068 1 .771 2.665 9.973 763.560 I8 2,3-dimethylhexane 0.129 0. 134 0. 134 10.017 764.340 18 2-methyl-3-ethylpentane 0.075 0.078 0.078 10.338 769.960 18 2-methylheptane 1 .089 1 .158 1 .132 10.403 771 .050 18 4-methylheptane 0.325 0.343 0.338 10.476 772.300 18 3,4-dimethylhexane 0.056 0.058 0.059 10.762 777.050 N8 1c,2c,4-trimethylcyclopentane 0.796 0.776 0.843 Page 9 of 20 Created with novaPDF Printer (www.novaPDF.com). Please register to remove this message. Detailed Hydrocarbon Analysis Detail Report - Report Date: 6/18/2009 11:38:35 AM RawFile: C:1Chem32111DATAITLIIDHA-061709-8528-02.DIDHA-061709-8528-02.CDF Acquired: 06/17/09 11:15:44 Sample: Condensate-001 Analyzed: 6/18/2009 11:31 :41 AM Processed 233 Peaks Reference File: C:1Chem32111DHAReRPONA-VI.DHA Comments: Normalized to 63.2300% NOTE: Components with a Weight % of Less Than 0.01 Not Reported. Components Listed in Chromatographic Order Page: 6 Minutes Index Group Component Mass % Volume % Mol % 10.813 777.880 18 3-methylheptane 0.050 0.052 0.052 10.842 778.360 18 3-ethylhexane 0.830 0.864 0.863 10.928 779.750 Ng 1t,4-dimethylcyclohexane 0.359 0.349 0.379 11 .197 784.020 N8 1 , 1 -dimethylcyclohexane 0.142 0. 135 0.151 11 .385 786.930 19 2,2,5-trimethylhexane 0.035 0.036 0.032 11 .576 789.830 N8 3t-ethylmethylcyclopentane 0.052 0.050 0.055 11 .859 794.030 N8 1t,2-dimethylcyclohexane 0.325 0.311 0.343 12.274 800.000 pg n-octane 2.581 2.728 2.682 13.339 819.050 19 2,3,4-trimethylhexane 0.086 0.086 0.079 13.617 823.750 O9 O52 0.250 0.258 0.235 14.025 830.450 __ unknown 0.798 0.846 0.750 14.060 831 .020 19 2,2,3-trimethylhexane 0. 177 0. 184 0.164 14.350 835.630 N8 N4 0.236 0.225 0.250 14.505 838.050 19 3,3-&3,5-dimethylheptane 0.337 0.345 0.312 14.604 839.590 19 2,6-dimethylheptane 0.069 0.073 0.064 15.360 850.940 N8 N7 0.291 0.277 0.308 15.439 852.090 A8 ethylbenzene 0.155 0. 133 0.173 16.147 862.110 A8 1 ,3-dimethylbenzene 2.181 1 .874 2.439 16.212 863.010 A8 1 ,4-dimethylbenzene 0.516 0.445 0.577 16.276 863.880 19 2,3-dimethylheptane 0.036 0.037 0.034 16.425 865.920 19 3,4-dimethylheptane 0.101 0. 103 0.094 16.714 869.790 19 3,4 -dimethylheptane 0.387 0.393 0.358 16.809 871 .060 19 15 0.468 0.476 0.433 17.171 875.790 _ unknown 0.111 0. 118 0.103 17.295 877.390 19 3-ethylheptane 0.518 0.530 0.480 17.623 881 .540 N9 1 c,2t,4c-trimethylcyclohexane 0.037 0.036 0.035 17.738 882.980 N9 1 c,2t,3c-trimethylcyclohexane 0.580 0.568 0.545 17.976 885.930 N9 N18 0.040 0.038 0.037 18.093 887.360 N9 N19 0.344 0.328 0.324 18.222 888.930 N9 N20 0.211 0.201 0.199 18.812 895.950 Ng N22 0.044 0.042 0.041 19.162 900.000 pg n-nonane 2.104 2. 177 1 .948 19.231 901 .690 N9 1 ,1 -methylethylcyclohexane 0.180 0.166 0.170 19.408 906.010 N9 N25 0.070 0.066 0.066 19.705 913.170 A9 i-propylbenzene 0.050 0.043 0.049 19.806 915.580 110 111 0.134 0. 136 0.111 19.911 918.060 __ unknown 0.065 0.069 0.054 19.986 919.830 110 112 0.036 0.037 0.030 Page 10 of 20 Created with novaPDF Printer (www.novaPDF.com). Please register to remove this message. Detailed Hydrocarbon Analysis Detail Report - Report Date: 6/18/2009 11:38:35 AM RawFile: C:1Chem32111DATA1TLIIDHA-061709-8528-02.D1DHA-061709-8528-02.CDF Acquired: 06/17/09 11:15:44 Sample: Condensate-001 Analyzed: 6/18/2009 11 :31 :41 AM Processed 233 Peaks Reference File: C:1Chem32111DHARef1PONA-VI_DHA Comments: Normalized to 63.2300% NOTE: Components with a Weight % of Less Than 0.01 Not Reported. Components Listed in Chromatographic Order Page: 7 Minutes Index Group Component Mass % Volume % Mol % 20. 114 922.840 110 2,4-dimethyloctane 0.194 0. 198 0.162 20.208 925.020 110 2,2-dimethyloctane 0.039 0.039 0.032 20.489 931 .510 110 2,5-dimethyloctane 0.524 0.533 0.437 20.680 935.870 _ unknown 0.100 0.106 0.083 20.733 937.070 N9 n-butylcyclopentane 0.054 0.051 0.050 20.927 941 .440 110 3,3-dimethyloctane 0.333 0.335 0.278 21 . 193 947.340 110 3,6-dimethyloctane 0. 117 0. 118 0.098 21 .250 948.600 _ unknown 0.083 0.088 0.070 21 .571 955.610 A9 1 ,4-methylethylbenzene 0.384 0.331 0.379 21 .649 957.310 __ unknown 0.145 0. 154 0.144 21 .747 959.410 N10 N33 0.049 0.045 0.041 21 .819 960.950 __ unknown 0.035 0.037 0.029 21 .854 961 .700 A9 1 ,3,5-trimethylbenzene 0.148 0. 127 0.146 21 .926 963.240 110 115 0.460 0.462 0.384 22.031 965.480 110 116 0.037 0.037 0.031 22.092 966.770 110 5-methylnonane 0.127 0.129 0.106 22. 178 968.590 110 4-methylnonane 0.316 0.317 0.264 22.291 970.940 A9 1 ,2-methylethylbenzene 0.384 0.323 0.379 22.409 973.410 110 3-ethyloctane 0.051 0.051 0.043 22.509 975.480 N10 N35 0.049 0.046 0.042 22.559 976.520 110 3-methylnonane 0.275 0.278 0.229 22.634 978.070 N10 N36 0.037 0.034 0.031 22.848 982.450 A9 1 ,2,4-trimethylbenzene 0.034 0.029 0.034 22.974 985.010 110 120 0.893 0.896 0.745 23.060 986.750 110 121 0.185 0.186 0.154 23.393 993.420 O10 2,3-dimethyloctene-2 0.048 0.048 0.040 23.461 994.760 N10 1t-methyl-2-n-propylcyclohexane0.075 0.069 0.063 23.726 1000.000 P10 n-decane 1 .803 1 .834 1 .505 23.994 1008.730 A9 1 ,2,3-trimethylbenzene 0.102 0.085 0.101 24.053 1010.630 A10 1 ,3-methyl-i-propylbenzene 0.079 0.068 0.070 24. 162 1014.140111 127 0.043 0.043 0.032 24.213 1015.800 111 128 0.039 0.040 0.030 24.242 1016.720 _- unknown 0.046 0.049 0.035 24.434 1022.860 N10 sec-butylcyclohexane 0.077 0.070 0.065 24.487 1024.540111 130 0.095 0.095 0.072 24.548 1026.470 A10 1 ,2-methyl-i-propylbenzene 0.307 0.260 0.271 24.710 1031 .590 _ unknown 0.067 0.071 0.060 24.748 1032.790 N11 N40 0.252 0.234 0.194 Page 11 of 20 Created with novaPDF Printer (www.novaPDF.com). Please register to remove this message. Detailed Hydrocarbon Analysis Detail Report - Report Date: 6/18/2009 11 :38:35 AM RawFile: C:1Chem32111DATA\TLIIDHA-061709-8528-02.D1DHA-061709-8528-02.CDF Acquired: 06/17/09 11 :15:44 Sample: Condensate-001 Analyzed: 6/18/2009 11 :31 :41 AM Processed 233 Peaks Reference File: C:1Chem32111DHARet1PONA-VI.DHA Comments: Normalized to 63.2300% NOTE: Components with a Weight % of Less Than 0.01 Not Reported. Components Listed in Chromatographic Order Page: 8 Minutes Index Group Component Mass % Volume % Mol % 24.877 1036.830111 132 0.067 0.062 0.052 24.932 1038.530 __ unknown 0.079 0.084 0.061 24.997 1040.550 A10 1 ,3-diethylbenzene 0.049 0.042 0.044 25.087 1043.340 A10 1 ,3-methyl-n-propylbenzene 0.271 0.234 0.240 25.213 1047.230 A10 1 ,4-diethylbenzene 0.079 0.068 0.070 25.247 1048.290 A10 1 ,3-dimethyl-5-ethylbenzene 0.032 0.027 0.028 25.316 1050.380 A10 n-butylbenzene 0.138 0. 119 0.122 25.395 1052.810 111 134 0.038 0.039 0.029 25.485 1055.550 N11 N41 0.140 0.129 0.107 25.592 1058.820 i11 135 0.034 0.035 0.026 25.669 1061 .140 i11 136 0.169 0.170 0.129 25.769 1064.130 111 138 0.161 0.161 0.122 25.885 1067.610 A10 1 ,4,dimethy1-2-ethylbenzene 0.241 0.204 0.213 25.926 1068.850 A10 A3 0.042 0.036 0.037 25.981 1070.500111 139 0.074 0.074 0.056 26.082 1073.510 111 140 0. 171 0. 171 0.130 26.173 1076.180 A10 1 ,2-dimethyl-4-ethylbenzene 0.081 0.069 0.072 26.483 1085.290 111 143 0.092 0.093 0.070 26.603 1088.790 __ unknown 0.062 0.066 0.047 26.663 1090.530 O11 undecene-1 0.055 0.055 0.042 26.720 1092.200 A10 1 ,2-dimethyl-3-ethylbenzene 0.058 0.048 0.051 26.788 1094. 70 A11 1 ,4-methyl-t-butylbenzene 0.070 0.061 0.056 26.863 1096.310 A11 1 ,2-ethyl-i-propylbenzene 0.069 0.058 0.055 26.991 1100.000 P11 n-undecane 1 .628 1 .625 1 .236 27.097 1104.160 A10 1 ,2,4,5-tetramethylbenzene 0.039 0.033 0.035 27. 155 1106.440 A11 1 ,2-methyl-n-butylbenzene 0.053 0.044 0.043 27.258 1110.470 A10 1 ,2,3,5-tetramethylbenzene 0.037 0.031 0.033 27.287 1111 .600 -- unknown 0.060 0.063 0.053 27.458 1118.220 __ unknown 0.068 0.072 0.060 27.491 1119.510 All 1 ,2-methyl-t-butylbenzene 0.065 0.054 0.052 27.647 1125.510 _- unknown 0.040 0.043 0.032 27.763 1129.970 A10 5-methylindan 0.149 0.125 0.134 27.948 1137.040 A11 1 ,2-ethyl-n-propylbenzene 0.237 0. 197 0.190 28.039 1140.460 A11 1 ,3-methyl-n-butylbenzene 0.032 0.026 0.025 28.155 1144.840 All s-pentylbenzene 0.050 0.042 0.040 28.348 1152.110 N12 lt-M-2-(4-MP)cyclopentane 0.086 0.080 0.061 28.401 1154. 100 A12 1 ,2-di-i-propylbenzene 0.042 0.035 0.031 28.468 1156.590 __ unknown 0.107 0. 114 0.078 Page 12 of 20 Created with novaPDF Printer (www.novaPDF.com). Please register to remove this message. Detailed Hydrocarbon Analysis Detail Report - Report Date: 6/18/2009 11:38:35 AM RawFile: C:1Chem32111DATA\TLIIDHA-061709-8528-02.D1DHA-061709-8528-02.CDF Acquired: 06/17/09 11:15:44 Sample: Condensate-001 Analyzed: 6/18/2009 11 :31 :41 AM Processed 233 Peaks Reference File: C:1Chem32111DHARef1PONA-VI.DHA Comments: Normalized to 63.2300% NOTE: Components with a Weight % of Less Than 0.01 Not Reported. Components Listed in Chromatographic Order Page: 9 Minutes Index Group Component Mass % Volume % Mol % 28.503 1157.880 A12 1 ,4-di-i-propylbenzene 0. 119 0.099 0.087 28.605 1161 .690 A10 tetrahydronaphthalene 0.119 0.091 0.107 28.719 1165.910 112 145 0.175 0.173 0.122 28.756 1167.280 A14 naphthalene 0.040 0.029 0.037 28.893 1172.310 Al2 1 ,4-ethyl-t-butylbenzene 0.174 0.145 0.127 29. 137 1181 .230 112 147 0.040 0.040 0.028 29.231 1184.640 112 148 0.062 0.061 0.043 29.337 1188.450 Al2 1 ,3-di-n-propylbenzene 0.117 0.098 0.086 29.460 1192.880 O12 dodecene-1 0.065 0.064 0.046 29.658 1200.000 P12 n-dodecane 1 .414 1 .394 0.985 29.721 1202.790 -- unknown 0.037 0.040 0.026 29.777 1205.280 _ unknown 0.036 0.038 0.025 29.923 1211 .780 A12 1 ,3,5-triethylbenzene 0.014 0.037 0.032 30.010 1215.610 _ unknown 0.298 0.316 0.218 30.085 1218.920 __ unknown 0.052 0.055 0.038 30. 193 1223.650 __ unknown 0.051 0.054 0.038 30.313 1228.910 _ unknown 0.034 0.036 0.025 30.352 1230.590 Al2 1 ,2,4-triethylbenzene 0.047 0.039 0.034 30.634 1242.830 A12 1 ,4-methyl-n-pentylbenzene 0.128 0. 107 0.094 30.674 1244.550 _ unknown 0.049 0.052 0.036 30.887 1253.690 A12 n-hexylbenzene 0.095 0.079 0.070 30.934 1255.720 _ unknown 0.095 0. 100 0.069 31 .042 1260.330 __ unknown 0.187 0. 198 0.137 31 . 151 1264.970 __ unknown 0.154 0.163 0.112 31 .201 1267.070 __ unknown 0.035 0.037 0.025 31 .309 1271 .640 113 150 0.128 0.125 0.082 31 .406 1275.740 All 1 ,2,3,4,5-pentamethylbenzene 0.216 0. 160 0.173 31 .696 1287.890 -- unknown 0.207 0.220 0. 166 31 .788 1291 .680 O13 tridecene-1 0.034 0.033 0.022 31 .810 1292.610 __ unknown 0.043 0.045 0.028 31 .896 1296. 160 All 1-methylnaphthalene 0.036 0.027 0.030 31 .988 1300.000 P13 n-tridecene 1 . 189 1 . 167 0.765 32.064 1303.680 + C14+ 0.106 0. 103 0.064 32.292 1314.800 + C14+ 0.039 0.038 0.024 32.348 1317.520 + C14+ 0.041 0.040 0.025 32.387 1319.410 + C14+ 0.085 0.083 0.051 32.745 1336.630 + C14+ 0.060 0.058 0.036 32.827 1340.540 + C14+ 0.055 0.054 0.033 Page 13 of 20 Created with novaPDF Printer (www.novaPDF.com). Please register to remove this message. Detailed Hydrocarbon Analysis Detail Report - Report Date: 6/18/2009 11:38:35 AM RawFile: C:\Chem32\1\DATAITLI\DHA-061709-8528-02.D1DHA-061709-8528-02.CDF Acquired: 06/17/09 11:15:44 Sample: Condensate-001 Analyzed: 6/18/2009 11 :31 :41 AM Processed 233 Peaks Reference File: C:1Chem32111DHARel1PONA-VI.DHA Comments: Normalized to 63.2300% NOTE: Components with a Weight % of Less Than 0.01 Not Reported. Components Listed in Chromatographic Order Page: 10 Minutes Index Group Component Mass % Volume % Mot % 32.987 1348. 170 + C14+ 0.158 0. 154 0.094 33.058 1351 .500 + C14+ 0.091 0.088 0.054 33. 119 1354.400 + C14+ 0.063 0.061 0.038 33.225 1359.410 + C14+ 0.099 0.096 0.059 33.331 1364.410 + C14+ 0.121 0.118 0.072 33.479 1371 .340 + C144- 0. 118 0. 115 0.071 33.542 1374.250 + C14+ 0.036 0.035 0.021 33.655 1379.510 + C14+ 0.220 0.214 0.132 34.098 1400.000 + C14+ 0.954 0.929 0.571 34. 166 1400.000 + C14+ 0.041 0.040 0.024 34. 184 1400.000 + C14+ 0.053 0.051 0.032 34.286 1400.000 + C14+ 0.062 0.061 0.037 34.437 1400.000 + C14+ 0.099 0.097 0.059 34.517 1400.000 + C14+ 0.073 0.071 0.044 34.844 1400.000 + C14+ 0.047 0.045 0.028 35. 125 1400.000 + C14+ 0. 137 0. 133 0.082 35.234 1400.000 + C14+ 0.057 0.055 0.034 35.357 1400.000 + C14+ 0.319 0.311 0.191 35.480 1400.000 + 014+ 0.071 0.069 0.042 35.624 1400.000 + C14+ 0.049 0.048 0.030 35.718 1400.000 + C14+ 0.044 0.043 0.026 36.050 1400.000 + C14+ 0.906 0.881 0.542 36. 130 1400.000 + C14+ 0.038 0.037 0.023 36.223 1400.000 + C14+ 0.044 0.043 0.026 36.314 1400.000 + C14+ 0.052 0.051 0.031 36.559 1400.000 + C14+ 0.034 0.034 0.021 36.669 1400.000 + C14+ 0.047 0.045 0.028 36.896 1400.000 + C14+ 0.044 0.043 0.027 37.076 1400.000 + C14+ 0.048 0.047 0.029 37. 109 1400.000 + C14+ 0.094 0.092 0.056 37.203 1400.000 + C14+ 0.091 0.089 0.055 37.296 1400.000 + C14+ 0.062 0.061 0.037 37.344 1400.000 + C14+ 0.063 0.061 0.038 37.590 1400.000 + C14+ 0.039 0.038 0.023 37.734 1400.000 + C14+ 0.041 0.040 0.025 37.876 1400.000 + C14+ 0.756 0.736 0.453 38.657 1400.000 + C14+ 0.067 0.065 0.040 38.770 1400.000 + C14+ 0.209 0.204 0.125 Page 14 of 20 Created with novaPDF Printer (www.novaPDF.com). Please register to remove this message. Detailed Hydrocarbon Analysis Detail Report - Report Date: 6/18/2009 11 :38:35 AM RawFile: C:IChem32111DATA1TL11DHA-061709-8528-O2.D1DHA-061709-8528-02.CDF Acquired: 06/17/09 11:15:44 Sample: Condensate-001 Analyzed: 6/18/2009 11:31 :41 AM Processed 233 Peaks Reference File: C:1Chem32111DHARef1PONA-VI.DHA Comments: Normalized to 63.2300% NOTE: Components with a Weight % of Less Than 0.01 Not Reported. Components Listed in Chromatographic Order Page: 11 Minutes Index Group Component Mass % Volume % Mol % 38.880 1400.000 + C14+ 0.046 0.045 0.028 38.975 1400.000 + C14+ 0.084 0.082 0.050 39. 121 1400.000 + C14+ 0.051 0.049 0.030 39.671 1400.000 + C14+ 0.645 0.628 0.386 39.851 1400.000 + C14+ 0.232 0.226 0.139 Page 15 of 20 Created with novaPDF Printer (www.novaPDF.com). Please register to remove this message. Signal e�, pip �pj� �v cn n N A p, b S g pN NN N �7Na cNp �7 W W OWE g pA gi pQA�� A CVVT N y i O 6 O O 3 O O O O O O O O O O O O O O O O O O O S O O O O O • C]. a , fD H d O C 0 O O c--1 n a a c4 3 ca ct ti 0 6 O D ...� r_ t7 ti - nLi.9538 : propane 7r r V O n2 . 1732 n -butane cn N) N _ �} OD 2 .5 ''' 30 : 1-pentane N n2 .7436 : n -pentane e ^ MW V w •time ' tern, • " 12---=1 .6c ge. : 2 -rnethvipentare N =3 .8477 . 3 -methylpentane o v n4.1565 : n-hexane 2 - at o t? r ' 78 74 2 .4 -dimethylpentarte 7258 . methyicyclopentane et U7 ---=5 .3641 benzene 3 4 . 26 . 2 -rnen 'v!-t-nexen X5 .5955 : cyclohexar: e r�r- '5 8931 . 2 "3-dimetTil�p2, §ta? ' ethyihexane r ' ' 9928 - t-a ^n ,1methyte{her moo . ; ? 99 : 3-methyihEx2ne r ,6 .3179 . 1c.3-dimethytcvclopentane !' - cJ"�5 .Q1 6 : ? t3-dirnethv cytio a lane "' 10 .350 ' 1 t.2 -iin` eMylc clopentane `n7.0692 : n-heptane ��o' bti ��i � r �A .r `� ex3 ? e `if! 9707 rnethylcyclohexaane °" " co x,187 3�: ethv Icyclopp• entane . .. 0 2 .4-d :metnyihexane 8 . § ' tc, eltliPKjgthyicyclopentane 9 .2536 : 037 so "C.71 'n.9 .7539 : toluene L.- M- c 733 • ,1 . +Q Imo\ qQop Signal CD O O O „O C S O O q�f pN N b QN� qNo (Q� W cJ pW� pWo pA A A �Ai QAp c.Tt C77 c,n Es �i �f ea O O O O �O O O O , .O . ,Oa O O O O O O O S d O O O E O En a 3 co W "=9 .7539 : toluene CO F.D. Ui ?fig 1411g OT1.11PA ia@Rtane o a 0 . jj 4 • ? t vlheptane a 0 10 .4762t p3;4°3§n:e` fip31 �tPli en • CD 3 ft+ a co a N . . .�' � � '� �' la , � ;tShpg 'itcyclopentane o t5 : 0 .921 ': 7t d +-methyicyc?oehexane g -4 A ing 1 974 1 .1 -dimathylcycichexane -- i 1 .3852 : 2 .2 .5 -trimethylhexane s 115b62 31-ethytrnethylcyclopentane V O _ =11 .8591 1 t.2-dimethylcyclohexane - N b 12 .2743 : n-octane o Cr rn J 0 w Co 63 cart 13 .3386 : 2 .3 .4-trimethylhexane b C.) - N a' n 13 .6172 : O52 0 14 .CRita: ?;_5. -tfiftiVIR 4fiexane 14 .3501 : N4 14 .6041 50 .6 meths hepianQh,ythepiane N 'J^ _ V• M9 : e , benzen . C n2751 4frlrticirkitatibeeri ,41tPytbenzene 18 .4251 : 3 .4-dimethyiheptane sil1 6J 092 .6.:Igdiretn}lheptane 7 1 7 10 : unknown 17 .2954 • 3 -ethylheptane 17 '7' 7 '17 1c.2t4c-trimethy lctctonexane n17 .7376 : 1 c.2t.3c-f-imethylcyclohesane � - 7 .9761 : N18 18 .0931 N19 S .2223 : N20 J CA 15 .8123 : N22 19 .2307 : 1 .1 methylet, 4jcii7e'x1'i9Pnane 9 .4078 . N25 CT 19 .75 ,g06 i-pri pylbenzene -, i.crew5ttn :ll,oknn n O J 1 . JIG __.. —Pam 17b120--__ — _ _ _ Signal N N N N N W W W W W a a a a A to ca C!+ ca L1 a o o o s 8 8 o o 8 o $ o o g g 8 c� o g $ g o o $ $ gi E 0 3 $ § o v a t i , a a Q pre iibenzer = 1 V e h' b2 -i1ir - ro C? - 1tg? tbt;': 124:knot'•� n (n o a J -d met ► yloctene o p : 0 :2-070 ". 2 ,2-dimetny.octane • m n n n a N) _ =20 .4888 : 2 .5 -dimethylcc!ane _+. "�3 w N r� CD `_. 4:6 °91 ni' itIelopentane co3 N - 20 .9274 3 .3-dimethyloctane b oD rt .:74 ?2b%i)8 U ftigkgi.th Vie ctane 6 N S V, ^, •r 570 • 1 4-,cnethtethvlbenzer, e a n_ 1461' 9C : un no�Vn ' • ^' y17 . "lI' • PiiIJ �thYibenZerie CD o '"L_ t f n o a e Ki CD s .1 , 8a : metnyinonane o 2-methyl y N —~'c. �22 .250ti • 1 : eih ibenzer, a b ,N _ -10.89 3 Athv'toctane 6 ♦ r �? � �3 �'� : 3 -meth, lnrnant = .: 2 6 .-, -: :: "J' o 0) 0) " '' f477 : 1 .2 .4-trimethvlbenzene w —'—° 0599 • !2��22 .y739 ' 120 0 es, cin ►V co co �%Abb, ...244A5V-YIA- 8Wcvrcloh •exa ,, e N 0. n 23 .7265 : n-decane N `' 3f 1 1 52 � -d I-"�y g�d .;,,1,�., ►� !1:18 6ynlbV6.e n e 2.•#4:fit ) known 4- 2.1 .4 • ' ► g c-butylcy�cloh x.ane 0. 24 .#478 : ; -met'rry;-i-propylbenzene C o cn V.VLLwS2itt7ene 6 .i- tny - ropylben n N a L t2t. ti-DE t� jf Z r~ r benzen :Ze C Crl .-D 4 49�: N41 ^ V { p 3 . a, - ID S : 0 .4 .dimethy!-i -etlty!henzene ,0 : .2 -dimethyt-4-ethylbenzcne N 0; _ 26 .4826 . 143 ,;h,a Rey' - :11� �'7� It P }-e uet� hl e-ne n e N .-. :1 Vt-r-DtaDV . 1Zt 26.9911 : n-undecane -.14 112 4 rt a 1 ,"c4 rtb�e��z ern% • &'i::.:l .gal��rametil yibenzene 2709718- ::thin t5yi-l-butytbenzene " ' 65 - unkno „ n --�27 7630 : 5 -methylinaan PV t.:5 .338 *7 � ,a -rn'e434 l!hvl-n-butylten°z` !nonzene an :8 .1546 : 5-perM5er. zene N) �� ' , • ' � gt Cu'Wa co cjr� titl L �! cD �i�enzene .6053 : tetrahy rortspnthalene ' • } a # •1r1190h:iene _ 8 .8933 : 1 .4 -ethyl-t-butyihenzene 75 : 147 X9 ,3367 • 7 ,3-di-n -propytbenzene v, - z9 4599 : dodecena - 1 --: ;-. 42 1: ,, 9 .6585 : n-dodecane ..s. C 7 :: .i ~, c7ty 1.•, IN . - ....tn .'. Z -Page 18 of 20 --- - Signal N r0. . N_ N W W W W W A A A A ()1 (r O pp ppep pp 11�� pp.� ppora p �y Q n 0 , .O , .O .O. O . O . .r0), .0 . .0 N A O O S 1► G w O N O O O 0 N Ja a S t , � V � � .?4.3 O O O O O O O O C7 O O � IY :i ? 76 : d n� �i p29 .6585 : n-dodecane Ro _ ° ° �? ,' 1 3 .' triethlbenzene v1 o ,". Q 1 un Known u .C85 � . un�C own , :•G .1931 : unknown 4 'QQCt(Pthylbenzene a CD u, W UI jus:4-•J4?3,mkA :crRethyl-n -Pentyibenzene e to 3, n : h yptcnzene ‘. 1 .3420. * unknown O • 661714i-16r own _S 4 4062 : 1 .2 ,3 .4 ,5 -pentamethylbenzene ,z1 S).965, :65 : unknown 1 o i3 Iw A A N ./L0638 41ti _ `31 .9885 : n -tridecane b w b J o igg 7 4 + do ;o 3'.11 & : 1'4' �, ?223 13 : C 1.1 + N 3 .6545 : ;.,,:�; � 3�.0 9 8 3 : C14+ 4 . 861 fC14 + . e : LCi14+ co = .8444 : C14+ 0 4.2 1253 : C 14+ .12531C14+ 39 : C 14+ 3'5 .3569 : C14 + .4795 : C14+ a' + - '36 .0499 : C14 + 1111 : II+ CI n .5586 : C14 + .6687 : C14+ ca = .8956 : C 14+• h6l4cri + c„, ii$ : 644*+ n3 .5904 : C 14+ =3 344 : C 14+ .8761 : C14 + CJ 90 =3 566 : C 14+ .7696 : C 14 + co $9Q754 : 1 0 414+ n .1207 : C 14+ 0 - (21 .01 '`3'9.6707 : C14+ 506 . C14+ - Page 19 of 20 - - - -------- Technology Laboratory Inc. Centre Professional Office Park 1012 Centre Avenue Fort Collins, CO 80526 970-490-1414 info(ctDtechlabusa.corn Compositional Analysis of Liquid (Atmospheric Pressure) CGRS Date Sampled: 06/15/09 PO Box 1489 Date Received: 06/15/09 Fort Collins, CO Date Analyzed: 06/16/09 Sample ID: Condensate-001 1-8019-10695aa Lab ID: 8528-02 Molecular Specific Component Mole % Volume % Weight % Weight Gravi C 1 0.00 0.00 0.00 16.04 0.300 C 2 0.00 0.00 0.00 30.07 0.356 C 3 0.00 0.00 0.00 44.10 0.507 C 4 0.00 0.00 0.00 58.12 0.563 C 4 0.00 0.00 0.00 58.12 0.584 C 5 0.00 0.00 0.00 72.15 0.624 C 5 1 .66 0.99 0.79 72.15 0.631 C 6 10.02 6.77 5.70 86.18 0.664 C 7 18.62 13.68 12.31 95.88 0.709 C 8 15.00 12.04 11 .30 107.35 0.740 C 9 14.92 12.67 12.62 116.95 0.785 C 10 6.81 6.46 6.39 134.00 0.779 C 11 5.33 5.48 5.49 147.00 0.790 C 12 4.23 4.68 4.75 161 .00 0.801 C 13 3.17 3.74 3.86 175.00 0.812 C 14 3.19 4.00 4.17 190.00 0.823 C 15 2.19 2.90 3.06 206.00 0.833 C 16 1 .95 2.73 2.91 222.00 0.840 C 17 1 .47 2.16 2.32 237.00 0.848 C 18 1 .07 1 .66 1 .80 251 .00 0.853 C 19 1 .31 2.13 2.32 263.00 0.858 C 20 0.99 1 .69 1 .85 275.00 0.863 C 21 1 .24 2.21 2.43 291 .00 0.868 C 22 0.90 1 .67 1 .85 305.00 0.873 C 23 0.86 1 .66 1 .85 318.00 0.878 C 24 0.71 1 .42 1 .58 331 .00 0.882 C 25 0.68 1 .41 1 .58 345.00 0.886 C 26 0.66 1 .40 1 .58 359.00 0.890 C 27 0.63 1 .40 1 .58 374.00 0.894 C 28 0.34 0.79 0.90 388.00 0.897 C 29 0.33 0.79 0.90 402.00 0.900 C 30 plus 1 .71 3.50 4.08 478.00 0.917 Total 100.00 100.00 100.00 147.16 0.794 Average Specific Gravity Page 20 of 20 � ❑ � t� -- r -til - o Lj il _T3 0 ri •\* • Cii* 17:i --- sh x, D Me X X O L D Vo o c ii O � m elm` I V 'v t'lj n, 0 j R -4 Xi 3:112-1- an P Qi- K> 1 Fr: 1/40 n � "rJ O ;32O o m o m O0 P i 1 rn �` , c 4s ir p O o mo= o ^ C > z * , i n n 41 Z © z C . iz o O to DE cn '5 of z o !� p ' -� C" Z I I � r � v v -- C) cr 'ri Z to to fa)m 75 O Ca , x n < oOtri SaZi% Z � � ao � is4 6 c N � y o Wen rn 17W Ul LS N N A ►c N Q N -uDel 4 n ■ .�■�■■ ■ z O SAMPLE MATRIX: SOIL(S)1 AQUEOUS WOTHER O, R (A) •kla■■■.■ ■■■■� NUMBER OF CONTAINERS ■■■�■ ■■ ■ i3 - FtAl . ■ ■.■■, rj TEPH (ORO) 4C.3 120 OeS (-A^ TRPH 418.1 I ■� ■■�■ ■■ Oit 8c Grease 413.1 / 1664 D !?' m !ri r�r ■■■ ■�■■ . . VOC 624 / 8260 TOTAL /TCLP _. 6(n LKE,!_ ■■..■ ■ ■■ SVOC 625 / 8270 / PAH Z T > I < O 1 -A C RCRA 8 PETALS(TOTAL 11W t DISSOLVED) (7 �! ■■�■�■�■ React./Ignite. /Carr_ /Paint Filter m I C.) OM O m Ca • ■■■■■■■ ■■� ■ TO-1 /410-14/TO-151TVPH 1O -u in -o m 3 NITRATE / NITRITE! A m Co z z m ■■■■■■ ■■■■■ AMMONIA (nco :{ 0 -< m BOD / COD 1 j •-.-� m o O m FIXED GASES (Nz, 02, COz, CH4) Li z cl m 0 PCBs C X Q/ , ' -.< C0 W Pll 13 PIO Po;te- -0 0 lPAL , ° D7 O m H 0 70 m HOLD AFTER ANALYSIS HOLD, DON'T ANALYZE TECHNOLOGY LABORATORY, INC. / CENTRE PROFESSIONAL OFFICE PARK 1012 Centre Avenue 7.1 Fort Collins, Colorado 80526 (970) 490-1414 CGRS Sampled: 06/15/09 PO Box 1489 Received: 06/15/09 Fort Collins, CO 80522 Analyzed: 06/24/09 Sample ID: Condensate-001 Project # : 1-8019-10695aa Laboratory ID: 8528-02 Matrix: Oil This oil sample was received in good condition and was sent to Questar Energy Services on June 23, 2009 for Reid Vapor Pressure Analysis. The results contained in this report relate only to those items tested. • TLCI INOLOGY LABORAT RY, INC. Page 1 of 2 1210 D Street Rock Springs, Wy. 82901 Ph: 307-352-7292 Fax: 307-352-7326 Questar Energy Services Applied TechnologyServices API Gravity Reid Vapor Pressure Producer: Tech Lab Inc. Well Name: Project # 8528-2 Field: N/A County and State: N/A Corrected API Gravity: 47.0 @ 60*F RVP: 3.2 #@100 *F Date Sled: 6/1509 Date Analyzed: 6/24/09 Sampled By: N/A Analyzed By: Putnam Page 2 of 2 NGL Water Solutions DJ, LLC C12 Salt Water Disposal Facility Slop Oil Tank and Sale Oil Tank Emission Composition from E&P Tanks Molecular Weight VOC Weight Liquid Constituent Weight Mole % (lb/Ibmole ° Corrected (lb/lb-mop Liquid) �° Weight * Methane 16.04 0.00% 0.00 0.00% NA Ethane 30.07 0.00% 0.00 0.00% NA Total HC (Non-VOC) 0.00% 0.00 0.00% NA Propane 44.10 0.00% 0.00 0.00% 0.00% Iso-Butane 58.12 0.00% 0.00 0.00% 0.00% N-Butane 58.12 0.00% 0.00 0.00% 0.00% Iso-Pentane 72.15 13.21 % 9.53 10.70% 10.70% N-Pentane 72.15 10.40% 7.50 8.42% 8.42% i-Hexanes 86.16 22.52% 19.40 21 .78% 21 .78% n-Hexane 86.18 15.73% 13.56 15.22% 15.22% Heptanes 100.20 23.51 % 23.56 26.46% 26.46% Octanes 114.23 5.27% 6.02 6.76% 6.76% Nonanes 128.28 2.75% 3.53 3.96% 3.96% Decanes+ 194.40 0.02% 0.03 0.04% 0.04% Benzene 78.11 2.19% 1 .71 1 .92% 1 .92% Toluene 92.13 3.27% 3.01 3.38% 3.38% Ethylbenzene 106.17 0.07% 0.07 0.08% 0.08% Xylenes 106.17 1 .07% 1 .13 1 .27% 1 .27% 2-2-4 TMP 114.24 0.00% 0.00 0.00% 0.00% Total NMNE VOC 100.00% 89.06 100.00% 100.00% Hydrogen Sulfide 34.80 0.00% 0.00 0.00% NA Carbon Dioxide 44.01 0.00% 0.00 0.00% NA Nitrogen 28.01 0.00% 0.00 0.00% NA Totals 100.00% 89.06 100.00% 100.00% * Weight Percent corrected to remove Non-VOC Hydrocarbons, Carbon Dioxide,Nitrogen, and H2S content. Appendix E Process Description, Process Flow, Facility Location, and Plot Plan Process description The Facility accepts production water from oil and gas exploration and production sites in Colorado and separates residual condensate and oil from the production water through a closed system of manifolded aboveground storage tanks. The refined production water is injected into one of two on-site class II injection wells for disposal. The oil recovered at the facility is transported offsite for further refinement. A simplified process flow diagram is attached. h -i V O tt N- i II" I - 4 t 1 g I O G . III y 4 $ _ ; . 1 O , r` -- � II�III � -III II O g . O co a O I I 0 I j U_ nl'AI cn U) a O i ��++--��,,1 o I 1 l� a6 -:$ a 1 I ' n =x -ER I i E I i I 1.; ! I s f-- U I g O I I ry - Y� Q Q ` p 1 I Q 03 Q 1 I N a F `- (n p I 1 I i.2a it Y C ! ' 13i t f. :} i : .'is 0 y 1 `, a W I a :� ` z ° 1 e co o t I I— 2 ! i co I aI I a 1 G n — i Q O Y z o CO �� S O1 '47 7 . 58 1 I E ' Z ' f- t 54 t I xt. :tjr u - ₹ r. t• L I - a = a ° I • a ! o ' - a g f; fs p,I I W E a ' I z ci I i ; ;; ::131 dI3818 t (I_ ;_ — µa41 N t 'P ro ,,,„ ,:i- ..., 3 0 z rr S Y 3 LL_; R g P P. Y 1 , Z W i n 2 Q I . � I OO of U J T " S z Ir.".a.++r4.1twaon.'warwti.:isIn yJACAV,++arnw 1•..ira a4 tLa. DETAILED CLOSURE PLAN NGL WATER SOLUTIONS DJ , LLC : C12 FACILITY TO : Weld County Dept. of Public Health and Environment Colorado Oil & Gas Conservation Commission FROM : NGL Water Solutions DJ, LLC RE : DETAILED CLOSURE PLAN — C12 SWD Facility DATE: January 22, 2015 Schedule A Notice of Intent to Close Facility will be issued to Weld County within 30-days of ceasing operations. lf the operator cannot accept waste for a 30-day period and does not intend to cease operations a variance request explaining the temporary discontinuance of operations will be submitted to all regulatory agencies. Closure operations will be initiated within 90-days of issuing the Notice of Intent. Equipment Removal All electrical equipment will be de-energized and electrical terminations removed . Treatment equipment mentioned in the table below will be removed from the facility. All equipment will be cleaned by triple rinsing each unit with high pressure sprayer using potable water prior to removal or in the case of pumps circulating fresh water. All waste water will be contained and disposed of in accordance with applicable regulations. It is anticipated that all decommissioned equipment will be functional and will be reclaimed as used equipment. Item Description Quantity Method of Disposal Offload Pumps 6 Pumps will be cleaned, parts will be Sump Pumps 3 sold or reused at other NGL facilities Oil Transfer Pump 1 and remaining housings and skids will Filter Pump 1 be scrapped. Charge Pumps 1 Injection Pump 1 DeSander Tank 1 Brine water and tank bottoms will be System Tanks 4 disposed of, tanks will be emptied and Clean Tanks 2 steam cleaned by confined space Oil Tanks 5 crews and the clean tanks will be reused or scrapped . Pump House Building 1 Buildings will be demolished, Offload Canopy 1 materials will be separated and Office Trailer 1 recycled/reused or scrapped . Impoundment and Ancillary Containments Removal a) Concrete Sump : The concrete sump will be cleaned by agitating residual or added liquid in the tank to suspended sediment to the extent possible. A vacuum truck will extract liquids and solids and will be transferred to a filter box to allow residual liquids to return to the sump. All residual liquid will be processed to the extent possible by the water treatment system . The sump will be tripled rinsed with potable water and all monitoring equipment removed. The tank will be decommissioned by demolishing the concrete with a vibratory breaker bar. The concrete will be crushed and used as recycled material . The secondary liner will be disposed of at an approved land fill . The excavation will be assessed for waste impacts and backfilled to grade with previously excavated fill . b) System Piping: All piping will be cleaned and removed for disposal or recycling. c) Off-Loading Pad : The concrete offload pad and offload trench will be removed, crushed and recycled . Prior to removal the trench will be cleaned by a high pressure washer and the waste water will be processed for reuse. d ) Facility Building: The building will be completely removed and will be recycled or scrapped . e) Site Grading: The site will be graded to conditions prior to development. Surface cover used or stored in the site development will be use to re-grade the site to match neighboring sites. Data Quality Objectives Data Quality Objectives (DQOs) have been developed to ensure that data collection is of the correct type, quality, and quantity to support defensible site decisions. a) ProblemStatement Weld County requires this facility to submit a Closure Plan, which provides pre- and post- operation assessments. The facility will accept, store and dispose of produced water associated with oil recovery operations . The waste streams will consist of solids generated as part of the filtration process, oil recovered from separation and produced water contaminated with petroleum . b) Decision Requirements The primary questions addressed by this sampling program are : 1) what are environmental base line conditions; 2) what, if any are the impacts of site operations subsequent to facility decommissioning; and, 3) what, if any, remedial actions will be required after facility closure. No waste will be impounded at the facility in perpetuity and long term monitoring is not anticipated based on favorable closure assessment data . c) Decision Inputs Soil and water screening levels will be based on CDPHE's Colorado Soil Evaluation Values. The screening levels presented here are not to be considered as cleanup goals, but as concentrations at which further consideration is necessary. Development of screening levels ensures that appropriate analytical methods are used . The CDPHE has calculated risk-based screening levels (RBSLs) for corrective action guidance for petroleum releases. The RBSLs are limited to petroleum hydrocarbon compounds common to petroleum release sites . The RBSLs assess human health risk from direct contact to the compounds in soil as well as leaching of those compounds from impacted soil to ground water . These RBSLs can be used to identify appropriate disposal methods for impacted soil . d ) Sampling Plan i ) Offload Pad Two soil samples will be obtained at this location . The samples will be screened in the field for petroleum hydrocarbon vapors by placing samples in new, unused airtight containers . Soil vapor will be allowed to equilibrate within the headspace above the sample and then tested . Measurements will be recorded and the sample examined, noting color, texture, consistency, moisture content, and other pertinent information . All information will be documented and samples will be analyzed for petroleum . ii ) Tank Farm Containment Up to four soil samples will be obtained from beneath the Tank Farm containment. The samples will be field screened for organic vapors as described previously. Any sample(s) indicating the presence of organics will be submitted to a contract laboratory to determine petroleum concentrations. iii ) Pump House Building A sample will be obtained from beneath the pump house building, one sample will provide worst case conditions. The sample will be analyzed for petroleum . iv) Off- Loading Sump The off-loading sump will be removed including the secondary containment liner. Two soil samples will be obtained . The samples will befield screened for organic vapors and submitted for analysis to determine concentrations of petroleum . Conclusion NGL Water Solutions DJ, LLC will commit to remediate this site in full . Any and all deficiencies will be rectified with the Weld County Department of Planning services. NGL Water Solutions pledges to address any case of environmental contamination, with the goal of identifying and treating any pollution, making the contaminated area usable again. i iis WERNSMAN ENGINEERING , INC . 1011 42nd STREET • EVANS, CO 80620 Phone (970) 353-4463 Fax (970) 353-9257 November 11, 2014 Ms. Jen Petrik Drainage Engineer Weld County Public Works P.O. Box 758 Greeley CO 80632 RE : Drainage letter for High Sierra's C12 facility near CR 69 near Kersey CO Dear Ms. Petrik: This letter addresses the Water Quality Capture Volume (WQCV) requirements and existing and proposed drainage ways on the site The storm-water historically enters the site from the north and drains across the site to the south . The site varies greatly in elevation . ( See grading plan ) The proposed plan will collect on site flows and direct them around the proposed improvements to three water quality ponds around the site. When the water quality pond (s) reach capacity at elevations shown, storm- water will leave the ponds as sheet flow, or continue to fill in natural low spots . From the two ponds on the south edge of the site, storm water will travel an average of 400 feet south on the lot to further dissipate flows before they travel onto the neighboring property to the south . The pond to the north edge of the site will flow as sheet flow north the property to the north . The proposed conditions imperviousness (including all future buildings but excluding the concrete containment areas that will retain storm water ) is 10. The WQCV required for the site is 8490 cubic feet. Each of the three ponds shown on the grading plan provide at least 8831 cubic feet of storage. If you have any further questions or comments regarding this matter, please contact this office. Sincerely, Eric Wernsman P. E. Total Site Imperviousness Calculations ENTIRE SITE AREAS C VALUE CXA C100 value C100 X A I VALUE I X A NEW BUILDING (s) 18,800 0.73 13724 0.81 15228 90 1692000 CONCRETE/ASPHALT 39,200 0.8 31360 0.96 37632 100 3920000 GRAVEL 175,000' 0.65 113750 0 0 40 7000000 LANDSCAPE 1,291,600 0.08 103328 0.35 452060 2 2583200 TOTAL 1524600 262162 504920 15195200 [COMP C5= 0.17ICOMP C 100= 0.3311= 9.97. ACRES ( approx) 35 WQCV Calculations WQCV= a(0.91*I^3-1.19*I^2+ 0.78*I; a = 1 for 40 hr drain time I = 0.1 WQCV= 0.06682021 Volume req'd = WQCV* A a = 35 12 Volume req'd = 0.195 acre feet Volume req'd = 8489.5 cu ft STORAGE CALCULATIONS NORTH WEST POND CONTOUR ELEVATIONS AREA DEPTH AVG AREA Volume Provided 4574 342 1 1092.5 1092.5 4575 1843 1 3189.5 3189.5 4576 4536 1 6479 6479 4577 8422 TOTAL VOLUME OF 10761 C.F. PROVIDED STORAGE CALCULATIONS SOUTH WEST POND CONTOUR ELEVATIONS AREA DEPTH AVG AREA Volume Provided 4563 753 1 1428 1428 4564 2103 1 3091.5 3091.5 4565 4080 1 5343.5 5343.5 4566 6607 TOTAL VOLUME OF 9863 C.F. PROVIDED STORAGE CALCULATIONS SOUTH EAST POND CONTOUR ELEVATIONS AREA DEPTH AVG AREA Volume Provided 4557 0 1 838.5 838.5 4558 1677 1 2773 2773 4559 3869 1 5220 5220 4560 6571 TOTAL VOLUME OF 8831.5 C.F. PROVIDED DUST ABATEMENT PLAN NLG WATER SOLUTIONS DJ , LLC : C 12 FACILITY Road Surface The road surface for the proposed access entering the property is a dirt road with an aggregate surface. Prior to site work traffic arriving, the road surface will be maintained, to ensure that there is adequate aggregate on the road to provide traction in the event of rain or moisture. Also prior to site work, the road surface will be moistened by water then a Chloride product will be applied to minimize dust. The Chloride product that will most likely be used will be Magnesium Chloride. 7 The Chloride product will be applied as needed throughout the entire construction/site work process as the road surface changes, due to traffic or weather conditions. Application of water & chemicals will be done with a 1200 gallon tank truck with a spray type applicator. Parking Area The primary parking area that is closest to the activities area will be constructed of the same material as the site access. This will provide for any handicap parking needs as well as a dust abatement plan for the heaviest traveled parking area . The overflow parking area will be moistened with non-potable water, not a chemical chloride product, to prevent any potential vegetation damage. The isles of the overflow parking area will be the largest concern for dust & they will be monitored throughout the day. Water will be applied as needed to this parking area . Application of water will be done with a 1200 gallon tank truck with a spray type applicator. Activities Area The activities area will be monitored daily & throughout the day for dust control. As surface may become loosened with traffic; non-potable water will be applied to the area as needed to lessen the effects of heavy foot traffic. Application of non-potable water will be done by either a 1200 gallon tank truck with a spray type applicator or a 30 gallon sprayer mounted on an All-Terrain Vehicle. FACILITY EMERGENCY PLAN NGL WATER SOLUTIONS DJ , LLC : C 12 SITE ■ 1 . Name : NGL Water Solutions DJ, LLC 2 . Location : WCR 69 & WCR 388 with the access on WCR 388 3 . Emergency Telephone Numbers: Day Night Facility Primary: Chris Lattimer: 720.708.6535 x: 314 720.530.7291 Facility Secondary: Ted Lopez 720.708.6535 x: 302 816.519.0056 Fire District 911 911 Platte Valley Protection District Ambulance Service Area 911 911 Platte Valley Fire Protection District Weld County Regional Communications Center 911 911 Other CDPHE Spill Line (877) 518-5608 National Response Center (800) 424-8802 CHEMTREC (Chemical Transportation Emergency Center) (800) 424-9300 4. Agency Notification Non Emergency: Phone# Fire Department/District: Platte Valley Fire District 970.353 .3890 Ambulance Service Area : Platte Valley Fire District 970.353 . 3890 Law Enforcement Agency: Weld County Sherriff 970. 356.4015 x: 2804 Communication Center 970-350-9600 Office of Emergency Management/LEPC 970-304-6540 5 . Surrounding Occupancies & Land Use Surrounding is primarily agricultural . 6. Personal Protective Equipment Available: Location Rubber or neoprene boots : On Site Rubber Gloves : On Site Face Shield or similar protection : On Site Eyewash station On Site 7 . Location of Emergency Equipment & Supplies: To be completed once site construction begins - will be in site office. 8 . Location & Types of Water Supplies: There is currently no water on this site but there will be several foam fire extinguishers located throughout the facility. 9. Transportation routes: WCR 69 Rt WCR 388 are the main transportation routes. Site access is on WCR 388 . 10. Coordination with First Responder Agencies: EHS representative and/or first responders will meet the day the Certificate of Occupation is presented to review emergency plan and tour facility. Please see Waste Handling Plan for chemicals kept on site. 1 1 . Safety and Training Review: Each year, all employees are provided with all necessary information concerning the proper handling of a chemical spill or accident. This information shall be in the form of a review sheet detailing proper procedures, which shall be signed and dated by each employee when all items are understood . Also, proper use of cleanup and containment tools and procedures will be demonstrated as necessary. Any new or updated information or procedures will be taught to employees immediately when applicable. FOR COMMERCIAL SITES, PLEASE COMPLETE THE FOLLOWING INFORMATION BUSINESS EMERGENCY INFORMATION: Business Name: NGL Water Solutions DJ, LLC Phone: 303 815 1010 Address: 373 Cherry Creek North Drive City, ST, Zip: Denver, CO 80209 Business Owner: Josh Patterson (Officer) Phone: 303 868 1286 Home Address: NA City, ST, Zip: NA List three persons in the order to be called in the event of an emergency: NAME TITLE ADDRESS PHONE Josh Hamblin Operations 13159 CR 39, Platteville 970 218 1739 Ryan Surroz Operations 8207 W. 20th St Suite B, Greeley 970 356 5560 Rae Chrisman Operations 8207 W. 20th St Suite B, Greeley 303 304 6532 Business Hours: 8:00am-5:00pm Days: Monday-Friday Type of Alan; Non Burglar Holdup Fire Silent Audible Name and address of Alarm Company: NA Location of Sale: NA *********A A******kA-k**ink*k**A A A A********-k***-A-* *****A A*.k A AA*****-A A ALA AAA*A****************************k***** irkoi AA kA kit**A AAA** MISCELLANEOUS INFORMATION: Number of entry/exit doors in this building: NA Location(s): Na Is alcohol stored in building? NO Location(s): NA Are drugs stored in building? NO Location(s): NA Are weapons stored in building? NO Location(s): NA The following programs are offered a public service of the Weld Coun riff's Office. Please indicate the programs of interest. Physical Security Check Crime Prevention Presentation UTILITY SHUT OFF LOCATIONS: Main Electrical: NA Gas Shut Off: NA Exterior Water Shutoff: NA Interior Water Shutoff: NA ENVIRONMENTAL flWQC© g November 3, 2014 Mr. Nick Valencia M3 Construction 2681 W. 120th Ave, Ste. 250 Westminster, CO 80234 Via email; nvalencia@M3-consult.com Subject: Site Groundwater Monitoring Plan NGL Water Solutions DJ, LLC: C12 Injection Facility Weld County Road 388 Kersey, Colorado NE1/4, SE1/4, Sec. 27, T5N, R63W CGRS Project No. 1-12462-14804aa Dear Mr. Valencia: This correspondence summarizes the water quality monitoring program and proposed groundwater monitoring well installation located at the above-referenced injection facility. The well installation and baseline soil and groundwater quality sampling activities will be scheduled after basic site infrastructure has been constructed. A site location map is included as Figure 1, and an approximate site layout map illustrating the anticipated monitoring well locations is included as Figure 2. The Groundwater Monitoring Plan provides baseline groundwater quality data, which will facilitate early detection of an unknown subsurface release of exploration and production fluids related to facility processing activities. In addition to groundwater sampling, depth to groundwater will be measured in each monitoring well and the groundwater elevation, flow direction, and hydraulic gradient will be calculated using surveyed well elevations in order to monitor groundwater flow trends. Water quality samples will be collected and analyzed for constituents associated with oil and gas exploration and production activity. Water quality sampling activities for the NGL Water Solutions DJ, LLC: C12 Injection facility will be performed on a quarterly basis. Water quality samples will be submitted to a contract laboratory for analysis of benzene, toluene, ethylbenzene, and xylenes (BTEX), total dissolved solids (TDS), and chlorides. A full description of CGRS' Methods and Procedures for field and reporting activities are provided in Attachment A. Four permanent groundwater monitoring wells (MW-1 through MW-4) will be installed up-gradient, down-gradient and/or adjacent to facility operation areas (Figure 2). The proposed monitoring wells will be installed to a depth of approximately 30 feet below ground surface (bgs). The wells will be constructed with approximately 25 feet of 2-inch diameter, 10-slot PVC screen and approximately 5 feet of solid PVC riser. 10/20 silica sand will be applied around the screened portion of the wells to a depth of approximately 2 feet above the well screen, at which point the well borings will be sealed with a hydrated bentonite/grout mixture to the surface. In the case where water is encountered at shallower or deeper depths, the wells will be advanced at least ten feet into the groundwater table and the screened interval will be adjusted accordingly. Monitoring wells will be finished with locking j-plug well seals and either 4-inch square aluminum stick-up mounts or flush-mounted traffic rated manways. Pertinent information, such as soil sample descriptions of color, texture, consistency, moisture content, and soil vapor readings along with well construction details of each monitoring well will be provided in the associated quarterly groundwater monitoring report. CGRS will begin quarterly groundwater monitoring prior to when the facility commences full-scale operation in order to obtain adequate baseline water quality samples. It should be noted that after the installation of groundwater monitoring wells, and after site construction has been completed, a revised monitoring plan will be submitted (as applicable) to document any updated site conditions. 1301 Academy Court Fort Collins, CO 80524 T 800-288-2657 F 970-493-7986 www.cgrs.com Site Groundwater Monitoring Plan NGL Water Solutions III, LLC: CI 2 Injection Facility Weld County Road 388 Kersey, Weld County, Colorado NE1/4, SE1/4, Sec. 27, T5N, R63W Should you have any questions or require additional information, please call Ms. Kelly Sutton or Mr. Craig Mulica at (800) 288-2657. Sincerely, CGRS, Inc., Kate McSherry Staff Scientist Reviewed By: . (eta2it Kelly Sutton Project Manager/Scientist Enclosures: Figure 1 — Site Location map Figure 2 — Approximate Site Layout Map Attachment A: CGRS' Field and Reporting Methods and Procedures , , •,,, , , , . . tar 44 • # - :). . ' i .-ts, vs):: ..0 9 • ' . - . • ~` I 49 • -,,I k 4 r _ Q r* '12 I „,\'*..,‘tlii ., \-f: C' ' : .:44?‘ TV:.H.. . . : . rjs. . 1181411iNlibiage: 4577 1 ,r. n ,. j1, s ' -.• I 11 ,1` l,, r. ` it , , ��0 ' , /��!, r+• J ii- � .j `' »< ', (� c i `til Al 1-'6\ i' t •►/ irk 6 ri ( i .... - \-N\eark LL---L.N.c - . 1 vg CI -.� . , N.."'S.,\ ,t;c. I 1. 71is . ) .%1-1- II i if . tor- ' ` 1 - G ••,.•„,„..,t se isle. an* II alien�,1kWP WPM >rf�!!r .... e .r ese ev .- -�- -r-— --- ----- --%---- " ` S -- _... __ _ . _ _ �... DC•t• s 7if4$t\kt• c\ - • r in,Pev �� act ! k. ; Jim,. _ (- - r • f "• ., at IN , • )I. i Sli..\\I 41Pe :.: -)1 2 ititlrett;t 4;1 • , •••.,/ '.` Siva.. O " cl% 4.4* i ‘ . , , , 0 1 • 1 -s; 1�-� c SITE o• a i �E o a _�r ' .d :, a"l*S'SQ ^ �, r: LOCATION • g37y4 t s �4 �. artea ?i 8 4+) ` V Ted:•S \ fi`� t�A± .` nom , _r o • \ f SI „ 0 4;1,4:' rl q t A: : :. * `►. >i,/ feW-•-' 1-. A ------A- 841 * s •IS Al \Se: 1 • 0.) I...A_ ' � 1` � Itil(� w 1 I tt L1/214? 3a;tayc neat. _ ! 7 �'t. ;�. � 4539 9.1 43,4 � i1 "•�}r � +e aWi�dmip sk -� r` v a '3 (:). • ti • ,y v 0 is,---; k. ./ i H. ea\ . I -,„____ _ -__ -.\....., • fli k :457:-.-1-44., * _..e ,. ,mil w )i-iiC crsc__f'Pag`[ll+++ * S'S 5 r' ., , � �O .1fL,M\ i„‘? 3NI 3 w , . *`-- le C.: •se : . .: Tank itot•• \ a • *� • 4527 •• ` " C9 i \ Hardin i 14522• BM r• <. . , - « \ yt\'‘. .,,,,st N , „ - n ‘ tali •;-well ' n ss \ .adi. �c ��` - n Seventy Rant h N. • ` a \--"N\-- . --s.- _ 4521 ' \\ 1 wen FIGURE 1 ■ SITE LOCATION MAP 0 NGL WATER SOLUTIONS C12 FACILITY COLORADO NE 1/4, SE 1/4, Sec. 27, 5N. 63W NORTH KERSEY, COLORADO PROJECT: DRAFT: 1000 2000 12462-14804aa MSP cG s ENVIRONMENTAL - CONSTRUCTION DATE: REVIEW: 4 A COMPLIANCE iii IS IN QUADRANGLE LOCATION SCALE IN FEET 10/23/2014 • • , , \ s 00000 .• .. .,.....c: , .. ..':...,„ : :. ... 00000 F17 0000 r. 000 C12 FACILITY - : . , '" • €; OWNED BY : .. . i- OTHERS •• \1\ �\ . \\• �. NATIVE GRASSES \\____y l NATIVE GRASSES N 1 \ . HI ° w n U • U — \ I X------_______ • \ / . PS/ 00 I' . / -4-", / NATIVE GRASSES 1 N. i E. . ..,,,, / �_ X X X LEGEND FIGURE 2A S PROPOSED MONITORING WELL LOCATION SITE CONDITIONS MAP 0 NGL WATER SOLUTIONS C12 FACILITY -� SURFICIAL FLOW DIRECTION NE 1/4, SE 1/4, Sec. 27, 5N, 63W NORTH KERSEY, COLORADO PROJECT: DRAFT: CG 0 100 200 300 12462-14804aa MSP DI ENVIRONMENTAL CONSTRUCTION CONSTRUCTION DATE: REVIEW: i its CONPCAHCE SCALE IN FEET 11/3/2014 ......" ATTACHMENT A CGRS' Field and Reporting Methods and Procedures CGRS, INC. NGL Water Solutions DJ LLC — C12 Injection Facility METHODS AND PROCEDURES NGL Water Solutions DJ LLC; C12 Injection Facility NE1/4, SE1/4, Sec. 27, T5N, R63W WCR 388 Kersey, Weld County, Colorado CGRS Project # 1-12462-14804aa Soil Borings Soil sampling will be conducted in accordance with ASTM:D 1586-08a. Using this procedure, a 2-inch O.D. split-spoon sampler will be driven into the soil by a 140-pound weight falling 30 inches. After an initial set of 6 inches, the number of blows required to drive the sample an additional 12 inches, known as the penetration resistance (N value), will be recorded. The N value is an index of the relative density of cohesionless soils and the consistency of cohesive soils. Soil Classification/Characterization As samples are obtained in the field, they will be visually inspected and classified in accordance with ASTM:D 1488-84. Representative portions of the samples will then be retained for further examination and for verification of the various strata, the N value, water level data, and pertinent information regarding the method of maintaining and advancing the boring will be provided. Charts illustrating the soil classification procedure, descriptive terminology, and symbols used on the logs will be provided. As samples are collected, they will be examined for evidence of petroleum hydrocarbons using visual appearance and by screening with portable photoionization detection equipment. Decontamination To avoid potential transport of contaminated materials to the project site, all drilling equipment and down- hole tools will be steam cleaned prior to mobilization. To prevent cross contamination between soil borings or monitoring wells, all down-hole equipment will also be steam cleaned and rinsed with water between soil borings. Monitoring Well Construction Monitoring wells will be installed utilizing the following general construction criteria: ❑ borehole diameter: minimum 2.0 inches push probe / 6.25 inches conventional boring ❑ well diameter: 1 inch for push probe / 2 inches for conventional boring ❑ estimated depth: ≥ 5 feet below static groundwater table • casing material: schedule 40, flush thread PVC -a- CGRS, INC. NGL Water Solutions DJ LLC — C12 Injection Facility well screen: 1 inch inside diameter (I.D.) for push probe / 2 inch 1. D. for conventional boring, #0.01 slot PVC ❑ estimated screened interval: 10 feet above and 10 feet below the groundwater table (may be adjusted based on total depth and water table position) annular pack: 10-20 silica sand ❑ protective casing: 4" aluminum above grade mount, locking cap; or 8" steel flush mount traffic rated manway. ❑ annular seal: cement grout and bentonite pellets. Groundwater Sampling All borings where groundwater is encountered will be sampled from the suspected cleanest to the most contaminated according to the protocols listed below. All pertinent information will be recorded on a sampling information form. Field Protocol Step 1 - Measure water level. Step 2 - A dedicated polyethylene bailer will be used to develop each well. Three bore volumes will be evacuated from each well prior to sampling. Step 3 - Collect water samples. Water samples will be collected using a polyethylene bailer. Step 4 - Store samples in a cooler on ice (-4° Celsius) for transport to the laboratory. Follow all documentation and chain-of-custody procedures. Step 5 - Clean equipment. Water level measurement equipment will be cleaned with ethanol followed by a distilled water rinse. Upon completion of soil or groundwater sampling, a chain of custody log will be initiated. A copy of the chain of custody will be returned to the project manager. Chemical Analysis An approved contract laboratory will provide stationary laboratory analysis. The following analyses will be performed: Soil Analyses: Initial well installation Chemical Parameters Method Used Benzene/Toluene/Ethylbenzene/Total Xylenes (BTEX) EPA - 8260 B -b- CGRS, INC. NGL Water Solutions DJ LLC — C12 Injection Facility Soil Analyses: Initial well installation (Continued) Chemical Parameters Method Used Total Volatile Petroleum Hydrocarbons IPA 8260B Water Analyses (Quarterly Groundwater Sampling) Chemical Parameters Method Used Benzene/Toluene/Ethylbenzene/Total Xylenes (BTEX) EPA - 8260 B Total Dissolved Solids (TDS) EPA - 160. 1 Chlorides EPA - 300. 1 Groundwater Trend Analyses Groundwater concentrations are measured in site monitoring wells on a quarterly basis. Upon receiving groundwater analytical data from the laboratory the data is inserted into an historic groundwater analytical data table. Chlorides and sulfates concentrations will be evaluated to ensure that the current concentrations in each well do not exceed 1 .25 times the average background conditions. If results indicate that this threshold is exceeded, then further analyses or investigation will be conducted. Any BTEX constituents discovered in a monitoring well water quality sample, which are above the Colorado Oil and Gas Conservation Commission (COGCC) levels, will be reanalyzed at the laboratory. The presence of BTEX will prompt a complete evaluation of site operations since the last sampling event, and prompt further subsurface investigation if warranted. Groundwater Elevation Measurements The following outlines our standard groundwater quality sampling methodology. Before purging any of the soil test borings or monitoring wells, water level measurements must be taken. Measuring Point Establish the measuring point for the well. The measuring point is marked on the north side of the top of the monitoring well riser. The top of the riser is normally a 2-inch schedule 40 PVC casing inside a locked protective casing. The measuring point should be described on the groundwater sample collection record. -c- CGRS, INC. NGL Water Solutions DJ LLC — C12 Injection Facility Access After unlocking or opening a monitoring well, the first task will be to obtain a water level measurement. Water level measurements will be made using an electronic water level indicator. Depth to water and total depth of the well will be measured for calculation of purge volume. Measurement To obtain a water level measurement, lower a decontaminated electronic water level probe into the monitoring well. Care must be taken to assure that the electronic probe hangs freely in the monitoring well and is not adhering to the well casing. The electronic probe will be lowered into the well until the audible sound of the unit is detected and the light on the electronic sounder illuminates. At this time, the precise measurement should be determined by repeatedly raising and lowering the probe to obtain an exact measurement. The water level measurement is then entered on the groundwater sampling collection record sheet or groundwater level data sheet to the nearest 0.01 feet. Decontamination The electronic probe shall be decontaminated immediately after use by wiping with isopropyl alcohol- soaked paper towels and rinsed with distilled water. Always proceed in order from the suspected cleanest well or soil test boring to the suspected most contaminated one. Purge Volume Computation All soil test borings, monitoring wells, and temporary monitoring wells will be purged prior to sample collection. Depending upon the rate of recovery, three to five volumes of groundwater present in a well or borehole shall be withdrawn prior to sample collection. If a well or borehole bails dry, the well or borehole should be allowed to recharge and a sample taken as soon as there is sufficient volume for the intended analysis. The volume of water present in each well or borehole shall be computed using the two measurable variables; length of water column in soil boring or monitoring well depth and diameter. Purging and Sample Collection Procedures Bailing Obtain a laboratory decontaminated disposable bailer and a spool of nylon rope or equivalent bailer cord. Tie a bowline knot or equivalent through the bailer loop. Test the knot for adequacy by creating tension between the line and the bailer. Tie again if needed. New rope and bailer will be used for every sample or purge event. New clean latex gloves will be used when touching the rope or bailer. -d- CGRS, INC. NGL Water Solutions DJ LLC — C12 Injection Facility O Spread a clean plastic sheet near the base of the well. The plastic sheet should be of sufficient size to prevent bailer or bailer rope from contacting the ground surface. Place the bailer inside the well to verify that an adequate annulus is present between the bailer and the well casing to allow free movement of the bailer. Lower the bailer carefully into the well casing to remove the sample from the top of the water column, taking care not to agitate the water in the well. Pour the hailed groundwater into a bucket. Once the bucket is full, transfer the water to a barrel and contain on-site. Li Raise the bailer by grasping a section of cord, using each hand alternately. This bailer lift method will assure that the bailer cord will not come into contact with the ground or other potentially contaminated surfaces. Sampling O Instructions for obtaining samples for parameters are reviewed with the laboratory coordinator to insure that proper preservation and filtering requirements are met. ❑ Appropriate sample containers will be obtained from the contract laboratory for each individual analyses requested. After samples are collected, they will be put on ice in coolers (4°C). Care will be taken to prevent breakage during transportation or shipment. ❑ Samples collected by bailing will be poured directly into sample containers from bailers. The sample should be poured slowly to minimize air entrapment into the sample bottle. During collection, bailers will not be allowed to contact the sample containers. ❑ Upon completion of sampling a chain-of-custody log will be initiated. Chain-of-custody records will include the following information: project name and number, shipped by, shipped sampling point, location, field ID number, date, time, sample type, number of containers, analysis required, and sampler's signature. The samples and chain-of-custody will be delivered to the laboratory. Upon arrival at the laboratory, the appropriate laboratory personnel will check in the samples. Laboratory identification numbers will be noted on the chain-of-custody record. Upon completion of the laboratory analysis, the completed chain-of-custody record will be returned to the project manager. Field Cleaning Procedures For all equipment to be reused in the field, the following cleaning procedures must be followed: -e- CGRS, INC. NGL Water Solutions DJ LLC — C12 Injection Facility ❑ Disassemble the equipment to the extent practical. ❑ Wash the equipment with distilled water and laboratory-grade detergent. ❑ Rinse with distilled water until all detergent is removed. ❑ Rinse the equipment with isopropyl alcohol, making sure all surfaces (inside and out) are rinsed. ❑ Triple rinse the equipment with distilled water. Laboratory Selection The project manager should consider the following factors when selecting a laboratory: ❑ Capabilities (facilities, personnel, instrumentation), including: LJ Participation in inter-laboratory studies (e.g. EPA or other Federal or State agency sponsored analytical programs); ❑ Certifications (e.g. Federal or State); ❑ References (e.g. other clients); and ❑ Experience (UST, RCRA and other environmentally related projects). El Service LJ Turnaround time; and ❑ Technical input (e.g. recommendations on analytical procedures). The project manager is encouraged to gather pertinent laboratory-selection information prior to extensively defining analytical requirements under the project. A request may be made to a laboratory to provide a qualifications package that should address the points listed above. Once the project manager has reviewed the various laboratory qualifications, further specific discussions with the laboratory or laboratories should take place. In addition, more than one laboratory should be considered. For large-scale investigations, selection of one laboratory as a primary candidate and one or two laboratories as fall-back candidates should be considered. The quality of the laboratory service provided is dependent on various factors. The project manager should be able to control the quality of the information (e.g. samples) provided to the laboratory. It is extremely important that the project manager communicate to the laboratory all the requirements relevant to the project. This includes the number of samples and their matrices, sampling schedule, parameters and constituents of interest, required analytical methodologies, detection limits, holding times, deliverables, level of QA/QC, and required turnaround of analytical results. -f- CGRS, INC. NGL Water Solutions DJ LLC — C12 Injection Facility Field and Laboratory Quality Control General Quality control checks are performed to ensure that the data collected is representative and valid data. Quality control checks are the mechanisms whereby the components of QA objectives are monitored. Examples of items to be considered are as follows: 1. Field Activities: Use of standardized checklists and field notebooks; Verification of checklist information by an independent person; I� Strict adherence to chain-of-custody procedures; Calibration of field devices; O Collection of replicate samples where applicable; and O Submission of field blanks, where appropriate. 2. Analytical Activities: ❑ Method blanks; ❑ Laboratory control samples: ❑ Calibration check samples; O replicate samples; O Matrix-spiked samples; ❑ "Blind" quality control samplers; ❑ Control charts; Surrogate samples; ❑ Zero and span gases; and ❑ Reagent quality control checks. Management of Waste Material During the advancement of soil borings, decontamination of field equipment and development of soil borings or temporary monitoring wells, waste materials will be generated. This section addresses both the management of solid waste (soils) and the liquid wastes generated. Soil generated during remedial activities will be containerized in 55-gallon drums or stockpiled on an impermeable membrane and covered with plastic, which ever is most appropriate. The waste characteristics of the soil will be determined by appropriate analytical methods and the soil disposed of in accordance with -g- CGRS, INC. NGL Water Solutions DJ LLC — C12 Injection Facility state and federal regulations. Water generated during field activities will be containerized in storage vessels that are compatible with the suspected or identified contaminant(s). If required, the water will be analyzed by appropriate analytical methods to determine its waste characteristics. If a water treatment system is available, wastewater will be treated on-site, thus eliminating the need for disposal. A portable aeration system can also be utilized to eliminate volatile contaminants in wastewater. In any event, the ultimate disposition of water will be in accordance with all applicable regulations. Reporting After data has been compiled and analyzed, CGRS submits a summary report to NGL Water Solutions DJ, LLC at the following address: Mr. Josh Patterson NGL Water Solutions DJ, LLC 8203 West 20th Street, Suite A Greeley, Colorado 80634 Furthermore, CGRS submits an electronic copy to the following recipients and email addresses: Mr. Josh Patterson; NGL Water Solutions DJ, LLC; jpatterson@highsierraenergy.com Additional reports may be submitted upon the request of, or permission from, NGL Water Solutions DJ, LLC. This includes the anticipated submittal of quarterly reports to the Weld County Department of Public Health and Environment. -h- C12 Secondary Containment Narrative The purpose of this document is to provide supplementary information to the containment storage calculations provided below. There are two containment areas on the C9 SWD facility, a tank farm containment and offload containment. The tank farm and offload containments are not hydraulically connected, thus the containment volumes are calculated separately. Both containments are constructed out of concrete, designed by a Colorado Professional Engineer. The required volume for each containment area is determined as the 125,6 of the largest tank that would be observed in that containment area plus the 25-year return interval, 24-hour storm . The design of the tank farm containment consists of a tank pad, tank farm sump and tank farm perimeter wall (all concrete) . An underdrain system will be installed to convey water from the tank pad to a sump contained in the southeast corner of the tank farm . The wall height of the tank farm perimeter wall is adequate to store 125,6 of the largest tank ( 1000 bbl) plus precipitation. The design of the offload pad consists of two surfaces—the offload approach and offload departure pads—sloped towards an offload trench . The offload trench is designed to convey all fluid at a 21 slope towards the offload sump. The combined volume of the offload pad, offload trench, and offload sump is adequate containment storage as defined above ( 125.6 of the largest tank plus precipitation) . During offload of each truck, the truck tank, and coupling is over part of either the approach or departure pad or the offload trench. Any construction joints will be sealed to prevent leaking through containment, additionally a 30 mm liner will be installed underneath the offload trench and offload sump containment. Additionally, a 3" PVC pipe will be installed under the offload sump to monitor any leaks in the containment. Secondary Containment Calculations bbl 42 gal Tank Pad Containment L 153. 5 ft Length of the Tank Pad VI/ := 88.666 ft Width of the Tank Pad Atankfarm l= L - 1/17 = 13610. 2 ft2 Eq. [ 1] Plan Area of the Tank Pad PDS-based point precipitation frequency estimates with 90% confidence intervals (in inches) Average recurrence interval (years) Duration - . - i 1 I 2 5 10 25 50 100 200 500 1000 5-min 0.242 0.292 0.389 0.483 0.633 0.764 0.910 1.07 1.31 1.50 (0.203-0.292) (0.245-0.353) (0.324-0.472) (0.399-0.590) (0.508-0.834) (0.590-1.02) (0.670-1.25) (0.745-1.53) (0.863-1.93) (0.952-223) 0.355 0.428 0.570 0.707 0.926 1.12 1.33 1.57 1.92 2.20 10-min (0.297-0.428) (0.358-0.518) (0.474-0.691) (0.584-0.863) (0.744-1.22) (0.864-1.49) (0.980-1.83) (1.09-2.23) (1.26-2.82) (1.39-3.26) 15-min 0.433 0.522 0.695 0.862 1.13 136 1.62 1.91 2.34 2.69 (0.362-0.522) (0.437-0.631) (0.578-0.843) (0.713-1.05) (0.907-1.49) (1.05-1.82) (1.20-2.23) (1.33-2.72) (1.54-3.44) (1.70-3.98) 30-min 0.581 0.700 0.930 1.16 1.52 1.83 2.19 2.58 3.16 3.63 (0.487-0.701) (0.585-0.846) (0.774-1.13) (0.955-1.41) (1.22-2.00) (1.42-2.45) (1.61-3.01) (1.79-3.68) (2.08-4.65) (2.30-5.38) 0.722 0.858 1.13 1.41 1.86 2.27 2.73 3.25 4.01 4.65 60-min (0.605-0.871) (0.717-1.04) (0.942-1.37) (1.16-1.72) (1.50-2.47) (1.76-3.04) (2.01-3.77) (2.26-4.64) (2.65-5.92) (2.94-6.88) 2-hr 0.863 1.01 1.33 1.66 2.21 2.71 3.27 3.91 4.86 5.66 (0.727-1.03) [(0.854-1.22) (1.12-1.61) (1.38-2.01) (1.80-2.92) (2.12-3.61) (2.44-4.49) (2.75-5.55) (3.25-7.12) (3.62-8.30) 3-hr 0.946 1.10 1.44 1.79 2.38 2.93 3.55 4.26 532 6.21 (0.800-1.13) (0.930-1.32) (1.21-1.72) (1.49-2.16) (1.95-3.15) (2.30-3.89) (2.66-4.86) (3.02-6.02) (3.58-7.75) (4.00-9.07) 6-hr 1.08 1.28 1.67 2.07 2.73 3.32 3.98 4.73 5.83 6.76 (0.923-128) (1.09-1.52) (1.42-1.99) (1.74-2.48) (2.24-3.54) (2.62-4.35) 1(3.00-5.37) (3.37-6.59) (3.95-8.39) (4.39-9.76) 12-hr1.27 1.51 1.97 2.41 3.09 3.69 434 5.06 6.11 6.96 (1.09-1.49) (1.29-1.78) (1.68-2.33) (2.03-2.86) (2.54-3.94) (2.92-4.75) (3.29-5.76) (3.63-6.95) (4.17-8.66) (4.58-9.96) 24-hr 1.51 1.78 2.27 2.73 3.44 4.05 4.71 5.44 6.48 733 (1.30-1.76) (1.53-2.08) (1.95-2.66) (2.32-3.22) (2.84-4.32) (3.23-5.15) (3.60-6.18) (3.94-7.37) (4.47-9.08) (4.87-10.4) 2-day1.75 2.06 2.61 3.11 3.85 4.47 5.12 5.83 6.83 7.63 (1.51-2.02) (1.78-2.38) (2.25-3.04) (2.66-3.63) (3.18-4.75) (3.58-5.60) (3.93-6.62) (4.25-7.79) (4.75-9.44) (5.12-10.7) 1.91 2.22 2.78 3.28 4.03 4.66 532 6.03 7.04 7.85 (1.66-2.20) (1.93-2.57) (2.41-3.22) (2.82-3.82) (3.35-4.95) (3.75-5.80) (4.11-6.84) (4.42-8.02) (4.92-9.67) (5.30-10.9) �� 2.04 2.36 2.93 3.44 4.19 4.82 5.49 6.20 7.21 8.02 (1.77-2.34) (2.05-2.71) (2.54-3.38) (2.96-3.99) (3.49-5.12) (3.90-5.98) (4.25-7.02) (4.57-8.21) (5.06-9.86) (5.44-11.1) 2.31 2,69 335 3.91 4.71 5.35 6.01 6.71 7.65 8.39 7-day (2.02-2.63) (2.36-3.08) (2.92-3.84) (3.39-4.51) (3.93-5.67) (4.34-6.56) (4.68-7.59) (4.96-8.75) (5.41-10.3) (5.74-11.5) 10_ 2.55 2.98 3.71 4.31 5.15 5.80 6.46 7.14 8.04 8.72 daY (2.24-2.90) (2.62-3.40) (3.24-4.23) (3.75-4.95) (4.30-6.15) (4.71-7.05) (5.04-8.09) (5.30-9.24) (5.70-10.8) (6.00-11.9) 3.26 3.77 4.61 5.29 6.21 6.91 7.59 8.28 9.16 9.81 y (2.88-3.67) (3.34-4.26) (4.06-5.22) (4.63-6.03) (5.21-7.31) (5.65-8.29) (5.97-9.38) (6.19-10.6) (6.56-12.1) (6.83-13.3) 30-day 3.83 4.41 5.33 6.08 7.08 7.83 8.56 9.28 10.2 10.9 (3.40-4.30) (3.91-4.95) (4.71-6.01) (5.34-6.89) (5.96-8.28) (6.43-9.33) (6.75-10.5) (6.98-11.8) (7.34-13.4) (7.61-14.6) 4.50 5.18 6.25 7.11 8.23 9.07 9.87 10.6 11.6 123 45-day (4.02-5.04) (4.61-5.80) (5.55-7.02) (6.26-8.02) (6.95-9.56) (7.47-10.7) (7.82-12.0) (8.05-13.4) (8.41-15.1) (8.68-16.4) 5.05 5.83 7.05 8.01 9.28 10.2 11.1 11.9 12.9 13.6 sclay (4.52-5.63) (5.21.6.50) (6.27-7.89) (7.09-9.02) (7.85-10.7) (8.42-12.0) (8.79-13.4) (9.02-14.9) (9.38-16.7) (9.66-18.1) I Precipitation frequency (PF) estimates in this table are based on frequency analysis of partial duration series (PDS). Numbers in parenthesis are PF estimates at lower and upper bounds of the 90% confidence interval. The probability that precipitation frequency estimates (for a given duration and average recurrence interval) will be greater than the upper bound (or less than the lower bound) is 5%. Estimates at upper bounds are not checked against probable maximum precipitation (RIP) estimates and may be higher than currently valid RIP values. Please refer to NOAA Atlas 14 document for more information. Vprecipitation `= 3.44 in 25-yr, 24-hour storm intensity Vprecipitation = ' precipitation ' Atankfarm = 3901 . 6 ft3 Eq. [2] Vprecipitation = 694. 9 bbl 25-yr, 24-hour storm volume in tank farm Vlargesttank °= 1000 bbl Volume of largest tank in tank farm Vtotal °= 1 .25 Vlargesttank + Vprecipitation = 1944. 9 bbl Eq [3] Req'd tank farm contain 2 A 15. 5tank ( 15. 5 ft) = 188. 7 ft2 Eq [4] Footprint of 15. 5' tanks 4 2 A 12tank °_ —y • ( 12 ft) = 113. 1 ft2 Eq [5] Footprint of 12' tanks 4 n 15.5tank 17 Number of 12' and 15. 5' tanks n 12tank `= 10 A ef f_containment `- Atankfarm n 15.5tank A 15.5tank + n 12tank ' A 12tank = 9271 . 5 ft2 Eq [6] Effective containment area of the tank farm H Vtotal containment '- = 1 . 2 ft Eq [7] Required Wall Hight for Tank Farm — - - Aeff_containment Result is a tank farm wall height of 1.5' per preferred structural wall height. Unloading Pad Containment Required Storage for Unloading Pad L off load '= 107. 5 ft Length of offload pad woff load '= 160 ft Width of offload pad A unload '= Loffload ' w off load = 17200 ft2 Footprint of offload pad Eq. [8] Volume of Vprecipitation I precipitation ' A unload = 878. 2 bbl precipitation from offload pad V truck l= 150 bbl Voffload req'd '7" Vprecipitation + 1 .25 • Vtruck = 5983.4 ft3 Eq. [9] Total Required Offload Storage Storage Provided by Offload Pad Geomety 1 . 17 ft - 80 ft - woffload 3 Eq. [ 10] Volume from Voffload approach :- 2 = 7488 ft offload pad approach slope 1 . 17 ft - 25 ft - woffload _ 3 Eq. [ 11] Volume from V off load departure :- 2340 ft offload pad departure slope 2 w off load trench '= 2. 5 ft Width of offload pad trench L offload trench '= woffload — 1 f t = 159 ft Length of offload pad trench Soffload_trench '= 0. 02 ft Slope of offload pad trench ft offload trench US '= 10 in Depth of offload pad trench at upstream side 2 - Doff load trench US + Soffload trench - Loffload trench ft3 Voffload trench '- woffload trench ' Lot-fload trench ' - - 2 - - = 963. 3 Eq. [ 12] Volume stored in offload pad area Storage Provided by Offload Sump Loffload_sump '= 20 ft Length of offload sump Woffload_sump '= 12 ft Width of offload sump D off load_sump '= 6 ft Depth of offload sump Voffload sump '= Loffload sump aWoffload sump ' Doffload sump — 1440 ft3 Eq. [ 13] Volume of offload sump Total Available Storage Voff load '= Voffload approach + Voffload departure + Voffload trench + Voffload sump = 12231 . 3 ft3 Eq. [ 14] Storage = if V > V " ade uate" , " inad uate" _ " ade uate" g offload offload regd q q ENVIRONMENTAL @EQWO©L!@ October 31 , 2014 Mr. Nick Valencia M3 Construction, LLC 2861 W. 120th Avenue, Suite 250 Westminster, Colorado 80234 Subject: Spill Prevention Control and Countermeasure (SPCC) Plan NGL Water Solutions DJ, LLC C12 Saltwater Disposal Facility NESW Section 27, T5N, R63W Kersey, Weld County, Colorado CGRS Project: 1-12462-14804ab Dear Mr. Valencia: Please find the enclosed SPCC Plan that CGRS, Inc. (CGRS), prepared for the above referenced NGL Water Solutions DJ, LLC (NGL) C12 Saltwater Disposal facility in Kersey, Colorado. The facility described in this Plan is not operational at this time as the facility is under construction. After construction is completed the facility will be inspected and SPCC plan amended, if needed, to accurately describe facility operations. CGRS, Inc., appreciates the opportunity to provide professional environmental services to NGL and M3 Construction. If you have any questions, please call me at (800) 288-2657. Sincerely, CGRS, Inc. Kenneth M. Rogowski Project Manager/Scientist Enclosures 1301 Academy Court Fort Collins, CO 80524 T 800-288-2657 F 970-493-7986 www.cgrs.com SPILL PREVENTION, CONTROL, AND COUNTERMEASURE PLAN NGL Water Solutions DJ LLC, C12 Saltwater Disposal Facility, Weld County, Colorado CGRS Project Number: 1 - 12462-14804ab Prepared for: M3 Construction, LLC 2681 W 120th Avenue, Suite 250 Westminster, Colorado 80234 Prepared by: CG Pprom CGRS, Inc. 1301 Academy Court Fort Collins, Colorado 80524 October 31, 2014 TABLE OF CONTENTS Section Description [SPCC Regulation Cross reference] Page 1 .0 PLAN CERTIFICATION 1 1 . 1 Certifying Engineer Statement [ 112.3(d)] 1 1 .2 Management Approval Statement [112.7] 1 2.0 GENERAL 2 2. 1 SPCC Plan Description [ 112.7(a)(1)] 2 2.2 SPCC Plan Location [ 112.3(e)] 2 2.3 Amendment and Review Procedures [112.5] 2 2.4 Facilities Not Yet Operational [ 112.7] 3 2.5 Deviation from Requirements [112.7(a)(2)] 3 2.6 Facility Description [112.7(a)(3)] 3 2.7 Facility Storage [112.7(a)(3)(i)] 4 2.8 Discharge Prevention Measures [ 112.7(a)(3)(ii)] 6 2.9 Discharge Controls [ 112.7(a)(3)(iii)] 7 2. 10 Countermeasures: Discovery/Response/Cleanup [ 112.7(a)(3)(iv)] 7 2. 11 Disposal [112.7(a)(3)(v)] 8 2. 12 Notification Phone List [ 112.7(a)(3)(vi)] 8 2. 13 Discharge Notification Form [112.7(a)(4)] 9 2. 14 Discharge Procedures [112.7(a)(5)] 9 2. 15 Discharge Prediction [112.7(b)] 11 2. 16 Secondary Containment for Loading/Unloading Areas Other Than Rack [ 112.7(c)] 11 2. 17 Statement of Impracticability [112.7(d)] 12 3.0 INSPECTIONS, TESTS AND RECORDS 12 3. 1 Inspections and Record-Keeping [ 112.7(e)] 12 4.0 PERSONNEL TRAINING 12 4. 1 Personnel Instruction [112.7(O(1)] 12 4.2 Designated Individual for Spill Prevention [112.7(O(2)] 13 4.3 Spill Prevention Briefings [112.7(O(3)] 13 5.0 SECURITY [ 112.7(g)] 13 5. 1 Securing and Controlling Access 13 5.2 Securing Master Flow/Drain Valves 13 5.3 Preventing Unauthorized Access to Starter Controls 13 5.4 Securing Loading/Unloading Connections 14 5.5 Security Lighting 14 6.0 TANK TRUCK LOADING AND UNLOADING 14 6. 1 Secondary Containment for Loading/Unloading Areas Including Racks [ 112.7(h)(1 )] 14 6.2 Warning Barrier Systems [112.7(h)(2)] 14 6.3 Bottom Drains of Vehicles Examined [112.7(h)(3)] 14 7.0 OTHER GENERAL REQUIREMENTS 14 7. 1 Brittle Fracture/Other Failure Evaluation — Field Constructed Aboveground Containers [ 112.7(i)] 14 7.2 Conformance with Stricter State Rules [112.7(j)] 14 7.3 Oil-filled Operational Equipment [ 112.7(k)] 15 8.0 FACILITY DRAINAGE 14 8. 1 Drainage from Diked Areas [ 112.8(b)(1)] 14 8.2 Dike Drainage Valves — Manual, Open/Closed Designed [ 112.8(b)(2)] 14 8.3 Drainage System for Undiked Areas [ 112.8(b)(3)] 14 8.4 Final Drainage Diversion System [112.8(b)(4)] 15 8.5 Backup Pump for Lift Station and Transfer Systems [112.8(b)(5)] 15 9.0 BULK STORAGE TANKS 15 9. 1 Containers Compatible with Materials Stored [112.8(c)( 1)] 15 9.2 Secondary Containment [112.8(c)(2)] 16 9.3 Rainwater Drainage Procedure [ 112.8(c)(3)] 16 9.4 Buried Metal Tanks Corrosion Protection [112.8(c)(4)] 16 9.5 Partially Buried Tanks Protected Against Corrosion [112.8(c)(5)] 16 9.6 Integrity Testing [112.8(c)(6)] 16 9.7 Internal Coils [ 112.8(c)(7)] 17 9.8 Engineered to Avoid Discharges [112.8(c)(8)] 18 9.9 Plant Effluent Discharges to Navigable Water [ 112.8(c)(9)] 18 9. 10 Oil Leaks Promptly Corrected [ 112.8(c)(10)] 18 9. 11 Mobile or Portable Oil Storage Tanks [112.8(c)(11 )] 18 10.0 FACILITY TRANSFER OPERATIONS 18 10. 1 General 19 10.2 Buried Pipe Installations [112.8(d)( 1)] 19 10.3 Terminal Pipe Connections Capped or Blank Flanged [112.8(d)(2)] 19 10.4 Aboveground Pipe Supports [112.8(d)(3)] 19 10.5 Testing and Inspection of Aboveground Pipes and Valves [112.8(d)(4)] 19 10.6 Warning for Trucks of Pipes [ 112.8(d)(5)] 19 11 .0 SUBSTANTIAL HARM [112.20(e)] 19 FIGURES FIGURE 1 : Site Location Map FIGURE 2A: Site Conditions Map FIGURE 2B: Site Conditions Map (Tank Farm Detail) APPENDICES APPENDIX A: SPCC Review Log APPENDIX B: Aboveground Storage Tank Ullage Log APPENDIX C: DOT Requirements APPENDIX D: Emergency Spill Response Contacts APPENDIX E: Spill Documentation Form APPENDIX F: Inspection and Recording Forms APPENDIX G: SPCC Training Signoff Sheet APPENDIX H: Secondary Containment Volume Calculations APPENDIX I: Self-Determination Criteria Spill Prevention Control and Countermeasure Plan NGL Water Solutions DJ LLC October 31, 2014Cl2 Facility Page I Weld County, Colorado 1.0 PLAN CERTIFICATION 1.1 Certifying Engineer's Statement 1112.3a1)1: The undersigned Registered Professional Engineer is familiar with the requirements of the Code of Federal Regulations, Title 40, Part 112 (40 CFR Part 112), and he or his agent has examined the facilities. The undersigned Registered Professional Engineer attests that this Spill Prevention, Control, and Countermeasure (SPCC) Plan has been prepared in accordance with good engineering practices including applicable industry standards, and in accordance with the requirements of 40 CFR Part 112; that procedures have been established for required inspections and testing; and that the Plan is adequate for the facilities. This certification in no way relieves the owner/operator of the duty to prepare and fully implement this SPCC plan in accordance with the requirements of 40 CFR Part 112. - Date: -v\t' f ) ,p ) 7 rannan Davis,, P.E.P.E / Colorado State Registration No: 44268 __�AQO��N.!t` �. •..•..•o, tk II - '0 •••NA. O .`sFp to .q to. �p i 3'3 e, i ` 4425k - /. t st valet••..o,••' se t91,(VONAtt�� 1.2 Management Approval Statement 1112.71: This SPCC Plan is fully supported by the management of NGL Water Solutions DJ LLC (NGL). NGL is committed to the prevention of discharges of oil to navigable waters or the environment, and maintains the highest standards for spill prevention, control, and countermeasures through periodic review, updating, and implementation of this Plan. NGL will implement this Plan and amend it as needed due to expansions, modifications and improvements at the NGL C12 Saltwater Disposal facility and will provide the manpower, equipment, and materials required to expeditiously control and remove any quantity of oil discharged that may be harmful. 1/'O0u "— C5j4e)-- Date: 11 ` b 14 Mr./osh Patterson VP of Operations NGL Water Solutions DJ Spill Prevention Control and Countermeasure Plan October 31, 20I4 NGL Water Solutions DJ LLC Page 2 C12 Facility Weld County, Colorado 2.0 GENERAL 2.1 SPCC Plan Description [112.7(a)(1)l The following SPCC Plan has been developed as part of a comprehensive plan to minimize the potential for oil discharges at the NGL C12 Saltwater Disposal facility located in Kersey, Colorado. The plan is designed to guide personnel in their oil spill prevention activities and satisfy applicable federal requirements outlined in 40 CFR, Part 112, and Colorado Oil and Gas Conservation Commission (COGCC) Rule 906 for facilities that have total aggregate aboveground oil storage capacity greater than 1 ,320 gallons. 2.2 SPCC Plan Location 1112.3(e)1 The NGL C12 Saltwater Disposal facility is manned 24 hours a day and in accordance with 40 CFR 112.3(e), a complete copy of the SPCC Plan is maintained on site for use by oil handling personnel. The NGL main office is located approximately 22 miles west from the NGL C12 disposal facility location. The plan is available for inspection by regulatory officials at all times. 2.3 Amendment and Review Procedures 1112.51 The SPCC Plan will be amended as needed by NGL whenever there is a change in the facility design, construction, operation, or maintenance which materially affects the potential to discharge oil into navigable waters or adjoining shorelines. Any technical amendment to this SPCC Plan will be effective only if certified by a Professional Engineer in accordance with 40 CFR, Part 112.3(d). In addition, NGL will review and evaluate the current SPCC Plan at least once every five years. As a result of such review, the SPCC Plan will be updated and modified to include more effective prevention and control technology where applicable. All technical plan amendments will be certified by a Professional Engineer and fully implemented within six months of the date of the facility change. All administrative plan amendments will be made by the operator; however, administrative amendments do not require certification by a Professional Engineer. SPCC Plan reviews will be documented on a review log that will be maintained with the SPCC Plan. The following table outlines non-technical verses technical amendments and describes the management review process. The SPCC Plan Review Log form is provided in Appendix A. Non-Technical Amendments • Non-technical amendments are not required to be certified by a Professional Engineer. • Examples of non-technical amendments include, but are not limited to, phone numbers, name changes, or any non-technical text changes. Spill Prevention Control and Countermeasure Plan October 31, 2014 NGL Water Solutions DJ LLC Page 3 C12 Facility Weld County, Colorado Technical Amendments • Technical amendments are certified by a Professional Engineer. • Examples of technical amendments include, but are not limited to, commissioning or decommissioning containers; replacement, reconstruction, or movement of containers; reconstruction, replacement, or installation of piping systems; construction or demolition that may alter secondary containment structures; changes of product or service; or addition or deletion of standard operation or maintenance procedures related to discharge prevention measures. It is the responsibility of the operator to determine, and confirm with the regulatory authority as necessary, what constitutes a technical amendment. The preamble of the rule states that an amendment is required only "when there is a change that materially affects the facility's potential to discharge oil" (67 FR 47091). • An amendment made under this section will be prepared within six (6) months of the change and implemented as soon as possible but no later than six (6) months following preparation of the amendment. [112.5(a)] 2.4 Facilities Not Yet Operational 1112.71 The NGL C12 Saltwater Disposal facility described in the SPCC Plan is expected to be fully operational in June 2015. Planned spill prevention improvements and procedures will be completed within six months of the date of the SPCC Plan. If the facility is not constructed according to the specifications of this SPCC plan, then this SPCC plan must be amended. 2.5 Deviations from Requirements 1112.7(a)(2)1 The NGL C12 Saltwater Disposal facility does not include any deviations from the SPCC requirements. 2.6 Facility Description 1112.7(a)(3)1 NGL owns and operates the C12 Saltwater Disposal facility which is currently under construction; an onshore oilfield water storage and Class II Saltwater Disposal facility. Oilfield production water with small amounts of oil, ranging from 1 .5-3%, is transported to the site by tanker trucks that vary in size. The largest transport has up to a maximum of approximately 9,240 gallons (220 BBL). The production water delivered to the site will be offloaded from the tank trucks in the offload bay, which includes a sloped concrete pad with a trenched drain, running to a sump that collects surface runoff. The sump routes runoff from the concrete offloading pad to the de-sanding tanks where it is pumped back into an oil skim tank. The water offloaded from the tanker trucks is pumped directly from the transports into two 29,400 gallon (700 BBL) de-sanding tanks (T-1, T-2) for particulate removal from the production water. The de-sanding tank removes solids greater than approximately 120 gm. Then the water is gravity fed into two 42,000 gallon (1000 BBL) oil skim tanks (T-3, T-4) for initial oil separation. Residual oil is skimmed from the tank and the recovered oil is pumped to the oil storage tanks, which consist of three 16,800 gallon (400 BBL) aboveground storage tanks (ASTs), which are identified as T-oil-1 , T-oil-2, and T-oil-3. After initial Spill Prevention Control and Countermeasure Plan October 31, 2014 NGL Water Solutions DJ LLC Page 4 CU Facility Weld County, Colorado separation, the liquid (approximately 98.5% water by volume) is transferred to the eight manifolded 35,280-gallon (840 BBL) water equalization/storage ASTs (T-5 through T-12). The majority of the remaining oil within the production water is recovered during this process, and the recovered oil is transferred to a 16,800 gallon (400 BBL) oil heat AST (T-Heat) where it is heated then piped into the 16,800 gallons (400 BBL) sale oil tank (T-Sale) or to the 16,800 gallon (400 BBL) slop oil tank (T-Slop). The water is then transferred to the pump house where it is filtered and transferred to one of two 42,000-gallon (1000 BBL) "clean water" tanks (T-13 and T-14), and subsequently injected into the subsurface injection well. Overall, the facility consists of a concrete offloading pad, pump house, one injection well, and a concrete secondary containment dike that stores two 29,400-gallon (700 BBL) de-sanding ASTs (T-1 , T-2), two 42,000-gallon (1 ,000 BBL) oil skim AST (T-3, T-4), eight 35,280-gallon ((840 BBL) water equalization ASTs (T-5 through T-12), three 16,800-gallon (400 BBL) recovered crude oil storage ASTs (T-oil-1 , T-oil-2, T-oil-3), one 16,800-gallon (400 BBL) sale oil AST (T-Sale), one 16,800-gallon (400 BBL) waste oil AST (T-Slop), one 16,800-gallon (400 BBL) oil heat AST (T-Heat), and two 42,000-gallon (1 ,000 BBL) clean water storage ASTs (T-13, T-14). All facility ASTs are contained within a secondary containment area. In addition, the facility contains a 2,520 gallon (60 BBL) sump which collects runoff from the offloading area which is manually pumped into the oil separation AST when necessary. The facility is located in the Norththeast % of the Southeast 'A of Section 27, Township 5 North, Range 63 West, in Weld County, Colorado. The facility is located approximately 960 feet North of Weld County Road (WCR) 388 and approximately 0. 12 miles west of WCR 69. The facility is surrounded by native grasses and agricultural land. The regional topography is relatively level with drainage to the south and southeast. Surficial runoff within the concrete unloading area will be captured within the pad drain which drains to the sump. All other site runoff is generally sheet flow to the south and southeast where the water should eventually infiltrate into surficial soils. The nearest significant water body is the Riverside Intake Canal located approximately 1 ,115 feet south of the facility. Additionally the South Platte River is located approximately 1 .05 miles to the south of the facility. Site location and area topographic and surface water features are depicted on Figure 1 (topographic map). General site conditions and facility details are shown on Figure 2. 2.7 Facility Storage f 112.7(a)(3)(i)1 The following table describes ASTs associated with storage of oil products at this facility: Capacity Tank Dimentions Tank ID# (gallons) Tank Process Dia. (ft)IHeight Construction Material (ft) De-Sanding Tank Fiberglass reinforced plastic AST within main concrete T-1 29,400 (unloading tank) 12/40 secondary containment T-2 29,400 De-Sanding Tank 12/40 Fiberglass reinforced plastic AST within main concrete (unloading tank) secondary containment Spill Prevention Control and Countermeasure Plan October 31, 2014 NGL Water Solutions DJ LLC Page 5 C12 Facility Weld County, Colorado Fiberglass reinforced plastic AST within main concrete T-3 42,000 Oil Skim Tank 15.5/30 secondary containment Fiberglass reinforced plastic AST within main concrete T-4 42,000 Oil Skim Tank 15.5/30 secondary containment T-5 35,280 Water 15.5/25 Fiberglass reinforced plastic AST within main concrete Equalization/Storage secondary containment T-6 35,280 Water 15.5/25 Fiberglass reinforced plastic AST within main concrete Equalization/Storage secondary containment T-7 35,280 Water 15.5/25 Fiberglass reinforced plastic AST within main concrete Equalization/Storage secondary containment T-8 35,280 Water 15.5/25 Fiberglass reinforced plastic AST within main concrete Equalization/Storage secondary containment T-9 35,280 Water 15.5/25 Fiberglass reinforced plastic AST within main concrete Equalization/Storage secondary containment T-10 35,280 Water 15.5/25 Fiberglass reinforced plastic AST within main concrete Equalization/Storage secondary containment T-11 35,280 Water 15.5/25 Fiberglass reinforced plastic AST within main concrete Equalization/Storage secondary containment T-12 35,280 Water 15.5/25 Fiberglass reinforced plastic AST within main concrete Equalization/Storage secondary containment T-13 42,000 Clean Tank 15.5/30 Fiberglass reinforced plastic AST within main concrete secondary containment T-14 42,000 Clean Tank 15.5/30 Fiberglass reinforced plastic AST within main concrete secondary containment T-Oil-1 16,800 Oil Storage 12/20 Single-wall steel shop fabricated vertical AST within main concrete secondary containment T-Oil-2 16,800 Oil Storage 12/20 Single-wall steel shop fabricated vertical AST within main concrete secondary containment T-Oil-3 16,800 Oil Storage 12/20 Single-wall steel shop fabricated vertical AST within main concrete secondary containment T-Sale 16,800 Sale Oil Storage 12/20 Single-wall steel shop fabricated vertical AST within main concrete secondary containment T-Slop 16,800 Slop Oil Storage 12/20 Single-wall steel shop fabricated vertical AST within main concrete secondary containment T-Heat 16,800 Slop Oil Storage 12/20 Single-wall steel shop fabricated vertical AST within main concrete secondary containment Total 580,440 The following table describes other oil containers with capacities of 55-gallons or greater at the facility: Oil Storage Location Number Type of Container Contents Capacity (gallons) Pump House 1 55-Gallon metal drum 55 Lubricant oil Total 55 Facility storage capacity for containers 55 gallons and greater is approximately 580,495 gallons. Spill Prevention Control and Countermeasure Plan October 31 , 2014 NGL Water Solutions DJ LLC Page 6 C12 Facility Weld County, Colorado 2.8 Discharge Prevention Measures (112.7(a)(3)(ii) NGL ensures that any releases due to spilling or overfilling do not occur. NGL only accepts disposal water when there is adequate capacity in the tanks to receive it. Monitoring of the transfer operation is done visually, with strict attention being paid to the volume received in accordance with available tank capacity. Manual tank gauging and sight confirmation of tank liquid levels are performed approximately every two hours with additional gauging as needed. Offloading procedures and equipment consist of a transfer pump, situated on the offloading pad that transfers fluid from the offloading tanker into the de-sanding/unloading ASTs. After the initial separation of the oil and water in the oil separation tank, the oil is transferred into the recovered crude storage ASTs. As aforementioned, tank filling does not begin until the plant operator has verified and documented the ullage (available capacity) based on manual tank gauge measurements and sight confirmation. In addition, electronic gauges are utilized that automatically shut down the transfer pump when approximately 90% of tank volume capacity is reached. After separation of the oil from the production water, the water is transferred to the manifolded water equilization ASTs, and subsequently transferred to the pump house for the final filtration process. After filtration of the production water, the water is transferred to the "clean" water ASTs, and back through the pump house where it is injected into the subsurface via the injection well located east of the pump house. Any water spilled within the pump house during pump maintenance or regular pump operation flows to a floor drain which drains into a sump located within the main secondary containment area. An example Ullage Log is provided in Appendix B. NGL requires all drivers to comply with DOT regulations in 49 CFR Part 177 regarding tank loading and unloading procedures. DOT requirements are provided in Appendix C. The following procedures are implemented when ASTs are being loaded: • Vehicle's motor and lights are turned off, and the parking brake is set • The driver does not remain in the vehicle • Outlet valves are closed • Grounding procedures are followed • Ungrounded objects are removed from loading/unloading areas • Flow is started slowly. The fill pipe is touching both the truck hatch and bottom of compartment • Transfer operator is present and attentive After loading is complete, the following procedures are followed: • All loading valves are closed and loading arms disengaged. Signs of spillage are noted and remedial action taken if necessary Spill Prevention Control and Countermeasure Plan October 31, 2014 NGL Water Solutions DJ LLC Page 7 C 12 Facility Weld County, Colorado • All hatches are closed tightly • Internal safety valves are closed 2.9 Discharge Controls (112.7(a)(3)(iii). The ASTs and all associated piping and equipment are located within a diked secondary containment or the offloading pad, which will contain and control any potential discharges from the tanks, equipment, and transport trucks. Any spills occurring within the pump house will be actively contained with a spill kit containing absorbent materials (boom, speedi-dry, etc) and will be disposed of properly. The design of the offloading pad consists of two surfaces; the offload approach and the offload departure pad. The offload trench, which is located between the approach and departure pad, is designed to convey all fluids at a 2% slope toward the offload containment sump, which is pumped into the de-sanding tank. Any construction joints will be sealed to prevent leakage through containment. Additionally, a 30mm liner will be installed underneath the offload pad trench drain and offload sump containment. A permanent 3-inch PVC pipe (Monitoring Point) will be installed vertically under the offload sump to monitor any leaks that may occur outside of the containment area. This monitoring point will be physically checked for the presence or absence of liquids on a daily basis by NGL personel. Furthermore, NGL maintains spill response oil absorbent materials readily available at the facility that can be deployed immediately to contain and abate potential discharges outside the secondary containment areas. Spill kits are located in the tank farm and the pump house and contain absorbent material and hand tools to mitigate smalls spills (< 50 gallons). NGL instructs oil handling personnel to assure that all 55-gallon oil drums are stored properly and within containment areas (if applicable) and that drum openings are sealed appropriately when not in use to prevent spills. NGL assures that all transfer equipment is compatible with the products being dispensed. Furthermore, drum fittings are securely attached to the appropriate bung openings and operated according to manufacturer recommendations. 2.10 Countermeasures: Discovery/Response/Cleanup [112.7(a)(3)(iv)1 NGL employees and contractors are aware of the need to immediately report all spills of oil products Mr. Josh Patterson, the primary contact. If the primary contact is not available, the NGL Main Office will be notified. In the event of a large spill requiring emergency response (i.e., spill spreads beyond the immediate spill area, enters surface water, requires special training or equipment, poses a danger of fire or explosion), emergency personnel from the Platte Valley Fire Protection District can be summoned by calling 911 . Spill response will be initiated as soon as possible to stop additional spillage and to implement containment measures. NGL personnel and contractors maintain spill response supplies and oil absorbent materials readily available in their vehicles to respond to spills and begin immediate cleanup measures. Heavy equipment, including excavation vehicles and equipment, are available in the area provided by Mundt Oilfield Services. Pumps and vacuum tanker trucks are Spill Prevention Control and Countermeasure Plan October 31, 2014 NGL Water Solutions DJ LLC Page 8 C12 Facility Weld County, Colorado available in the area from either Wright Choice or Magna Energy Services. Manual tools, such as shovels and rakes, for use in containment and cleanup of spills will also be used if needed. Discovery, response, and cleanup activities are described in more detail in the following sections. 2.11 Disposal [112.7(a)(3)(v)j The final operation in spill response and cleanup is the disposal of impacted materials. Any plan for disposal used by NGL must be coordinated through the appropriate regulatory agency. If the impacted material is related to a release of oil or produced water from the tank battery system, the agency for oversight is the Colorado Oil and Gas Conservation Commission (COGCC). If from a source not regulated by COGCC (such as a tanker truck in transit), the agency for oversight is the Colorado Department of Public Health and Environment (CDPHE), Solid Waste Division. Impacted material must be disposed of at an appropriate facility permitted with the CDPHE, or other appropriate regulatory agency, to receive the type of waste being shipped and with shipment documented using proper manifest or bill-of-lading forms, if required. NGL will submit a follow-up written report to the appropriate agency within 60 days following a release, or in accordance with the requirements of the agency. 2.12 Notification Phone List [112.7(a)(3)(vi)1 A contact list and phone numbers for individuals, emergency response authorities, spill response/cleanup contractors and regulatory agencies to be notified in the event of leakage or spills is provided in Appendix D. Spills ultimately reaching navigable waters in harmful quantities as defined by 40 CFR Part 110.3 (that which violates applicable water quality standards or causes a sheen on the water surface) are required to be reported under 40 CFR Part 110.6. If a spill or release of exploration and production waste or produced fluids occurs and is greater than 1 BBL (42 gallons), it must be reported to the following regulatory agency within 24 hours: Colorado Oil and Gas Conservation Commission Environmental Release/Incident Report Hotline Denver, Colorado (1-877-518-5608) After hours or related to a container not regulated by COGCC contact: Colorado Department of Public Health and Environment Denver, Colorado (1-877-518-5608) (24-Hour) In the event of a large spill requiring emergency response (i.e., spill spreads beyond the immediate spill area, enters surface water, requires special training or equipment, poses a danger of fire or explosion), contact the following: Platte Valley Fire Protection District — Station 37 Kersey, Colorado 911 (24-Hour) (970) 353-3890 (Main Number) Spill Prevention Control and Countermeasure Plan October 31 , 2014 NGL Water Solutions DJ LLC Page 9 C12 Facility Weld County, Colorado If the release reaches navigable water, contact the following: National Response Center Washington, DC (1-800-424-8802) (24-Hour) 2.13 Discharge Notification Form 1112.7(a)(4)l An example form for spill documentation and reporting is provided in Appendix E. When contacting regulatory agencies, the following information should be provided: • name and owner/operator of facility • responsible company/person, including mailing address and telephone number • name of person reporting the release • date and time of release • legal description of release location • type and amount of substance released • waterway affected, including amount reaching water • cause of release • action taken to control, contain, and remove release • other pertinent information specific to the release In accordance with 40 CFR Part 112.4(a), if the facility has a discharge to navigable water of more than 1,000 gallons of oil in a single event or discharges more than 42 gallons of oil in each of two discharges occurring within any twelve month period, NGL will submit the following information to the EPA Regional Administrator within 60 days from the day of the discharge: • Name of the facility • Callers name • Location of the facility • Maximum storage or handling capacity of the facility and normal daily throughput • Corrective action and countermeasures taken, description of equipment repairs and replacements • Description of the facility, including maps, flow diagrams, and topographic maps, as necessary • Description of the cause of the discharge, including a failure analysis of the system or subsystem that failed • Additional preventative measures taken or contemplated to minimize the possibility of recurrence • Any other information as the Regional Administrator may reasonably require pertinent to the Plan or discharge 2.14 Discharge Procedures 1112.7(a)(5)1 After identifying and locating a spill, the necessity for and feasibility of effective containment can be assessed. Containment must be initiated as soon as possible to prevent undue spreading of released product. The first action Spill Prevention Control and Countermeasure Plan October 31, 2014 NOL Water Solutions DJ LLC Page 10 C12 Facility Weld County, Colorado should be the elimination of any additional spillage. This may be accomplished by shutting off a pump or valve, placing a cap or a plastic or epoxy patch over the leak, putting a temporary plug in a puncture or tear, or other appropriate action. A review of operations at the NGL C12 facility indicates a low potential for a petroleum release to the environment. Additionally, several of the manifolded ASTs are equipped with high level alarms to reduce the risk of overfilling. The C12 facility has yet to be constructed and therefore has had no reported spills of petroleum products from the ASTs or oil storage containers which have qualified as "spill events" under the federal definition. The following table describes storage containers and associated equipment where potential discharges could occur. The table includes predictions of failure types, estimated volume, flow rate and the direction of flow, which could be discharged from the facility as a result of each type of major equipment failure and general secondary containment notes. Source Volume Estimated Direction of Secondary Type of Failure (contents) (gallons) Flow Rate Flow Containment Outward Desanding Tanks 29,400 Gradual to within Concrete secondary (oil/water) Rupture each instantaneous containment containment with (T1 , T2) collection sump to south Outward Oil Skim Tanks Concrete secondary 29,400 Gradual to within (oil/water) Rupture each instantaneous containment containment with (T3, T4) collection sump to south Production water Outward (water and minor 35,280 Gradual to within Concrete secondary Rupture containment containment with oil mixture) each instantaneous to south collection sump (T5 - T12) Outward Clean Water 42,000 Gradual to within Concrete secondary (water and minor Rupture each instantaneous containment containment with oil mixture) to south collection sump (TI3, T14) Outward Oil Storage Tanks Concrete secondary (T-Oil-I ' T-Oil-2, Rupture 16,800 Gradual to within p each instantaneous containment containment with T-Oil-3) collection sump to south Outward Oil Slop Tank within Concrete secondary (water/oil) Rupture 16,800 Gradual to containment containment with (T-Slop) each instantaneous ( p) to the east or collection sump south Outward Oil Heat Tank within Concrete secondary 16,800 Gradual to (oil) Rupture each instantaneous containment containment with (T-Heat) to the west collection sump or south Spill Prevention Control and Countermeasure Plan October 31, 2014 NGL Water Solutions DJ LLC Page 11 C12 Facility Weld County, Colorado Source Type of Failure Volume Estimated Direction of Secondary (contents) (gallons) Flow Rate Flow Containment Outward Sale Oil Tank within Concrete secondary (oil) Rupture 16,800 Gradual to containment containment with (T-Sale) each instantaneous ( ) to the west collection sump or south Outward Concrete secondary AST Piping Rupture *1 to 30 1 to 60 gal/min within containment with containment collection sump to sump Tanker Truck Hose rupture, West loading from oil connection failure or *1 to 50 50-100 gal/min towards AST concrete tank load out overfill containment containment drain Active secondary 55-Gallon drum in Rupture 1 to 55 Gradual to Radial containment Pump house instantaneous across floor materials, spill response absorbents * Predicted releases associated with oil transfer activities are based on the attendant being present in close proximity to the pump controls, the loading valve or pump switch accessible, and the attendant shutting the valve or pump switch within a conservative time frame of 30 seconds. Oil absorbent materials maintained at the C12 facility will be used to contain and clean up spilled product. If required, excavation equipment and/or manual tools, such as shovels and rakes, will be used to erect earthen berms along the leading edge of the spill to prevent spreading. Materials recovered during cleanup will be placed in appropriate containers or stockpiled using an impermeable liner and cover (such as polyethylene sheeting) to prevent cross- contamination with unexposed media prior to disposal. If free phase petroleum product is present or if the spill reaches surface water, the spill must be contained and removed. Mechanical methods of spill removal include suction hoses, excavation, the use of skimmers, and sorbent materials. The use of chemical or biological collecting agents is discouraged and may only be used with prior approval from both state and federal regulatory officials. NGL instructs all personnel who operate the tank battery systems on deployment measures needed to contain and cleanup a potential spill. 2.15 Discharge Prediction 1112.7(b)1 A review of operations at the C12 Saltwater Disposal Facility indicates a low potential for release. Since the initial installation of the saltwater disposal facility storage tanks, there have been no reported spills of petroleum products at the tank battery facility that have qualified as "spill events" under the federal definition. A detailed description of the storage containers and associated equipment where potential discharges could occur are summarized in facility specific spill prediction tables in Appendix H. Spill Prevention Control and Countermeasure Plan October 31, 2014 NGL Water Solutions DJ LLC Page 12 C12 Facility Weld County, Colorado 2.16 Secondary Containment for Loading/Unloading Areas Other Than Rack 1112.7(c)] The production water delivered to the site is offloaded within the load/unload secondary containment area (unloading pad). The design of the unloading pad is such that liquids would be contained on the pad and into the trench drain if a spill were to occur. The unloading pad trench drain routes any release to the unloading pad sump. Transfer pumps and piping used to fill all tanks are within the secondary containment dike or unloading pad containment. Secondary containment for oil transfer activities from the oil ASTs to the tanker trucks are provided by the concrete unloading/loading pad. Overfills, valve or connection failures or dispensing spills at the recovered oil, process water ASTs, and the clean water AST would be contained within the concrete secondary containment. Spill response absorbent materials maintained on-site provide secondary containment for potential discharges that may occur within the pump house or outside any containment area. In the event of a spill outside the secondary containment areas, oil absorbent materials maintained on-site will be placed along the leading edge of the flow path and, if needed, excavating equipment will be used to erect soil berms to contain spills on-site until cleanup measures are completed. NGL instructs all operations personnel who operate the AST systems and are involved with oil handling activities on the location of the spill containment materials and deployment measures needed to contain and clean up spills. 2.17 Statement of Impracticability (112.7(d)] Not applicable; secondary containment is provided for all oil storage containers at the facility. 3.0 INSPECTIONS, TESTS AND RECORDS 3.1 Inspections and Record-Keeping 1(112.7(e)] Inspections are an integral part of NGL operations. As described in more detail in Section 9.6, the AST systems are visually inspected every two hours in addition to each month and annually to ensure that there has been no failure of the tanks or associated equipment. Periodic certified inspections are also performed on the tanks, piping, and transfer equipment. Storage tank inspection reports which have been completed are signed by the appropriate supervisor or inspector and are made part of the current SPCC Plan. NGL management is responsible for all inspection reporting and documentation procedures. These records are kept on file with the SPCC Plan for a minimum period of three years. Inspection and recording forms are provided in Appendix F. Spill Prevention Control and Countermeasure Plan October 31, 2014 NGL Water Solutions DJ LLC Page 13 C12 Facility Weld County, Colorado 4.0 PERSONNEL TRAINING 4.1 Personnel Instruction 1112.7(0(1)1 NGL provides training for personnel involved with handling oil products and in the operation and maintenance of the AST systems to prevent discharges and requires that contracted personnel are similarly trained. Operations and maintenance training includes review of applicable owner's manuals and reference guides related to the ASTs and associated equipment, and general facility operations. Moreover, specific training to instruct oil handling personnel in discharge procedure protocols, applicable pollution control laws, rules, and regulations, which includes a complete review of the SPCC Plan, is provided. Training is provided upon initial employment of each new hire and during periodic safety meetings. Annually, refresher training is provided and spill response deployment exercises are reviewed and/or conducted. Initial employee training, periodic safety meetings and annual refresher training activities are documented, with documentation records maintained on file at the NGL main office. NGL ensures that all contract personnel responsible for operating and maintaining the oil storage tank systems and associated equipment (contract oil handling personnel) are familiar with the facility operations, tank contents, and safety procedures. All contract oil handling personnel who work at the tank battery facility are aware of the SPCC Plan, the plan location, requirements, and spill prevention, control, and reporting procedures prior to working at the tank battery facility. 4.2 Designated Individual for Spill Prevention 1112.7(0(2)1 The designated individual and Response Coordinator (RC) for spill prevention and reporting for NGL is Mr. Josh Patterson, who can be contacted at 970-356-5560 (office). 4.3 Spill Prevention Briefings 1112.7(0(3)1 NGL schedules and conducts spill prevention briefings at least annually during regularly scheduled safety meetings for all personnel involved with oil handling operations to assure adequate understanding of the SPCC Plan. These briefings highlight and describe spill events or failures, malfunctioning components, recently developed precautionary measures, and a review of spill response deployment measures. Employees acknowledge attendance and understanding of these briefings with their signatures on an attendance form. An SPCC training attendance form is provided in Appendix G. Spill prevention briefing attendance forms are maintained on file in the NGL main office. Spill Prevention Control and Countermeasure Plan October 31, 2014 NGL Water Solutions DJ LLC Page 14 C12 Facility Weld County, Colorado 5.0 SECURITY (112.70)] 5.1 Securing and Controlling Access The NGL C12 facility is manned and operates 24 hours per day, 7 days per week. Access is controlled by the facility entry and exit roads and the requirement of personnel to check in at the office upon arrival. Security is provided by the presence of NGL operations personnel 24 hours a day which provides a deterrent to unauthorized access. 5.2 Securing Master Flow/Drain Valves NGL locks master flow/drain valves on applicable ASTs when not in use, or in standby mode for extended periods of time. 5.3 Preventing Unauthorized Access to Starter Controls Starter controls for the AST transfer pumps are located in a control panel which is locked with switches in the off position when not in use, or in standby mode for extended periods of time. NGL limits access into the control panel to authorized personnel trained in the operation of the AST systems. 5.4 Securing Loading/Unloading Connections Loading/unloading pipe connections are securely capped and valves locked when not in use. 5.5 Security Lighting Overhead lighting is present in all of the fuel and production water storage/transfer areas and outlying areas that will assist in the discovery of discharges occurring during hours of darkness both by operating personnel and non- operating personnel and to deter acts of vandalism. 6.0 TANK TRUCK LOADING/UNLOADING 6.1 Secondary Containment for Loading/Unloading Areas Including Racks 1112.7(h)(1)] The ASTs at the facility do not include loading/unloading racks. As described in Section 2. 15, all loading and unloading connections and equipment on the ASTs are within the secondary containment dikes and loading/unloading areas. If a spill occurs from a tanker truck outside the containment areas, NGL maintains readily available absorbent materials and equipment on-site that can be deployed to contain and mitigate potential spills on- site. 6. 2 Warning/Barrier Systems f 112.7(h)(2)] Signs warning drivers to disconnect transfer lines before departure are posted in offloading/loading areas. Spill Prevention Control and Countermeasure Plan October 31, 2014 NGL Water Solutions DJ LLC Page 15 C12 Facility Weld County, Colorado 6. 3 Bottom Drains of Vehicles Examined 1112.7(h)(3)1 NGL assures that prior to filling and departure of any tank truck, the lowermost drain and all outlets of such vehicles are closely examined for leakage and, if necessary, tightened, adjusted, or replaced to prevent liquid leakage while in transit. 7.0 OTHER GENERAL REQUIREMENTS 7.1 Brittle Fracture/Other Failure Evaluation — Field Constructed Aboveground Containers 1112.7(i)1 The NGL C12 facility does not include field-constructed ASTs. 7.2 Conformance with Stricter State Rules 1112.7(1)1 No stricter State discharge prevention and containment procedures are applicable to this facility. 7.3 Oil-filled Operational Equipment 1112.7(k)l The NGL C12 facility has an electrical transformer located on the property. The transformer is not owned by NGL but periodic checks are made to ensure the integrity of the structure and for the evidence of leaks. 8.0 FACILITY DRAINAGE 8.1 Drainage from Diked Areas 1112.8(b)(1)1 The C12 secondary containment area will be constructed entirely of concrete, with storm drains that drain to the sump. All fluids outside of the ASTs and/or piping within the containment area are routed to the sump, which is pumped into the desanding tank. The drain located on the unloading/loading pad also drains to the sump. No fluids are discharged outside of the secondary containment areas. 8.2 Dike Drainage Valves — Manual, Open/Closed Designed [112.8(b)(2)1 There will be no dike drainage valves associated with the AST secondary containment area. The AST secondary containment area routes all water to the sump. 8.3 Drainage System for Undiked Areas f 112.8(b)(3)1 Secondary containment is provided for all aboveground tanks, piping and tanker truck transfer areas to prevent discharges to storm drainages outside the secondary contained areas. 8.4 Final Discharge Diversion System 1112.8(b)(4)1 Spill Prevention Control and Countermeasure Plan October 31, 2014 NGL Water Solutions DJ LLC Page 16 C12 Facility Weld County, Colorado In the event of a discharge outside secondary containment areas, oil absorbent materials maintained at the facility will be used to contain a spill on-site. If required, earthen berms will be constructed with on-call excavating equipment along the leading edge of the spill to retain oil on-site until cleanup measures are completed. 8.5 Backup Pump for Lift Station and Transfer Systems 1112.8(b)(5)1 There is one sump pump to drain the entire contents of the sump into the on-site treatment system. In the event of a sump pump failure, fluids would back up into the primary containment area. 9.0 BULK STORAGE TANKS 9.1 Containers Compatible with Materials Stored [112.8(c)(1)1 The ASTs and any portable containers used for storage of water and petroleum products at the NGL C12 facility are shop manufactured for their intended use. The containers are constructed with materials compatible with the products stored and conditions of storage, such as pressure and temperature. 9.2 Secondary Containment I112.8(c)(2)1 All production water and oil ASTs are contained within the concrete secondary containment area. The containment area is drained by storm drains which route stormwater and any released fluids to the sump. The containment areas are designed to hold the tank with the largest capacity (42,000-gallons) plus freeboard allowance for precipitation. The total calculated capacity is 145,880 gallons. Considering the volume occupied by other tanks and freeboard allowance for a predicted 24-hour, 100-year storm event for the area, the adjusted available holding capacity is approximately 77,946 gallons. The total calculated capacity of the truck offload area and sump containment areas is 63,802 gallons. Considering the freeboard allowance for a predicted 24-hour, 100-year storm event for the area, the adjusted available holding capacity is approximately 25,912 gallons. The unloading pad at the C12 facility drains into the sump located in between the secondary containment areas. The unloading pad is designed with adequate capacity to hold the volume of the largest tank of tanker truck (9,240 gallons) should a release occur. The secondary containment systems at the NGL C12 facility are designed to be impervious to contain spills from the largest tank without loss of oil until cleanup measures are implemented. NGL assures that excess precipitation is removed from the secondary containment areas to maintain adequate spill retention volume for the tanks. Secondary containment volume calculations are presented in Appendix H. 9.3 Rainwater Drainage Procedure 1112.8(c)(3)l Spill Prevention Control and Countermeasure Plan October 31, 2014 NGL Water Solutions DJ LLC Page 17 C12 Facility Weld County, Colorado Precipitation that accumulates within the diked areas drains to the containment area sump, then pumped into the holding tanks. 94 Buried Metal Tanks Corrosion Protection 1112.8(c)(4)1 The facility does not currently operate buried tanks. 9.5 Partially Buried Tanks Protected Against Corrosion [112.8(c)(5)1 The facility does not operate partially buried tanks. 9.6 Integrity Testing 1112.8(c)(6)1 NGL assures that the ASTs and associated equipment are maintained in good condition. The ASTs, valves, transfer equipment, and aboveground piping components are readily accessible for visual inspection. Preventive spill measures include regular periodic inspections of the storage tanks and associated equipment and secondary containment systems following guidelines of the Steel Tank Institute (STI) Standard for the Inspection of Aboveground Storage Tanks SP001 September 2011 5t" Edition. Based on the tank configurations, tank volumes, the tanks being in contact with the ground, and spill control provided by the secondary containment dikes, these activities include the following: • On a monthly basis, the owner inspects the tanks, piping, and associated equipment for evidence of leakage. If needed, gaskets are replaced and threaded connections are tightened. Secondary containment areas are checked for the presence of spills or leaks, which are removed if present. The secondary containment sump pumps are checked to assure they are operable and water transfer piping is unobstructed. Tank gauge calibrations are checked by obtaining stick readings to verify gauge readings. Overfill equipment is tested to assure proper operation. • On an annual basis, the owner inspects the condition of the tank containment structures. Tank foundations and supports are inspected for evidence of settling, cracking or distortion, proper water drainage and grounding. • Inspections of the AST exteriors are performed to identify and repair damage to the tanks or surface coatings. Bolts on flanged manways, piping and equipment are inspected for tightness, wear and corrosion. Normal operating and emergency vents are inspected for proper operation and cleaned if needed. Tank liquid level sensing and overfill prevention devices are tested for proper operation. Electrical equipment, including grounding devices, control boxes and lights are inspected for proper operation. All tanks are Category 1 tanks (as defined by the STI SP001 standard), and should follow the inspection schedule for tanks between 5,001 -50,000 gallons. At a maximum 20 year interval, formal internal inspections are performed by a Certified Tank Inspector. The formal internal inspections generally include inspection of mechanical damage, corrosion, cracking, etc., including the internal attachments and piping. Furthermore, shell thickness testing of the AST floor is Spill Prevention Control and Countermeasure Plan October 31 , 2014 NGL Water Solutions DJ LLC Page 18 C12 Facility Weld County, Colorado performed every 15 years. Additional inspection criteria may be deemed necessary by the certified inspector based on tank configurations and industry standards. The extent and frequency of future inspections will be based on the recommendations of the Certified Inspector. Any leaks discovered during inspection are promptly evaluated and reported to the General Manager. NGL assures that personnel who operate, maintain, and inspect the AST systems are properly trained in the operation and maintenance of the systems and characteristics of the fluids stored, which helps to reduce the probability for a spill. As noted in Section 3.1 , monthly and annual inspection documentation forms are provided in Appendix F. 9.7 Internal Coils f 112.8(c)(7)1 Internal coils are present in the oil heat tank AST (T-Heat). Steam return and exhaust lines are part of a closed loop system so that any oil that accumulates in the steam is not discharged. The tank and associated piping are inspected on a monthly basis to detect leaks or malfunction of the heating element. 9.8 Engineered to Avoid Discharges 1112.8(c)(8)1 NGL only accepts disposal water when there is adequate capacity in the tanks to receive product. Monitoring of the transfer operation is done visually, with strict attention being paid to the volume received in accordance with available tank capacity. Manual tank gauging and sight confirmation of tank liquid levels are performed approximately every two hours with additional gauging as needed. Offloading procedures consist of a transfer pump situated on the pad that transfers fluid from the tanker into the desanding tank, where solids are allowed to settle out and the oil is separated from the water and transferred into the oil tanks. Production water is then pumped into the manifolded system ASTs and then to the pump house where the water is filtered and transferred to the "clean water" tanks. The "clean water" is then transferred back to the pump house and injected into the subsurface via the injection well located east of the facility. Tank filling does not begin until the plant operator has verified and documented the ullage (available capacity) based on manual tank monitoring and sight confirmation. Furthermore, all tanks are equipped with overfill pump shut off sensors, which automatically shut down the pumps once tanks reach approximately 90% available capacity. 9.9 Plant Effluent Discharges into Navigable Water 1112.8(c)(9)l The facility does not have plant effluent discharges to navigable waters. 9.10 Oil Leaks Promptly Corrected [112.8(c)(10)1 Any oil leaks identified through routine inspection are promptly corrected, reported to management, and abated. Spill Prevention Control and Countermeasure Plan October 31, 2014 NGL Water Solutions DJ LLC Page 19 C12 Facility Weld County, Colorado 9.11 Mobile or Portable Oil Storage Tanks [112.8(c)(11)l Currently, there are no portable oil storage containers at the facility. Should any portable container containing over 55- gallons comes on site, they will be placed within a containment area and included in routine inspections. Oil-handling personnel are instructed to maintain appropriate seals and plugs on the container when not in use to prevent spills. If a spill occurs, spilled product will be contained within the building walls and cleaned up with readily available oil absorbent materials. 10.0 FACILITY TRANSFER OPERATIONS 10.1 General General safety features which are applicable to maintaining the integrity of transfer operations include: • Valves and pipelines are examined monthly to assess the condition of the transfer equipment • If corrosion damage is found, additional examination and corrective action are taken as indicated by the magnitude of the damage 10.2 Buried Pipe Installations [112.8(d)(1)1 Most facility piping is aboveground and readily visible for inspection. However, piping related to the pump house including piping connecting the clean water AST to the pump house and piping from the pump houses to the injection well are underground. The piping is subject to additional protection per section 112.8(d)(1). Any replacement of the subsurface piping will be subject to corrosion protection or wrapping. Furthermore, any buried piping that is exposed will be inspected for deterioration. If corrosion damage or leakage at exposed piping is found, additional examination and corrective action will be taken commensurate with the magnitude of the damage. 10.3 Terminal Pipe Connections Capped or Blank Flanged [112.8(d)(2)1 There is no out-of-service piping associated with the AST systems. The terminal pipe connections where the tanker truck connects to unload oil from the oil ASTs are securely capped when not in use and are located inside spill containment enclosures with locking lids, which are labeled to identify what types of product are to be transferred. 10.4 Aboveground Pipe Supports [112.8(d)(3)l NGL maintains adequate bracing on aboveground pipe runs to avoid excess movement that can cause stress and abrasion. Piping on the ASTs is of heavy gauge steel construction and is securely attached with threaded fittings to the tank and ground. 10.5 Testing and Inspection of Aboveground Pipes and Valves [112.8(d)(4)1 Spill Prevention Control and Countermeasure Plan October 31, 2014 NGL Water Solutions DJ LLC Page 20 C12 Facility Weld County, Colorado As discussed in section 9.6, valves and piping are examined monthly to assess the condition of the transfer equipment. The transfer system equipment is maintained in good condition. If corrosion damage or leakage at valves or pipe connections is found, additional examination and corrective action will be taken commensurate with the magnitude of the damage. 10.6 Warning for Trucks of Pipes f 112.8(d)(5)1 No aboveground piping is exposed outside of the secondary containment or exposed to vehicular traffic. The unloading pump and associated piping are protected by steel parking bumpers. NGL instructs personnel operating in the unloading area to be aware of piping and pumping equipment and to use caution when approaching the area. 11.0 SUBSTANTIAL HARM f 112.20(e)1 40 CFR 112.20 (f)( 1 ) lists criteria under which "a facility could, because of its location, reasonably be expected to cause substantial harm to the environment by discharging oil into or on the navigable waters or adjoining shorelines. . ." if it meets any of the listed criteria. NGL does not meet the listed criteria, including: (1) does not transfer oil over water; and (2) has a total oil storage capacity of less than one million gallons. Because of the design of the tanks, limited spill history at the facility, no proximity to drinking water intakes, and the well-trained personnel at this facility, no Facility Response Plan should be required. The required Certification of Applicability of the Substantial Harm Criteria, Part 112.20, Appendix D, Attachment C-II, has been completed and is maintained at the facility in Appendix I of SPCC plan. FIGURES •.\_ (; -) \ 454 t>..{Yt 'y _•\.,, ;. N (2Ib.1b t 2St - 1 f' - • 1 R - l �a i • 4 IS '0\ .., et 4 • + s�( sue, ; � a r,. t r, e r t *44 s4 I \ L • S s I �•�' -e`er ! B q •"�`« } I �`• \ y.. ) . . VI 1 LL "\._1- d '. s i (y s r z W1inda�tl ) c°.. 1 ka •M `N-: r N. $90 r (N.J../ /: V •_ , V rte{`• , _ \ t '. . �, =nit s: t37L712c a at s avigASR,ssl�le8»�A,a,}et Iii ...c eerar- .� - _ -- • — ..y. -»-- -. -"• r-_,IN..^ 'v. ._- ... _ ,.1 .. ... - B '�� 2-��'-_- •... �_ .7. -4,3',, - •. •,, e a 4 ^ Windmj • t i 1 „ r . 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"' • o �N Q ,0:\ �� i z. t."4-a (, '^�� t 1: ) NC fi r. ` -454O ~ y �N t*e : ...... �= A .0 R • L (i y b lt 4 Pt Vy •p 3T7i t CS_t'bti==LZt} 1a :\ . ,\ 1 'Y age •t• ` V T .kç sa ° `� '� - y �.YYat Tank . _ Ca 4 a X . � R R r �.-.'J 7 ti o Y • 9 • s.c 4527 Cry M • Hardin j ....\ , 4522 i L 4• \ \..) 1 --.--3 ••"4•:-... _ ' -.i. 414-7 ; —•-••••-•-•244---••• — ._.^ ' '•. • _ la `Wail ! 4,"S,1 _ --— Al eb SEYl1'tty Ranch \\ p --Co.- . 521 �` t wP31� � � , NI t� FIGURE 1 • SITE LOCATION MAP NGL WATER SOLUTIONS DJ LLC E1 FACILITY COLORADO NE 1/4, SE 1/4, Sec. 27, 5N, 63W NORTH KERSEY, COLORADO PROJECT: DRAFT: c^ • 0 1000 2000 12462-14804ab ;Aspv INVCO AL _ ON DATE: REVIEW: CONPUANCI , IN QUADRANGLE LOCATION SCALE IN FEET 10/23/2014 ri • - •,r c —\ . p.. -.. C12 FACIL1T1 `. OWNED BY I i ) . 1 h OTHERS ) . . 1 ( \\ NATIVE GRASSES �`� / NATIVE'GRASSES\ \ ,/ \ ? i t -- • 0 w 1 U I! W < / \\ J/ 7• N. 9‘'‘ NATIVE GRASSES / ' .� • lel/ NK... _ / `-._�` X / LEGEND FIGURE 2A SURFICIAL FLOW DIRECTION SITE CONDITIONS MAP NGL WATER SOLUTIONS C12 FACILITY NE 1/4, SE 1/4, Sec. 27,5N,63W NORTH KERSEY, COLORADO PROJECT: DRAFT: CG • 0 100 200 300 12462-148040 DRS IIIIITRONMINTAL CONIIMUCTON DATE: RE 'IEW w O0111PUANCE r SCALE IN FEET 10/30/2014 ACCESS ROAD 1 NATIVE GRASSES PARSING PUMP HOUSE N\ O i iQQQQQ 20 NATIVE GRASSES O U MAP SIZE TANK © Q 6 8 10 12 0 ID (BBLS) ID CONCRETE UNLOADING PAD 1 700 T1 1 © 5 7 O 11 ® (OFFLOAD DEPARTURE) 2 700 T2 3 1000 T3 4 1000 T4 f-- DRAIN 4 5 840 15 NATIVE GRASSES SUMP 6 840 T6 7 840 T7 8 840 T8 CONCRETE UNLOADING PAD 9 840 f9 (OFFLOAD APPROACH) 10 840 T10 11 840 , T11 12 840 T12 13 1000 T13 14 1000 T14 \ \ 15 400 T-OIL-1 16 400 T-OIL-2 17 400 T-OIL-3 18 400 T-HEAT O ce 19 400 T-SLOP 0 20 400 T-SALE o / FIGURE 2B / SITE CONDITIONS MAP -0.- SURFICIAL FLOW DIRECTION 0NGL WATER SOLUTIONS DJ LLC C12 FACILITY _ NE 1/4, SE 1/4. Sec. 27.5N.63W NORTH KERSEY, COLORADO PROJECT: DRAFT: �� o to 20 30 40 50 60 12462-14804ab DRS 'u CONITINCTION DATE: REVIEW: OOMIlANCI SCALE IN FEET 10/30/2014 APPENDIX A SPCC REVIEW LOG SPILL PREVENTION CONTROL AND COUNTERMEASURE PLAN REVIEW LOG FOR TECHNICAL AMENDMENTS: NGL Water Solutions DJ LLC C12 Saltwater Saltwater Disposal Facility In accordance with 40 CFR Part 112.5(b), a review and evaluation of this Spill Prevention Control and Countermeasure (SPCC) Plan will be conducted at least every five years. As a result of such a review and evaluation, the SPCC Plan will be amended within six months of completing said review and evaluation to include more effective and proven prevention and control technologies if: 1) such technologies will significantly reduce the likelihood of a spill event from the facility, and 2) if such technologies have been field-proven at the time of review. Any amendment to this SPCC Plan shall be certified by a Professional Engineer, in accordance with 40 CFR Part 112.3(d), within six months after a change in the facility design, construction, operation, or maintenance occurs which materially affects the facility's potential for the discharge of oil into or upon the navigable waters or the United States or adjoining shorelines (40 CFR Part 112.5(a)). Amendments to the plan shall be completed and implemented within six months of the facility changes. • I have completed review and evaluation of the SPCC Plan for the NGL, C12 Saltwater Saltwater Disposal Facility, Kersey, Colorado and ( will / will not ) amend the plan as a result. Date Name Signature Title Amendment (if applicable) Certifying Engineer Statement (if applicable) This plan amendment was prepared using sound engineering practices. I have examined the facility and find this plan conforms to the guidelines and provisions of 40 CFR Part 112. Date Name Signature • I have completed review and evaluation of the SPCC Plan for the NGL Water Solutions DJ LLC, C12 Saltwater Disposal Facility, Kersey, Colorado and ( will / will not ) amend the plan as a result. Date Name Signature Title Amendment (if applicable) Certifying Engineer Statement (if applicable) This plan amendment was prepared using sound engineering practices. I have examined the facility and find this plan conforms to the guidelines and provisions of 40 Part CFR 112. Date Name Signature SPILL PREVENTION CONTROL AND COUNTERMEASURE PLAN REVIEW LOG FOR NON-TECHNICAL AMENDMENTS: NGL Water Solutions DJ LLC C12 Saltwater Disposal Facility Review and Amendment Log Review/Amend Amend Plan Description of Review Date Signature (will/will not) Amendment Affected Page(s) APPENDIX B ABOVEGROUND STORAGE TANK ULLAGE LOG ABOVEGROUND STORAGE TANK ULLAGE LOG "Use a Separate Log Sheet for Each Tank" Use either this form or its equivalent to document ullage (available capacity) calculations before transferring product to the aboveground storage tank (AST). Use the correct tank chart to convert from inches to gallons. If ullage is calculated by an automatic tank gauge (ATG), it is acceptable to save the ATG inventory tape that shows the ullage in gallons. Facility name NGL Water Solutions DJ LLC, C12 Saltwater Disposal Facility AST # Street NE 1/ SE 1/ , Sec. 27, T5N, R63W Product in tank address City Kersey, Colorado ZIP Tank capacity (gallons) Date Gauge or stick Conversions to Available Capacity Quantity Added Initials reading gallons APPENDIX C DOT REQUIREMENTS Department of Transportation 49 CFR Page 1 DOT LOADING AND UNLOADING OF TRANSPORT VEHICLES 173.30 Loading and unloading of transport vehicles. A person who loads or unloads hazardous materials into or from a transport vehicle or vessel shall comply with the applicable loading and unloading requirements of parts 174, 175, 176, and 177 of this subchapter. [Amdt. 173-94, 41 FR 16064, Apr. 15, 1976] 174.67 Tank car unloading. a) In unloading tank cars, the following rules must be observed (see subpart F of this part for gases): 1 ) Unloading operations must be performed only by reliable persons properly instructed in unloading hazardous materials and made responsible for careful compliance with this part. 2) Brakes must be set and wheels blocked on all cars being unloaded. 3) Caution signs must be placed on the track or cars to give necessary warning to persons approaching the cars from the open end of a siding and must be left up until after the cars are unloaded and disconnected from the discharge connection. The signs must be of metal or other comparable material, at least 30 cm (12 inches) high by 38 cm (15 inches) wide in size, and bear the words, "STOP — Tank Car Connected", or "STOP — Men at Work", the word "STOP" being in letters at least 10 cm (3.9 inches) high and the other words in letters at least 5 cm (2 inches) high. The letters must be white on a blue background. 4) Before a manhole cover or outlet valve cap is removed from a tank car, the car must be relieved of all interior pressure by cooling the tank with water or venting the tank by raising the safety valve or opening the dome vent at short intervals. However, if venting to relieve pressure will cause a dangerous amount of vapor to collect outside the car, venting and unloading must be deferred until the pressure is reduced by allowing the car to stand overnight or otherwise cooling the contents. These precautions are not necessary when the car is equipped with a manhole cover which hinges inward or with an inner manhole cover which does not have to be removed to unload the car, and when pressure is relieved by piping vapor into a condenser or storage tank. b) After the pressure is released, the seal must be broken and the manhole cover removed as follows: 1) Screw type. The cover must be loosened by placing a bar between the manhole cover lug and knob. After two complete turns, so that vent openings are exposed, the operation must be stopped, and if there is any sound of escaping vapor, the cover must be screwed down tightly and the interior pressure relieved as prescribed in paragraph (a)(4) of this section, before again attempting to remove the cover. 2) Hinged and bolted type. All nuts must be unscrewed one complete turn, after which same precautions as prescribed for screw type cover must be observed. 3) Interior type. All dirt and cinders must be carefully removed from around the cover before the yoke is unscrewed. c) When the car is unloaded through a bottom outlet valve, the manhole cover must be adjusted as follows: 1 ) Screw type. The cover must be put in place, but not entirely screwed down, so that air may enter the tank through the vent holes in threaded flange of the cover. 2) Hinged and bolted type. A non-metallic block must be placed under one edge of the cover. 3) Interior type. The screw must be tightened up in the yoke so that the cover is brought up within one-half inch of the closed position. d) When unloading through the bottom outlet of a car equipped with an interior manhole type cover, and in each case where unloading is done through the manhole (unless a special cover with a safety vent opening and a tight connection for the discharge outlet is used), the manhole must be protected by asbestos or metal covers against the entrance of sparks or other sources of ignition of vapor, or by being covered and surrounded with wet burlap or similar cloth material. The burlap or other cloth must be kept damp by the replacement or the application of water as needed. e) Seals or other substances must not be thrown into the tank and the contents may not be spilled over the car or tank. 0 The valve rod handle or control in the dome must be operated several times to see that outlet valve in the bottom of tank is on its seat before valve cap is removed. g) The valve cap, or the reducer when a large outlet is to be used, must be removed with a suitable wrench after the set screws are loosened and a pail must be placed in position to catch any liquid that may be in the outlet chamber. If the valve cap or reducer does not unscrew easily, it may be tapped lightly with a mallet or wooden block in an upward direction. If leakage shows upon starting the removal, the cap or reducer may not be entirely unscrewed. Sufficient threads must be left engaged and sufficient time allowed to permit controlled escape of any accumulation of liquid in the outlet chamber. If the leakage stops or the rate of leakage diminishes materially, the cap or reducer may be entirely removed. If the initial rate of leakage Department of Transportation 49 CFR Page 2 continues, further efforts must be made to seat the outlet valve (see paragraph (f) of this section). If this fails, the cap or reducer must be screwed up tight and the tank must be unloaded through the dome. If upon removal of the outlet cap the outlet chamber is found to be blocked with frozen liquid or any other matter, the cap must be replaced immediately and a careful examination must be made to determine whether the outlet casing has been cracked. If the obstruction is not frozen liquid, the car must be unloaded through the dome. If the obstruction is frozen liquid and no crack has been found in the outlet casting, the car may, if circumstances require it, be unloaded from the bottom by removing the cap and attaching unloading connections immediately. Before opening the valve inside the tank car, steam must be applied to the outside of the outlet casting or wrap casting with burlap or other rags and hot water must be applied to melt the frozen liquid. h) Unloading connections must be securely attached to unloading pipes on the dome or to the bottom discharge outlets before any discharge valves are opened. i) Tank cars may not be allowed to stand with unloading connections attached after unloading is completed. Throughout the entire period of unloading, and while car is connected to unloading device, the car must be attended by the unloader. j) If necessary to discontinue unloading a tank car for any reason, all unloading connections must be disconnected. All valves must first be tightly closed, and the closures of all other openings securely applied. k) As soon as a tank car is completed unloaded, all valves must be made tight, the unloading connections must be removed and all other closures made tight, except that heater coil inlet and outlet pipes must be left open for drainage. The manhole cover must be reapplied by the use of a bar or wrench, the outlet valve reducer and outlet valve cap replaced by the use of a wrench having a handle at least 0.9 m (3.0 feet) long, and the outlet valve cap plug, end plug, and all other closures of openings and of their prospective housings must be closed by the use of a suitable tool. I) Railroad defect cards may not be removed. m) If oil or gasoline has been spilled on the ground around connections, it must be covered with fresh, dry sand or dirt. n) All tools and implements used in connection with unloading must be kept free of oil, dirt, and grit. (49 U.S.C. 1803, 1804, 1808; 49 CFR 1 .53, app. A to part 1 ) [Amdt. 174-26, 41 FR 16092, Apr. 15, 1976 as amended by Amdt. 174-26A, 41 FR 40685, Sept. 20, 1976; Amdt. 174-43, 48 FR 27699, June 16, 1983; Amdt. 174-68, 55 FR 52978, Dec 21 , 1990; 56 FR 66280, Dec. 20, 1991 ] (174C/Rail: Handling and Loading Preface/174.67 Tank car unloading., Heading) thru (174C/Rail: Handling and Loading Preface/174.67 Tank car unloading., 23) 177B Highway: Loading and Unloading Subpart B — Loading and Unloading Note: For prohibited loading and storage of hazardous materials, see 177.848 177.834 General requirements a) Packages secured in a vehicle. Any tank, barrel, drum, cylinder, or other packaging, not permanently attached to a motor vehicle, which contains any Class 3 (flammable liquid), Class 2 (gases). Class 8 (corrosive), Division 6.1 (poisonous), or Class 7 (radioactive) material must be secured against movement within the vehicle on which it is being transported, under conditions normally incident to transportation. b) No hazardous materials on pole trailers. No hazardous materials may be loaded into or on or transported in or on any pole trailer. c) No smoking while loading or unloading. Smoking on or about any motor vehicle while loading or unloading any Class 1 (explosive), Class 3 (flammable liquid), Class 4 (flammable solid), Class 5 (oxidizing), or Division 2.1 (flammable gas) materials is forbidden. d) Keep fire away, loading and unloading. Extreme care shall be taken in the loading or unloading of any Class 1 (explosive), Class 3 (flammable liquid), Class 4 (flammable solid), Class 5 (oxidizing), or Division 2. 1 (flammable gas) materials into or from any motor vehicle to keep fire away and to prevent persons in the vicinity from smoking lighting matches, or carrying any flame or lighted cigar, pipe, or cigarette. Department of Transportation 49 CFR Page 3 e) Handbrake set while loading and unloading. No hazardous material shall be loaded into or on, or unloaded from, any motor vehicle unless the handbrake be securely set and all other reasonable precautions be taken to prevent motion of the motor vehicle during such loading or unloading process. 1) Use of tools, loading and unloading. No tools which are likely to damage the effectiveness of the closure of any package or other container, or likely adversely to affect such package or container, shall be used for the loading or unloading of any Class 1 (explosive) material or other dangerous article. g) Prevent relative motion between containers. Containers of Class 1 (explosive), Class 3 (flammable liquid), Class 4 (flammable solid), Class 5 (oxidizing), Class 8 (corrosive), Glass 2 (gases) and Division 6. 1 (poisonous) materials, must be so braced as to prevent motion thereof relative to the vehicle while in transit. Containers having valves or other fittings must be so loaded that there will be the minimum likelihood of damage thereto during transportation. h) Precautions concerning containers in transit; fueling road units. Reasonable care should be taken to prevent undue rise in temperature of containers and their contents during transit. There must be no tampering with such container or the contents thereof nor any discharge of the contents of any container between point of origin and point of billed destination. Discharge of contents of any container, other than a cargo tank, must not be made prior to removal from the motor vehicle. Nothing contained in this paragraph shall be so construed as to prohibit the fueling of machinery or vehicles used in road construction or maintenance. i) Attendance requirements. 1 ) Loading. A cargo tank must be attended by a qualified person at all times when it is being loaded. The person who is responsible for loading the cargo tank is also responsible for ensuring that it is so attended. 2) Unloading. A motor carrier who transports hazardous materials by a cargo tank must ensure that the cargo tank is attended by a qualified person at all times during unloading. However, the carrier's obligation to ensure attendance during unloading ceases when: (i) The carrier's obligation for transporting the materials is fulfilled; (ii) The cargo tank has been placed upon the consignee's premises; and (iii) The motive power has been removed from the cargo tank and removed from the premises. 3) A person "attends" the loading or unloading of a cargo tank if, throughout the process, he is awake, has an unobstructed view of the cargo tank, and is within 7.62 meters (25 feet) of the cargo tank. 4) A person is "qualified" if he has been made aware of the nature of the hazardous material which is to be loaded or unloaded, he has been instructed on the procedures to be followed in emergencies, he is authorized to move the cargo tank, and he has the means to do so. 5) A delivery hose, when attached to the cargo tank, is considered part of the vehicle. j) Prohibited loading combinations. In any siNGL e driven motor vehicle or in any siNGL e unit of a combination of motor vehicles, hazardous materials shall not be loaded together if prohibited by loading and storage chart, 177.848. This section shall not be so construed as to forbid the carrying of materials essential to safe operation of motor vehicles. (See Motor Carrier Safety Regulations part 393 of this title.) k) [Reserved] 1) Use of cargo heaters when transporting certain hazardous material. Transportation includes loading, carrying, and unloading. 1) When transporting Class 1 (explosive) materials. A motor vehicle equipped with a cargo heater of any type may transport Class 1 (explosive) materials only if the cargo heater is rendered inoperable by: (i) Draining or removing the cargo heater fuel tank; and (ii) disconnecting the heater's power source. 2) When transporting certain flammable material — (i) Use of combustion cargo heaters. A motor vehicle equipped with a combustion cargo heater may be used to transport Class 3 ( flammable liquid) or Division 2. 1 (flammable gas) materials only if each of the following requirements are met: A) It is a catalytic heater. B) The heater's surface temperature cannot exceed 54 °C (130 °F) — either on a thermostatically controlled heater or on a heater without thermostatic control when the outside or ambient temperature is 16 °C (61 °F) or less. C) The heater is not ignited in a loaded vehicle. D) There is no flame, either on the catalyst or anywhere in the heater. E) The manufacturer has certified that the heater meets the requirements under paragraph (1)(2)(i) of this section by permanently marking the heater "MEETS DOT REQUIREMENTS FOR CATALYTIC HEATERS USED WITH FLAMMABLE LIQUID AND GAS." F) The heater is also marked "DO NOT LOAD INTO OR USE IN CARGO COMPARTMENTS CONTAINING FLAMMABLE LIQUID OR GAS IF FLAME IS VISIBLE ON CATALYST OR IN HEATER." G) Heater requirements under 393. 77 of this title are complied with. Department of Transportation 49 CFR Page 4 (ii) Effective date for combustion heater requirements. The requirements under paragraph (l)(2)(i) of this section govern as follows: A) Use of a heater manufactured after November 14, 1975, is governed by every requirement under (1)(2)(i) of this section; B) Use of a heater manufactured before November 14, 1975, is governed only by the requirements under (1)(2)(i) (A), (C), (D), (F) and (G) of this section until October 1, 1976; and C) Use of any heater after September 30, 1976, is governed by every requirement under paragraph (1)(2)(i) of this section. (iii) Restrictions on automatic cargo-space heating temperature control devices. Restrictions on these devices have two dimensions: Restrictions upon use and restrictions which apply when the device must not be used. A) Use restrictions. An automatic cargo-space-heating temperature control device may be used when transporting Class 3 (flammable liquid) or Division 2. 1 (flammable gas) materials only if each of the following requirements is met: 1 ) Electrical apparatus in the cargo compartment is non sparking or explosion proof. 2) There is no combustion apparatus in the cargo compartment. 3) There is no connection for return of air from the cargo compartment to the combustion apparatus. 4) The heating system will not heat any part of the cargo to more than 54 °C (129 °F). 5) Heater requirements under 393. 77 of this title are complied with. B) Protection against use. Class 3 (flammable liquid) or Division 2.1 (flammable gas) materials may be transported by a vehicle, which is equipped with an automatic cargo-space-heating temperature control device that does not meet each requirement of paragraph (I)(2)(iii)(A) of this section, only if the device is first rendered inoperable, as follows: 1 ) Each cargo heater fuel tank, if other than LPG, must be emptied or removed. 2) Each LPG fuel tank for automatic temperature control equipment must have its discharge valve closed and its fuel feed line disconnected. (m) Tanks constructed and maintained in compliance with Spec.106A or 110A (Secs. 179.300, 179.301 of this subchapter) that are authorized for the shipment of hazardous materials by highway in part 173 of this subchapter must be carried in accordance with the following requirements: 1 ) Tanks must be securely chocked or clamped on vehicles to prevent any shifting. 2) Equipment suitable for handling a tank must be provided at any point where a tank is to be loaded upon or removed from a vehicle. 3) No more than two cargo carrying vehicles may be in the same combination of vehicles. 4) Compliance with Secs. 174.200 and 171 .204 of this subchapter for combination rail freight, highway shipments and for trailer-on-flat-car service is required. (n) Specification 56, 57, IM 101 , and IM 102 portable tanks, when loaded, may not be stacked on each other nor placed under other freight during transportation by motor vehicle. [29 FR 18795, Dec. 29, 1964. Redesignated at 32 FR 5606, Apr. 5, 1967] Editorial Note: For Federal Register citations affecting 177.834, see the List of CFR Sections Affected appearing in the Finding Aids section of this volume. 177B Highway: Loading and Unloading Subpart B — Loading and Unloading Note: For prohibited loading and storage of hazardous materials, see 177.848 177.837 Class 3 (flammable liquid) materials (See also 177.834 (a) to (j).) a) Engine stopped. Unless the engine of the motor vehicle is to be used for the operation of a pump, no Class 3 (flammable liquid) material shall be loaded into, or on, or unloaded from any motor vehicle while the engine is running. b) Bonding and grounding containers other than cargo tanks prior to and during transfer of lading. For containers which are not in metallic contact with each other, either metallic bonds or ground conductors shall be provided for the neutralization of possible static charges prior to and during transfers of Class 3 (flammable liquid) materials between such containers. Such bonding shall be made by first connecting an electric conductor to the container to be filled and subsequently connecting the conductor to the container from which the liquid is to come, and not in any other order. To provide against Department of Transportation 49 CFR Page 5 ignition of vapors by discharge of static electricity, the latter connection shall be made at a point well removed from the opening from which the Class 3 (flammable liquid) material is to be discharged. c) Bonding and grounding cargo tanks before and during transfer of lading. 1 ) When a cargo tank is loaded through an open filling hole, one end of a bond wire shall be connected to the stationary system piping or integrally connected steel framing, and the other end to the shell of the cargo tank to provide a continuous electrical connection. (If bonding is to the framing, it is essential that piping and framing be electrically interconnected.) This connection must be made before any filling hole is opened, and must remain in place until after the last filling hole has been closed. Additional bond wires are not needed around All-Metal flexible or swivel joints, but are required for nonmetallic flexible connections in the stationary system piping. When a cargo tank is unloaded by a suction-piping system through an open filling hole of the cargo tank, electrical continuity shall be maintained from cargo tank to receiving tank. 2) When a cargo tank is loaded or unloaded through a vapor-tight (not open hole) top or bottom connection, so that there is no release of vapor at a point where a spark could occur, bonding or grounding is not required. Contact of the closed connection must be made before flow starts and must not be broken until after the flow is completed. 3) Bonding or grounding is not required when a cargo tank is unloaded through a nonvapor-tight connection into a stationary tank provided the metallic filling connection is maintained in contact with the filling hole. d) Manholes and valves closed. A person shall not drive a cargo tanks and motor carrier shall not require or permit a person to drive a tank motor vehicle containing a Class 3 (flammable liquid) material (regardless of quantity) unless: 1) All manhole closures on the cargo tank are closed and secured; and 2) All valves and other closures in liquid discharge systems are closed and free of leaks. [29 FR 18795, Dec. 29, 1964. Redesignated at 32 FR 5606, Apr. 5, 1967] Editorial Note: For Federal Register citations affecting 177.837, see the List of CFR Sections Affected appearing in the Finding Aids section of this volume. APPENDIX D EMERGENCY SPILL RESPONSE CONTACTS AND PROCEDURES EMERGENCY SPILL RESPONSE CONTACTS NGL Water Solutions DJ LLC, C12 Saltwater Disposal Facility; NESE Section 27, T5N, R63W Kersey, Colorado In the event of leakage or spills, the following individuals and/or companies are to be contacted: Primary On-Site Contact Mr, Josh Patterson 970-356-5560 office VP Operations 970-868-1286 cell phone Alternate On-Site Contacts NGL Water Solutions Office 970-356-5560 office cell phone Local Emergency Contacts Are: • Platte Valley Fire Protection District — 911 • • Emergency Response Contractors / Waste Disposal Vendors: • • • If a petroleum release occurs and is greater than 42 gallons, it must be reported to the following regulatory agencies within 24 hours: Colorado Oil and Gas Conservation Commission 1120 Lincoln Street, Suite 801 Denver, Colorado 80203 303-894-2100 If the release reaches navigable water, the following agency must be contacted: National Response Center Washington, DC 800-424-8802 (24-hour phone) SPILL RESPONSE PROCEDURES NGL Water Solutions DJ LLC, C12 Saltwater Disposal Facility; NESE Section 27, T5N, R63W Kersey, Colorado • After identifying and locating a spill, containment must be initiated as soon as possible to prevent undue spreading of released product. The first action should be the elimination of any additional spillage by pressing the emergency shutoff button, shutting off a pump or valve, placing a cap or a plastic or epoxy patch over the leak, putting a temporary plug in a puncture or tear, righting an overturned container, or other appropriate action. • Spill response materials maintained at the facility will be used to contain and clean up spilled product. Place portable dike materials or erect berms with granular absorbent or earthen material along the leading edge of the spill to prevent spreading. Apply absorbent pads or granular absorbent to the spilled product for clean up. • Using the Emergency Contact List for reference: 1 . Alert and notify on-site supervisory personnel. 2. If the spill exceeds the capabilities of on-site facility personnel (ie: spill spreads beyond the immediate spill area, enters surface water, requires special training or equipment, poses a danger of fire or explosion), immediately contact the local fire authority by calling 911 . 3. If the spill enters surface water, contact the National Response Center at (800) 424-8802. • Materials recovered during cleanup must be placed in appropriate containers (such as DOT rated drums) or stockpiled using an impermeable liner and cover (such as polyethylene sheeting) to prevent cross-contamination with unexposed media prior to disposal. APPENDIX E SPILL DOCUMENTATION FORM SPILL RESPONSE NOTIFICATION FORM Fill out this form as completely as possible prior to calling regulatory agencies. Refer to the Emergency Contact List for guidance on regulatory agencies to notify and telephone numbers. RELEASE INFORMATION Notification Person Name: Date: Time: Agency Being Notified: Phone Number: Facility Name: Address: City: State: Zip Code: Telephone Number: Fax Number: Owner/Operator Name: Address: City: State: Zip Code: Primary Contact Name / Position: Work Phone: Cell Phone: Other (24-Hour): Location of Release: Address: Section: Township: Range: County: Latitude: Degrees Minutes Seconds Longitude: Degrees Minutes Seconds Date/Time of Release: Date/Time of Discovery: Type of Oil Released: Quantity Released: Duration of Release: Describe Source and Cause of Release: Actions Taken to Stop, Contain, Remove and Mitigate Impacts of the Release: Impacted Media: Soil: Water: Air: Stormwater Sewer: Sanitary Sewer: (Check All That Dike/Berm: Oil-Water Separator: Other: Apply) Did Oil Reach a Waterway: Yes / Quantity Released to Waterway: Waterway Name: No Number of Injuries: Number of Deaths: Was Evacuation Required: Yes / No Environmental Impacts: Was There Damage: Yes / No Damage Cost: $ Notification Person: Work Phone: Cell Phone Other (24-Hour) Any additional information about the incident that was not recorded elsewhere: Local Agency Notified: State Agency Contacted: Federal Agency Notified: State/Local Agency On-Scene: Other: APPENDIX F INSPECTION AND RECORDING FORMS ABOVEGROUND STORAGE TANK "MONTHLY" VISUAL INSPECTION FORM Facility Name/Address: NGL Water Solutions DJ I,LC, C12 Disposal Facility NESE, Sec. 27, T5N, Inspection Date: R63W Tanks Inspected (ID #'s): (1) Tank Containment Secondary containment system free of If"no," describe and record action taken to correct problem and date done. tank product, water, debris and fire _No _Yes hazards? Secondary containment drain valve(s) No Yes If"no," describe and record action taken to correct problem and date done. operable and closed? N/A Containment entry.'exit clear of If"no," describe and record action taken to correct problem and date done. No Yes obstructions? — — (2) Leak Detection Visible leaks on tanks, tank seams, If"yes," identify tank, describe, record corrective action taken, and date done. connections, fittings or valves? No —Yes If"yes," describe, record corrective action taken and date done. Visible leaks on aboveground pipes, fittings, flanges, pumps or valves? No —Yes Concrete surfaces and ground free of If"no," describe, record corrective action taken and date done. evidence of leakage or spillage? No —Yes (3) Tank Components Ladder or platform structure secure If"no," describe, record corrective action taken and date done. with no sign of severe corrosion or No —Yes damage —N/A Is tank gauge readable and in good If"no," describe, have tank gauge calibrated and record date done. condition and do stick readings and No —Yes tank gauge readings match? Is overfill prevention equipment in If"no," describe, record corrective action taken and date done. good operating condition? No —Yes Is audible/visual overfill alarm No _Yes If"no," describe, record corrective action taken and date done. operable? N/A Check tank openings: Are all openings If"no," describe, seal openings and record date done. properly sealed No —Yes (4) Other Conditions Check tank for the presence of water at If"yes," have water removed and record date done. lowest point: Is water present? No —Yes If double-wall tank, check the If"yes," describe, record corrective action taken and date done. interstitial space for liquid: Is liquid No Yes present? —N/A If double-wall tank equipped with If"no," describe, record corrective action taken and date done. interstitial monitoring equipment, is it —No —Yes operating properly? —N/A Are there other conditions that should If"yes," describe, record corrective action taken and date done. be addressed for continued safe No Yes operation or that may affect the site — — SPCC plan? Additional Comments: Inspector Name Signature Date IABOVEGROUND STORAGE TANK "ANNUAL" VISUAL INSPECTION FORM Page 1 of 2 Facility Name/Address: NGL Water Solutions DJ LLC, C12 Disposal Facility NESE, Sec. 27, TSN' Inspection Date: R63 W • Tanks Inspected (ID #'s): Item Inspected Status Comments (1) Tank Containment Secondary containment structure If"no," describe and record action taken to correct problem and date done. in satisfactory condition? No -Yes Secondary containment drain If"no," describe and record action taken to correct problem and date done. pipes and valves fit for No —Yes N/A continued service? — (2) Tank Foundation and Supports Evidence of tank settlement or No Yes If"yes," describe and record action taken to correct problem and date done. foundation washout? — If"no," describe and record action taken to correct problem and date done. Evidence of cracking or deterioration of the concrete pad No —Yes or tank foundation ring? Tank supports in satisfactory If"no," describe and record action taken to correct problem and date done. condition? No -Yes Water able to drain away from If"no," describe and record action taken to correct problem and date done. the tank? No -Yes Grounding strap secured and in If"no," describe and record action taken to correct problem and date done. good condition? No —Yes (3) Cathodic Protection Cathodic protection system _No _Yes Record rectifier reading if applicable: functional? N/A (4) Tank External Coating Evidence of tank shell paint If"yes," describe and record action taken to correct problem and date done. coating failure? No —Yes (5) Tank Shell/Heads Noticeable tank shell/head If"yes," describe and record action taken to correct problem and date done. distortions, buckling or bulging? —No —Yes Evidence of tank shell/head If"yes," describe and record action taken to correct problem and date done. No Yes corrosion or cracking? — — (6) Tank Manways, Piping and Equipment within Secondary Containment Flanged liquid level manway If"no," describe and record action taken to correct problem and date done. bolts and seals tight, no signs of No —Yes wear, corrosion of leakage? Flanged pipe connection bolts If"no," describe and record action taken to correct problem and date done. and seals tight, no signs of wear, No _Yes corrosion or leakage? ABOVEGROUND STORAGE TANK "ANNUAL" VISUAL INSPECTION FORM Page 2 of 2 Item Inspected Status Comments (7) Tank Roof Standing water present on tank No Yes If"yes," describe and record action taken to correct problem and date done. roof? — — Evidence of tank roof paint If"yes," describe and record action taken to correct problem and date done. coating, cracking, pealing or _No _Yes blistering? Holes or other evidence of No Yes If"yes," describe and record action taken to correct problem and date done. corrosion on roof? — (8) Venting Normal and emergency vents If"no," describe and record action taken to correct problem and date done. free of obstructions? No —Yes Emergency vent operable and If"no," describe and record action taken to correct problem and date done. lifts as required? No —Yes (9) Insulated Tanks If tank insulated, is insulation _No Yes If"yes," describe and record action taken to correct problem and date done. missing or damaged? N/A Noticeable areas of moisture on _No _Yes If"yes," describe and record action taken to correct problem and date done. the insulation? N/A No _Yes If"yes," describe and record action taken to correct problem and date done. Is there mold on the insulation? —N/A Is insulation sufficiently No -Yes If"no," describe and record action taken to correct problem and date done. protected from water intrusion? N/A (10) Level and Overfill Prevention Instrumentation Has tank liquid level sensing If"yes," record date done. device been tested to ensure No —Yes If"no," when will it be tested? proper operation? Does tank liquid level sensing If"no," describe and record action taken to correct problem and date done. device operate as required? No —Yes Are overfill prevention devices If"no," describe and record action taken to correct problem and date done. in proper working condition? No _Yes (11) Electrical Equipment Are tank grounding lines in If"no," describe and record action taken to correct problem and date done. good condition? No —Yes Is electrical wiring for control If"no," describe and record action taken to correct problem and date done. boxes and lights in good No Yes condition? Additional Comments: Inspector Name Signature Date PORTABLE CONTAINER "MONTHLY" VISUAL INSPECTION FORM Facility Name/Address: NGL Water Solutions DJ LLC, C12 Disposal Facility NESE, Sec. 27, T5N, Inspection Dater R63W Portable Container Area Inspected: Item Inspected Status Comments (1) Container Storage Area / Containment Containers are positioned within the No Yes designated storage area? — — Debris, spills or fire hazards present in No Yes the storage containment area? — — Is water present in outdoor storage No —Yes containment area? N/A Are dike drain valves operable and in a _No _Yes closed position? N/A Are storage area egress pathways clear No Yes and gates/doors operable? — — (2) Leak Detection Visible signs of leakage on or around the containers or on the floor of the No Yes storage area? (3) Container Condition Noticeable container distortions, No Yes buckling, denting or bulging? —Are container openings properly sealed No Yes when not in use? — — Comments: Inspector Name Signature Date APPENDIX G SPCC TRAINING SIGNOFF SHEET SPILL PREVENTION CONTROL AND COUNTERMEASURE PLAN SPILL PREPAREDNESS TRAINING COMPANY NAME: NGL Water Solutions DJ LLC, C12 Saltwater Disposal Facility FACILITY ADDRESS: NESE Section 27, T5N, R63W Kersey, Colorado INSTRUCTOR: SUBJECT: SIGNATURES OF ATTENDEES: Signature indicates awareness and understanding of the SPCC Plan and its contents. Signature Printed Name Date APPENDIX H SECONDARY CONTAINMENT VOLUME CALCULATIONS Above Ground Storage Tanks Secondary Containment Volume Calculations NGL Water Solutions DJ LLC, C12 Facility NESE Section 27, T5N, R63W Kersey, Colorado CGRS Project # 1 -12462-14804ab 1 . Volume of Largest Tank (cu. ft.) = Tank Volume x 0. 1337cu. ft./gal. conversion factor 42,000 gals. x 0. 1337 cu. ft./gal. = 5615.4 cubic feet 2. Total Diked Area Containment Area Section 1 Volume 19,500 cubic feet Enter Height 2 feet Enter Width 65 feet Enter Length a 150 feet Total Volume 19,500 cubic feet = 145,880 gallons 3. Base Area of Vertical Tanks (within the containment) Tank Sizes Size A Volume 1 ,810 cubic feet Size A (De-Sanding Tanks, Oil Heat Tank, Slop Oil Enter Diameter 12 feet Tank, Sale Oil Tank) Enter Height 2 feet Quantity 8 each Size B Volume 4, 151 cubic feet Size B (Water Equalization/Storage Tanks, Clean Enter Diameter 15.5 feet Tanks, Oil Skim Tanks) Enter Height 2 feet Quantity 11 each Total Volume 5,961 cubic feet = 44,593 gallons Above Ground Storage Tanks Secondary Containment Volume Calculations NGL Water Solutions DJ LLC, C12 Facility NESE Section 27, T5N, R63W Kersey, Colorado CGRS Project # 1 -12462-14804ab 4. Available Diked Area = (Total Diked Area) — (Base Area of Tanks) = 19,500 - 5,961 = 13,539 cubic feet 101 ,287 gallons 5. Estimated Freeboard Allowance Containment Area Section 1 Volume 3,120 cubic feet Enter Height 0.32 feet Enter Width 65 feet Enter Length 150 feet Total Freeboard 3,120 cubic feet 23,341 gallons 6. Adjusted Available Diked Area = (Available Diked Area) — (Base Area of Tanks + Recommended Freeboard Allowance) = 19,500 - 9,081 = 10,419 cubic feet Available Volume in Diked Area = 77,946 gallons Note: Freeboard allowance is based on a historical 24-hour storm event for a 100 year recurrence interval for the region from the National Oceanic and Atmospheric Administration's (NOAA) Atlas 14, Volume 8, Version 2, Greeley Station (PDS-based point precipitation frequency estimates with 90% confidence intervals (in inches)) Horizontally mounted tanks do not significantly impinge on available containment volumes. Offload Pad Containment & Offload Sump Containment NGL Water Solutions DJ LLC C12 Water Disposal Facility NESE Sec. 27, T5N, R63W Kersey, Colorado CGRS Project # 1 -12438-14804ab Volume of Largest Truck (cu. ft.) = Tank Volume x 0. 1337cu. ft./gal. conversion factor 9,240 gals. x 0. 1337 cu. ft./gal. = 1235 cubic feet 1 . Volume Of Offloading Pad And Sump Offload Approach Offlload Approach Section 1 Volume 5,616 cubic feet Enter Height 1 . 17 feet 42,013 gallons Enter Width 120 feet Enter Length 80 feet Offload Departure Offload Departure Section 2 Volume Enter Height 1 .17 feet 1 ,755 cubic feet Enter Width 120 feet 13129 gallons Enter Length 25 feet Drain/Trench Drain Section 3 Volume 197.54 cubic feet Enter Height 0.83 feet 1478 gallons Enter Width 2 feet Enter Length 119 feet Total Volume of Offload Pad 7,569 cubic feet 56,620 gallons Sump Volume Sump Section 4 Volume 960 cubic feet Enter Length 10 feet 7,182 gallons Enter Width 12 feet Enter Depth 8 feet Total Sump Volume 960 cubic feet = 7,182 gallons Total Volume Available in Containment Pad and Sump = 8,529 cubic feet (sections 1 through 4) 63,802 gallons 2. Estimated Freeboard Allowance Offload Approach Offload Approach Section 1 Freeboard 3,744 cubic feet Enter Height 0.39 feet 28,009 gallons Enter Width 120 feet Enter Length 80 feet Offload Departure Section 2 Freeboard 1 ,170 cubic feet Offload Departure 8,753 gallons Enter Height 0.39 feet Enter Width 120 feet Enter Length 25 feet Drain Drain Section 3 Freeboard 93 cubic feet Enter Height 0.39 694 gallons Enter Width 2 Enter Length 119 Sump Section 4 Freeboard 47 cubic feet Sump 350 gallons Enter Length 10 feet Enter Width 12 feet Enter Depth 0.39 feet Total Freeboard Allowance 5,065 cubic feet = 37,890 gallons 3. Adjusted Available Diked Area = (Offload Pad Areas, sump, drain) — (Recommended Freeboard Allowance) = 8,529 - 5,065 = 3,464 cubic feet Available Volume in Offload Area & Sump = 25,912 gallons Note: Freeboard allowance is based on a historical 24-hour storm event for a 100 year recurrence interval for the region from the National Oceanic and Atmospheric Administration's (NOAA) Atlas 14, Volume 8, Version 2, Greeley Station (PDS-based point precipitation frequency estimates with 90% confidence intervals (in inches)) Horizontally mounted tanks do not significantly impinge on available containment volumes. APPENDIX I SELF-DETERMINATION CRITERIA CERTIFICATION OF THE APPLICABILITY OF THE SUBSTANTIAL HARM CRITERIA CHECKLIST FACILITY NAME: NGL Water Solutions DJ LLC, Cl2 Saltwater Disposal Facility FACILITY ADDRESS: NESE Section 27. T5N. RG3W Kersey. Colorado I . Does the facility transfer oil over water to or from vessels and does the facility have a total oil storage capacity greater than or equal to 42,000 gallons? Yes No X 2. Does the facility have a total oil storage capacity greater than or equal to I million gallons and does the facility lack secondary containment that is sufficiently large to contain the capacity of the largest aboveground oil storage tank plus sufficient freeboard to allow for precipitation within any aboveground oil storage tank area? Yes No X 3. Does the facility have a total oil storage capacity greater than or equal to I million gallons and is the facility located at a distance (as calculated using the appropriate formula in Attachment C-Ill or a comparable formula') such that a discharge from the facility could cause injury to fish and wildlife and sensitive environments? For further description of fish and wildlife and sensitive environments, see Appendices 1, II, and III to DOC/NOAA's "Guidance for Facility and Vessel Response Plans: Fish and Wildlife and Sensitive Environments" (see Appendix E, section 13, for availability) and the applicable Area Contingency Plan. Yes No X 4. Does the facility have a total oil storage capacity greater than or equal to I million gallons and is the facility located at a distance (as calculated using the appropriate formula in Attachment C-Ill or a comparable formula') such that a discharge from the facility would shut down a public drinking water intake'? Yes No X 5. Does the facility have a total oil storage capacity greater than or equal to I million gallons and has the facility experienced a reportable oil discharge in an amount greater than or equal to 10,000 gallons within the last 5 years? Yes No X CERTIFICATION I certify under penalty of law that I have personally examined and am familiar with the information submitted in this document, and that based on my inquiry of those individuals responsible for obtaining this information, I believe that the submitted information is true, accurate, and complete. Mr. Josh Patterson Name (please type or print) Si kirr VP Operations ( 1 - 4 - tit Title Date l Form 40 CFR 112 Appendix C, Attachment C-II WASTE HANDLING PLAN NLG WATER SOLUTIONS DJ , LLC : C12 SITE Scope: This Waste Management Plan has been prepared to provide onsite operations personnel at the with the information necessary to properly identify, manage and dispose of wastes, and to ensure the safety and protection of employees, the public and the environment. The objective of this plan is to ensure waste generated at the site is managed according to all Local, Colorado and Federal regulations. Further, the plan will define operational chemicals used or stored on site requiring specific disposal pathways. Chemicals Stored On Site: The following materials will be stored at the site to support operations and have specific disposal requirements. The quantities given are the maximum amount to be stored on site at a single time . NOTE: The oil collected as part of the skimming process is stored at the site in five 500 BBL steel tanks and is considered production oil that will be trucked out for sales. Therefore, it is not considered waste and is not listed in this plan . Chemicals Description Quantity Diesel Fuel Distillate fuels suitable for use in high and medium speed internal 50 Gal . combustion engines of the compression ignition type Emulsion Breaker Clear to Slightly Hazy Light 30 Gal . Amber to Dark Amber liquid with pungent odor Crude Oil ( petroleum ) Naturally occurring, yellow-to-black liquid found in geologic 90 BBL's formations beneath the Earth's surface, which is commonly refined into various types of fuels Unleaded Gasoline Light straw to red clear liquid with characteristic strong odor of 15 Gal . gasoline Chevron Way Oil Vistac Brown liquid with Petroleum odor 20 Gal . WT-990 Corrosion inhibiting cleaning compound < 1 Gal . Wolf's Head Gear Oil Dark amber lubricant with mild petroleum odor 40 Gal . NOTE: All chemicals listed above will have Material Safety Data Sheets on-site. 1 Projected Waste Streams and Volume: Waste Stream Waste Constituents Volume Disposal contact Filter Socks Produced water and 48 to 96 50 micron sock Waste management silts/sands >50 microns filters per day, removed weekly Sale Oil Crude oil 2-4 Loads per week NGL Crude Oil Transportation Solid Wastes Oily sand 100 BBL Waste Management CSI Tanks cleaned 6-12 disposal times per year Dumpsters Trash 4-6 Cubic yard Waste Management dumpsters, removed weekly NOTE: Waste generation during the life of this site is anticipated to be minimal. Any wastes that may be generated during the construction of this site will be temporarily stored in covered containers and will be removed from the site for proper disposal at a permitted facility. Spill Prevention and Response: Activities related to salt water disposal facilities require storage of hazardous and nonhazardous products and wastes. All efforts will be made to prevent spills of any amount of these products. The scope of this plan is intended to cover activities related to associated facilities. The following items will be followed to help avoid spills and minimize the impact of spills that accidentally occur: Bulk quantities of any chemical will be stored in above ground tanks, which will be diked or be of double wall secondary containment design, or smaller containers. Secondary containment will also be provided for loading/unloading areas. No underground tanks will be used . A Safety Data Sheet (SDS) for each hazardous material will be located on site. Fuel will be stored within secondary containment and as much as practical all equipment will be refueled there . Any equipment that must be refueled in the field will be fueled from tanks carried to the work area . Lesser quantities of chemicals ( i .e., cleaning supplies, lubricants) may be stored at the work area as necessary to service equipment provided that this storage does not conflict with other parts of this plan . All chemical storage areas will be located at least 200 feet from active private water wells, and at least 400 feet from municipal water wells. Equipment servicing, lubricating, and refueling will also be in accordance with these requirements whenever possible . Use of hazardous materials for vehicle maintenance will follow the same requirements mentioned above for equipment refueling. Impervious or sorbent materials will be placed under the work area before the work begins. Additional sorbent materials will also be readily available. Waste materials created during maintenance ( i .e ., used oil ) will be collected for proper disposal . The work site for which these chemicals are used will be inspected after the maintenance work is complete to ensure that all hazardous materials are properly contained . All waste material, including partially used or empty containers, discarded parts, dirty rags, and used sorbent 2 material, as well as discarded hazardous materials containers ( i .e., oil cans, grease tubes) will be collected and placed in open-top drums for proper disposal . All motor fuel, lube oil, chemicals, and other polluting substances will be tightly sealed and clearly labeled during transportation and storage . Runoff resulting from facility equipment washing operations will not be permitted to directly enter any water body or wetland area . Construction equipment, vehicles, materials, hazardous materials, chemicals, fuels, lubricating oils, and petroleum products will be parked, stored, or serviced 100 feet from all water bodies and wetlands when not in use and when possible. Any materials, hazardous materials, chemicals, fuels, lubricating oils, and petroleum products that must be used within 100 feet of a water body or wetland to support the work will only be used within the secondary containment protection and will be stored within temporary secondary containment during work hours. No materials, hazardous materials, chemicals, fuels, lubricating oils, or petroleum products that are not contained within equipment will be stored within 100 feet of a water body or wetland . All other sections of this plan will be followed for spill prevention and mitigation and cleanup methods. All equipment will be inspected daily for leaks prior to beginning operations. Steps will be taken to repair leaks or remove the equipment from service, if necessary. All containers containing any hazardous material ( i .e. chemicals, lubricants, oils) will be neatly labeled . The height of stacked containers will be limited and done so careful manor, for stability to avoid spills. Clean up procedures and materials will be readily available and clearly posted at work areas. Pollution Incident Response: In the event of a spill the following will occur: The source will be immediately stopped . ❑ The spill will be contained by placing sorbent booms or constructing dikes. El The spill will be collected with sorbent materials, skimmed off water surfaces with booms, and/or the contaminated soil will be excavated; and the waste materials will be properly disposed in accordance with NGL's internal policies. P Document the spill and its clean-up procedures whether reporting is required or not. At a minimum document the following: o Nature of spill o Quantity of spill o Date/time spill occurred : Agency notification if necessary o Clean-up procedures used o Daily monitoring (7 days) after clean-up o Photographs o Interview(s) with any witnesses of the event The affected areas will be restored as closely as possible to their previous condition . Spills of oil or petroleum products should be reported immediately to the Site Manager. Environmental support staff will determine the reporting requirements and contact the appropriate State and 3 Federal environmental agencies for notification requirements. If the Site Manager cannot be contacted, then the Site Supervisor should make the necessary notifications. A reportable release is a quantity or an unknown quantity of regulated substance released to or posing an immediate threat to surface water, groundwater, bedrock, soil or sediment. The term does not include the following, provided the owner or operator has control over the release, the release is completely contained, and within 24 hours of the release, the total volume of the release is recovered or removed in the corrective action : o A release to the interstitial space of a double-walled aboveground or underground storage tank. o A release of less than 25 gallons to a containment area, structure or facility around an aboveground storage tank. o A release of less than five gallons to a synthetic surface, such as asphalt or concrete, which prevents migration of the regulated substance to surface water, groundwater, bedrock, soil or sediment; and a release of less than one-gallon to surface soils. Some spills will need to be reported to the Division of Water Quality immediately including the following: o Over 25 gallons of petroleum . o 5 CCs of mercury. A release of any chemical, oil, petroleum product which entered waters of the State of Colorado (which include surface water, groundwater, dry gullies or storm sewers leading to surface water) . C Any spill or release of raw sewage . C If any of the above criteria is met or exceeded, the Colorado Department of Public Health and C Environment (CDPHE), Local Emergency Planning committee, downstream users and other agencies ( N/ S4s) will be notified . The CDPHE will be notified by telephone within 24 hours. In addition, written notification describing the spill and the cleanup procedures used will be sent to the agencies 5 days following the spill . If a spill does not meet the above criteria, reporting is not mandatory. CDPHE 24-hour environmental emergency spill reporting line is 1-877-518-5608 . Company Emergency Contacts : Josh Patterson Vice President of Operations O : 970-356-5560 jpatterson@highsierraenergy.com 8207 W. 20th St Suite B, Greeley, CO 80634 4 Hello